Text

Proposed Tech Specs Reflecting Changes to Electrical Distribution Sys & Mods to Inverter Power Supply Sys & Undervoltage/Overvoltage Protection Sys.W/Five Oversize Diagrams
	ML20212B420
Person / Time
Site:	Rancho Seco
Issue date:	12/19/1986
From:	; SACRAMENTO MUNICIPAL UTILITY DISTRICT
To:	;
Shared Package
ML20212B386	List: ML20212B378; ML20212B420;
References
	TAC-63030, NUDOCS 8612290240
	Download: ML20212B420 (414)
	v • d • e

Enclosure 2 Proposed Technical Specification Amendment No. 147 1

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i-i 0612290240 861219 POR P A000K 05000312 PDR I

a RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS TABLE OF CONTENTS (Continued)

Section Page 4.26 RADIOLOGICAL ENVIRONMENTAL MONITORING 4-83 4.27 LAND USE CENSUS 4-86 4.28 EXPLOSIVE GAS MIXTURE 4-87 4.29 FUEL CYCLE DOSE 4-89 4.30 INTERLABORATORY COMPARISON PROGRAN SURVEILLANCE REQUIREMENT 4-90 4.31 NUCLEAR SERVICE ELECTRICAL BUILDING EMERGENCY HEATING 4-91 VENTILATION AND AIR CONDITIONING 147> 4.32 TDI DIESEL GENERATOR CONTROL ROOM E'SENTIAL 4-92

< VENTILATION SY5lLM 5 DESIGN FEATURES 5-1 5.1 SITE 5-1 5.2 CONTAINMENT 5-2 5.2.1 Reactor Building 5-2 si 5.2.2 Reactor Building Isolation System 5-3 5.3 REACTOR 5-4 5.3.1 Reactor Core 5-4 5.3.2 Reactor Coolant System 5-4 5.4 NEW AND SPENT FUEL STORAGE FACILITIES 5-6 5.4.1 New ' Fuel Inspection and Temporary Storage Rack 5-6 l

l 5.4.2 New and Spent Fuel Storage Racks and Failed 5-6

! Fuel Storage Container Rack l

5.4.3 New and Spent Fuel Temporary Storage 5-6 5.4.4 Spent Fuel Pool and Storage Rack Design 5-6 l

Proposed Amendment No. 147 vii

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS LIST OF TABLES Table Page 2.3-1 REACTOR PROTECTION SYSTEM TRIP SETTING LIMITS 2-9 3.5.1-1 INSTRUMENTS OPERATING CONDITIONS 3-27 3.5.5-1 ACCIDENT MONITORING INSTRUMENTATION OPERABILITY REQUIREMENTS 3-38b 3.6-1 SAFETY FEATURES CONTAINMENT ISOLATION VALVES 3-40 3.7-1 VOLTAGE PROTECTION SYSTEM RELAY TRIP VALUES 3-41a 3.7-2 VOLTAGE PROTECTION SYSTEM LIMITING CONDITIONS 3-41b 3.12-1 SAFETY RELATED HYDRAULIC SNUBBERS 3-51a-e

3.14-1 FIRE DETECTION INSTRUMENT 5 FOR SAFETY SYSTEMS 3-55 3.14-2 INSIDE BUILDING FIRE H0SE STATIONS 3-57a 3.15-1 RADI0 ACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION 3-61 3.16-1 RADI0 ACTIVE GASES EFFLUENT MONITORING INSTRUMENTATION 3-64 3.22-1 RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM 3-83 3.22-2 REPORTING LEVELS FOR RADI0 ACTIVITY CONCENTRATIONS 3-86 IN ENVIRONMENTAL SAMPLES 4.1-1 INSTRUMENT SURVEILLANCE REQUIREMENTS 4-3 4.1-2 MINIMUM EQUIPMENT TEST FREQUENCY 4-8 4.1-3 MINIMUM SAMPLING FREQUENCY 4-9 m

i 4.2-1 CAPSULE ASSEMBLY WITHDRAWAL SCHEDULE AT DAVIS-BESSE 1 4-12b 147>< 4.6-1 DIESEL GENERATOR TEST SCHEDULE 4-35d 4.10-1 ENVIRONMENTAL RADIATION MONITORING PROGRAM 4-42 4.10-2 OPERATIONAL ENVIRONMENTAL RADIATION MONITORING PROGRAM 4-22a 4.14-1 DESIGNATED SAFETY RELATED HYDRAULIC SNUBBERS FUNCTIONALLY 4-47d.e TESTED ONLY AS REQUIRED BY THE SNUBBER SEAL REPLACEMENT PROGRAM 4.17-1 MINIMUM NUMBER OF STEAM GENERATORS TO BE INSPECTED 4-56 DURING INSERVICE INSPECTION 4.17-2A STEAM GENERATOR TUBE INSPECTION 4-57 4.17-2B STEAM GENERATOR TUBE INSPECTION (SPECIAL LIMITED AREA) 4-57a 4.17-3 OTSG AUXILIARY FEEDWATER HEATER SURVEILLANCE 4-57b,c 4.19-1 RADI0 ACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION 4-64 SURVEILLANCE REQUIREMENTS 4.20-1 RADI0 ACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION 4-66 SURVEILLANCE REQUIREMENTS Proposed Amendment No. 147 ix

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation

1. Reactor Coolant Loop (A) and its associated steam generator and at least one associated reactor coolant pump, l

2. Reactor Coolant Loop (B) and its associated steam generator and l at least one associated reactor coolant pump,

3. Decay Heat Removal Loop (A)

4. Decay Heat Removal Loop (B)

With less than the above required coolant loops OPERABLE, f immediately initiate corrective action to return the required ,

coolant loops to OPERABLE status as soon as possible; be in COLD SHUTDOWN within 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months .

3.1.1.6 Reactor Coolant System High Point Vents A. The vent path on Loop A and vent path on Loop B shall be operable and closed during power operation.

B. The vent path on the pressurizer shall be operable and closed during power operation.

j C. With one of the above reactor coolant system vent paths inoperable, STARTUP and/or POWER OPERATION may continue ME provided the inoperable vent path is maintained closed with power removed from the valve actuator of all the valves in the inoperable vent path; restore the inoperable vent path to OPERABLE status within 30 days. If the status is not restored to operable in 30 days, be in HOT STANDBY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

O. With two or more of the above reactor coolant system vent paths inoperable; maintain the inoperable vent paths closed with power removed from the valve actuators of all the valves in the inoperable vent paths, and restore at least (two) of the vent paths to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . If the status is not i

restored to operable in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , be in HOT STANDBY within 12 l hours and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

f 147>

3.1.1.7 The pressurizer shall be operable, except when the reactor is in cold shutdown, with 3 groups of heaters in two separate banks that are capable of being powered by the diesel generator trains. With

l the heaters in one bank inoperable, either restore the bank to operable status within 15 days or be in at least hot standby within 4

' the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in hot shutdown within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

With the heaters in both banks inoperable, either restore one bank to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in at least hot standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in hot shutdown

< within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Proposed Amendment No. 147 3-2

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation Bases A reactor coolant pump or decay heat removal pump is required to be in operation before the boron concentration is reduced by dilution with makeup water. Either pump will provide mixing which will prevent sudden positive reactivity changes caused by dilute coolant reaching the reactor. One decay heat removal pump will circulate the equivalent of the reactor coolant system volume in one half hour or less. (1)

The decay heat removal system suction piping is designed for 300 F and 300 psig; thus, the system can remove decay heat when the reactor coolant system is below this temperature. (2) (3)

One pressurizer code safety valve is capable of preventing overpressurization when the reactor is not critical since its relieving capacity is greater than that required by the sum of the available heat sources which are pump energy, pressurizer heaters, and reactor decay heat. (4) Both pressurizer code safety valves are required to be in service prior to criticality to conform to the system design relief capabilities. The code safety valves prevent overpressure for rod withdrawal accidents. (5) The pressurizer code safety valve lift set point shall be set at 2500 psig

1 percent allowance for error and each valve shall be capable of relieving 345,000 lb/hr of saturated steam at a pressure not greater than 3 percent above the set pressure.

We The electromatic relief valve setpoint was established to prevent operation of the Safety Valves during transients.

Two pump operation is ifmited until further ECCS analysis is performed.

When TAV is below 280*F, a single reactor coolant loop or DHR loop provides sufficient heat removal capability for removing decay heat; but single failure considerations require at least two loops be OPERABLE. Thus, if the reactor coolant loops are not OPERABLE, this specification requires two DHR loops to be OPERABLE.

The purpose of the high point vents is to vent noncondensible gases from the RCS which may inhibit core cooling during natural circulation. In compliance with 10CFR50 Appendix R the power to all the valve actuators in the vent path has been removed.

147> There are 3 groups of heaters in bank 2, and 3 groups of heaters in bank 3 that are capable of being powered by the diesel generator. Each set of the 3 groups of heaters has a nominal rating of 126 kw which provides assurance that these heaters can be energized during a loss of offsite power condition to

< maintain natural circulation at HOT SHUTDOWN.

Proposed Amendment No.147 3-2a

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation REFERENCES (1) FSAR Tables 9.5-2, 4.2-1, 4.2-2, 4.2-4, 4.2-5, 4.2-6 (2) FSAR paragraph 9.5.2.2 and 10.2.2 (3) FSAR paragraph 4.2.5 (4) FSAR paragraph 4.3.8.4 and 4.2.4 (5) FSAR paragraph 4.3.6 and 14.1.2.2.3 6:

Proposed Amendment No. 147 3-2b

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation 3.7 AUXILIARY ELECTRICAL SYSTEMS Applicability Applies to the availability of off-site and on-site electrical power for station operation and for operation of station auxiliaries.

Objective To define those conditions of electrical power availability necessary to provide for safe reactor operation and to provide for continuing availability of engineered safety features in an unrestricted manner.

Specification 3.7.1 The reactor shall not be brought critical unless the following conditions are met:

147> A. At least two 220 KV lines are in service.

B. The switchyard voltage is 219 KV or above.

C. Both startup transformers, No.1 and No.2, are in service.

- D. Nuclear services 4160V buses 4A, 4A2, 4B, and 482 are operable.

E. Nuclear services 480V buses 3A, 3A2, 38, 382, 2A1, 281, 2A3, 2B3, 2A4, and 284 are operable.

4 F. Two separate and independent diesel generator trains (train A is both diesel generators A and A2, train B is both diesel generators B and B2) are operable each with:

1. Separate day tanks containing a minimum volume of 65 percent of tank capacity (265 gallons) of fuel for each A and B and 50 percent of tank capacity (315 gallons) of fuel for A2 and 82.

! 2. A separate fuel storage system containing a minimum useable volume of 35,000 gallons of fuel for each A and B and 42,000 gallons of fuel for each A2 and B2.

3. A separate fuel transfer pump for each engine of a train.

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G. Nuclear Service batteries BA, BB, BC, BD, BA2, BB2, BC2, and BD2, which supply vital 125 volt DC buses SOA, SOB, SOC, S0D, SOA2, SOB 2, SOC 2, and S002 are charged and in service.

H. Each vital 125 volt CC buses SOA, SOC, 508, 500, SOA2, 5082, SOC 2, and 5002 shall have its normal battery charger aligned to it.

I. Nuclear service inverters S1A2, S182, SIC 2, and S102, and static l switches H8TA3, H8TB3, H8TC3, and H8TD3 are operable for 120 volt

< AC vital bus power.

Proposed Amendment No.147 3-41 I

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS (

Limiting Conditions for Operation 1

3.7.2 .The reactor shall not remain critical unless all of the following I requirements are satisfied. ,

147> A. At least two 220 KV lines shall be in service except should all i but one 220 KV line be removed from service the operability of the remaining 220 KV line shall be demonstrated by performing ,

surveillance requirement 4.6.1.A within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter and surveillance requirement 4.6.3.A.4 is perfomed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . If at least two 220 KV lines are not in service within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

B. Both diesel generator trains shall be operable except should one diesel generator train become inoperable the operability of at least two 220 KV lines shall be demonstrated by performing surveillance requirement 4.6.1.A within I hour and at least once 3

per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter and surveillance requirement 4.6.3.A.4 is perfomed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and at least once per 7 des l thereafter. If the diesel generator train is not restored to

! operable status within 15 days, the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

C. At least two 220 KV lines and both diesel generator trains shall be operable except should all but one 220 KV line and one diesel 1.

generator train both become inoperable the operability of the remaining 220 KV line shall be demonstrated by performing surveillance requirement 4.6.1.A within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once

' per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter, and the diesel generator train shall be demonstrated to be operable by performing surveillance

! requirement 4.6.3.A.4 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . If either the 220 KV line or the diesel generator train is not restored to operable status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the fol' lowing 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

With the diesel generator train restored to operable status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , follow 3.7.2.A. With the 220 KV line restored to service within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , follow 3.7.2.B.

D. At least two 220 KV lines shall be in service except should all 220 KV lines become inoperable the operability of the two diesel generator trains shall be demonstrated by perfonning surveillance requirement 4.6.3. A.4 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . This surveillance requirement does not have to be performed t m e the diesel generator train (s) already in service. If at least one 220 KV line is not returned to service in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . With one off-site circuit restored to service within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , follow

< 3.7.2.A.

Proposed Amenchent No.147 3-41a

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RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation 147> 3.7.2 (Continued)

E. Both diesel generator trains shall be operable except should both trains be inoperable the operability of at least two I?O KV lines shall be demonstrated by performing surveillance requirement 4.6.1.A within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter.

If one diesel generator train is not restored to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . With one diesel generator train restored to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , follow 3.7.2.B.

F. Both startup transfonners shall be in service except should one startup transformer become inoperable the operability of at least two 220KV lines shall be demonstrated by perfonning surveillance requirement 4.6.1.A within 1 hcur and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter and the diesel generator trains shall be demonstrated to be operable by perfonning surveillance requirement 4.6.3.A.4 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . If startup transfonner no.1 is not restored to operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 205 hours0.00237 days 0.0569 hours 3.38955e-4 weeks 7.80025e-5 months . If startup transformer no. 2 is not restored to operable status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 205 hours0.00237 days 0.0569 hours 3.38955e-4 weeks 7.80025e-5 months .

G. If both startup transfonners become inoperable, within one hour 9 take action to place the reactor in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 205 hours0.00237 days 0.0569 hours 3.38955e-4 weeks 7.80025e-5 months .

H. Nuclear service buses as listed in 3.7.1.D and 3.7.1.E shall be operable except should one nuclear service bus become inoperable for greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . If more than one nuclear service bus as listed in '

3.7.1.0 and 3.7.1.E should become inoperable, within one hour l

take action to place the reactor in hot shutdown within the next 1

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

I.

Nuclear service batteries as listed in 3.7.1.G shall be charged and in service except should one nuclear service battery become inoperable for greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . If more than one nuclear service battery as j

listed in 3.7.1.G should become inoperable, within or,e hour take action to place the reactor in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

J. Nuclear service battery chargers as listed in 3.7.1.H shall be l

operable except should one nuclear service battery have no battery charger for greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor Proposed Amendment No. 147 3-41b I _ - - _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation 147> 3.7.2 J. (Continued) shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . If a standby charger is aligned in place of its normal charger for greater than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . If more than one nuclear service battery has no required battery charger as listed

in 3.7.1.H, within one hour take action to place the reactor in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

K. Nuclear service inverters and static switches as listed in 3.7.1.I shall be operable except should one inverter or static switch become inoperable for greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . A static switch shall not be aligned to the backup source in place of a operable nuclear service inverter except for switching period. If more than one nuclear service inverter or static switch as listed in 3.7.1.1 should become inoperable, within one hour take action to place the reactor in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

L. Should the switchyard voltage drop belcw 219KV, positive actions,

. within the District's procedures, will be implemented in an attempt to return the voltage to at least 219 KY. If the j;

switchyard voltage goes below 219 KY, both diesel generator

trains shall be demonstrated operable within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months by 1 performing surveillance requirement 4.6.3.A.4. Should the switchyard voltage not be restored above 219 KV within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the reactor shall be in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

3.7.3 The voltage protection system trip setting shall be as stated in Table 3.7-1.

< 3.7.4 Voltage Protection System Limiting Conditions A. Startup and operation are not permitted unless the minimum requirements and action statements of Table 3.7-2 are met. ,

I B. In the event the number of protective channels falls below that listed in Table 3.7-2, the plant will be brought to a hot shutdown within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Proposed Amendment No. 147 3-42

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1 RANCHO SECO UNIT 1 TECHNICAL SPECIFICAfIONS

+

Limiting Conditions for Operation Bases The auxiliary electrical power systems are arranged so that no single failure can inactivate enough safety features equipment to jeopardize plant safety.

The normal source of power to the redundant nuclear service loads is by the two startup transformers to connect the 220-KV station switchyard. All of the l 147> nomal power supply to plant auxiliary loads can be provided through the two unit auxiliary transformers connected to the generator buses. Emergency power for the nuclear service loads is obtained from two on-site diesel generator trains (train A is both diesel generators A and A2, train B is both diesel

< generators B and B2). Since~ the startup transformers are sized to carry full-plant auxiliary loads, if plant auxiliaries' power is not available from the unit auxiliary transformer, it will be obtained from the startup transformers.

The five 220-KV transmission lines are not under the direct control of the

. Rancho Seco station. Therefore, all five cannot be assumed to available at all times. However, extensive reliability and protective features are utilized so that the probability of losing more than one source of 220-KV power from faults is low. By requiring that two 220-KV lines are in service prior to startup, one circuit will be immediately available following a loss of the onsite alternating current diesel power supplies and the other offsite 220-KV line.

If there is a loss of all 220-KV remote connections, power to the safety i features will be supplied by the diesel generator trains. The 35,000 gallons i 147> of fuel stored in each storage tank permit operation of the diesel generators A

and 8 for seven days. The 42,000 gallons of fuel stored in each storage tank I

< permit operation of the diesel generators A2 and 82 for seven days. It is ca considered unlikely not to be able to secure fuel oil from an outside source l during this time under the worst of weather conditions.

j 147> The set of eight 125 volt DC control buses (SOA, SOB, SOC, S00, SOA2,

< SOB 2, SOC 2, and S002', are arranged so that less of one bus will not preclude

, safe shutdown or operation of safety features systems. During periods when one i plant battery is de-energized for test or maintenance, the associated 125 volt

DC bus can be supplied from its battery charger.

l l

I Proposed Amendment No. 147

. 3-42a ,

i.

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wee en w wyw _wwmew9--g-+=my--.

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS TABLE 3.7-1 VOLTAGE PROTECTION SYSTEM RELAY TRIP VALUES EQUIVALENT TIME DELAY UNDERVOLTAGE RELAYS 4160 BUS VOLTS (SECONDS) NOTES 1 (VOLTS) 147> A. Definite Time Delay Trip Set Point 3771

38 5.0

0.5 (Drop Out)

B. Inverse 3771

38 N/A Time Delay Trip Set Point (Drop Out) 70 Percent of Set Point 2640

27 3.0

0.5 NOTE 1 - For bus tripping, an additional 0.5 second time delay must be added.

We <

Proposed Amendment No. 147 3-42b

147>

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS TABLE 3.7-2 (Note 1)

Total No. of Minimum Functional Number of Relays / Channels Channels Action Unit Channels Channel To Trip Operable 2 2/8us 2 A Undervol tage 3/ Bus ACTION STATEMENTS Action A - With the number of OPERABLE channels one less than the total Number of Channels, operation may proceed until performance of the next required CHANNEL FUNCTIONAL TEST provided the Inoperable Channel is placed in the tripped condition within one hour.

Note 1: The table is not applicable when the plant is in cold

< shutdown.

km Proposed Amendment No.147 3-42c

l l

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation Each redundant and "D") of the "C", "B" 147> centrol buses (pair ("A" and eight 125 volt DCSOA and SOC, 508 and S00

- a standby battery charger in addition to its normal battery charger. On the loss of power from one battery charger per pair the standby battery charger is put in service. However, the standby charge can be aligned in place of its normal charger for only 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months because the standby battery charge is powered from a different diesel generator than the normal battery charger. There are potential interactions after 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months that could occur upon the loss-of-off-site power and a single diesel generator failure. This situation has not been analyzed but by limiting the time this configuration could exist, the probability of occurence is sufficiently low to justify limited operation

< in this condition.

During periods of station operation under the condition of electrical system degradation, as described above in Specification 3.7.2, the operating action required is to start and run sufficient standby power supplies so as not to compromise the safety of the plant. As seen in Specification 3.7.2, a time limit is placed on operation during certain degraded conditions based on the

! reliability of the available power supply.

j 147> Four nuclear service inverters (S1A2, S182, S1C2, and S102) and static switches (H8TA3, H8TB3, H8TC3, and H8TD3) are required to be operable to power the 120 volt AC vital buses. The nuclear service inverters are powered from diesel generators A2 and B2 and the static switches are powered from diesel generators A and B. This design ensures that upon loss of an inverter or a 4

single diesel generator the 120 volt AC vital buses will continue to receive power and that there are no system interactions. One nuclear service inverter or static switch is permitted to be inoperable for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The static switch is only used as a backup for the inverter. It is not permitted to be used when an inverter is operable except for switching period because it receives power from the nuclear service 480V buses and there is no battery backup available.

The voltage protection system is designed to isolate the nuclear service buses from the startup transformers before the voltage drops below the allowable operating limit of the equipment. The undervoltage protection for the 4160 volt nuclear service buses is 3771

38 volts. This corresponds to a nominal

< switchyard voltage range of 219 KV.

REFERENCE FSAR, Section 8 Proposed Amendment No.147 3-43

Y

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation Table 3.14-1 (Continued)

FIRE DETECTION INSTRUMENTS FOR SAFETY SYSTEMS Minimum operable Zone Instrument Location Heat Flame Smoke' 75-1 B Switchgear Room (NSEB) 0 0 1 75-2 BB2 Battery Room (NSEB) 0 0 1 75-3 B02 Battery Room (NSEB) 0 0 1 76-1 A Switchgear Room (NSEB) 0 0 1 76-2 BA2 Battery Room (NSEB) 0 0 1 76-3 BC2 Battery Room (NSEB) 0 0 1 77-1 North B Electrical Equipment Room (NSEB) 0 0 1 77-2 South B Electrical Equipment Room (NSEB) 0 0 1 78-1 North A Electrical Equipment Room (NSEB) 0 0 1 78-2 South A Electrical Equipment Room (NSEB) 0 0 1 81 B Cable Tunnel / Shaft (NSF.8) 0 0 3 A Cable Tunnel / Shaft (NSEB) 0 0 3 82 84-2 B Mechanical Equipment Room (NSEB) 0 0 1 84-3 A Mechanical Equipment Room (NSEB) 0 0 1 147> 105 Diesel Generator Building 0 3 6 y < 106 Diesel Generator Building 0 3 6 Proposed Amendment No.147 3-55a

_ - - _ . .__.n_______,___ _ _ _ , _ _ _

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Liaiting Ccnditirns fcr Op;ritica 3.14.3 Spray and Sprinkler Systems Specification 3.14.3.1 The spray and/or sprinkler systems located in the following areas shall be OPERABLE:

a. Control Room (Zone 3)

b. Controlled Area, Mezzanine Level (Zone 20)

c. Main Lute Oil Area, Grade Level (Zone 32)

d. Grade Level (Zone 34)

e. North Diesel Room (Zone 40)

f. South Diesel Room (Zone 41) 9 West Controlled Area, Grade Level (Zone 42)

h. East Controlled Area, Grade Level (Zone 43)

1. South and East -20' Level (Zone 46) .

j. NSEB B Cable Tunnel / Shaft (Zone 81)

k. NSEB A Cable Tunnel /Shaf t (Zone 82)

1. NSEB Mechanical Equipment Rooms A and B (Zone 84) 147> m. Diesel Generator Building (Zone 105)

< n. Diesel Generator Building (Zone 106) vg 3.14.3.2 With one or more of the above, items a through f, required spray and/or sprinkler systems are inoperable, within one hour establish a continuous fire watch with backup fire suppression equipment for those areas in which redundant systems or components required to safely shut down and cool down the plant could be damaged; for other areas, establish an hourly fire watch patrol. Restore the system to OPERABLE status within 14 days or, in lieu of any other report required by Specification 6.9, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.5.E within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.

I 3.14.4 CO2 System i

Speci fication 3.14.4.1 The CO2 systems located in the following areas shall be OPERABLE with a minimum capacity of 66 and a minimum pressure of 275 psig in the storage tank.

t

a. Zone 12 West DC Control Room Mezzanine Level

b. Zone 13 West 480 VAC Room Mezzanine Level

c. Zone 14 West Cable Tray Area

d. Zone 15 East Cable Tray Area

e. Zone 16 East 480 VAC Room Mezzanine Level

f. Zone 17 East DC Control Room Mezzanine Level

g. Zone 36 West Battery Room Grade Level Proposed Amendment No.147 3-56

147>

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation Table 3.14-2 (Continued)

INSIDE BUILDING FIRE HOSE STAT 10'4S ID No. Location III Diesel Generator Building Hose Stations FPHS-D-001 Train A Engine Room Elevation O' FPHS-D-002 Train A Control Room Elevation O' FPHS-D-003 Train A Mezzanine Elevation 18'6" FPHS-D-004 Train B Engine Room Elevation O' FPHS-D-005 Train B Control Room Elevation O' FPHS-D-006 Train B Mezzanine Elevation 18'6"

'!fs)

< Proposed Amendment No. 147 3-57b

TEC CAL SP Cl L miting Conditions for Operadon 3.27 Nuclear Service Electrical Building Emergency Heating Ventilation and Air Conditioning System Applicability This specification applies to the operability of the Nuclear Service Electrical Building Emergency Heating Ventilation and Air Conditioning System.

Objective To assure that this system will be able to perform its designed function.

Specification 3.27.1 Both Nuclear Service Electrical Building Emergency Heating Ventilation and Air Conditioning trains shall be operable at all times except as noted in 3.27.2.

3.27.2 With one Nuclear Service Electrical Building Emergency Heating Ventilation and Air Conditioning train inoperable, restore the train to operable status within 7 days or be in at least hot standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . With both Nuclear Service Electrical Building Emergency Heating Ventilation and g

Air Conditioning trains inoperable, restore the trains to operable status within 3.5 days or be in at least hot standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Bases The Nuclear Service Electrical Building (NSEB) Emergency Heating Ventilation and Air Conditioning System is required to provide cooling to protect required

< electrical components in the NSEB.

Proposed Amendment No.147 3-93 e

147>

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Limiting Conditions for Operation 3.28 TDI Diesel Generator Control Room Essential Ventilation System Applicability This specification applies to the operability of the TDI Diesel Generator Control Room Essential Ventilation System.

Objective To assure that this system will be able to perform its design function.

Specification 3.28.1 Both TDI Diesel Generator Control Room Essential Ventilation trains shall be operable at all times except as noted in 3.28.2 and 3.28.3.

3.28.2 With one TDI Diesel Generator Control Room Essential Ventilation train ,

inoperable, demonstrate the operability of the remaining train.

Restore the inoperable train to operable status within 15 days or be in at least hot shutdown within six hours and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

3.28.3 With both TDI Diesel Generator Control Room Essential Ventilation trains inoperable, restore at least one inoperable train to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in at least hot shutdown within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months a and in cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . With one inoperable train restored to operable status, follow 3.28.2.

Bases The TDI Diesel Generator Control Room Essential Ventilation System is required to provide cooling whenever the temperature in the control room reaches 122*F

< to protect required electrical components.

Proposed Amendment No. 147 3-93a

RANCNO SECO UNIT 1 TECINICAL SPECIFICATIONS Serveillance Standards TABLE 4.1-1 (Continued)

IIISTalpENT SURVEILLANCE REQUIADENTS Channel Descriptfen Check Test Calfbrate Reserks

57. Voltage Protectfon 5(1)

a. Undervoltage (1) Compare voltmeter readtags M R me 6. Time Delay M R

58. Contaf ament Area Nigh 5 M(2) R (2) Test using installed source 'I Range Montter

59. Nf de Range Contaf anent M N/A R Nater Level

60. ContainmentIqrdrogen 5 M Q Analyrer

61. Emergency Sump Level M N/A R

62. Contef ament Nf de range M -

N/A R Pressure Moniter/ Recorder

63. High Range Noble Gas 5 M R Effluent Montters

- RS Enhaust Stack

- Auu. Befiding Stack

- Redenste Vent 64 Mein Steam Line Radiation 5 M R (2) Test using installed source Montters

65. Sebcooling Mergin Moniters M N/A R

66. Incore The:< w ouples M N/A R s

5 . Each shift M = Monthly P = Prior to each startup f f not done previous seek D Daily 0 . Quarterly R _once during the refueling interval W . Neekly $Y . Seefannual Propored Amendment Ile.147 4-7c

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards

~

2. The test will be considered satisfactory if control board indication verifies that all components have responded to the actuation signal and the appropriate breakers shall have cumpleted their travel.

3. Additionally it shall be verified that the NSCW flow through each operating cooler exceeds 1400 gpa and air flow through the cooler exceeds 40,000 cfm.

4.5.2.2 Component Tests A. Testing At least quarterly, Inservice testing of Reactor Building Spray pumps and valves shall be performed in accordance with Section XI of the ASE Boiler and Pressure Vessel Code and applicable. Addenda as required by 10 CFR 50, Section 50.55a(g), except where specific written relief has been granted by the NRC pursuant to 10 CFR 50, Section 50.55a(g)(6)(1).

B. Flow Path Verification Following Inservice testing of pumps and valves as required by paragraph 4.5.2.2.A. required flow paths shall be 4'

demonstrated operable by verifying that each valve (manual, power-actuated or automatic) in the flow path that is not locked in position is in its normal operating position.

Positions of locked valves shall be verified in accordance with the provision of Section XI of the ASME Boiler and Pressure Vessel Code.

147> C. The pressurizer shall be tested as follows:

1. The pressurizer water level shall be determined to be within its limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

2. The power supply for the nuclear service backed

- pressurizer heaters shall be demonstrated OPERABLE at least once per 18 months by using the Nuclear Service

< Bus to energize the heaters.

Proposed Amendment No.147 4-30

U l

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards Bases The Reactor Building emergency cooling systems and Reactor Building spray system are designed to remove the heat in the containment atmosph9r to prevent the building pressure from exceeding the design pressure.tly.

The delivery capability of one Reactor Building spray pump at a time can be tested by opening the valves in the line from the borated water storage tank, opening the corresponding valve in the test line, and starting the corresponding pump. Pump discharge pressure and flow indication demonstrate perfonnance.

With the pumps shutdown and the borated water storage tank outlet valves closed, the Reactor Buf1 ding spray injection valves can each be opened and closed by operator action. With the Reactor Building spray inlet valves closed, air can be blown through the test connections of the Reactor Building spray nozzles to demonstrate that the flow paths are open.

The equipment, piping, valves, and instrumentation of the Reactor Building emergency cooling system are arranged so that they can be visually inspected.

The cooling units and associated piping are located outside the secondary concrete shield. Personnel can enter the Reactor Building during power operations to inspect and maintain this equipment. The nuclear service cooling water piping and valves outside the Reactor Building are inspectable 4 at all times. .

147> The operability of the nuclear service bus backed pressurizer heaters is

< demonstrated by energizing the heaters once per 18 months.

REFERENCES ,

(1) FSAR, section 9.

l f

Proposed A.nendment No.147 4-31

- - , - - - - - , - - - . - . , . - - . - - - , - , - . - - ------,,r,--,,.-,,n.n,.,,n----...-,,-,,,,.,.--?,*,,--, , . - - - . , - - . - - - , - ~ . _ _ - , _

i l

RANCHO SECO UNIT 1-TECHNICAL SPECIFICATIONS Surveillance Standards 4.6 EMERGENCY POWER SYSTEM PERIODIC TESTING ;

Applicability Applies to the periodic testing and surveillance of the emergency power system.

4 Objective To verify that the emergency power sources and equipment are operable '

and respond properly when required.

Specification

147> 4.6.1 Offsite Power Sources A. Each of the 220 KV lines required by 3.7.1.A shall be

1 Determined OPERABLE at least once per 7 days by verifying correct breaker alignments and indicated power availability, and B. Each Start-up Transformer required in 3.7.1.C shall be demonstrated OPERABLE at least once per refueling shutdown by transferring nuclear service buses as listed in 3.7.1.0 from the normal startup transformer supply circuit to the alternate startup transformer supply circuit.

Mi 4.6.2 Nuclear service buses required by 3.7.1.D and 3.7.1.E shall be determined to be OPERABLE at least once per 7 days by verifying correct breaker alignment and indicated power availability. -

4.6.3 Each diesel generator train shall be demonstrated OPERABLE by verifying that both diesel generators in the train are OPERABLE (A and A2, B and B2). Each diesel generator shall be demonstrated i OPERABLE:

A. In accordance with the frequency specified in Table 4.6-1 by:

1. Verifying the fuel level in the day tank,

2. Verifying the fuel level in the fuel storage tank, 3.* Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day tank,

Surveillance shall not be perfonned when a diesel generator 4 train is not operable in accordance with TS 3.7.2. .

Proposed Amendment No. 147 4-34

. - - _ - - . . - _ _ ~ _ - _ . - - __ - . - --:..- - - . - _ . . - . . . - _ . . - . -

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards 147> 4.* Verifying the diesel starts from a manual signal and accelerates to a nominal 900 rpm for A and B and a nominal 450 rpm for A2 and 82. The generator voltage and frequency shall be 4160 (+420) volts and 60 (+1.2)

Hz af ter the start signal. (liote 1) 6.* Verifying the generator is synchronized and operates with its load of 2650 (+100)kw for A and B and 2475

(+100)kw for A2 and B2 Tor at least 60 minutes,(Note 1).

6.* Verifying the diesel generator is aligned to provide emergency power to the nuclear service buses at the conclusion of the test.

B. By sampling at least once per 92 days the oil in each fuel oil storage tank and by sampling new fuel oil prior to addition to the storage tanks and verifying:

1. A water and sediment content of less than or equal to

.05 volume percent when tested in accordance with ASTM-D975-77,

2. A kinematic viscosity at 40*C of greater than or equal to 1.9 but less than or equal to 4.1 when tested in accordance with ASTM-D975-77.

C. At each refueling shutdown, by:

M

1. Diesel Generator Inspections a) Subjecting the diesel generators A and 8 to an inspection in accordance with procedures prepared

, in conjunction with the maintenance recommendations provided by its manufacturer for this class of standby service.

I Note 1 All planned engine starts may be preceded by an engine prelube

period. Further, all surveillance tests, with the exception of

once per 184 days and 10-year duration test, may be preceded by warmup procedures reconsnended by the manufacturer and may also include slow starting and gradual loading so that mechanical stress and wear on the diesel engine is minimized. The testing performed once every 184 days shall include fast starting l

< (less than or equal to 10 seconds). Testing performed every refueling shutdown shall include fast loading.

t

Surveillance shall not be performed when a diesel generator

! train is not operable in accordance with TS3.7.2.

Proposed Amendment No.147 4-35 l

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards 147> b) Subjecting the diesel generators A2 and 82 to an inspection in accordance with procedures prepare in conjunction with the maintenance and surveillance program recommended by the TDI Owners Group in

" Design and Revalidation Report for Rancho Seco,"

Appendix II.

2. Simulating a loss of off-site power in conjunction with a safety features actuation signal (Note 2), and a) Verifying de-energization of the nuclear service buses and operation of the load shedding circuitry.

l b) Verifying the diesel starts on the auto-start signal (Note 1), energizes the nuclear service buses, verifying proper operation of the automatic load sequencing circuitry, and operates for greater than or equal to 5 minutes in this condition.

After energization, the steady state voltage and frequency of the emergency buses shall be maintained at 4160 (+420) volts and 60 (+ 1.2) Hz

~ -

i during this test.

s

< 3. Simulating a loss of off-site power and verifying that on interruption of the emergency power sources the loads are shed from the nuclear services buses in accordance with design requirements and that subsequent loading of the emergency power sources is through the automatic load sequencing circuitry. The diesel generator will be M operated for at least 5 minutes in this condition.

i 147> 4. Verifying the diesel generator operates for at least 24

) hours. During the first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test, the i diesel generator shall be loaded to 2750 (+100)kw for A i and B and 2475 (+100)kw for A2 and B2 and Tor the I remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of this test, the diesel generator

, shall be loaded to 2650 (+100)kw for A and B and 2475

~

! (+100)kw for A2 and B2.

i j Note 1 All planned engine starts for the purpose of this surveillance

! testing may be preceded by an engine prelube period. Further, all l

surveillance tests, with the exception of once per 184 days and

10-year duration test, may be preceded by warmup procedures

! recommended by the manufacturer and may also include slow starting

and gradual loading so that mechanical stress and wear on the

! diesel engine is minimized. The testing performed once every 184

. days shall include fast starting (less than or equal to 10

< seconds). Testing performed every refueling shutdown shall

! include fast loading.

! Note 2 Prior to the performance of this test the diesel generators shall i be operated at 2650 * (100) kw for A and B and 2475 * (100) kw for i

A2 and 82 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or until operating temperature has stabilized.

4 Proposed Amendment No. 147 4-35a l

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards 147> 0. At least once per 10 years, by starting all four diesel generators simultaneously and verifying that they accelerate to a nominal 900 rpm for A and 8 and a nominal 450 rpm for A2 and 82 within 10 seconds after the start signal. The generator voltage and frequency shall be 4160 (+420) volts and 60 (+1.2) Hz within 10.0 seconds af ter the start signal.

E. In lieu of r.erforming 4.6.3.C.2 at least once per 10 years simulating a loss of off-site power in conjunction with a simulated SFAS, and

1. Verifying de-energization of the nuclear service buses and load shedding from the nuclear service buses.

2. Verifying the diesel starts on the aut)-start signal, energizes the nuclear service buses with permanently connected loads, loads through the loau sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the emergency loads. After energization, the steady state voltage and frequency of the emergency buses shall be maintained at 4160 (+420) -

volts and 60 Q 1.2) Hz during this test.

3. Verifying for the A and B diesel generators that all automatic diesel generator trips, except engine overspeed, ground fault and generator differential, and 4 verifying for the diesel generators A2 and 82 that all automitic diesel generator trips, except engine overspeed, low lube oil pressure and generator differential, are automatically bypassed with an SFAS.

i

< 4.6.4 Batteries in the 125 volt DC systems shall be tested as follows:

A. The voltage and specific gravity of each pilot cell shall be measured and recorded weekly.

B. The spect fic gravity, level and voltage of each cell shall be measured and recorded every month.

C. Each time data are racorded, new data shall be compared with old to detect signs of deterioration. '

O. During each refueling interval, the battery shall be sutdected to a rated load or equivalent test. The battery voltage as a function of time shall be monitored to establish that the bittery perfoms as expected.

Proposed Amendment No.147 4 3Sh

1

. k j'

s RANCHO SECO UNIT 1 e

TECHNICAL SPECIFICATIONS ,

Surveillance Standards Bases -

s 14h The operability, of the 220V lines, the nuclear service 4160V buses, and the nuclear service 480V buses are demonstrated by verifying correct breaker alignments and indicated power availability. Surveillance 4.6.1.0s can only be

' performed during a refueling shutdown when both diesel generator trains are operable or the core is flooded to 37 feet to ensure the required decay heat

< removal capability is available.

The test's specified are designed to demonstrate that the diesel generators will provide power for operation of safety features equipment. They also assure th'at the emergency generator control system and the control systems for the safety features equipment will function automatically in the event of a~

loss of all nonnal a-c station service power, and upon receipt of a safety features actuation signal. The testing frequency specified is intended to identify before it can result in a system failure. The fuel oil supply, starting circuits and controls are continuously monitored and any faults are alarmed and indicated. An abnormal condition in these systems would be .

signaled without having to place the diesel generators on test. ,

147> The limiting of the maximum load on the TDI diesel generators A2 and B2 to less than the qualifiedsload of 3300 kw provides assurance that the crankshafts will stay within the proven limits for high-cycle fatigue cracks.

Diesel generators A2 and B2 will be loaded during surveillance testing to 2475 KW which provides assurance that the qualified load of 3300 KW will not be exceeded. The 2475 KW loading is 75 percent the qualified load and 25 percent over the maximum load of safety equipment during the loss-of-offsite power.

At least once per 10 years a diesel generator test will be performed simulating a loss of off-site powed in conjunction with a simulated SFAS and loading of actual loads to the maximum extent possible without damaging plant systems (i.e., use' of recirculation flow or manual valving out a system to

< protect plant.coraponents).

l Precipitous failure of the plant battery is extremely unlikely. The surveillance specified is that which has been demonstrated over the years to provide an indication of a cell becoming unserviceable long before it fails.

l t

REFERENCE l

4 (1) IEEE 308 l

l l

I Proposed Amendment No. 147 4-3Sc

RANCHO SECO UNIT 1

- TECHNICAL SPECIFICATIONS Surveillance Standards 147> ELECTRIC POWER SYSTEMS Table 4.6-1 DIESEL GENERATOR TEST SCHEDULE Number of Failure in Last-20 Valid Tests

Test Frequency 1 At least once per 31 days 2 At least once per 7 days **

sq

Criteria for determining number of failures and number of valid tests shall be in accordance with Regulatory Position C.2.e of Regulatory Guide 1.108, Revision 1, August 1977, where the number of tests and failures is determined on a per diesel generator basis. For the purposes of this test schedule, only valid tests conducted after the license amendment issuance date shall be included in the computation of the "last 20 valid tests."

- This test frequency shall be maintained until seven consecutive failure free demands have been performed and the number of failures in the last 20 valid

< demands has been reduced to one or less.

Proposed Amendment No. 147 4-35d

._.?.__-__. . - _ _ _ . __ _- - . _ _ -

. RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards Specification (Continued)

,' 4.10.1 C. 2. (b) Verify that the HEPA filter bank removes >99.9 percent of the DOP when tested in-place in accordance with ANSI N510 while operating the filter train at a flow rate of 3200 cfm

10 percent.

D. Started on a manual signal and operated for 15 minutes in each 31-day period.

Bases The purpose of the Control Room /TSC Emergency Filtering System is to limit the :

particulate and gaseous fission products and toxic products to which the Control Room area and Technical Support Center would be subjected during an accidental radioactive or chemical release in or near the Auxiliary Building.

The system is designed with two redundant filter trains each of which consists

. of a moisture separator, a heater, a high efficiency particulate filter, two banks of charcoal filters, a second high efficiency particulate filter and a booster fan to pressurize the Control Room and Technical Support Center with outside air.

Since this system is not normally operated, a periodic test is required to ensure its operability when needed. Monthly testing of this system will show q' that the system is available for its designed safety action. During this test the system will be observed for unusual or excessive noise or vibration when the fan motors are running. The flow of 1600 cfm makeup air was selected to limit the maximum radiation dose to occupan,ts of the Control Room /TSC in an accfdent. For this analysis, both charcoal) filter banks were assumed to provit.e DF's of 10, while the HEPA filter DF is assumed to be 100. The laboratory analysis to show >95 percent removal of methyl radiciodide is j necessary to receive credit Tor a DF of 10.

l Refueling interval testing will verify the methyl iodide removal efficiency of the charcoal and the amount of leakage past tne charcoal and HEPA filters are at least equal .to the design values.

147> The filtering system is automatically started and the normal system isolated i

< when the radiation level or when the Chlorine level increase.

The testing required after painting, fire or chemical release, is not to be interpreted to include minor touch-up painting, housekeeping chemicals and detergents, or other routine maintenance or housekeeping activities.

l 1

Proposed Amendment No. 147 4-41b

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS Surveillance Standards 4.31 NUCLEAR SERVICE ELECTRICAL BUILDING EMERGENCY HEATING VENTILATION AND AIR CONDITIONING Applicability Applies to the Nuclear Service Electrical Building (NSEB) Emergency Heating Ventilation and Air Conditioning (HVAC) System components.

Objective To verify that this system and its components will be able to perform their design functions.

Specification 4.31.1 The NSEB Emergency HVAC shall be:

A. Demonstrated operable at least once per 31 days by initiating flow through the essential air handling unit.

1. Verify that the air handling unit maintains a flow rate of 24,500 cfm

10 percent.

2. Verify that the condensing unit is operational.

Bases 1

The purpose of the Emergency Nuclear Service Electrical Building Emergency HVAC is to limit high temperatures which the building would be subjected to upon loss of normal cooling. The high temperatures will affect the environmental qualification of safety related electronic equipment housed within the NSEB which is used to support the Control Room /TSC upon accident l

condition ;. The system is designed with an air handling unit and a condensing l unit which are activated upon high temperature signals.

Since this system is not normally operated, a periodic test is required to ensure its operability when needed. Monthly testing of this system will show that the system is available for its safety action. During this test the system will be observed for unusual or excessive noise or vibration when the fan motors are running. The air flow of 24,500 cfm was selected to limit the temperatures in the building to 80*F maximum (with the exception of the cable l shafts).

The system is automatically started when the temperature in the NSEB 147x Switchgear Room exceeds 95,F.

i Proposed Amendment No.147 4-91

147>

RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS i

Surveillance Standards 4.32 TDI DIESEL GENERATOR CONTROL ROOM ESSENTIAL VENTILATION SYSTEM Applicability Applies to the TDI Diesel Generator Building Control Room Ventilation System components.

Objective To verify that this system and components will be able to perform their design functions.

Specification 4.32.1 The Diesel Generator Control Room Essential Ventilation System shall be:

Demonstrated operable at least once per 31 days by initiating flow through the essential air handling unit by verifying that the air handling unit maintains a flow rate of 11,000 cfm

10 percent.

Bases The purpose of the TDI Diesel Generator Control Room Essential Ventilation System is to limit high temperatures which the local control room would be 44 subjected to upon loss of normal cooling. The high temperatures will affect the environmental qualification of safety related electronic equipment housed within the Diesel Generator Control Room. This Control Room is designed with an air handling unit which is activated upon a high temperature signal.

Since this system is not normally operated, a periodic test is required to ensure its operability when needed. Monthly testing of this system will show that the system is available for its safety action. During this test the system will be observed for unusual or excessive noise or vibration when the fan motors are running. The air flow of 11,000 cfm was selected to limit the temperatures in the building to 122 degrees F maximum.

The system is automatically started by a thermostat when the temperature in

< the Diesel Generator Control Room equals or exceeds 122 degrees F.

Proposed Amendment No.147 4-92

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Enclosure 3

SUMMARY

OF DIESEL GENERATOR MODIFICATION AND PRESENT STATUS OF EMERGENCY POWER The District determined that in meeting the requirements of NUREG 0737 the resulting modifications would exceed the electrical capacity of its existing emergency diesel generators. The District decided in 1980 to purchase two additional diesel generators to augment the existing system. The District originally planned the installation of these new generators during the Cycle 7 refueling outage (Spring 1985). This schedule was compatible with the installation of the majority of the TMI modifications, as well as the implementation of Emergency Feedwater Initiation and Control (EFIC). The diesels purchased were made by TDI and the operation of the diesels had been delayed until Cycle 8 due to the deficiencies identified on the Shoreham plant diesels. Recently, the District has decided to install the TDI diesel generators and implement changes associated with its electrical distribution system during the current extended outage.

To solve the TDI generic problems, the District, as a pcrt of an Owners group with eleven other utilities, developed a major TDI generator requalification program. This requalification program has required both time (several years) and resources to complete. As part of this program an initial Design Review and Quality Revalidation (DR/QR) report was submitted by the District to the NRC by a June 12, 1985 letter. The District's plans for future activities in this program include:

Startup testing of the engines Additional inspection following startup testing Submission of testing and inspection results to the NRC as a revision to the initial DR/QR report Implementation of a detailed maintenance and surveillance program The District's June 12, 1985 letter stated that it will address and close out all Quality Revalidation items which pertain to the l

Phase I sixteen major components prior to the final plant tie-in j of these diesels during Cycle 8 refueling outage. The closeout of the 16 items will now occur prior to startup. In the event that Quality Revalidation items remain open on any Phase II components, the District will address and close them out not later l than the completion of the Cycle 8 refueling outage.

These new diesel generators have been housed in a new QA Category

, I diesel generator building. The generators each have their own fuel oil storage tanks and transfer system, heat exchanger system,

, and Class 1 electrical power distribution and control (including load shedding and sequencing) system. The Class 1 electrical power distribution system is in the Nuclear Service Electrical t Building (NSEB) and consists of 4.16 KV Switchgear, 480 V Motor l Control Centers, 125 VDC busses, and 120 V vital AC busses, i

d

Prior to the final power distribution configuration described herein, the temporary configuration in the NSEB allows operation with certain loads being powered from the existing two diesel generator emergency power system. The following loads, presently powered from the existing diesel generators on loss of offsite power, will be powered from the new diesel generators:

o Control Room / Technical Support Center essential HVAC o 126 KW of pressurizer heaters o NSEB Battery Chargers o Aux. Feedwater pumps o Pressurizer Heaters In addition to the transferred loads, the new diesel generators will power on loss of offsite power the following loads:

o NSEB HVAC o New DG support systems Proposed technical specification amendment 147 will reflect the emergency power system in its final configuration and will remove restrictions imposed on the operation of certain equipment for Cycle 7.

A 6

Enclosure 4 Design Basis Report - ECT A-3748 O

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7 DESIGN basts REPORT

,, December 1, 1986

- ms os . .cn =

Mechanical - 1=

104183,104184,104231 36 sc* A - 3 e . 5

.. 104239,104334,50439 i 1.

PURPOSE OF DESIGN CHANGE:

See Attached

11. DESIGN CRITERIA USED:

See Attached

, C. CALCULATIONS & DESIGN iNFORMATION:

See Attached IV. FA! LURE MODES:

O THIS CHANGE DOES NOT AFFECT CONTROL ROOM INCTRUMENTATION O THIS CHANGE AFFECTS CONTROL ROOM INSTRUMENTATION. SEE ANALYSIS See Attached

v. SPECIAL MAINTENANCE REQUIREMENTS See Attached VI. SPEQAL OPERATING REQUIREMENTS:

See Attached Vll. VERIFICATION CRITERIA:

Not Applicable i

VI!!. COMMENTS:

None 4

IX. APPROVALS: 8e %EAn DATE I

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R e DESIGN BASIS REPORT 2 i FOR ECN A-3748 TABLE OF CONTENTS SECTION Pace No.

I. PURPOSE OF DESIGN CHANGE . 5 II. DESIGN CRITERIA USED 5

1. Diesel Generator Systems 5 A. Design Criteria, Codes, and Standards 5 B. Diesel Generator Systems 6

1. Diesel Generator 6

2. Diesel Fuel Oil Storage and Transfer System '9

3. Starting Air System 11

4. Jacket Water Cooling System 12-

5. Combustion Air Intake and Exhaust Gas Systems 13

2. HVAC Systems for the Diesel Generator Building 13 A .- Design Criteria, Codes, and Standards 13 B. Design Conditions 14

1. Outside Conditions 14

2. Inside Conditions 14

a. Normal HVAC Systems 14 b.,

Essential Ventilating Systems 14

.C. HVAC Systems 15

1. Normal HVAC Systems 15

2. Essential Ventilating Systems 15

a. DGB Control Room 15

b. Diesel Generator Rooms 16

3. Fire Protection System for the Diesel Generator Building 16 A. Design Criteria, Codes and Standards 16 B. Automatic Pre-Action Sprinkler System 16 C. Standpipe and Hose Stations 17 D. Portable Extinguishers 17 E. Fire and Smoke Detection System 17 F. Water Supply 17 G. Power Supply 18 1

< 1 SECTION Pace No.

4. Diesel Generator Building and Utilities 18 A. General Requirements 18 l B. Civil / Structural 18 i

1. Codes, Standards, and Reference Documents 18

2. Analysis and Design 19

3. Design Data 20

4. Construction Materials 22 C. Architectural 22 l D. Electrical 23 ,

E. Mechanical 23 l F. Piping System 24 G. Building Security System 24 ,

III. CALCULATIONS AND DESIGN INFORMATION 25

1. Diesel Generator Systems 25 A. Design Features 25 B. Design Calculations 25

2. HVAC Systems for the Diesel Generator Building 31 A. Design Features 31

1. Normal HVAC 32

2. Essential Ventilating Systems 32

a. D/G Building - Control Rooms 32

b. Diesel Generator Rooms 33

3. System Operational Requirements 33 B. Design Calculations 33

3. Fire Protection Systems for the Diesel Generator Building 37

^

A. Design Calculations and Reports 37 B. Automatic Pre-Action Sprinkler System 37 C. Standpipe and Hose Stations 38 D. Portable Extinguishers 38 E. Fire and Smoke Detection System 38 F. Water Supply 38 G. Power Supply , 38 I

4. Diesel Generator Building and Utilities 39 A. General Features 39 B. Civil / Structural Features 39 C. Design Calculations 41 D. Building Security System 43 l 2

-- o -- ~~m .m - - - --- _ _ - - - - - -... _ _ _ _ _ .

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SECTION Pace No.

IV. FAILURE MODES 44

1. Diesel Generator Systems 44

2. HVAC Systems for the Diesel Generator Building 44

3. Fire Protection Systems for the Diesel Generator Building 44 A. Seismic Protection 45 B. Inadvertent Operation 45 C. Consequences if the Fire Protection and Detection System Fails to Operate 45

4. Diesel Generator Building and Utilities 45 V. SPECIAL MAINTENANCE REQUIREMENTS 45 VI. SPECIAL OPERATING REQUIREMENTS 45 3

- _ - _ ~ _ _ _

g W LIST OF TABLES Pace No.

Tcble 1 HVAC Equipment Mode of Operation 34 Tcble 2 HVAC System Temperature Control 35 Tcble 3 Train "A" Damper Position. 36 Table 4 Train "B" Damper Position 36 LIST OF PEFERENCES RSference 1 Design Criteria for Diesel Generator System, Rev. 2, 3-12-84 Raference 2 Design Criteria for Diesel Fuel Oil Storage and Transfer System, Rev. O, 7-2-82 Roference 3 Design Criteria for Diesel Generator Building, Rev. 6, 1-12-84 R2ference 4 ASME Code,Section III, Design Specification No. M-869, Diesel Generator Syst&ms Rsference 5 Appendix 7C Piping Design Specification, Drawing M-870 1 Rsference 6 NRC Supplemental Safety Evaluation Report - Shoreham .

, Nuclear Power Station - Reliability of Standby Emergency l Diesel Generators, Docket 50-322, December 18, 1984 Rnference 7 NEC Safety Evaluation Report Related to the Operability and Reliability of Emergency Diesel Generators Manufactured by Transamerica Delaval, Inc. - NUREG 1216, September 8, 1986.

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Ravicion 7 DESIGN BASIS REPORT ECN A-3748 NCR N/A DISCIPLINE Mechanical WORK ORDERS 104183. 104184. 104238. 104239. 104334. 504396 TAGKO G50/655/656/659/036 IBe.chtel) r 246 (Imnell) MOD 036 I. PURPOSE OF DESIGN CHANGE:

The purpose of this design change is to' provide standby diesel generator pcwer capacity for the essential HVAC loads which are required for the Control Room / Technical Support Center habit-ability, general plant improvements, and other TMI related safety changes.

The design change includes the addition of two new redundant diesel generators each with a nominal capacity of 3,500 KW, to supply new buses S4A2 and S4B2, along with the new structure to house them, and all necessary services and systems to supply the diesels and the building. These systems include but are not limited to HVAC, fire-protection, security, fuel oil, starting air, cooling water, lube oil, utility power, lighting, and communications. The design basis report is divided into four sections; Diesel Generator System, HVAC, Fire Protection, and Diesel Generator Building. Each is discussed separately and, taken together, will encompass all the systems necessary for a completely functional diesel generator system.

The electrical tie-in of these generators to the power distribution system is discussed in the Design Basis Report for Modification 40, ECN A-3660. The fuel oil storage tank cathodic protection system is discussed in the Design Basis Report for Modification 43, ECN A-5122.

II. DESIGN CRITERIA USED

1. Diesel Generator Systems A. Design Criteria, Codes, and Standards

1. The Diesel Generator Systems, including the diesel fuel oil storage and transfer system, shall be designed and constructed with guidance from the codes and standards listed in the Diesel Generator i System Design Criteria, Ref. 1, the Diesel Fuel and Storage Transfer System Design Criteria, Ref. 2, and the Diesel Generator Building, Ref. 3, and will l meet pertinent provisions of the Design Basis Report for Modification 40, ECN A-3660, Power 5

. . . _ . _ _ - - . , , . . _ ,_. - _ . _ , . , _ . _ -___..-.m,_.____,.-...._,,_,,____--___._.-.,.-.___-_s. _ . - ,

') l Dietributien Syct;m Additi0n. Th3 off-;ngins piping cnd cecociated cquipm:nt chall comply with requirements of the ASME Code,Section III and/or augmented ANSI B31.1, or ASME Section VIII as described in Design Specification M-869, Ref. 4.

2. The unbalanced forces of diesel engines, generators, and other rotating' equipment, together with their operating frequencies, shall be considered in the overall design of the structures housing this equipment.

3. The diesel generator units and auxiliary systems shall be seismically qualified to ensure that they will perform their safety related functions during and/or following a safe shutdown earthquake (SSE) preceded by five operating basis earthquakes (OBE).

4. Complete separation shall be maintained between trains such that the effects of fire, flooding, and moderate energy pipe breaks in one train will not prevent the other train from performing its safety related function.

5. The systems shall be designed so that a single active component failure in one train will not prevent the other train from performing its safety related function.

B. Diesel Generator Systems

1. Diesel Generator

a. Each diesel generator shall be sized to meet the power requirements of its portion of the load for for one train of safety related equipment with spare margin for future loads,

b. The diesel generators shall be automatically started and connected to their respective buses following the loss of voltage to the bus to which each standby diesel generator is assigned. The signal for loss of bus voltage shall be bypassed after the diesel generator breaker is closed.

c. The diesel generators shall be automatically started following receipt of an Engineered Safety Features Actuation Signal (ESFAS). They shall remain on running standby and not be connected to their buses except in the event of a loss of offsite power. The diesel generator units shall be capable of operation at no load for extended periods without degradation of performance or reliability.

6

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d. . A manunl start cap 2bility chall.bo providad for test purpocco. Testing of the diesel g:noratora shall be through the preferred source of offsite power for a given train. Synchronizing can only be done from the main control room.

I

e. The diesel generators shall be able to attain rated frequency and voltage and be ready to accept loa'd within 10 seconds after receiving a starting signal.

f. The diesel generator system shall be monitored and controlled from either the control panel in the main control room or the generator and engine control panels located in the diesel generator control room in the Diesel Generator Building.

Provisions shall be made to isolate all control functions from the main control room for diesel A2 only by means of a switch located in the Nuclear Service Electrical Building (NSEB) in order to provide an alternative emergency control station.

g. The diesel generators shall be sized to withstand 10% overload for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

h. The diesel generators shall be capable of start-ing and accelerating, in the required sequence, all the needed ESF and emergency shutdown loads assigned to them within the prescribed time interval after being connected to their respec-tive 4.16 kV Class 1 buses. These loads are listed in the Design Basis Report for Modifi-cation 40, ECN A-3660. Voltage and frequency shall not drop below 75 percent and 95 percent, respectively, of rated during the application of listed loads,

i. Physical separation shall be maintained between the diesel generators. Electrical cables for the diesel generators will be routed to maintain i physical separation between Train A and Train B.

The DC power sources for the diesel generator i instrumentation and control system shall be part j of the same train or load group as the diesel generator and its associated switchgear.

! j. The neutral of the generators shall be grounded through a distribution transformer with its secondary winding connected to a loading resistor sized to limit primary ground fault current to 5 amperes in the generator winding.

2 7

k. Equipmint chall bD providad for occh diesel generator to permit the following modes of operation:

Automatic operation Remote manual control from the main control room Local manual control from the diesel generator control room

1. The governor and the voltage regulator manually actuated droop modes shall be automatically reset to the isochronous modes if an ESFAS is received or if the units are shut down.

m. Protective devices shall be provided to monitor and shut down the diesel engine during non-accident conditions in the event of the following:

Engine overspeed High jacket water temperature Low jacket water pressure Low lube oil pressure High crankcase pressure Generator differential current Generator neutral overcurrent (or neutral overvoltage)

Generator overcurrent Reverse power protection Loss of field Turbocharger high vibration Turbocharger low lube oil pressure Engine bearing high temperature Engine vibration high High lube oil temperature i -

Generator load unbalance (negative phase sequence)

! n. During an accident, all of the above functions l

! shall be restrained from tripping the diesel l generator except the following: l 1

i 4 -

Engine overspeed l Generator differential current j Low lube oil pressure i l

j However, the other blocked trip conditions shall l still be annunciated in the diesel generator l control room.

o. The maximum short circuit current of the 4.16KV system when a diesel generator is periodically tested shall be within the short circuit rating of the 4.16 KV switchgear. l 8

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p. Ths discal gansrators ch211 not bs unsd for commerical power production.

q. Auxiliary power for the Generator Field Ground Relay shall be disconnected automatically when the diesel generator is placed in a shutdown condition. This is necessary to eliminate a potential hazard to maintenance personnel by generation of a DC potential on the exciter field.

r. Annunciation of the "DG Inoperative" Alarm shall be provided in the Diesel _ Generator Room and in the Main Control Room Computer. The follcwing funct' ions shall generate "DG Inoperative" Alarms:

. Loss of Control Power to DG Breaker

. Lockout of DG Breaker

. Lockout of Nuclear Service Transformer Supply Breaker

. Lockout of Startup Transformer #2 Supply Breaker

. Starting Air Pressure Low

. Starting Air Receiver Isolation Valves Not Open i

s. The 480V load center feeder breaker, which provides power to the MCC for essential diesel

. generator auxiliary loads, shall be designed to trip and close as controlled by the bus loading sequencer upon receipt of ESFAS or LOOP signals.

2. Diesel Fuel Oil Storage and Transfer System

a. The diesel fuel oil storage and transfer system shall consist of two redundant flow trains. Each train shall consist of a 60,000 gallon diesel fuel oil' storage tank, two 25 gpm transfer pumps, fuel supply and return piping to the fuel oil day tank, and associated valves, fittings, strainers, and instrumentation.

b. The system shall provide adequate storage of

! diesel fuel oil to permit 7 days continuous I operation of each standby diesel generator at its full load rating of 3500 KW.

c. The system shall have an additional 15% fuel oil storage capacity available for the routine

} scheduled operational testing of the diesel generators without compromising the system's

ability to meet its minimum operational

! requirements.

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d. Each diocol fuel oil etorags tank chn11 ba provided with two fuel oil transfer pumps. Each pump shall be sized to deliver 25 gpm to the engine day tank at the required total head. .

Interconnecting piping with two locked closed '

valves shall be provided between the two DG systems to allow transfer of diesel fuel oil from the train "A" storage tank to the train "B" storage tank and vice-versa.

e. The diesel fuel oil system shall be provided with instrumentation to monitor the level in the fuel oil day tanks and provide an alarm in the Diesel Generator Control Room and in the Main Control Room Computer on low and high level conditions.

The transfer pumps shall be started automatically on a low level signal from the fuel oil day tank and shall be stopped by the high level switch in the day tank.

f. The start-stop operation of the fuel-oil transfer pumps will be indicated in the diesel generator control room to alert operators of an abnormal condition such as pump failure to start.

g. Each diesel fuel oil storage tank shall be provided with a non-class 1 level transmitter (including a level switch) and a class 1 level switch. The level element which is part of the level transmitter loop, shall meet seismic Category II requirements. The level transmitter 1

and non-Class 1 switch shall be used for local level indication and for low and high level alarms at the engine control panel and on the plant computer. The Class 1 level switch shall be used to alarm low-low storage tank level in

! the main control room via the plant computer.

The low level alarm shall signify that the minimum volume for 7 days of continuous full load operation will be reached shortly. The low-low level alarm shall signify that the useable fuel oil volume will be expended shortly.

h. The diesel fuel oil storage and transfer system shall be capable of being monitored and controlled from the engine control panel. All diesel generator system trouble alarms shall be provided to the plant computer. A local manual

" hand-auto" switch shall be provided for operating each diesel fuel oil transfer pump on the engine control panel,

i. Each diesel fuel oil storage tank shall be provided with connections for truck fill, day tank overflow, level switch, level transmitter, vent, water drain, dip stick, two manholes, and pump mounting flanges.

10

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j. Flcm3 crrastoro ch011 ba provid;d on tha vanta for the diesel fuel oil storage tanks.

k. The diesel fuel oil storage tanks shall be buried underground and protected from corrosion by properly coating inside and outside tank surfaces, and by the station cathodic protection system, and shall be designed to withstand the earth loading for static and seismic conditions and normal highway surcharge.

1. The fuel oil transfer pump shall be powered by 480V, 3-phase, AC power from Class 1 motor control centers in their respective train.

m. Each day tank shall have a ca'pacity to store fuel oil for approximately 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of diesel generator operation at maximum load. Each tank shall be provided with a drain connection including water draw-off valve, instrument connections, fill connection, and overflow connection to return excess fuel back to the storage tank.

n. The day tank level alarms shall actuate in both the diesel generator control room and the main control room. The low level alarm shall signify that the day tank contains fuel for at least one hour of diesel generator operation at maximum load,

o. The diesel fuel oil storage and transfer system shall be capable of being tested during normal plant operation.

p. The diesel fuel oil system for the new engines shall be independent of and not connected to the diesel fuel oil system of the existing engines.

3. Starting Air System

a. Each diesel generator shall have a completely independent starting air supply system. The starting air system shall contain one air compressor, one air dryer, and two air receivers.

b. Each compressor shall be powered by 480V, 3-phase, AC power from a non-Class 1 MCC. The compressors shall be capable of recharging the air receivers from minimum starting air pressure to full charge in approximately 30 minutes. Air compressors are provided with non-Class 1 motors.

11

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c. Ecchcirrccaivhrchn11h;vaocrpcitytotupply air for at least 5 consecutive cold diesel engina starts without requiring recharging. Each air receiver shall be fitted with a relief valve, pressure gauge, low pressure alarm switch, low-low pressure alarm switch, drain, and shutoff valve.

4. Jacket Water Cooling System

a. A closed water circulating system with air cooled radiators shall be used for cooling the jacket water of the diesel generator units. The radiators shall be sized for the maximum engine heat load plus a 10 percent margin.

b. The system shall be provided with a standpipe serving as an expansion tank.

c. The cooling water shall be a mixture of 80%

demineralized water and 20% ethylene glycol based corrosion inhibitor by volume for freeze protection down to 19F.

d. The engine driven jacket water cooling pump shall maintain a flow of up to 800 gpm to cool jacket water from 1700F to 145oF at the design condition and shall have adequate head to overcome pressure losses through the radiators and the associated piping. A three-way bypass valve shall be provided to allow temperature control of jacket water.

e. Stacks shall be provided on the radiator exhaust to prevent recirculation of radiator exhaust air to the diesel engine combustion air intake.

f. The radiators shall be located outside the Diesel Generator Building and shall be enclosed by an 18 foot high wall.

g. A chemical feed tank shall be provided for the jacket cooling water system to enable the operator to add a corrosion inhibitor to the system. The inlet and outlet connections of the tank shall be coupled to the outlet and inlet of the keep warm pump respectively. The tank will be isolated from the system with a pair of shutoff valves. A sample connection shall also l be provided at the chemical feed tank.

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O 5 Ctabuction Air IntEka and Exh2ust Gas Systsm

a. The Combustion Air Intake System shall be designed for 15,000 SCFM flow of air from outside of the D/G Building. The system shall' consist of intake air louvers, piping, dry type air filters, and intake silencers.

. b. The filter housing shall be designed for ease of filter removal.

c. A high and low pressure alarm in the combustion air intake manifold will annunciate in the diesel generator control room and main control room-computer upon receipt of high or low-pressure signal,

d. The exhaust piping shall be insulated inside the building for personnel protection and to reduce the engine room temperature. The exhaust piping i on the roof and the silencer shall not be j insulated. Personnel access to the roof shall be restricted and the silencer and stack shall be

fenced _off and provided with a sign warning of j hot surfaces.

2. HVAC Systems for the Diesel Generator Building

A. Design Criteria, Codes and Standards l

l The following codes and standards shall apply to the HVAC system:

1. HVAC components shall be designed in accordance with ARI 20, ARI 360-81, ANSI B9.1 and Bl.5, ASHRAE 36

, and 52-68.

l

2. Air handling centrifugal fan units and essential exhaust fans shall be designed in accordance with AMCA 210 and AMCA 211.

j 3. Dampers and their actuators shall be designed in accordance with IEEE 323 and 344.

i 4. Quality Class 1, Seismic Category I motors shall be j designed to meet the requirements of IEEE 323, 334, and 344.

1

5. Duct systems shall be designed, constructed, and tested in accordance with SMACNA Section II.

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6. B:chtal Dacign Guid2 C-2.39 chall b3 used.for tha design of Seismic Category I ducts and supports.

Non-safety related duct supports will be designed to Seismic Category II requirements and failure of the non-safety related duct supports will not impair the-operation of Quality Class 1, Seismic Category I equipment.

~

B. Design Conditions The D/G Building normal and essential HVAC systems shall be designed for the following conditions:

1. Outside Conditions:

a. Temperature Summer 1150F DB/76oF WB Winter 190F to 300F

b. Wind Velocity:

Summer 7-1/2 mph Winter 15 mph

2. Inside Conditions:

a. Normal HVAC Systems

1. The temperature of D/G Building control room numbers 161 and 163 shall be maintained up to a maximum of 900F. The relative humidity shall range from approximately 20%

to a maximum of 90%.

2. The temperature of Diesel Generator room numbers 162 and 164, and mezzanine floor room numbers 250 and 251 shall range from 440F minimum to a maximum of 1400F. No separate room heating units shall be provided. All heat will emanate from the diesel and its auxiliary skid components. The diesel generator will be maintained in a stand-by mode; the lube-oil and jacket water systems are equipped with keep warm heaters and circulating pumps,

b. Essential Ventilatino Systems

1. The temperature of D/G Building control room numbers 161 and 163 shall not exceed 70F above outside ambient temperature (to a maximum of 1220F) with the use of air ventilating system. The relative humidity shall range from apporoximately 20% to a maximum of 90%. Continuous occupancy is not required.

14

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2. Similarly, tha temparctura of diecal gunsr-ator room numbers 162 and 164, and mezzanine floor room numbers 250 and 251 shall not exceed 25oF above outside ambient temperature to a maximum of 1400F.

C. HVAC Systems The D/G Building Control Room HVAC systems shall consist of one 100% normal package direct expansion (DX) air conditioning unit and one 100% essential air handling unit for each train designed to the outside and inside conditions established in Section II.2.B. The diesel generator rooms shall be provided with one essential-exhaust fan for each train which could operate continuously during essential conditions and during other non-emergency periods of extended operation of the diesel generator. The air handling units and exhaust fan flow shall be controlled and monitored for malfunction in the Diesel Generator Control Room. The HVAC system's operation shall also be monitored for malfunction in the plant computer in the Main Control Room.

1. Normal HVAC - Systems

~

The normal HVAC aystem shall consist of one 100%

capacity unit for each train designed to Quality Class 2 and Seismic Category II requirements.

The normal package DX air conditioning units shall be complete with moderate efficiency filters, DX cooling coil, centrifugal fan with motor, compressors, condenser fans with motor, condensing coil, dampers, instrumentation and controls.

2. Essential Ventilatina Systems

a. D/G Building Control Room The cssential ventilating system shall consist of one 100% capacity unit for each train designed to Quality Class 1 and Seismic Category I requirements. It shall be designed to remain functional during and after safe shutdown earthquake (SSE).

The essential air handling units shall be complete with moderate efficiency' filters and a centrifugal fan with electric motor, instrumentation, and associated controls.

Essential supply ducts and transfer grilles shall be provided with isolation dampers to isolate the i essential ventilating system during normal operation.

15

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Tha eccential air handling units chall stort whenever the temperature in the control room reaches 1100F as determined by a high temperature l sensing switch in the diesel generator control room.

b. Diesel Generator Rooms Each diesel generator room shall be provided with a separate vaneaxial type essential exhaust fan. The essential exhaust fan for each train will be designed to Quality Class 1 and Seismic Category I requirements.

Each fan shall be designed to maintain the diesel generator rooms at a temperature less than 1400F.

3. Fire Protection System for the Diesel Generator Building A. Design Criteria, Codes and Standards

1. Piping, valves, switches, sprinklers, canopies, detectors, and pressure regulators shall be UL listed or FM approved for the fire protection and detection service.

2. The fire protection systems shall meet the National Fire Protection Association (NFPA) Codes and Standards described below:

I NFPA 10-1981, Portable Fire Extinguishers NFPA 13-1980, Automatic Sprinkler System Installation NFPA 14-1980, Standpipe and Hose Systems NFPA 24-1970, Outside Protection NFPA 72D-1979, Proprietary Protective Signaling Systems NFPA 72E, Automatic Fire Detectors NFPA 90A, Air Conditioning and Ventilating Systems

3. The fire protection system shall meet the require-( ments of 10CFR Part 50, Appendix R, Fire Protection Program of Operating Nuclear Power Plants.

B. Automatic Pre-Action Sprinkler System l An automatic pre-action sprinkler system shall be

installed for protection of both trains of the Diesel I

Generator Building including the engine rooms, control

, room, and mezzanine areas. The sprinkler system shall be

! designed in accordance with NFPA 13-1980, l

l 16 l

t

b C. Strndpipa cnd Hora StOtions Class II standpipe and hose stations shall be provided in the engine room, mezzanine, and control room. Each hose station shall consist of a fire hose, hose reel, nozzle, and angle valve. Standpipes and hose stations shall be designed in accordance NFPA 14-1980.

D. Portable Extinguishers Portable extinguishers shall be located in the engine room, mezzanine, and control room. The extinguishers shall be installed in compliance with the requirements of NFPA 10-1981, Portable Fire Extinguishers.

E. Fire and Smzke Detection System

1. Ionization smoke detectors shall be provided in the diesel generator control room and the mezzanine.

2. Infra-red flame detectors shall be provided in the engine room and the mezzanine.

3. Photo-electric smoke detectors shall be provided in the engine room.

4. Fire detection zone number 105 is assigned for Train "A" and fire detection zone 106 for Train "B".

5. Detectors shall be located and mounted per NFPA 72E and wired per NFPA 72D-1979.

6. A Manual Fire Alarm Station (MFAS) shall be provided at each exit from the building.

7. Detector actuation (fire condition) and detector system trouble condition shall be alarmed and annunciated on the local panel (H4FCP6) and in the main control room.

F. Water Supply The existing yard fire main shall be extended to the Diesel Generator Building to supply the water for hydrants, automatic pre-action sprinkler system, and manual hose stations. Adequate capacity is available from the existing fire pumps. Separate lead-ins shall be provided for the automatic and manual fire water extinguishing system. The existing yard fire mains system is assured operable by testing defined in Section 4.18.2 of the Rancho Seco Unit 1 Technical Specifications. The outside fire protection shall be provided per NFPA 24-1970.

17

A

] h 4 G. Powar Supply 120V single phase power shall be provided from an uninterruptible power supply system.

4. Diesel Generator Building and Utilities A. General Requirements The building shall be designed for separation between Train A and Train B such that the effects of fire and '

flooding in one train will not affect the safe operation of the other train.

B. Civil / Structural *

1. Codes, Standards, and Reference Documents The following codes, standards, and documents shall be used in the design of the Diesel Generator Building:

a. American Concrete Institute (ACI) Standard 349-80, Code Requirements for Nuclear Safety Related Concrete Structures.

i b. American Concrete Institute (ACI) Standard 318-77, Code Requirements for Reinforced Concrete (for masonry wall focting only).

c. American Concrete Institute (ACI) Standard 531-79, Code Requirements for Masonry Structures.

d. Uniform Building Code, 1973 edition for masonry wall seismic analysis and special inspection requirements as per section 305.

e. American Institute for Steel Construction (AISC)

Manual for the Design, Fabrication, and Erection of Structural Steel for Buildings, Eighth l Edition, 1980.

f. Bechtel Topical Reports

] BC-TOP-3-A, Rev. 3, Tornado and Extreme Wind 3

Design Criteria for Nuclear l

Power Plants

g. Bechtel Design Guides Design Guide C-2.26, Rotating Equipment Foundation Design Guide C-2.44, Seismic Analysis for Structures and Equipment for Nuclear Power Plants Design Guide C-2.45, Design of Structures for l Tornado Missile Impact

18 l

. - _ _ _ _ _ . - , , - - _ . _ , _ . ., __ . , - - - , <_m____._._______m__,___,-____._._____,m ..._-,._ _ ...-. -,

, 7 - :; N ; -}

Design Guide 'C-2.!7,, e SeismicTategory I Cable Tray e -

and Conduit Raceway Support System c -

Design Guide C--2.23, Seismic Category I HVAC Duct and Supports

h. tNRC Regulatory Guides ,

,, Regulatory Guide 2 60, . .Rev. 1, Dec. 1973, Design

,. ( Response Spectra for

^

s'- , Seismic Design of. Nuclear Power Plants

\'

'Na'gulatory Guide 1.61, Oct. 1973, Damping

5 o Values for Seismic

{\ S ,

\>i

,s g' ,

4 j Design of Nuclear Power Plants I[ . '

j Rev. 1, Feb. 1976,

, , g BeguintoryGuide(k.92,Combining Modal Responses j

g and Spatial Components in Seicmic Response Analysis s

g'/,'/t' '

,, .n ttegult. tory' Guide 1.142, April 1978, Safety-

/ /

, Related Concrete

(; i

( , Structures for Nuclear

, '. s

't Power Plants (Other than

)

\ Reactor Vessels and j b i C(ntainments) sN y . '? s *3 ', ,

, i. M ndustry Standards

' ,, /, l>

Nationally recognized industry standards, such as those poblished by American Society for Testing

?> \ and, Materials (ASTM), shall be used whenever gpossidfe-to describe material properties, testing

~

j procedures, fabric) tion, and construction methods. '

/

os

2. Ana3ysis an:.' Design '

l ' a 2. R!inforcedJconcrete Category I: structures shall

', bs y be designed in accordance with ACI 349-80 as i

, modified by Regulatory Guide 1.142.

b. Structural - steel structures shall satisfy the

, 4following load combinations without exceeding ti*a specified stresses:

! i ( 3 .l S: D+L+Eo l g 2, S:, D+L+W

3. 1. 6 S : . D+L+Ess

! q t 4. 1.6S: D+L+Wt l

l i l -

l 19

3 Notoc w= -

D = dead loads or their related internal moments ,

and forces l L = appSlcable live loads or their related '

-int 5rnal' moments and forces L .

l Eo = loads' generated by the operating basis ,

I earthquake (OBE) )

Ess = loads generated by the safe shutdown '

.; earthquake (SSE) l W = loads generated.by winds (SAR 5.1.2.1.6)

Wt = loads generated by the design tornado specified for the building. They include combined loads due to the tornado winds pressure, due to tornado-created differential pressures, and due to tornado-generated missiles.

S = the required strength based on elastic design methods and the allowable stresses defined in the part I of the AISC " Specification for the Design Fabrication and Erection of Structural Steel for Buildings", November 1, 1978 (local yielding is permitted under loading combinations No. 3 and 4 mentioned above).

For seismic load calculation (Eo and Ess) total dead load plus 25% live load is considered.

c. Hydro-static loads from piping rupture shall be considered as live loads.

3. Design Data

a. Design Loads

1. Uniform Live Loads The follcw!ng uniform live loads shall be used in the design of the Diesel Generator Building:

a. Floors Basemat Elev. O'0" 200 psf Mezzanine Elev. 18'6" 125 psf Roof Elev. 34'6" 31 psf (Equiv. to 6" standing water) 20

A n

b. Grcting Elev. O'0" 200 p f or 2000 lbs, capacity forklift truck

c. Elevated Platforms Elev. 11'0" 125 psf Elev.'18'6" 125 psf

2. Equipment, Piping, HVAC Ducts, Electrical Cable Trays, and Conduits

a. Equipment Loads Basemat Elev. O'0" 125 psf Mezzanine Elev. 18'6" 75 psf Roof Elev. 34'6" 25 psf '

b. Piping, HVAC Ducts Basemat Elev. O'0" 50 psf Mezzanine Elev. 18'6" 50 psf Roof Elev. 34'6" 25 psf

c. Electrical Cable Trays and Conduits Mezzanine Elev. 18'6" 50 psf Roof Elev. 34'6" 25 psf

3. Crane Loads 5 Ton Underhung Single Girder Crane. Impact load and seismic load shall not be applied concurrently.

4. The floor area live load shall be omitted from areas occupied by equipment whose weight is specifically included in dead load or equipment dead load. Live load shall not be omitted under equipment where access is provided.

b. Allowable soil bearing pressures based upon recommendation by Bechtel Geotechnical Group of December, 1981, are as follows:

SP (D+L) = 8 KSF at approximately 10 ft.

below grade !

SP (D+Ess) = 16 KSF at approximately 10 ft.

below grade Total estimated settlement = 0.5 !inches at center Differential settlement = 0.25 inches (between center and corner) 21

M,

c. dig 231 Information Total Weight (approx.) = 196,175 lbs.

Weight of Rotating Parts = 30,675 lbs.

Maximum Speed = 450 rpm.

Unbalanced force = 17,250 lbs.

Recommended Mass Ratio = 1.55 (conc. to engine)

Max. Amplitude (Allow) = 0.0032 inches

4. Construction Materials concrete Compressive strength (28 days) f'c = 4,000 psi for Diesel Building f'c = 3,000 psi for yard structures concrete Masonry (with Special Inspection)

Prism strength of hollow concrete unit, Grade N, Grouted Solid f'm = 1,500 psi Mortar type 'S' f'c = 1,800 psi Grout f'c = 2,000 psi (min.)

Reinforced Steel Grade 60, fy = 60,000 psi per ACI 349-80 Structural Steel ASTM A36-77a fy = 36,000 psi Hich Strenath Bolts ASTM A325-79 (Bearing Type), 3/4" diameter minimum C. Architectural

1. The wall separating Train "A" and Train "B" diesel generator units shall have a minimum fire resistance of 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . Suitable firestops shall be provided for all penetrations and openings in this wall to maintain the 3-hour fire rating of the barrier.

2. All interior doors, and doors and gates at the con-crete masonry wall shall be monitored with position i switches.

3. Diesel TanL Vault roof hatch and the tank manhole cover shall be provided with lock and position switch.

22

- ----..---,m .---. -w ....e -.-,v-- , - - , - - .-r-----------------w- - - - - - - - - , - v-.--.-y, -,--.--..v.,-,-- -y---r-- - - - - - - - - - , -. - --

n D. E1Cctrical

1. An electrical raceway system consisting of cable trays, embedded conduits, underground electrical ducts, electrical manholes, and exposed conduits, shall be provided. Building grounding shall be provided and connected to the existing plant ground grid. Provisions for equipment grounding shall also be zade. SMUD Rancho Seco Nuclear Generating Station Construction Methods and Procedures shall be used.

2. Lighting fixtures similar to the fixtures used in the existing Auxiliary Building shall be used to provide the following:

- Diesel Generator areas: 30 foot-candles

- Control Rooms: 30 foot-candles

- Mezzanine: 30 foot-candles

3. No Train A raceway shall be located in a Train B room, and vice versa.

4. All major pieces of electrical equipment shall be mounted on concrete pads.

5. A telephone shall be provided in the Diesel Generator Building Control Room. Paging speakers shall be provided in the Diesel Generator Room.

6. Welding receptacles shall be provided.

7. Flashing amber lights for evacuation shall be provided in high noise level areas.

8. Seismic Category I supports and mountings shall be provided for Quality Class 1 equipment and raceways.

9. 8-hour emergency lighting in each major room at each building exit shall be provided.

10. Class 1 480 volt power supplies from the respective trains shall be provided to power the essential auxiliaries of the two diesel generators and diesel generator building facilities. Non-class 1 power supplies shall be provided for auxiliaries not essential to the safety of the plant.

E. Mechanical a

1. The Diesel Generator Building Heating, Ventilating, and Air Conditioning (HVAC) System Design Criteria is described in Section II.2.

2. The Diesel Generator Building Fire Protection / i Detection System Design Criteria is described in Section II.3.

23

' T <N

3. .BridgD Crcnso

a. Bridge crane shall be 5 ton capacity, single girder, underhung type.

b. The bridge cranes shall be designated as Seismic Category II. They shall be designed to maintain structural integrity during or after SSE.

c. Bridge cranes shall be Quality class 2.

4. Drainage System / Sump Pumps

a. Floor drains in the control room and engine room shall be connected to a sump in the engine room.

Each train shall be provided with a sump and'a duplex sump pump. -

b. The sump pumps shall be sized to provide at least 100 gpm per pump.

c. New lines shall be provided to direct the water discharged from the sump pumps to the existing oil / water separator.

F. Piping System

]

1. All safety related piping shall be train separated.

2. Safety related piping supports and components shall be designed to Seismic Category I requirements.

3. General criteria for the design and construction of the piping and components shall conform to the Piping Design Specification, Ref. 5.

G. Building Security System

1. A security system shall be provided to control access to the new D/G Building doors as required by Amendment 12 to the Physical Security Plan. This '

, system shall include computer controls, card reader, I door locks, alarms, and tamper switches.

2. All security equipment shall be classified as not safety related, and will not require seismic and environmental qualification.

3. The power for security equipment shall be obtained from the existing diesel-backed UPS source.

4. The diesel generator security system shall be fully integrated into the existing plant security system, and as such shall utilize existing system design characteristics.

I 24 t- - _ _ - ,- ,,~ _ _.

m O III. Calculations and Desian Information

1. Diesel Generator Systems A. Design Features The Diesel Generator System is designed to meet the criteria established in Section II.l. The design of the fuel oil storage tank cathodic protection system is covered under Modification 43, ECN A-5122.

Although the diesel generators are sized to accept a nominal full load of 3,500 KW per train, the naximum loading will not exceed a " qualified load" based upon 10 E7 cycle testing. This provides assurance that the crankshafts will stay within the proven limits for high-cycle fatigue cracks. Testing performed at Shoreham indicates a " qualified load" of 3,300 KW (Ref. 6), but this is subject to confirmatory testing and analysis for applicability to Rancho Seco.

B. Design Calculations Z-DFO-M0287 - Calculation M17.03, Diesel Generator Fuel Oil Storage Tank Sizing, Rev. 1, 3-25-85 Z-EGS-M0288 - Calculation M17.04, Diesel Fuel Oil Transfer Pump Sizing, Rev. O, 11-23-82 Z-EGS-M0289 - Calculation M17.06, Pressure Drop for Jacket Water Piping to-from Air Cooled Radiator, Rev. O, 6-3-82 Z-EGS-M0290 - Calculation M17.07, Expansion Volume in Radiator and Piping, Rev. O, 6-3-82 Z-EGS-M0291 - Calculation M17.08, Diesel Generator Exhaust Stack Height, Rev. 1, 3-3-86 Z-EGS-M0292 - Calculation M17.10, Exhaust Silencer Temperature, Rev. O, 7-30-82 Z-EGS-M0293 - Calculation M17.ll, Pressure Drop in Jacket Water Cooling Makeup Line, Rev. O, 9-17-82 Z-DFO-M0294 - Calculation M17.12, Fuel Oil Return Flow from Day Tank to Storage Tank, Rev. O, 5-18-83 Z-EGS-M0295 - Calculation M17.13, Design Temperatures and i Pressures of the Diesel Generator System, Rev. O, 12-13-83 Z-EGS-M0296 - Calculation M17.14, Diesel Generator System Volume of Jacket Water Cooling System, Rev. O, 5-8-84 Z-DGB-MO501 - Stress Calculation 321, Pipe 10020/10021-26"-HE7, Rev. 1, 11-25-85.

25

. , s ,

Z-LOS-MO507 - Stre:s Calculation 327, Luba Oil Sump Tank Vent, Rev. O, 2-22-84 Z-DGB-MO513 - Stress Calculation 333, D/G Building Buried Pipe Analysis, Rev. O, 1-30-86.

'Z-DGB-MO516 - Stess Calculation 336, D/G Building Starting Air, Rev. O, 1-13-84.

Z-DFO-MO517 - Stress Calculation 337, Pipe 10802-2 1/2" and 10808-2 1/2", Rev. O, 4-7-83.

Z-DFO-MO518 - Stress Calculation 338, Pipe 10800-4"-HE7, Rev. O. 12-19-83.

Z-DGB-MO519 - Stress Calculation 339, Pipe 10012-4"-HE7, Rev. O, 3-15-84.

Z-DGB-MO520 - Stress Calculation 340, Pipe 10013-4"-HE7, Rev. O, 3-15-84.-

Z-DFO-MO521 - Stress Calculation 341, Pipe 10810-2 1/2" and 10812-2 1/2"-HE7, Rev. O, 2-28-84.

Z-DGB-MO522 - Stress Calculation 342, Pipe 10400-8"-HE7, Rev. O, 3-5-84.

Z-DGB-MOS23 - Stress Calculation 343, Pipe 10401-8"-HE7, Rev. O, 3-7-84.

Z-DGB-MOS24 - Stress Calculation 344, Pipe 10406-8"-BE7, Rev. O, 3-5-84.

Z-DGB-MO525 - Stress Calculation 345, Pipe 10407-8"-HE7, Rev. O, 3-7-84.

Z-DFO-MO526 - Stress Calculation 346, Pipe 10811-2 1/2" and 10813-2 1/2"-HE7, Rev. O, 2-28-84.

Z-DGB-MO528 - Stress Calculation 348, Pipe 10600-24"-BE7, Rev. O, 12-28-83.

Z-DGB-MOS29 - Stress Calculation 349, Pipe 10601-24"-HE7, Rev. O, 12-23-83.

Z-DGB-MO535 - Stress Calculation 355, Pipe 10414/10415-1"-HE7, Rev. O, 3-15-84.

Z-DGB-MO540 - Stress calculation 361, Pipe 10ll7-3"-GE2, Rev. O, 1-13-84.

Z-DGB-MO541 - Stress Calculation 362, Pipe 10110-3"-GE2, Rev. O, 2-15-84.

Z-DGB-MO542 - Stress Calculation 363, Pipe 10ll6-3"-GE2, Rev. O, 2-15-84.

26

Z-DFO-MO543 - Strsos Csiculaticn 364, Pipe 10804-4*-HE7, Rev. 0, 12-19-83.

Z-DFO-MO546 - Stress Calculation 367, Pipe 10803-2 1/2" and 10809-2 1/2", Rev. O, 4-7-83.

Z-DGB-M0566 - Support Calculation 321A, Pipe 10020/10021-26"-HE7, Rev. O, 1-13-84.

Z-DFO-MO576 - Support Calculation 336A, D/G Building Starting" Air, Rev. O, 2-24-84.

Z-DFO-MO577 - Support Calculation 337A, Pipe 10802-2 1/2" and 10808-2 1/2", Rev. O, 11-17-83.

Z-DFO-MO578 - Support Calculation 338A, Pipe 10800-4"-

HE7, Rev. O, 12-19-83.

Z-DGB-MO579 - Support Calculation 339A, Pipe 10012-4"-

HE7, Rev. O, 3-15-84.

Z-DGB-MO580 - Support Calculation 340A, Pipe 10013-4"-

HE7, Rev. O, 3-15-84.

Z-DFO-MO581 - Support Calculation 341A,. Pipe 10810-2 1/2" and 10812-2 1/2-HE7, Rev. O, 2-28-84. -

Z-DGB-MO582 - Support Calculation 342A, Pipe 10400-8"-

HE7, Rev. 0 3-5-84.

Z-DGB-MO583 - Support Calculation 343A, Pipe 10401-8"-

HE7, Rev. O, 3-7-84.

Z-DGB-MO584 - Support Calculation 344A, Pipe 10406-8"-

HE7, Rev. O, 3-5-84.

Z-DGB-MO585 - Support Calculation 345A, Pipe 10407-8"-

HE7, Rev. O, 3-7-84.

Z-DFO-MO586 - Support Calculation 346A, Pipe 10811-2 1/2" j and 10813-2 1/2"-HE7, Rev. O, 2-29-84.

Z-DFO-MO587 - Support Calculation 348A, Pipe 10600-24"-

HE7, Rev. O, 12-28-83.

Z-DGB-MO588 - Support Calculation 349A, Pipe 10601-24"-

HE7, Rev. O, 1-4-84.

Z-DGB-MO594 - Support Calculation 355A, Pipe 10414/10415-i 1"-HE7, Rev. O, 3-15-84.

Z-DGB-MO596 - Support Calculation 361A, Pipe 10117-3"-

GE2, Rev. O, 2-23-84.

l Z-DGB-MO597 - Support Calculation 362A, Pipe 10110-3"-

GE2, Rev. O, 2-21-84.

27

-r-,,-s- ,-~~w-- ---~- - , - ~ , - + - - - , - - - * - - - - - - - - - - - ---

Z-DFO-MO598 - Support Calculction 363A, Pipe 10116-3"-

GE2, R;v. O, 2-15-84.

Z-DGB-MO599 - Support Calculation 364A, Pipe 10801-4"-

HE7, Rev. O, 12-19-83.

Z-DFO-MO600 - Support Calculation 367A, Pipe 10803-2 1/2" and 10809-2 1/2"-HE7, Rev. O, 11-17-83.

Z-DFO-MO609 - Stress calculation 1301, Pipe 10002/10003-2"-HE7, Rev. O, 11-16-83.

Z-DFO-MO610 - Stress Calculation 1302, Pipe 10006-2"-BE7, Rev. O, 11-10-83.

Z-DFO-MO611 - Stress Calculation 1303, Pipe 10007-2"-HE7, Rev. O, 11-10-83.

Z-DFO-MO612 - Stress Calculation 1304, Pipe 10010-1 1/2"-

HE7, Rev. O, 1-13-84.

Z-DFO-MO613 --Stress Calculation 1305, Pipe 10011-1 1/2"-

HE7, Rev. O, 3-2-84.

Z-DFO-MO614 - Stress Calculation 1306, Pipe 10014-1"-HE7, Rev. O, 1-16-84. _

Z-DFO-MO615 - Stress Calculation 1307, Pipe 10015-1"-HE7, Rev. O, 2-24-84.

Z-DFO-MO616 - Stress Calculation 1308, Pipe 10016-1"-HE7, Rev. O, 1-16-84.

Z-DFO-MO617 - Stress Calculation 1309, Pipe 10017-1"-HE7, Rev. O, 1-18-84.

Z-DGB-MO618 - Stress Caiculation 1310, Pipe 10100-1 1/2"-

GE3, Rev. O, 2-22-84.

Z-DGB-MO619 - Stress Calculation 1311, Pipe 10101-1 1/2"-

GE3, Rev. O, 2-27-84.

Z-DGB-MO620 - Stress Calculation 1312, Pipe 10104/10105-1 I 1/2"-GE3, Rev. O, 11-21-83.

Z-DGB-MO621 - Stress Calculation 1313, Pipe 10106/10107/10112/10113-1"-GE2, Rev. O, 11-17-83.

Z-DGB-MO622 - Stress Calculation 1314, Pipe 10408/10409-2 1/2"-HE7, Rev. O, 11-17-83.

Z-DMW-MO623 - Stress Calculation 1315, Pipe 66002-2 1/2"-

HD2, Rev. O, 11-17-83.

Z-DMW-MO624 - Stress Calculation 1316, Pipe 66003-2"-HD2, Rev. O, 11-21-83.

28

.~ . ,_ ,- -

q q Z-DGB-MO627 - Stress Calculation 1321, Pipe 10504/10505-3/4"-HD2, Rev. O, 11-14-83.

Z-DGB-MO628 - Stress Calculation 1322, Pipe 10506/10507-3/4"-HD2, Rev. O, 11-20-83.

Z-DGB-MO629 - Stress Calculation 1323, Pipe 10508/10509-3/4"-HD2, Rev. O, 11-16-83.

Z-DGB-MO630 - Stress Calculation 1324, Pipe 10510/10511-3/4"-HD2, Rev. O, 11-20-83.

Z-DFO-MO631 - Stress Calculation 1325, Pipe 10000/10001-4"-HE7, Rev. O, 11-29-83.

Z-DFO-MO632 - Support Calculation 1301A, Pipe 10002/10003-2"-HE7, Rev. O, 11-16-83.

Z-DFO-MO633 - Support Calculation 1302A, Pipe 10006-2"-

HE7, Rev. O, 9-29-83.

Z-DFO-MO634 - Support Calculation 1303A, Pipe 10007-2"-

HE7, Rev. O, 11-16-83.

Z-DFO-MO635 - Support Calculation 1340A, Pipe 10010-1 1/2"-HE7, Rev. O, 1-13-84.

Z-DFO-MO636 - Support Calculation 1305A, Pipe 10011-1 1/2"-HE7, Rev. O, 3-2-84.

Z-DFO-MO637 - Support Calculation 1306A, Pipe 10014-1"-

HE7, Rev. O, 1-16-84.

Z-DFO-MO638 - Support Calculation 1307A, Pipe 10015-1"-

HE7, Rev. O, 2-24-84.

Z-DFO-MO639 - Support Calculation 1308A, Pipe 10016-1"-

HE7, Rev. O, 1-16-84.

Z-DFO-MO640 - Support Calculation 1309A, Pipe 10017-1"-

HE7, Rev. O, 1-18-84.

Z-DGB-MO641 - Support Calculation 1310A, Pipe 10100-1 1/2"-GE3, Rev. O, 2-22-84.

Z-DGB-MO642 - Support Calculation 1311A, Pipe 10101-1 1/2"-GE3, Rev. O, 2-28-84.

Z-DGB-MO643 - Support Calculation 1312A, Pipe 10104/10105-1 1/2"-GE3, Rev. O, 11-22-84.

Z-DGB-MO644 - Support Calculation 1313A, Pipe 10106/10107/10112/10113-1"-GE2, Rev. O, 11-17-83.

29

__ __ _ - . . _ . _ _ . _ __~. -

Z-DMN-MO645 - Support' Calculation 1315A, Pip 2 66002-2"/l"-BD2, Rev. O, 11-17-83.

Z-DMW-MO646 - Support Calculation 1316A, Pipe 66003-2"-

HD2, Rev. O, 11-21-83.

Z-DGB-MO649 - Support Calculation 1321A, Pipe 10504/10505-3/4"-HD2, Rev. O, 12-8-83.

Z-DGB-MO650 - Support Calculation 1322A, Pipe 10506/10507-3/4"-HD2, Rev. O, 11-29-83.

Z-DGB-MO651 - Support Calculation 1323A, Pipe 10508/10509-3/4"-HD2, Rev. O, 11-16-83.

Z-EDS-E0087 - Calculation A5.08.2.95 - Motor (Class

1) O/L Motor Heater Operation at Low Voltage, Rev. 2 Z-EGS-E0089 - Calculation A5.08.2.99 - Diesel Generator Radiator Fan Running Current, Rev. 1 Z-EGS-E0094 - Calculation A5.08.2.111 - Voltage Controlled O/C Relay Setting for Diesels, Rev. 2, 10-15-85 Z-EGS-E0095 - Calculation A5.08.2.112 - Voltage Relay Settings on Diesel Generators, Rev. 1, 10-8-84 Z-EGS-E0096 - Calculation A5.08.2.ll3 - Negative Sequence Relay Settings for Diesel Generators, Rev.

1, 10-8-84 Z-EGS-E0097 - Calculation AS.08.2.ll4 - Voltage Balance Relay Settings for Diesel Generators, Rev.

+ 1, 10-8-84 Z-EGS-E0098 - Calculation A5.08.2.ll5 - Generator Ground Voltage Relay (459G) Settings, Rev. 1, 10-15-85 Z-EGS-E0099 - Calculation A5.08.2.116 - Diesel Generator Reverse Power Relay (432) Settings, Rev.

1, 10-8-84 Z-EGS-E0100 - Calculation AS.08.2.117 - Diesel Generator Loss of Field Relay (440) Settings, Rev.

1, 10-15-85 Z-EGS-E0101 - Calculation A5.08.2.ll8 - Permissive Voltage and Frequency Relay Settings, Rev. 1, 10-8-84 Z-EGS-E0102 - Calculation AS.08.02.119 - Diesel Generator Field Ground Detector Relay Settings, Rev.

O, 3-12-84 30

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Z-EGS-E0103 - Calculcticn A5.08.2.122 - Diccal Generator Differential Relay Settings, Rev. 1, 10-8-84 Z-EGS-E0106 - Calculation A5.08.2.132 - Ampacity and Voltage Drop of 125VDC Circuit to Generator Control Panel, Rev. O,~6-22-84 Z-EDS-E0lli - Derating 250 and 350 MCM Cable Inside Insulated 3" Conduit, Rev. O, 1-30-85 Z-EDS-E0ll8 - Calculation A5.08.2.138 - Feeder Cable and Breaker Sizing, Non-Class 1 MCCs S2C8 and S2D7, Rev. O, 8-27-84 Z-SEP-E0164 - Separation Requirements for Non-Class 1 Circuits in Panel H2EW, Rev. O, 5-28-85 Z-SEP-E0183 - Separation Requirements for Non-Class 1 Circuits in Switchgear S4A2 and S4B2, Rev. O, 4-16-85 Z-EGS-E0573 - Design for Replacement of Diesel Generator Differential Relays (487), Rev. O Z-EDS-E0629 - Load Study on Inverters SlGA and SlGB, Rev. O, 10-10-86 Z-EGS-E0647 - Field Flash Circuit Burden, Rev. 0 Z-EGS-E0655 - Power Demand for 125VDC Control and Monitoring Circuits, Rev. O Z-EGS-E0658 - Size Verification of Diesel Generators: GEA, GEB, GEA2, GEB2, Rev. 0 Z-EGS-E0665 - Load Summary and Voltage Drop Calculations for 125VDC Feeders, Rev. O Z-EGS-E0668 - Design of Wattmeter, Varmeter and Voltmeter in Main Control Room, Rev. O Z-EGS-E0669 - Sizing Diesel Generator Field Cables, Rev. 0

2. HVAC Systems for the Diesel Generator Building A. Design Features The D/G Building HVAC system is designed to meet the criteria established in Section II.2.

31 n , . - - . .

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1. Normal HVAC D/G Building control rooms normal package DX~ air conditioning units (U-357A for Train A and U-3578B for Train B) furnish conditioned air during normal plant operation to maintain the room temperature in the Diesel Generator Control Room below 900F. The cooling coil bank is rated for air entering at 92.00F (b, 69.00F wb and leaving at 67.DoF db, 61.0oF wb.

An enthalpy control allows automatic control of dampers internal to U-357A and U-357B for admitting

. cool, filtered outside air and providing economizer cooling when possible. Both units receive power from separate 480V non-Class 1 power sources.

The filter efficiency of the normal package DX air conditioning units for dust removal is at least 60%

when tested according to ASHRAE atmospheric dust spot test, method 52-68. The pressure drop for clean filters is rated at 0.50 inches water and for dirty filters is at 1.00 inches water.

A belt driven centrifugal supply fan in the DX air conditioning unit circulates the conditioned air.

The designed air flow of the supply fans will be 3,240 CFM per train. The package air conditioning units are located on the roof at elevation 34'-6".

2. Essential Ventilatino Systems

a. D/G Buildina Control Rooms The essential air handling units AH-DG-1A for Train "A" and AH-DG-1B for Train "B" furnish outside air during emergency operation to maintain the control room temperature at 70F above outside ambient temperature which limits the maximum to 122oF. The two systems receive power from their respective 480V Class 1 power sources.

The filter efficiency of the air handling unit for dust removal is 60% when tested according to the ASHRAE atmospheric dust spot test, method 52-68. The pressure drop for clean filter is rated at 0.50 inches water and for dirty filter is at 1.2 inches water.

The centrifugal fan in the air handling unit supplies 100% outdoor air into the control room.

The designed air flow is 11,000 CFM per air handling unit. The air handling units are located in the Mezzanine floor rooms at elevation 18'-6".

32 x .-. - . . +_--x=-,----------___-_-=______--_-_n_n- -- -

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b. Diesel Generator Rooms The diesel generator rooms will be provided with separate essential exhaust fan EF-556A for Train A and EF-556B for Train B. The exhaust fans remove the hot air within the D/G Building with a designed air flow of 82,500 CFM per train, allowing cooler air to circulate during emergency operation. The temperature in the diesel generator room will not exceed 250F above outside

ambient temperture (to a maximum of 1400F). Power for the fan drive motors is obtained from their respective Class 1 power sources.

3. System Ooerational Reauirements

1. The modes of operation of the D/G Building HVAC systems for each train are shown in Table 1.

2. The D/G Building HVAC system temperature controls are shown in Table 2.

3. Damper positions for each train are as listed in Tables 3 and 4.

B. Design Calculations Z-HVS-M0274 - Calculation M13.18, D/G Building HVAC Calculation and Equipment Selection, Rev. 3. 8-27-82 Z-HVS-M0275 - Calculation M13.19, Switchgear Room and Diesel Generator Control Room Temperature Analysis, Rev. O, 2-2-82 Z-HVS-M1997 - Outside Air Temperature Prediction to Maintain Diesel Generator Control Room Temperature, Rev.

O, 8-26-86.

33

'\ O di Tzblo 1 EQUIPMENT MODE OF OPERATION Normal Plant Essential Plant Activation of SyJt03 Description and Operation Operation Fire Protection Designation D.G. Not Running D.G. Running System Signal Normal Package Air Operating Operating Not Operating Canditioning Units: (recirculating) if Operable U-357A for Train A; U-357B for Train B EOCOntial Air Handling Not Operating Not Operating No Effect on Unita AH-DG-1A for See Note 1 See Note 1 Operation Train A and AH-DG-1B for Train B EOCOntial Exhaust Fans Not Operating Operating No Effect on EF-556A for Train A and See Note 2 Operation EF-556B for Train B Notens

1. Provided room temperature does not exceed 1100F l 2 Provided room temperature does not exceed 1300F l i

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34

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,q Tcblo 2 HVAC SYSTEM TEMPERATURE CONTROL tap 3ratur'a Indicating Switch or Sensing Elcment Numbers Function Power Source Train "A" TIS-55709 Energizes the normal air handling Non-Class 1E, unit U-357A to maintain the 120 VAC, temperature in the D/G Building 1 phase, 60 Hz Control Room #R-161 at 85oF TSH-55701 Energizes the essential air handling Class 1E, unit AH-DG-1A when the temperature 120 VAC, in the D/G Building Control Room 1 phase, 60 Hz reaches a temperature of 1100F l during normal conditions TSH-55707 Energizes the essential exhaust fan Class 1E, EF-556A when the temperature in the 120 VAC diesel generator room reaches a 1 phase, 60 Hz temperature of 130oF during l normal conditions Train "B" TIS-55710 Energizes the normal air handling Non-Class 1E, unit U-357B to maintain the 120 VAC, temperature in the DG Building - 1 phase, 60 Hz Control Room #R-163 at 850 TSH-55702 Energizes the essential air handling class 1E, unit AH-DG-1B when the temperature 120 VAC in the D/G Building Control Room 1 phase, 60 Hz reaches a temperature of 1100F l j during normal conditions I TSH-55708 Energizes the essential exhaust fan Class 1E, i EF-556B when the temperature in the 120 VAC, room reaches but not to exceed a 1 phase, 60 Hz diesel generator room temperature of 1300F during normal conditions l l

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O Tcblo 3 TRAIN "A" DAMPER POSITION Normal Essential Dampor Plant Plant Fall Equipment and NumbJrs Location Operation Operation Position Area Served HV-55711 Supply Closed Open As Is Duct Essential ABU

AH-DG-1A for Control Room HV-55713 Exhaust Closed Open As Is (R-161) l Air Table 4 TRAIN "B" DAMPER POSITION Normal Essential D mpor -

Plant Plant. Fail Equipment and Numb 3rs Location Operation Operation Position Area Served

'HV-55712 Supply Closed Open As Is Duct Essential AHU 4AH-DG-1B for Control Room HV-55714 Exhaust Closed Open As Is (R-164) l Air r

36

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3.< Firo ProtSction Sy0t0m2 for tha Diccal GIngrator Building A. Design Calculations and Reports Z-FPS-M0310 - Calculation M31.09, Determination of D/G Building Fire Protection Water Demand, Rev. 0,-7-27-82 SP201.03F - Fire Protection Surveillance Test Report, 3-19-81 Supplier Document M31.07A-63 Grinnell Calculation on Pre-Action Sprinkler System Hydraulics for D/G Building B. Automatic Pre-Action Sprinkler System

1. The pre-action sprinkler demand is 748 gpm a't 91 psig. The allowance for inside and outside hose stations is 1,000 gpm and the total system demand is, therefore, 1,748 gpm at 91 psig. This total flow demand can be supplied by the existing fire pumps based on flow test data.

2. The sprinkler pipe is pressurized by nitrogen to 30 psig. A pressure switch (PSL-99647) is installed downstream of the check valve to provide a low pressure trouble alarm which is annunciated on the local fire control panel (H4FCP6) and in the main control room via the plant computer.

3. A pressure switch (PSH-99647) is provided downstream of the deluge valve to initiate a high pressure trouble alarm which is annunciated on the local fire control panel (H4FCP6) and in the main control room via the plant computer.

4. A-supervised outside screw and yoke gate valve (FPW-558) is provided for system shut-off. The valve closed position is indicated on the local panel (H4FCP6) and in the main control room via the plant computer.

5. The engine room and mezzanine heads are 2120F temperature rated and the diesel generator control room sprink'er heads is 1650F temperature rated.

6. The sprinkler pipe size and schedule are in accordance with NFPA 13-1980, Section 3-6.

7. The sprinkler pipe size and schedule are in NFPA 13-1980, Section 3-15 and Seismic Category I.

8. The pre-action sprinkler system are actuated by the detection system or by operation action in the D/G Building Train B control room.

37

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In the cvcnt of UPS invartor fciluro, the powar to th]

fire protection system is automatically transferred to the non-Class 1 standby source of power by a transfer switch.

Retransfer from standby power to the normal inverter power source has to be done manually.

C. Standpipe and Hose Stations Hose stations are provided in the building for manual '

fire protection. Class C hose nozzles are provided in the control room and regular nozzles in the engine room and mezzanine. Hoses are 1-1/2 inch diameter and of the required lengths to reach all areas to be protected.

D. Portable Extinguishers The portable extinguishers in the Diesel Generator Building are installed in accordance with NFPA 10-1981.

E. Fire and Smoke Detection System

1. Ionization smoke detectors are in the D/G Building Control Room.

2. Both infra-red flame detectors and photo-electric smoke detectors are in the engine room. Infra-red flame detectors and ionization smoke detectors are in the mezzanine.

3. Manual fire alarm stations are provided at each exit.

4. The automatic pre-action sprinkler system is actuated by a detector signal from fire areas 105 or 106. In addition, the normal air handling units (U-357A and U-357B) are tripped by a detector signal from fire areas 105 or 106 respectively.

F. Water Supply Separate lead-ins are provided for the automatic sprinkler system and the manual hose stations. A fire hydrant provides protection outside the building. The total demand for the D/G Building sprinkler system and hose stations can be supplied from the existing fire pumps.

G. Power Supply The 120V, single phase power is supplied from a non-Class 1 Uninterruptible Power Supply (UPS) system. The UPS uses offsite power as the primary source of power. In the event the offsite power is lost, the AC power supply to the UPS system is automatically restored after the diesel generator is connected to the 4.16kV bus. During the transition period from offsite to diesel power, the power to the fire protection system is supplied by the UPS battery.

38

4. DiCCOl GenCratcr Building Cnd Utiliticc A. General Features The architectural, electrical, mechanical, piping, and security features of the D/G Building are designed to meet the criteria established in Section II.4. The civil / structural and security featyres are discussed in detail in subsequent sections.

The new Diesel Generator Building houses two redundant trains of new emergency diesel generators with auxiliary equipment. The building is designed for separation between Train A and Train B such that the effects of fire and flooding in one train will not affect the safe operation of the other train.

The Diesel Generator Building is a two-story re-inforced concrete structure. Nominally it is 65 feet wide, 89 feet long, and 34.5 feet high with a 3-foot parapet at the roof perimeter. A mat foundation of 8.5 feet overall thickness supports the building and the diesel generators.

Air cooled radiators for the diesel engines are located outside the Diesel Generator Building (one on the east side and one on the west) and are enclosed by 18-foot hight concrete block walls. A clearance of approximately 20 feet is provided around the radiators for air-intake.

The 60,000 gallon Diesel Fuel Oil Storage Tanks are buried approximately 9 feet below grade; one to the east side and one to the west side of the building. One concrete vault is provided for each tank to house the fuel transfer pumps, piping, and associated equipment.

One 480 volt Class 1 MCC and one 480 volt non-Class 1 MCC provide power for both essential and non-essential auxiliaries required for each of the diesel generators.

The Class 1 MCCs meet the requirements of IEEE 323 and 344 and are located in the Diesel Generator Control Room associated with each train. The Class 1 MCCs are designed to operate for at least 30 days in an ambient temperature of 122 F and are powered from the 480 volt Class 1 load centers located in the Nuclear Service Electric Building.

B. Civil / Structural Features

1. Applicable codes, standards design data, and referenced documents are used.

2. Analysis and Design

a. The Diesel Generator Building, Air Cooled Radiator Foundations, Diesel Fuel Oil Storage 39

q Tcnk C:ncrcto V2. ult StructurCJ, Cnd Elcctrical M::nholca cro d:Jign d CJ C10201 ctructurca.

b. Safe shutdown Earthquake (SSE, originally designated as DBE in FSAR) is 0.25g and Operating Basis Earthquake (OBE) is 0.13g for the design of the Diesel Generator Building.

Free-field design spectra are in accordance with Regulatory Guide 1.60. Design time histories are developed in accordance with Bechtel Design Guide C-2,44, Section 2.5.

c. Modeling techniques and analytical procedures for seismic analysis of the building are in accordance with Section 3.0 of Bechtel Design Guide C-2.44. Damping values are in accordance with Regulatory Guide 1.61. Lumped parameter representation of the building are used in the analysis. Combination of spatial components of earthquake forces are in accordance with Regulatory Guide 1.92.

d. In-structure response spectra are generated in accordance with section 5.2 of Bechtel Design Guide C-2.44.

e. Concrete structural elements for Diesel Generator Building, Radiator Foundations, Diesel Fuel Oil Storage Tank Concrete Vault, and Electrical Manholes are designed in accordance with ACI 349-80, subject to additional requirements described in Regulatory Guide 1.142. The concrete block masonry wall and its footings are designed in accordance with ACI 318-77, and UBC-79.

f. Structural steel members are designed in accor-dance with AISC Manual for the Design, Fabrication, and Erection of Structural Steel for Building, Eighth Edition, 1980.

g. Exterior walls and roof slabs of Diesel Generator Building, Diesel Tank Vault, Radiator Yard, and Electrical Manholes are designed as a minimum to withstand the following tornado characteristics:

External Wind Velocity:

Minimum - 175 mph Transient Differential Pressure Peak - 1.0 poi 40

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Tornado Generated Missiles 4o X 12o X 10' wooden plank (108 lbs) at 175 mph 3" diameter, schedule 40 pipe (76 lbs) at 60 mph Automobile (4,000 lbs) at 30 mph, up to 25' above grade The northerly building doors and the radiator wall doors are designed, as a minimum, to withstand a wind velocity of 175 mph.

h. Calculation of wind force on class 1 structures is in accordance with BC-TOP-3-A.

i. Design of missile barriers for tornado missiles is in accordance with Bechtel Design Guide C-2.45. (Ductility ratios for shear were not considered in the design. Flexural response governed missle impact design.)

j. Vibration characteristics of foundations for the diesel generators are evaluated per Design Guide C-2.26.

k. Supports for Class 1E cable-trays and conduits are designed as Seismic Category I, Quality Class 1 Structures.

1. All embedded steel insert plates for the con-nection of structural steel, pipe supports, duct supports, and cable tray supports are designed as Seismic Category I structures and are designated as Class 1. .

m. Exterior louver fino are made of 3/8 inch thick steel'and are designated as Quality Class 2.

n. Structural supports for cranes are designed not to collapse during and/or after SSE.

o. Platforms, stairs, and gratings are designed as Seismic Category II/I structures and are desig-nated as Quality Class 2.

C. Desigh Calculations Z-DGB-C0119 - Calculation AS.08.3.15-01, Diesel Generator Building Design Criteria, Rev. O, 5-5-82 Z-DGB-C0120 - Calculation AS.08.3.15-02, Diesel Generator Building; Stick Model, Rev. O, 10-2-81 41

Z-DGB-C0121 - CClculcticn A5.08.3.15-03, DiCCol G:norctt:

Building; Seismic Load Summary, Rev. O, 7-30-81 Z-DGB-C0122 - Calculation A5.08.3.15-04, Diesel Generator Building; Equivalent Static Seismic Analysis, Rev. O, 10-2-81 Z-DGB-C0123 - Calculation A5.08.3.15-05, Diesel Generator Building; Wind & Tornado Analysis, Rev. 1 Z-DGB-C0124 - Calculation A5.08.3.15-06, Diesel Generator Building; Stability Analysis, Rev. O, 10-5-81 Z-DGB-C0125 - Calculation AS.08.3.15-07, Diesel Generator Building; Basemat, Rev. O, 8-2-82 Z-DGB-C0126 - Calculation A5.08.3.15-08, Diesel Generator Building; Floor Slab EL 18-6, 34-6, Rev. O, 8-30-83 Z-DGB-C0127 - Calculation AS.08.3.15-09, Diesel Generator Building; Walls from EL 0 to EL 34-6, Rev. O, 10-5-81 Z-DGB-C0128 - Calculation AS 08.3.15-10, Diesel Generator Building; Steel Floor EL 18-6, 34-6, Rev. O, 9-30-82 Z-DGB-C0129 - Calculation A5.08.3.15-11, Diesel Generator Building; Engine & Generator Pads, Rev. 1 Z-DGB-C0130 - Calculation A5.08.3.15-12, Diesel Generator Building; Insert Plates, Sleeves, Etc., Rev. O, 9-25-81 Z-DGB-col 31 - Calculation AS.08.3.15-13, Diesel Generator Building; Cable Tray Supports, Rev. O, 12-8-82 Z-DGB-col 32 - Calculation A5.08.3.15-14, Diesel Generator Building; Category 1 HVAC Duct & Supports, Rev. O, 9-13-84 Z-DGB-col 33 - Calculation A5.08.3.15-15, Diesel Generator Building; Equipment Supports, Rev. O, 3-14-83 Z-DGB-C0134 - Calculation A5.08.3.15-16, Diesel Generator Building; Miscellaneous, Rev. O, 2-16-83 Z-DGB-C0135 - Calculation A5.08.3.15-17, Diesel Generator Building; Radiator Foundation, Rev. O, 2-4-82 Z-DGB-col 36 - Calculation A5.08.3.15-18, Diesel Generator i

Building; Diesel Tank Vault, Rev. O, 11-29-82 Z-DGB-col 37 - Calculation A5.08.3.15-19, Diesel Generator Building; Concrete Masonary Wall, Rev. O, 2-23-82 Z-DGB-col 38 - Calculation AS.08.3.15-20, Diesel Generator Building; Electrical Manholes, Rev. O, 3-19-82 42

' s T gj Z-DGB-col 39 - C21culction A.08-3.15-23, DiGr@l G2narctor ,

Building; Drainage Design, Rev. O, 9-7-83 l Z-DGB-C0142 - Calculation A5.08.3.15-24, Diesel Generator Building; Verification of Mass Computer, Rev. O, 6-6-83 Z-DGB-C0565 - Calculation A5.08.3.15-25, Diesel Generator Building; Cat I HVAC Duct & Supports-Field Mod, Rev. 1 ;

Z-DGB-C0566 - Calculation A5.08.3.15-26, Diesel Generator Building; Conduit Supports-Field Modification, Rev. O, 8-1-84 Z-DGB-C0583 - Calculation A5.08.3.15, Diesel Generator Building; Conduit Supports, Rev. O, 10-3-83 ,

Z-DGB-CO692 - Diesel Generator Building; Class 2A Elect Box Support, Rev. O, 12-6-85 Z-DGB-C0715 - Diesel Generator Building Components; Wind

. & Missile Analysis, Rev. 0 Z-DGB-C0722 - Diesel Generator Building; JIB Crane Attachment to East Walls, Rev. 0 Z-DGB-CO832 - Diesel Generator Building and Radiator Wa31; PRA - 175 MPH Tornado, Rev. 0 Z-CDS-M0286 - Calculation M16.06, Diesel Generator Building Sump Pump Sizing, Rev. 1, 5-12-84 D. Building Security System

1. The Diesel Generator Building Security System is designed to meet the criteria established in Section II.4.G.

2. The following access controls are installed:

Card Reader Doors: DG 101, DG 102 Locked and Alarned Doors: DG 110, DG 107, DG 108, DG 109 Tamoer Switches (Manholes and Roof Hatch):

DG 111, DG 112, DG 113, DG 114, DG 115 (Roof Hatch)

Fire Doors (Alarmed): DG 104, DG 105, DG 103, DG 105

3. Mounting and routing of conduit and wiring does not jeopardize safety related systems.

43

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4. Tha powar eupply for th Dic:al'G:narctor Building security system is the 24V DC supply fed from the existing diesel generator backed UPS source for the plant security system.

IV. Failure Modes The failure modes of the existing emergency diesel generators have been previously identified and explained in Section 8.2 3.4 of the Safety Analysis Report for this plant. This modification adds two additional emergency diesel generators onto t he existing two trains of emergency power sources. With the new diesels in operation, train A will include the existing generator GEA and new generator GEA2, while train B will include the existing generator GEB and the,new generator GEB2. This modification will not create any new modes of failure, nor will it reduce the degree of safety of the existing diesel configuration.

The new diesel generators are completely independent of the existing machines are housed in a separate' building. The new engines do not rely upon any mechanical auxiliaries of the existing diesels. The fuel oil supplies are separate from and not cross-connected with the fuel oil supplies of the existing engines.

1. Diesel Generator Systems Unit failure is the only failure of any significance relating to the mechanical aspects of the added diesel generators.

The system design allows failure of one unit because the second redundant diesel generator unit is independent of the failed unit. Furthermore, the availability of the engines to produce emergency power after receipt of accident signals is enhanced by the design which limits the number of engine monitoring signals that can shutdown the unit (to overspeed, differential overcurrent, and low oil pressure). The electrical failure modes resulting from the addition of these emergency diesel generators and the impact on Main Control Room Instrumentation are covered in the Design Basis Report for Modification 40, ECN A-3660, which covers the electrical l power distribution system and diesel interactions with other systems.

2. HVAC Systems for the Diesel Generator Building Failure of the normal system units U-357A for Train A and U-357B for Train B will activate the emergency systems AH-DG-1A and AH-DG-1B respectively. Systems will be initiated by temperature sensing elements located in the diesel control rooms TE, TT and TSH-55701 for Train A and TE, TT, and TSH-55702 for Train B.

3. Fire Protection Systems for the Diesel Generator Building The Diesel Generator Building contains safety related systems which are to be protected by fire protection features:

44

A. S31cmic ProtGction Pipe supports and hangers for fire water piping are capable of supporting the dead weight plus seismic loads.

B. Inadvertent Operation

The pre-action sprinkler system is designed to prevent inadvertent operation. The system will be actuated by a detector signal. However, water will only be discharged from the sprinkler heads if the temperature rating of

the fusible link is exceeded.

C. Consequences if the Fire Protection and Detection System Fails to Operate A design basis fire in either train will be separated from the other area by a 3-hour fire barrier and will not affect safety-related systems or equipment in the other train.

4. Diesel Generator Building and Utilities

, The Fire Hazard Analysis Report (FHAR) will be revised to include the Diesel Generator Building. The addition of the diesel generator building and utilities does not degrade the plant's protection from fire hazards.

MCC S2A4 supplies power to essential auxiliaries of diesel generator GEA2, and MCC S2B4 supplies power to essential auxiliaries of diesel generator GEB2. Each MCC is located in its respective diesel generator control room with no common failure mode involving both MCCs.

V. SDecial Maintenance Reanirements i

The enhanced maintenance and surveillance program developed by the TDI Owners Group will be implemented, as required by Ref. 7. l VI. Soecial Oneratina Reauirements ,

1. Control and Instrument Air Limitations The starting air receivers are sized to provide air for 10 l initial starts plus control and instrument air for 30 days.of normal, uninterrupted operation of the diesels. The starting air compressors are not intended for operation after the diesels start because they are not powered from the Class 1 electrical bus nor are they designed to Class 1 standards . l The diesel engines themselves do not require engine control air to run continuously but all automatic engine trip capabilities (such as low lube oil pressure trip, high jacket water temperature trip) are lost should there be a loss of engine control air from the starting air receivers. However, l 45

& q c2 tha centrol cir prc;:uro continu23 to drep bolew ito cinrm i c;tpoint, et c m3 point c pnsunctic ccncor will cttsmpt to I use the residual air in tubing to shut down the engine. As a I result, the spring-loaded fuel rack shutdown cylinder may l partially yet momentarily close, causing a significant change of engine speed and subsequent unloading of generator loads.

If a low control air pressure alarm occurs during operation '

of the diesel generator unit, the operator has the following options:

A. Immediately shutdown the unit by utilizing the remainder of the control air or by manually closing the combustion air intake valve or the fuel oil supply valve.

B. Allow the unit to run until either the electronic high fluid temperature alarms indicate imminent malfunction or the generator unloads, and then shutdown manually.

In either of the above cases, the redundant train would then take over the emergency operations.

2. Crankshaft Qualified Load Limitations Once a qualified load capability for Rancho Seco engines has been established (see Section III.1.A), operating restrictions such as the following will be imposed, as indicated in Ref. 7 (section 2.1.3.9):

A. Technical Specifications must have load restrictions to limit surveillance testing loading to less than the qualified load.

B. Operating procedures and training should provide guidance to avoid exceeding the qualified load.

C. Crankshaft contingency inspections are required if the qualified load is exceeded.

46 1

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Table of Contents List of Acronyms and Abbreviations List of Tables List of Figures I. Executive Summary II. Background III. Offsite Power System IV. 4160/480V System V. 125 Vdc System VI. 120 Vac UPS System VII. System Interaction VIII. References 1692d i l

List of Acrcnyms and Abbreviations

1. DGB - Diesel Generator Building

2. GEA - Original plant diesel generator for "A" train. Manufactured by Bruce GM.

1

3. GEA2 - New plant diesel generator assigned to "A" train and supplementing GEA. Manufactured by TDI.

4. GEB - Original plant diesel generator for "B" train. Manufactured by Bruce GM.

5. GEB2 - New plant diesel generator assigned to "B" train, and supplementing GEB. Manufactured by TDI.

6. LOCA - Loss of Coolant Accident

7. LOOP - Loss of Offsite Power

8. MCC - Motor Control Center

9. NRC - Nuclear Regulatory Commission

10. NSEB - Nuclear Service Electric Building

11. NSST - Nuclear Service Supply Transformer

12. NUREG - Nuclear Regulatory Guide

13. SFAS - Safety Features Actuation Signal

14. STU #1 - Startup Transformer #1

15. STU #2 - Startup Transformer #2

16. UPS - Uninterruptable Power Supply 1692d 11

List cf Tables i

Table 1 -

Automatic Sequence Starting of Safety Equipment "A-A2" Train Final Plant Configuration Table 2 -

Automatic Sequence Starting of Safety Equipment "B-B2" Train Final Plant Configuration Table 3 -

Changes to the Electrical Distribution System Implemented Between 1985 and 1987 I

1692d iii

a List cf Figures Fiaures Description 1 Safety Buses 2 125Vdc Battery A2 and C2 and associated equipment 3 125Vdc B3ttery B2 and D2 and associated equipment 4 125Vdc Batteries A, 8, C, and D and associated equipinent 5 125Vdc Batteries E and F and associated equipment 6 125Vdc Battery N1 and associated equipment 7 125Vdc Batteries GA and GB and associated equipment 8 Diesel loads 9 Train A power and control assignments 10 Train B power and control assignments 11 Diesel loading 12 Combinations of 2 diesel generators which can be used to shut down the plant 13 Table of 120Vac loads fed by Channel A 14 Table of 120Vac loads fed by Channel B 15 Table of 120Vac loads fed by Channel C 16 Table of 120Vac loads fed by Channel D 17 Loads fed from Panel SIN 1-1 18 Loads fed from Panel SlGA-1 i

19 Loads fed from Panel SlGB-1 j

20 Loads fed from Panel SlJ SK-E132-1 Main One Line Diagram

SK-E132-2 One Line Diagram 125Vdc and 120Vac Distribution System l

1692d iv l

l L

m i

Descriptien of tha Electrical Distribution System at Rancho Seco I. Executive Summary

1. Purpose-This document describes the electrical distribution system at Rancho Seco after.the. implementation of all changes currently scheduled for completion by May 1,1987.

2. Summary of Changes The implementation of NUREG 0737 (Clarification of TMI Action Requirements) and NUREG 0696 (Functional Criteria for Emergency Response Facilities) required that electrical power be supplied to various new safety related systems. The existing onsite power system and power distribution system did not have adequate capacity to accommodate the new loads. The diesel generators, rated 2750kw, could not supply sufficient power for all of the new electrical loads because of limited spare capacity. The 480V load centers and MCCs did not have sufficient spaces nor spare circuit breakers. The addition of load would aggravate a marginal minimum voltage level at the MCC's.

In order to accommodate the required loads, the following changes were made to the onsite distribution system. These changes have been approved by the NRC.Il A. Two new, class lE, 4.16kV switchgear buses: 54A2, and S4B2 were added. Each can draw offsite power from 2 sources, STU #1 and STU #2.

B. Two new, Class 1E 480V load centers: S3A2 and S382 were installed. They derive power f rom the new 4.16kV switchgear S4A2 and S482 respectively.

C. Two new, Class IE motor control centers: S2A3, and S2B3 were installed. Power is supplied to S2A3 by load center S3A2.

Power is supplied to S2B3 f rom load center S3B2.

D. Four new, Class 2 MCC's: S2A2, S2B2, S208, and S2C9 were installed. Power is supplied to S2A2 and S2B2 by load centers S3A2 and S3B2 respectively. MCC S2C9 is fed from Load Center S3C2, and MCC S208 is fed from Load Center S3Dl.

E. Four new Class 1E 120Vac and 125Vdc systems were added. The systems include 4125Vdc batteries, 6 battery chargers, 4 inverters, 4 125Vdc distribution panels and 4 120Vac distribution panels. (Refer to Figures 2 and 3).

Batteries A2 and C2 derive power from MCC S2A3 and channels B2 and D2 derive power from MCC S283.

l l

l 1692d 1

One additicnal change to the ensite distributicn system, which still requires NRC approval, is the addition of two new diesel generators rated 3300kw, and the MCC's required to support their operation. The diesel generators are designated GEA2 and GEB2, and the MCC's are designated S2A4, S2B4, S207, and S2C8.

3. Conclusions All of the changes described above have been analyzed in depth both individually and collectively. The changes improve the overall reliability of the safety systems at Rancho Seco.

II. Backaround The changes described in Section I occurred in several discrete steps covering 1981 to 1985. In NRC to SMUD letter dated , lune 4,1985 the NRC approved an interim configuration of the electrical distribution system for plant operation. The addition of the TDI diesels will require changes to this NRC approved interim configuration, and the changes are described in Table 3.

III. Offsite Power System

1. System Description There has been no change to the offsite power system. It includes the 220kV transmission system (5 lines), the 220kV switchyard, two (2) startup transformers, the NSST, and the 4.16kV system from the startup and NSST transformers to the 4.16kV bus source circuit breakers. The 4.16kV, Class 1E buses can be connected to either STU #1 through the NSST or to STU #2.1 Refer to Sketch SK-E132-1.

The minimum voltage required at the switchyard is 219kV; this has I

not changed. As noted above, there ha: been an increase in electrical loading; however, elimination of certain loads, changes in operating procedures, and more stringent technical specifications have had the net effect that no change in the minimum switchyard voltage is required.3 The rating of all transformers and bus ducts is adequate to support the electrical loading.4

2. Conclusions The offsite system has the capacity and capability to supply the electrical loads of the plant. No physical changes have been made to the offsite system. The effect of new electrical loading has been analyzed and it has been found to be acceptable.

1692d 2

IV. 4160/480V System

1. Class lE System Description The Class lE 4160/480V power system is a two train system. Either train is capable of supplying sufficient power to safely shut the plant down.

The 4.16kV "A" train consists of Nuclear Service Buses S4A and S4A2. Similarly the 4.16kV "B" train consists of Nuclear Service Buses S4B and S482. Each 4.16kV nuclear service bus has its own independent diesel generator for emergency onsite power. Each 4.16kV nuclear service bus can be connected to STU #1 through the NSST or to STU #2. (Figure 1)

The 480V "A" train consists of 480V load centers S3A and S3A2 and MCC's S2A1, S2A3 and S2A4. The 480V "B" train consists of load centers S3B and S382 and MCC's S281, S283 and S2B4. Load centers S3A, S3A2, S3B and S382 derive power from 4.16kV buses S4A, S4A2, S4B and S482 respectively. Load center S3A powers MCC S2A1, load center S3A2 powers MCC's S2A3 and S2A4.

Similarly, load center S3B powers MCC S281 and load center S3B2 powers MCC's S283 and S284.

The following original plant equipment is installed in the auxiliary building:

o 4.16kV switchgear S4A and S4B o 480V load centers S3A and S3B o 480V MCC's S2Al and S2B1 o Diesel Generators GEA and GEB The separation criteria for this installation meets the requirements imposed by the NRC.2.ll

The following, new equipment is installed in the NSEB and the DGB

o 4.16kV Switchgear S4A2 and S4B2 0 480V load centers S3A2 and S382 o 480V MCC's S2A3, S2A4, S283, and S284 o Diesel Generators GEA2 and GEB2 The separation criteria for this installation meets the requirements imposed by the NRC.7 l

1692d 3

The receptable cperating voltages fcr tha system are 3733V to 4626V at the 4.16kV level and 385 to 520V at the 480V level.8,9,10 Undervoltage and overvoltage relays monitor the voltage conditions at the buses, and the following actions are initiated by the. relays at the voltages indicated.

Class lE Bus Voltage Action Ref. #

All 4160V 3771V 38V Trip from offsite 8, 11 or less source All 4160V 4500V 23V Overvoltage alarm 8 or greater All 480V 420V i 4V or Undervoltage alarm 8 less All 480V 504V SV or Overvoltage alarm 8 greater Each Class 1E 4.16kV bus is equipped with a coincident logic undervoltage protection scheme. In the event of a LOOP, this scheme, using two out of three logic, will separate the bus from the of f site system, initiate transfer to the onsite source (i.e.

the diesel generator), and it initiates automatic load sequencing.

An independent load sequencing scheme is implemented for each 4.16kV bus. If an SFAS should occur the sequencers are actuated.

The 2 sequence schemes for buses S4A and S4A2 respond concurrently to an SFAS signal which occurs without a LOOP (i.e. the power for the Class lE, safety related system is derived from the offsite system). The 2 schemes respond independently to an SFAS signal which occurs coincident with, occurs af ter, or exists af ter a LOOP (i.e. the power for the Class 1E safety related systems is derived from the diesel generators). The 2 sequence schemes for buses S4B and S4B2 respond similarly. See Tables 1 and 2 for the specific loads making up the loading sequence for each bus. Figure 11 compares the rating of each diesel generator with the maximum load which it is expected to supply.

The power and control for each safety system is wholly assigned to one diesel generator. This was implemented in order to preclude any undesirable interaction as a result of one diesel generator operating and the other (same train) not operating. Figures 8, 9 and 10 show the assignments of system loads. Figure 12 identifies the four combinations of two diesel generators which can safely shut the plant down.

1692d 4

E The 480V lead centsrs S3A and S3A2 have a bus tie ccnnecticn. The connection is intended to be used when the plant is in shutdown mode, and it is necessary to perform maintenance on load center transformers X43Al or X43A2 or switchgear S4A or S4A2 respectively. 480V load centers S3B and S382 have a bus tie connection also, and it is available for the same reason.

2. LER 86-17 and IE Notice NO. 86-70 LER 86-1713 for Rancho Seco indicated that Diesel Generator GEA could be overloaded as a result of the aux feedwater pump P319 being automatically sequenced onto the bus S4A, and the pump operating at runout conditions.

IE Notice No. 86-70 identified 2 basic design deficiencies at Turkey Point. Units 3 and 4:

A. The diesel generators could be overloaded B. A single failure causing one diesel generator to fail to operate would result in the'other diesel generator running out of fuel As indicated on Figure 11 the diesel generators at Rancho Seco are not overloaded.5, No interaction between diesel generators occurs at Rancho Seco.12 The system interaction is discussed in more detail in Section VII.

3. Non 1E System Six (6) new MCC's were added to the non-lE 480V system. they were designated S2A2, S282, S2D7, S208, S2C8, and S2C9. These MCC's were added to support non-class lE power requirements in the NSEB and the DGB, and to provide a diesel backed source for certain pressurizer heaters. .The additional load resulting from MCC's S207, S2D8, S2C8 and S2C9 is minimal, and has no impact on the Class lE system.3 MCC's S2A2 and S282 supply diesel backed power to the pressurizer heaters, from the Class 1E system.

MCC's S2A2 and S282 were purchased and installed meeting Class 1E criteria. At the present time they are classified as non-Class 1E and in the event of LOCA they are tripped off the Class 1E system.

V. 125Vdc System

1. Class lE System Description The Class lE 125Vdc system is divided into 4 channels: A,B,C and D. Figures 2, 3 and 4 show all of the equipment and the associated interconnections within each of the channels. Each channel basically consists of 2 batteries plus individual chargers and distribution panels. Batteries A and A2 are assigned to channel A, batteries B and B2 are assigned to channel B, batteries C and C2 are assigned to channel C, and batteries 0 and D2 are 1692d 5

assigned to chann21 D. Batteries A2, B2, C2 and D2 were addsd to support the NUREG 0737 and NUREG 0696 effort. Batteries A, B, C and D were replaced with new lead calcium batteries in 1986, because the old batteries were at the end of their life.

Batteries' A, B, C, D and their associated equipment are installed in the auxiliary building. The separation criteria for this installation meets the requirements imposed by the NRC.2,ll Batteries A2, B2, C2, 02 and their associated equipment are installed in the NSEB. The separation criteria for this installation meets the requirements imposed by the NRC.7 The equipment is Class lE and it is qualified in accordance with IEEE -

323 (1974) and IEEE 344 (1975) and the appropriate daughter documents.

Normal system operating voltage is maintained by the charger at 130Vdc and this corresponds to a float charge of 2.17 volts per cell. The maximum system voltage is 140Vdc and it occurs when the battery chargers provide an equalizing charge to the batteries, or when the batteries are being recharged. The voltage at the dc distribution panels is monitored by the plant computer. When it drops to 125Vdc the plant computer generates an alarm indicating that the battery charger has failed.

The 125Vdc systems draw power from the Class lE 480V system.

Figure 4 shows that the 125Vdc systems associated with batteries A and C are backed up by diesel generator GEA thru battery charges H4BA and H4BC respectively. In the event of failure of one of the normal chargers, H4BA and H4BC are backed up by a single battery charger, H4BAC. H4BAC in turn is backed up by diesel generator GEA2. Figures 2, 3 and 4 show that batteries B and D, A2 and C2, and B2 and D2 are designed similar to battery A and C.

4 The 125Vdc buses associated with batteries A and C supply any dc loads required for those safety systems backed by diesel generator GEA. The batteries are backed by a normal charger powered from GEA. Similarly buses associated with batteries A2 and C2 supply systems backed by diesel generator GEA2. The normal battery chargars for A2 and C2 are powered from GEA2. Batteries B and D supply systems backed by diesel generator GEB and their normal chargers are backed by GEB. Batteries 82 and D2 supply diesel l generator GEB2 and their normal chargers are backed by GEB2.

{ Refer to Sketch SK-E132-2.

i

2. Non-Class lE System The Non-Class lE 125Vdc system consists of batteries, E, F, N1,

< BGA, and BGB plus associated battery chargers and distribution panels. Refer to Figures 5, 6 and 7 for additional details.

This system interfaces with the Class lE, 480V system at MCC's S2A1, S2B1 and load centers S382 and S3A2. The isolation i

devices between the Class lE and non-lE systems are the battery

chargers. They are Class lE qualified, and are qualified to be j used as an isolation device.

i 1692d 6

VI. 120Vac UPS System

1. Class 1E System Description The Class lE, 120Vac system is divided into 4 channels: A, B, C and D. Figures 2 and 3 show all of the equipment and the associated interconnections within-each of the channels. Each channel is composed of 1 inverter with 2 distribution panels.

Inverter S1A2 is assigned to channel A, inverter SlB2 is assigned to channel 8, inverter SlC2 is assigned to channel C and inverter S102 is assigned to channel D. Panels S1A, SlB, Sic and SlD are original plant equipment. Panels SlA2-1, SlB2-1, S1C2-1 and S102-1 and inverters Sl A2, S182, SlC2 and SlD2 were added to

. support the NUREG 0737 and NUREG 0696 efforts.

Panels S1A, SlB, S1C and S10 are installed in the auxiliary I building. The separation criteria for this installation meets the requirements imposed by the NRC.2.11 Panels Sl A2-1 SlB2-1. SlC2-1 and S102-1, plus inverters Sl A2, SlB2, SlC2, and S102 are installed in the NSEB. The separation criteria for this installation meets the requirements imposed by the NRC.7 Each of the inverters is rated 25kVA. They supply regulated ac power at 118 Vac i 2%.

The inverters draw power from the new 125Vic system associated with their channels (refer to Figures 2 and 3). It should be noted that each 120Vac channel is backed up by 2 diesel generators. The channel A and C systems are backed by GEA2 through the de system (note that MCC S2A3 is backed by GEA2).

These same channels are also backed up by GEA via a feeder from MCC S2A1 through a 25kVA regulating transformer to the static switch (MCC S2Al is backed by GEA). Channels B and D are backed similarly by GEB2 and GEB.

Figures 13,14,15 and 16 show a breakdown of the loads fed by each Class lE UPS system. Furthermore, the loads are categorized as to which diesel generator they are ultimately associated with.

Channel A and C 120Vac UPS systems are backed by both diesel generators GEA and GEA2 as noted above. The 120Vac power requirements of safe shutdown loads associated with the same diesel generators will therefore, always be met. Similarly, the requirements for loads associated with diesel generator GEB and GEB2 will always be met. There are no unacceptable interactions.

2. Non-Class lE System The Non-Class lE 120Vac UPS system consists of the inverters:

SlG, SlN1, S1GA and SlGB, and the distribution panels associated with them: S1G2-1, SlN1-1, S1J, SlGA-1 and S1GB-1.

1692d 7

- . . . .. a

t Inverter SIG is backed up by[ diesel g:nerator GEA. Inverter SlN1 is backed up by diesel generator GEB2, and inverters SIGA and SIG8 are. backed up by diesel generators GEA2 and GEB2 respectively.

Refer to figures 5, 6 and 7 for additional details. Panel SlG2 supplies electrical power to the plant computer. Figures 17,18, 19, and 20 show the loads which are supplied by each of the other panels.

VII. System Interaction A Systems Interaction Evaluation was conducted to determine the effects of loss of one Diesel Generator and associated power distribution system in the two-diesel per train configuration 12 It included a review of system components with regard to their power supplies, and whether failure of some components within a system could' escalate or

~

aggravate an event or present confusing information to the control room operators. The results of the interaction evaluation indicate that no unacceptable interactions exist.

Figures 9 and 10 show the onsite source of power for each of the redundant systems required to safely shutdown the plant. If one diesel generator in a train fails, only those systems for which it serves as backup will be disabled. Those systems on the other diesel generator 4

making up the train will continue to function since there is no interaction between the diesels or the electrical systems which they serve. Extending this concept we can conclude that since a failure of GEA2 does not impact GEA and the safety systems it serves, GEA and GEB2 together can safely shut down the plant. Similarly GEB and GEA2 together can shut down the plant. Figure 12 shows all combinations of 2 diesel generators which can be used to safely shut down Rancho Seco.

As noted abcve, the Class lE 120Vac UPS systems are backed up by both diesel generators in the train with which they are associated (figures 2 & 3). If one diesel generator in a train fails the static switch automatically switches the system over to the other diesel in that train. Therefore, if either of diesel generators GEA or GEA2 are operating, channel A and C 120Vac UPS systems will continue to operate. If either of diesel generators GEB or GEB2 are operating,

! channels B and D 120Vac UPS systems will continue to operate. If both diesel generators in a train fail, the 120Vac UPS systems associated with the train will operate from batteries for approximately 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

i Based on the evaluation described above, the design of the four (4) diesel generator system does not include unacceptable system interactions. Future power assignments to Diesel Generators GEA2 and GE82 shall be analyzed to assure that no unacceptable system interactions are added.

{ VIII. References

1. Paragraph 1.5.13 of Rancho Seco Updated Safety Analysis Report, l

Docket 50-312. " Criterion 17" 1692d 8 i

2. Secticn 8 cf Rancho Seco Updated Safety Analysis Rep:rt, Docket 50-312, " Electrical Systems"

3. Calculation Z-EDS-E0076 Rev 3 " Class lE System Voltage Study"

4. Calculation Z-EDS-E0661 Rev. O " Class lE System Load Study"

5. Calculation Z-EDS-E0658 Rev. O " Size Verification of Diesel Generator GEA, GEB, GEA2 & GEB2"

6. DBR for ECN A3660 Rev. 7

7. SMUD letter to the NRC dated October 2,1986 Enclosure 6,

" Standard Review Plan Comparison" ,

i 8. Calculation Z-EDS-E0104 Rev. 1 "Undervoltage and Overvoltage Relay Settings ESF Switchgear"

9. SMUD letter to the NRC dated August 1,1980, John J. Mattimoe to Robert W. Reid.

10 Design Criteria 5104.1, " Electrical Systems Design"

11. NRC letter to SMUD dated June 4,1985, Amendment No. 68 to Facility Operating License No. DPT-54, Docket No. 50-312

12. Engineering Report. ERPT-E0179, " System Interaction Study of the Two-Diesel Generator Per Electrical Train Design"

13. SMUD letter to the NRC John E. Ward to J. B. Martin dated September 26, 1986 l

1692d 9

Tatie 1 - Autaentic Set.ea:e !tartie; cf fi fttyima;aent '

I

'A-A2' TF.A!Il - F3AL PLANT C3F:S;7AT :t

(

! Acc. ;taseplate: Espected '

Expected : Starting :

Leading Ser+ce :EMw:t : Tise lRattig HP! Lcad 4 : Lead A2 l L?ad ;

Train *. ' 1 Tag ! 5es:rtstion l Sec.1 (Totall 3 n KVAR : G KVAR ! GA t (.

l l 1 : ! : : :

!!!act 1 - Energ:ze at: 1 I i !

! ! I -

! ! ! I A. 0 + 15 sec :P-314 lDe:ay heat pm (1s. press inji ! 0.9 : 350 1 303 !!41 - - : 1717 : e Initial load is 298 WA decreastag to 152 UA

. 2. 10 see af ter Iss: : : ! ! l :

1 1 af ter 50 sec.

C. 0 + 0 set :S'A2 l Lead center 5:A2, and : 1.01210 KVA : - - 1 176 115 i 904 :

lS33 : Pat:r cc:tr:1 center 533 : 1 ! :

1 ** Start of the sake-up pump (high pressare inji

S';41 :9ator control center 52A1 1 1.01 !!2 UA*: 127* 84*l - -! 1420 t is delayed 3 seconds to alice its bearing tube 1 ! t I i ! ! : I eil f!cu to start.

l A. 0 + 18 sec e* lP-236 lMakeus pi.sp (high press inil ! : i 1 ! !

9. Il set af ter loss u ;iF-2:2Al i 0.71700 16:0 305 - - t 34C C. 0 + 3 set u ! ! ! ! ! '

I. ;

Blact 2 - Energire ats : 1 : i I 1 1 N'E 1: Starting signal at 0 second for the 1 1 1 1 1 1 : I folloeing events: -

l A. 0 + 25 sec l A-500A lRB energency air cocler i 4.2 : 100 t 63 37 1 - -! 521 1

E. 20 sec af ter Isss 4 'AOC lRB energercy a;r cofer 1 5.8 : 75 1 53 30 1 - - 1 32 1 A. Loss of bus sc1tage coincidental eith safety

0. 0 + 16 sec :P-462A :% clear service cooling sater pus; i 0.6 l 250 t193 109 : - - t 1112 : features actuatia.

p B. Loss of sorsal supply tus voltage af ter

' Block 3 - Energtze ats : 1 1 I I ! ! : safety features actuatia.

i 1 1 1 ! ! ! ! C. Safety features actuatica eith es less of bus ',

A. 0 + !5 sec :P-472A :htirar service ras eater puse : 0.6 : MO 13% 206 : -- -1 1775 : voltage.

B. 30 sec af ter 1:ss 534 : Rot:r control cente $34 3 ! 155 1- - 1 137 125 15 !

C. 0 + 3 sec ! : : 1 I i ! Tises given for event A above includes 10 b

. t : I ! ! ! I seconds sanimus for the combined action of 1 4. 0 + 40 sec :P-!19 IAustliary frecuater pump 1 2.5 11000 - ! 770 1 - 394 3 5094 I startieg a diesel generatar and the subsequent l B. !! set af ter less ill-50!A 14SEB essertial WAC condensor : 2.8 i 202 1 1 97 82 1 11M i b.

connection to its nuclear service bus.

i C. 0 + 31 sec ! ! ! ! ! 1 - !

Times given for event I above include 5

Sloch 4 - Energize at ! ! ; ; ; g I t g ; ; seconds masiste for connecting a diesel ;-nerator 3 3 1 3 1 : to its nuclear service bus.

1 A. 0 + 50 sec l A-544A l Diesel race ventilator fans ! 5.3 : 120 t 101 54 I - -l 65 :

s.

i B. 45 sec af ter loss l A-5448 i :

l C. 0 + 41 sec i ! I 1

i I I I I ETE 2: Each bus to and 421 has a diese! '

k I I i generator and a set:: enter.

Block 5 - Energize ats : :

l 1

i I I : (

! A. 0 + 60 sec ill-545A CR/TS: essential HVAC condensar ! 2.8 202 1- - t 97 92 i !!M *

8. 55 set af ter loss !

I t ! ! ! : , l

C. 0 + 51 su l

1 i l'

I : ;

!! t 1 ! I t 8

B1: ca 6 - Ecerg:re at: . i i I

I : 1 & k

. ! 1 ! : i : ,

1 A. 0 + !00 sec i i i I I I t :

! 8. 30 sec af ter loss :P-2914 lRB spray systee including paap l 0.5 ! 300 12% 152 1 - -i 133 8 l w 3M su af tw i l 1 _ .l. 1. : ~'

1 safety features actuatton _ _

t '

! ! I I I t

! C. 0 + 300 sec I

I I

I b

bergi:e "anually 532 ":t:r cartrol cente 532 : 1.0 ! 126 n ! - - 1 13 -: 13 : C

: : l 1 : I ! '

T;TA. : i :

1 l2062 1111 :1403 799 : I

: . I t 1

( * .

I Tatie 2 - A.t:satic Seneace Starti!:3 cf Safety Equi;aeat f

'l-32' TRAIN - FIEAL PLAKT CN!53AAi:A p4 l : I :1ce. 3asepiste: Espectes l Egetted ! Starting i Lea:t g iem.eite E;4i; sect! IIise :tatirg Pi Lsad I i Lcad 12 - : 1:ad :

Traig *B* t Tag *

es:riptica !!ec. ! (Total) : FM FVAR ! KM KVAR l G4 I I I l l l

51sch 1 - Enrgi:e at: ? 1 I i ! ! I I

. . ; f : : ! !

4. O + 15 sec lP-26:3 : Decay test pues (lon press inj} ! 0.9 i 350 t 303 1:41 - - l 1717 i - ' For 'B' Trais, Ausillary Feedwater peep P-318 is -

1 B. It se: af ter 1:ss ! ! I I l ; normally tartine drives. When P-!18 is actor .

I C. 0 + 0 sec 1332 l Lead center $32, ar.d : 1.0 ! 267 KVA I - - ! 221 151 1 1459 1 driven it cas im started by cperatsr action 5 1 1533 Matar centrol center,533 I i ! 'I i 1 seconds af ter the llect 3 loads have been 1 fS31 l Motor centrst center,531 11.0 210 G4 8173e 119el - - l 1641 1 energired.

I ! ! ! ! I t !

! A. 0 + 16 sec n iPC6 3 deus he, 'higs press inji ! 0.7 i 700 I 6:0 305 i - -1 3443 i e laitial load is 56 TV4 decreasing to 210 KV4 -

! 8. 13 see af ter 1 css ** (P2P 1 1 ! !

t C. 0 + 3 sec n ; !. I af ter 90 sec.

: ; I :

- Start of the aske-up peep thigh pressure inji

tisca 2 - Energize at g ; t :

1 1 : i is delayed 3 secords to altos its bearing tube q i 1 : 1 I I eil flas to start. -p

4. 0 + 3 sec lA-5003 lR8 energency air cooler ! 4.2 ! 100 1 63 36 i - -1 53:

i B. 20 sec af ter Icss :A-!C3 ;tB energency air ccaler 15.88 75 i 51 29 I - - t 392t C. 0 + 16 sec :P-433 l Nut! ear service casting eater pue; l 0.6 I 250 '109 I - '!!!41 i 193 -1 '

Bisch 3 - Erergt:e att t : ! i 1 : : 1 NGTE 1: Starting signal at 0 second for the t : 1 1 1 1 I 1 : fo!!ceing events:

4. 0 + 35 sec lP-473 lklear service rae sater peep 8 4.6 i 400 1 347 196 ! - - ! 1715 1

B. 30 sec af ter ! css !! 14 : Pct:r certr:1 center 5"!4 i ! lE5 : - - 1 !!7 13 ! 1325 I A. Loss of tus voltage coincideatal eith safety

C. 0 + 3 sec 1 i 1 ! ! I !

features actaation.

1 i 1 1 i ! 8. Loss of moraal supply bus voltage af ter

4. 0 + 40 sec :ti-503 53EB essential HVAC cordense- ! 2.8 ! 202 1 - -t 97 82 i - 1161 : safety features actuation.

t 8. 5 sec site Inss : 1 1 1 1 I- C. Safety featwes attoation eith no loss of bus

C. 0 + 31 sec 1 1 b-

! I i i : I voltage.

t

Black 4 - Energt.e att i : ;

1 i a i 8 Tiees given for event A above incisdes 10 l l l ; i ! ! 1 I seconds easiens for the combined actio of . -

4. 0 + 50 sec 1 A-5440 Diesel race ventilater fans ! 5.3 : 120 : 101 54 i - -! 686 I starting a diesel generator and the subsequent

i B. 45 set af ter Inss in-5443 1 i i 1 C. 0 + 41 sn !

! connection to its nuclear service bus. 'k

! I I i 1 1 Times given for event I above include 5 l Block 5 - Eaergi:e att t : ; : : ;

I 1 seconds easiens for connecting a diesel generator {

I I 1 1 1 1 to its neclear service bus.

4. 0 + 60 sec 1U-545B l CRIT 3 essential uv4" sattchgear ! 2.8 ! 202 !- - l 97 B21 1161 ! ,

! 8. 55 set af ter loss : :

! C. 0 + 51 sec ! !

I I

!* 1 1 : NCTE 2: Each has (I and 321 bas a diesel l.

l *

! ! ! . generator and a sequenter.

k. . . . . .

j

B10: k 6 - Erergize att i i

1 I !

I

! 1 I I 1

'l 1 : t ! I 't A. 0 + 300 sec :P-2?:B lFB spray systes including pasp I 0.5 i 300 ! 236 152 1 - -t 1:84 1 1 9. 30 sec after loss ! ! !

3 or 300 set af ter I i

! ! I i 1 % k' 1 ! ! t 1 i safety features actuatica I i t i 1 1 !

! C. 0 + !00 sec I I i

-(

'Ene";t:n 'alually 52!2 !?ct:r c:ntrol center 532 1.0 : !!4 KVA 1 - - t 194 i

91 134 I

P-::E 4aillary feefeate Pus; ! 2.5 1000 1- - 1 770 394 5094 1 5-TOTAL 1 I : i - l2097 E 1134 11:06 352 ! !

t l -: : ! I a

Changes to the Electrical Distributien System Implemented Between 1985 and 1987 Table 3 1987 1985 Comments 4 Vital Class lE 8 Vital Class lE Deleted 4 unreliable inverters inverters inverters Offsite and onsite Only offsite power New TDI diesel genera-

power available to available to Class 1, tors GEA2 and GEB2 were

. Class 1, 4.16kV 4.16kV Buses S4A2 and not available Buses S4A2 and S482 S482 Independent sequencer Voltage relays on There was just 1 diesel provided for each sequencers within each generator per train Class 1, 4.16kV Bus train tripped both buses in the train -

4 Overvoltage is Offsite supply to Automatic trip on OV has ala rned. Operator Class 1, 4.16kV Buses caused undesirable emer-takes action to tripped on overvoltage gency starting of diesel lower the voltage generators.

3 definite time, and 3 inverse time under- 2 step protection pro-3 inverse time under- voltage relays used per vided per NRC guidelines voltage relays used Class 1, 4.16 kV Bus per Class 1, 4.16kV Bus Class 1, 125Vdc/ C2 and D2 systems The C2 and D2 systems are-120Vac C2 and D2 installed, but not in needed for EFIC system systems placed in service loads, and for sic and service SID panel loads.

R. B. spray pumps and R. B. spray pumps and Interlock prevented over-emergency pressurizer emergency pressurizer load of DGA and DGB.

heaters not inter- heaters interlocked Pressurizers moved to i locked GEA2 and GEB2. Inter-t lock not required Use of TIE BKR between Use of TIE BKR between New, TDI diesel generator 480V Bus S3A and S3A2 S3A and S3A2 allowed if GEA2 available as source permitted only during GEA loading conditions of power during LOOP.

shutdown were at acceptable level Tie breaker no longer required

! Use of TIE BKR between The breaker automatically New, TDI, diesel gener-480V Bus S3B and S382 closed during LOOP ator GEB2 is available as l permitted only during source of power during shutdown LOOP. TIE BKR no longer l

required

{

1 i

1743d 1

Table 3 (C ntinu:d) 1987 1985 Comments Both trains A and B. Train A CR/TSC essen- New, TDI diesel generator CR/lSC essential HVAC tial HVAC loaded manu- GEA2 is available. Capa-automatically loaded ally onto diesel genera- city is adequate to when required tor GEA, train B auto support auto load loaded Both trains A and B NSEB essential HVAC New, TDI, diesel genera-NSEB essential HVAC loaded manually tors are available.

automatically loaded Capacity is adequate to when required support auto load Aux. feedwater pumps Aux. feedwater pumps Reduce load on GEA and P319 and P318 on P319 and P318 on S4A GEB. Resolve LER 86-17 Bus S4A2 and S4B2 and S4B respectively respectively 1

l l

1743d

SAFETY BUSES STARTUP #1 STARTUP#2 mm wm mv wm 6.9 K V 4 KV n-REACTOR CIRC. WATER =

OOOLANT PP PP 4 KV

, ; 2 CLASS 2 LOADS y, " NUCL. SERV. SUPPLY

,, ,, 4.16 KV ,

) ) ) ;;

N.C. N.O. N.C. N.O.

4A2 " 4A N.C. } N.O.

4B

}N.O.'}N.C.

4B2 l SEO l:',, ,;- ';

;';l SEQ l ;;;, , ; ;lSEOl ,,: ' ,; ;l SEQ]

DGA2

@DGA DGB DGB2 wu w .u wu wu mm wm mm wm 3A2 3A 480V 3B ,

382 480V N.O.

}N.O. }N.O. '}N.O.

FIGURE 1 J

MCC S2 A1 MCC S2A3 MCC S2A1 MCC,S 2 A 3 MCC S2 A1 T T I) )70A T)70A )70A. )

200A. 200A. 200A.

BATT.CHGR. BATT.CHGR, BATT.CHGR.

H4DA2 H4BA2C2 H4BC2

)300AT )300AT )300AT )300AT

, 125 VD C 125VDC , ,

' PNL SOA2' ' PNL SOC 2"

)400A ) 1000 AF )400AF )400A (NON- (NON-AUTO) AUTO) 25KVA 25KVA w w REGULATED _. __ w w REGULATED m m TRANS. BA2 - - BC2 m m TRANS.

480-120 V 48 0-120 V 1 ,2 W BATTERY BATTERY 1W ,2 W

' A 2- 'C 2' S1A2 S1C2 INVERTER INVERTER 25KVA 25KVA M AIN T. STATIC STATIC M AIN T.

BYPASS SW. XFR. SWITCH XFR. SWITCH BYPASS SW.

l l

) 100 A ) 100 A

) 100 A )225AT )225AT ) 100 A 1

1 1 1

.120VAC PNL S1A 120VAC PNL S1 A2-1 120VAC PNL S1C2-1 120VAC PNL S1C FIGURE 2 125VDC BATTERY A2 AND C2 AND ASSOCIATED EQUIPMENT

MCC _S2B1 MCC _S 2 B 3 MCC_S2B1 MCC _S 2 B 3 MCC _S 2 B1

) )70A )70A )70A )

200A. 200A. 200A.

BATT.CHGR. BATT CHGR. BATT.CHGR.

H4BB2 H4BB2D2 H4BD2

)300AT )300AT )300AT )300AT 125VDC 125VDC PNL SOB 2 PNL SOD 2

)400A )1000 AF )400AF )400A (NON- (N ON-AUTO) AUTO) 25KVA 25KVA ww REGULATED " **

w w REGULATED T m TRANS. BB2 - -

BD2

, m m TRANS.

480-120V BATTERY BATTERY 48 0-120 V 1p,2W "B 2' 'D2' 1W,2 W S182 S1D2 INVERTER INVERTER 25KVA 25KVA M AIN T. __ STATIC STATIC M AIN T.

BYPASS SW. XFR. SWITCH XFR. SWITCH BYPASS SW.

)100 A )100A

)100 A )225AT )225AT ) 100 A 1 - 1 1 1 120VAC PNL S1B

~

120VAC P'NL S182-1 120VAC PNL S1D2-1 120VAC PNL S1D FIGURE 3 125VDC BATTERY B2 AND D2 AND ASSOCIATED EQUIPMENT I

l MCC S2B1 MCC S2B3 MCC S2B1 ! '

l MCC _S2 A1 MCC_S 2 A 3 j) 100 A j) 100A 100A MCC _S 2 A1 l I) 100 A I) 100 A I) 100 A 200A. 200A. 200A.

BATT.CHGR. BATT.CHGR. BATT.CHGR. 200A. 200A. 200A.

H4BB H4BBD H4BD BATT.CHGR. BATT.CHGR. BATT.CHGR.

H4BA H4BAC H4BC

}_ _ __ __ __)

\ KIRK KEY INTERLOCK \ -KIRK KEY INTERLOCK i

')225A

)225A125VDC1)225A 1)225 125VDC A )225A )225A PNL SOB ' ' PNL SOD' 125VDC 1)225A1)225A 125 VD C

)225AF )225AF PNL SOA ' ' PNL SOC (N ON- AUTO) (NON-AUTO) 225AF )225AF

)(N ON- AUTC) (N ON- A U TO)

BB -

BD - -- --

~

BATTERY BATTERY !

B* 'D' BATTERY CATTERY

.g. .C-l FIGURE 4 I 125VDC BATTERIES A, B C AND D AND ASSOCIATED EQUlPMENT r

l MCC_S2B1 MCC _S 28 3 MCC _S 2 81 l lM _S2A1 MCC_S 2 A 3 MCC _S 2 A1 l T) 100 A T) 100 A T) 100 A I) 100 A I) 100 A I) 100 A 200A. 200A. 200A.

B ATT. CHGR. B ATT. CHGR. B ATT. CHGR. 200A. 200A. 200A.

H4BB H4BBD H4BD BATT.CHGR. BATT.CHGR. BATT.CHGR.

H4BA H4BAC H4BC i I

~~

)_ _ _ __ __)

b KIRK KEY

\

INTERLOCK KIRK KEY INTERLOCK l

l

~)225A

)225A125VDC1)225A 1)225 125 VD C A )225A )225A

, PNL SOB ' ' PNL SOD' 125 VDC 1)225A1)225A 125 VD C

)225AF )225AF PNL SOA ' ' PNL SOC (N ON- AUTO) (N ON- AUTO) 225AF )225AF

)(N ON- AUTO) (N ON- A UTO)

I l

l BB -

BD - -- --

~ ~

BATTERY BATTERY

'B' 'D" BATTERY CATTERY

.A' 'C' FIGURE 4 125VDC BATTERIES A, B, C AND D AND ASSOCIATED EQUIPMENT

MCC S2A1 MCC S2A1 MCC G281 MCCS2C1

)100A ) 125 A )125 A )100A H8TH4BEF 120VAC PWR SOURCE c LTG SWBD 200A. 200A. 200A.

) BATT.CHGR. BATT.CHGR. BATT.CHGR.

H4BE H4BEF H4BF

}-- . - - -)

-KIRK KEY INTERLOCK

)225A )400A )400A )225A 125VDC PNL SOE 125VDC PNL SOF

)150 A )400AF )1200 AF (NON- (N ON- AUTC)

AUTO) 1 1 BE gh l ) 150 A l BATTERY BATTERY E' 'F"

l l INVERTER SYNC !

25KVA !

l 1

l )100^ )

l STATIC l SWITCH l

I i l ) 100 A )100A I I I

L _ _ ._ _ _ _ _ _ _a 120VAC PNL S1G2 FIGURE 5 125VDC BATTERIES E AND F ASSOCIATED EQUIPMENT

480V POWER SOURCE LIC S3B2

)225A 200A.

BATT.CHGR.

H4BN1 I

)800AT 125VDC PNL SON 1

) 400 A }2000AF ;

(NON-AUTC) '

INVERTER 1 l

BN1 3 BATTERY '

' N 1'

)225AT 120VAC P L S1N1-1 i

l FIGURE 6 125VDC BATTERY N1 AND ASSOCIATED EQUIPMENT

MCC S2A2 MCC S3A2 MCC S382 MCC S2B2

) )225A )225A )

600A. 600A.

BATT.CHGR. BATT.CHGR.

H48GA H4BGB 50KVA REGULATED 50KVA WW WW REGULATED m m TRANS. &% TRANS.

480-120V 48 0-120 V 1 5 ,2 W INVERTER S1GA INVERTER S1GB r - - -

- q r-- - - - - - - - - - -

l l

)CB2 )CB1 l )CB1 )CB2 I I l l

l

l ; I l l = I =

INVERTER INVERTER l l j

50KVA I 50KVA I = =

l l l l = l = l

)CB4 l )CB4 l l ) cas I >=3 l l STATIC STATIC l l

l SWITCH l l SWITCH l L___________.._ _ __ _] L_ _ __ _ _ _ _ _ _ _ _ __J

)100 A BGA b BGB b BATTERY BATTERY.

"GA" GB'

)600AT )600AT

.. s 120VAC PNL S1GA-1 120VAC PNL S1GB-1

)100A 120VAC PNL S1J FIGURE 7 125VDC BATTERIES GA AND GB AND ASSOCIATED EQUIPMENT

i DIESEL LOADS ,

l j DIESEL LOADS i

l DGA(B) - BRUCE GM

HIGH PRESSURE INJECTION

DEC AY H E AT l

REACTOR BUILDING SPRAY l

REACTOR BUILDING ISOLATION l

DGA2(B2) - TDI *HVAC

AUXILIARY FEEDWATER FIGURE 8

i i

l TRAIN "A" POWER & CONTROL

~

l

SYSTEM DECAY RB EQUIP. AUX -

HPl HVAC HEAT SPRAY COOLING FEEDWKTER GEA l (BRUCE X X X X GM DIESEL DIESEL )

SOURCE GEA2 (TDI X X DIESEL)

FIGURE 9

TRAIN "B" POWER & CONTROL SYSTEM DECAY RB EQUIP. AUX HPI HVAC HEAT SPRAY COOLING FEEDWATER GU5 (BINCE X X X X Givi DIESEL DIESEL)

SOURCE GEB2 (TDI X X DIESEL)

FIGURE 10 1

4 4

l DIESEL LOADING i

RATING, kW LOAD, kW MARGIN, % '

i DGA 2750 2062 25 i

! DGA2 3300 1403 57 DGB 2750 2097 24 DGB2 3300 1506 54 1 FIGURE 11

ACCEPTABLE 2 DIESEL CONFIGURATIONS DGA DGA2 DGB DGB2 X X

X X t

! X X X X

) COMBINATIONS OF 2 DIESEL GENERATORS WHICH l CAN BE USED TO SHUT DOWN THE PLANT.

1 FIGURE 12

f 120V AC LOADS FED BY CHANNEL A GEA SYSTEM LOADS PNL S1A GEA2 SYSTEM LOADS PNL S1A2

1. REACTOR PROTECTION SYSTEM 'A*. 1. SIGNAL CONV. CAB. H4SIA.

2. REACTOR COOLANT PUMP 'A' UNDER 2. MULTIPLEXER CAB. H4CDAR7.

POWER. 3. EFIC ' A'.

3. SAFETY FEATURE ACTUATION ' A'. 4. VENTING OF RCS HIGH POINTS.

! 4. MULTIPLEXER CAB. H4CDAR3. 5. CONTROL ROOM & TSC HVAC CONTROL.

, 5. SIGNAL CONVERSION CAB. H4SCA. 6. CALCULATOR MODULE CHANNEL 'A'

6. SAFETY PARAMETER DISPLAY SPDS -A . U Y-21031.

7. SF CONTROL PANEL 'A' INSTRUMENTS. 7. CONTAINMENT WATER AND EMERGENCY

]

j 8. BATTERY ROOM 'A' FAN. SUMP LEVEL MONITORS.

l 9. CONTROL ROD DRIVE TURB. TRIP.

i 10.' POWER FEEDER GROUND PROT. SHUNT l

j TRIP S2A1.

9 4

FIGURE 13 TABLE OF 120VAC LOADS FED BY CHANNEL A l

i l

120V AC LOADS FED BY CHANNEL B GEB SYSTEM LOADS PNL S1B GEB2 SYSTEM LOADS PNL S182 1

l 1. REACTOR PROTECTION SYSTEM *B'. 1. SIGNAL CONVERSION CAB. H4S1B.

l 2. REACTOR COOLANT PUMP 'B' 2. MULTIPLEXER CAB. H4CDAR9.

! UNDER POWER. 3. SAFETY PARAMETER DISPLAY SPDS-B .

3. SAFETY FEATURE ACTUATION 'B'. 4. EFIC 'B'.

l 4. MULTIPLEXER CAB. H4CDAR5. 5. VENTING OF RCS HIGH POINTS. '

5. SIGNAL CONVERSION CABINET H4SCB. 6. CONTROL ROOM & TSC HVAC col TROL.

6. BATTERY ROOM 'B' FAN. 7. CALCULATOR MODULE CHANNEL 'B' l 7. SF CONTROL PANEL 'B'INSRUMENT. UY-21032.

8. EMERGENCY AIR AND DAMPER. 8. CONTAINMENT WATER & EMERGENCY

9. CONT. DOD DR. TURB. TRIP. SUMP LEVEL MONITORS.

10. POWER FEEDER GROUND SHUNT 1

TRIP S2B1.

FIGURE M TABLE OF 120VAC LOADS FED BY CHANNEL B

120V AC LOADS FED BY CHANNEL C GEA SYSTEM LOADS PNL S1C GEA2 SYSTEM LOADS PNL S1C2

1. REACTOR PROTECTION 1. EFIC 'C' i

SYSTEIA 'C'

2. REACTOR COOLANT PUMP 'C'

! UNDER POWER I 3. SAFETY FEATURE i

ACTUATION 'C'

4. EMERGENCY SHUTDOWN PANEL H2SD

5. CRD SYSTEM LOGIC #3

6. DBR FOR ECN R-0927 REV. 0 l 7. BATTERY RM. C FAN l

l l

l l FIGURE 15 TABLE OF 120VAC LOADS FED BY' CHANNEL C l

1 1

l 120V AC LOADS FED BY CHANNEL D i

GEB SYSTEM LOADS PNL S1D GEB2 SYSTEM LOADS PNL S1D2 i

1.- REACTOR PROTECTION 1. EFIC 'D'.

4 SYSTEM 'D'.

j 2. REACTOR COOLANT PUMP 'D' ,

l UNDER POWER.

l 3. - SIESMiC RECORDER.

l l 4. - BATTERY RM. D FAN.

5. - CRD SYSTEM LOGIC.

I FIGURE 16 TABLE OF 120VAC LOA"' FED BY CHANNEL D

PANEL S1N1-1 LOADS

}

l j

MAIN STEAM LINE RADIATION MONITORS RY-15047,RY-15048 WIDE RANGE GAS RADIATION MONITORS RE-15044,RE-15045

& RE-15546 A '

i PANELS: H4SP

> SAFETY PARAMETER DISPLAY SYSTEM H4SPDS, j H4CDAL - ANATEC REMUX CCU H4CDAR1 - COMPUTER RM 1E MUX PANEL H4FCP8 - FIRE DETECTION l

CABINET H4S1B - SIGNAL ISOLATION ;

CABINETS H4CDAR4 & 6 - WEST & EAST SWGR. RM. NON 1E MUX j

PANELS H4HTQ & H4HTR - HEAT TRACE l

TURBINE BYPASS & ATMOS DUMP VALVES FIGURE 17 LOADS FED FROM PANEL S1N1-1

I l

l i :

i

[

l l

l PANEL S1GA-1 LOADS

! . CABINET H4CDAR8 - NSEB .NON 1E MUX l

- CABINET H4SIA - SIGNAL ISOLATION CABINET i

i

- FIRE PROTECTION PANELS - H4FCP5,H4CO278,H4HCP90, i

l H4CO280,H4CO276 I

FREEZE PROTECTION - MAIN STEAM TRAIN "A" PRESSURE 1

SWITCH INSTRUMENT TUBING FIGURE 18 LOADS FED FROM PANEL S1GA-1

1 i

! PANEL S1GB-1 LOADS t

FIRE PROTECTION PANELS - H4CO277,H4HCP88,H4CO279,H4CO275 IDADS COMPUTOR SYSTEM i

- CABINET H4 CAR 2 - CONTROL ROOM NON 1E MUX

CABINET H4CDAR10 - NSEB NON 1E MUX l

FREEZE PROTECTION - MAIN STEAM TRAIN "B" PRESSURE I

SWITCH INSTRUMENT TUBING -

ICS CABINETS (DBR FOR ECN R-0927 REV. 0) l l

NNI CABINETS (DBR FOR ECN R-0927 REV. 0) l FIGURE 19 LOADS FED FROM PANEL. 81GB-1 L - - - - - - - -- --

1 i

l l PANEL S1J LOADS l

CRD SYSTEM LOGIC #2A i

. PANEL H4RH - REGENERANT WASTE CONTROL l

VIBRATION & LOOSE PARTS MONITOR l

i

COMMUNICATIONS SYSTEM i

CABINET H2 AB - AUX BOILER i

CABINET H7T262 - EMER. COMMUNICATIONS EQUIP.

ICS CABINETS ( ALTERNATE) l l

NNI CABINETS (ALTERNATE)

FIGURE 20 l LOADS FED FROM PANEL S1J

OVERSIZE DOCUMENT PAGE PULLED SEE APERTURE CARDS l

NUMBER OF OVERSIZE PAGES FILMED ON APERTURE CARDS 2 1

APERTURE CARD /HARD COPY AVAILABLE FROM RECORD SERVICES BRANCH,TIDC FT5 492-8989

,-~~r--n--- - , , - _ -

p ,_

v a.,n r DESIGN BASIS REPORT -

,_ g oAn 12/17/86 WG.E MGEST fan, m TNG 054 5 SAND ON sot sen, y A-3660, Rev. 5 None. 104353 mao = 40 m ,,,v .

l. PJRPOSE OF DESIGN CHANGE: ,

See attached.

11. DESIGN CRITERIA USED: ,

See attached.

C. CALCULATIONS & OESIGN INFORMATION: ,

See attached.

IV. FAILURE MODES.

O TMS CHANGE DOES NOT AFFECT CONTROL ROOM INSTRUMENTATION E THIS CHANGE AFFECTS CONTROL ROOM INSTRUMENTATION: SEE ANALYSIS See attached.

V. SPECIAL MAINTENANCE REQUIREMENTS:

None.

VI. SMCIAL OPERATING REQUIREMENTS Within DBR.

VI: VERIFICATION CRITERIA:

No special verification documentation and/or inspections are required to meet v/V Program commitments.

Vill. COMMENTS:

None.

y o.+

kite

ix.pOVALS: , , j %

Cd MTMUMENTATI N d@ TACMu I ((A *C OAL nGe, oMik A [ kb b

'C'7f2 Lf~F%SM "/'7"'$W n d^c"m urg casNArydcNina '

oart m swata //

oars

?. 11,1 Ar11h ? t v ll1lf Al l uct?). -l fnlI 1 I 7]n I(/L

TABLE OF CONTENTS Section Pace No.

I. Purpose of Design Change 1 A. Modifications Required II. Design Criteria 2 III. Design Basis 2 A. System Description 2 B. Operating Voltage Levels and Limits 5 C. Equipment Location and Environment 5 IV. Calculations Supporting Auxiliary Power System Addition 6 V. Equipment Failure Analysis 7 VI. Emergency Power System Interactions 7 VII. Special Maintenance Requirements 8 VIII. Special Operating Requirements 8 Table 1 - 120Vac Vital Power Buses and Inverters 9 Table 2 - 125Vdc Buses and Battery Sizing 9 Table 3 - Motor Control Centers for 1E and Non-1E Service 10 Table 4 - Load Study 10 Table 5 - Non-1E 125Vdc Buses E, F, N, and Computer Dedicated Batteries BGA and BGB 11 Table 6 - Automatic Sequence Starting of Safety 12 Equipment, "A-A2" Train Table 7 - Autcmatic Sequence Starting of Safety 13 Equipment "B-B2" Train Figure 1 -

Safety Buses, Final Configuration 14 Figure 2 - 125V Batteries A2 and C2, Final Configuration 15 1735d i

TABLE OF CONTENTS (C:nt'd)

Section Page No.

Figure 3 -

125V Batteries 82 and D2, Final Configuration 16 Appendix A - Equipment Failure Analysis A Appendix B - Operation With Interim #1 System (Cycle 6 Period: August 1983 to March 1985) B Appendix C - Operation Description for Plant Configuration From Interim #1 to Interim #2 (Cycle 7 - Beginning June 1985) C Appendix D - Electrical Distribution System's Final Plant Configuration From Interim #2 0 1735d 11

I. Purpose cf Design Ching2 The February 1983 Class 1 Electrical Distribution System could not support the new loads imposed by NUREG 0737, clarification of TMI i

- Action Requirements and NUREG 0696, Functional Criteria for Emergency Response Facilities. Deficiencies in this system were as follows:

o Insufficient spare capacity in the diesel generators (GEA and i GE8) to supply new loads of the magnitude required.

o Insufficient spare positions in the existing motor control centers for Class 1 service. NUREG 0737 and 0696 requirements added 73 new loads. See Table 3 for more details of the changes imposed by the new requirements on the present motor control centers.

i o Insufficient spare capacity in the existing Class 1 125V de and 120V ac systems including panels, batteries, battery chargers and l inverters to add additional loads required by NUREG's 0737 and 2

0696. Tables 1 and 2 list the condition of each battery and inverter with regard to capacity, the additional loads being added, and new capacity required.

1 A. Modifications Required to Correct 1983 Deficiencies i

o Add new diesel generators, GEA2 and GE82, to provide 4

sufficient additional standby power for the nuclear service loads.

o Add Class 1, 4.16 kV switchgear buses S4A2 and S482 to power the new Class 1 load centers. The new 4.16 kV switchgear will be paralleled with the existing switchgear allowing connection

through either paths of offsite power. Each of these buses will have diesel generator backup. The new 4.16 kV switchgear and associated relays and other components are qualified in

accordance with IEEE 323 (1974) and IEEE 344 (1975).

o Extend the 1200A, 5 kV non-segregated phase bus duct from the

! auxiliary building to the NSE8 to provide a feed from the NSS i transformer and from Startup Transformer #2 to the new 4.16 kV buses, S4A2 and S482. The bus duct is non-class lE as defined j by IEEE 384, is not seismically qualified but is designed such that it will not jeopardize the integrity of the Class 1 4.16 kV switchgear, or any other Class 1 equipment during or af ter a seismic event. The bus duct hangers are seismic 1

Category 1 and the design is verified by Calculation No. Z-NSE-C0112.

} '

o Add Class 1480V switchgear S3A2 and S382 to provide 480V power to new Class 1 motor control centers which serve the i auxiliary electrical equipment that is either being added or is being relocated to satisfy new requirements. They also supply power to the new "N1" battery and two new UPS systems for the plant integrated computer system. This equipment is i

4 qualified in accordance with IEEE 323 (1974) and IEEE 344 (1975).

l 1735d 1 i

o Add motsr'centrol cent:rs S2A2 and S282 to supply power to th2 prcssurizer h:ators from Clcss 1 buses to prsvide th2 required diesel generator backing in case of loss of offsite power.

The motor control centers have been purchased and installed to meet Class 1 criteria, if required in the future, but are classified as non-class 1 and are tripped off the Class 1 supply bus in the event of a LOCA.

o Add motor control centers S2A3 and S283 to provide power to numerous new equipment. These are Class 1 and are qualified in accordance with IEEE 323 (1974) and IEEE 344 (1975).

o Add four Class 1 120V ac and 125V dc systems. These are

qualified in accordance with IEEE 323 (1974), IEEE 344 (1975),

, IEEE 535 (1979), IEEE 650 (1979). These new systems are independent and redundant and are similar to the existing four channel systems.

o Add Class 1 sequencers including undervoltage sensing /

activation, in switchgear S4A2 and S482. The scheme is a two-out-of-three logic circuit which initiates the nuclear service bus unloading and loading scheme should an undervoltage condition occur. The unloading and loading circuitry is also used during Safety Features Actuation for sequencing the required loads onto offsite power, thereby maintaining acceptable voltages at the loads. The components are qualified in accordance with IEEE 323 (1974) and IEEE 344 (1975).

I. NOTE: This Design Basis Report (DBR) does not address the following modifications:

8- to -4 inverter change (ECN R-0955)

Addition of static transfer switches to the inverters (ECN R-0955)

Change of power supply to standby battery chargers

, H4BAC and H4BBD (ECN R-1127)

The DBR does accomodate the movement of the Auxilary Feed Pumps to buses S4A2[S482) (ECN A-5415N[V]) and the removal of i

the overvoltage trip and change of undervoltage sensing (ECN i

R-1045) .

I The System Interaction Evaluation ERPT-E0179 did encompass all

of the items listed above.

II. Design Criteria l

! Design criteria is described in the following system description.

i III. Design Basis A. System Description i

i Figures 1 through 3 show that the expanded auxiliary power system j at Rancho Seco meets the intent of the reference standards and documents as regards to offsite preferred power supplies and

, onsite stored energy (diesel) backup power supplies. The new 1735d 2 i

u wa ,-a- + -n,,--,y-w--r,w--w y +_-.,,4,-,y,,,gp a g m.n.,y, ,y4,__p ,m--m,,,,mw,._, ,y -__ _ _ _ _ _ _ _ _ _ _ , , s_w--,om_emw_n_-_

equipment fer tha safaty bus 2s is qualifisd as Class 1 inicccrd:nce with IEEE-323 (1974) and IEEE-344 (1975) and tha appropriate daughter documents. Separation and isolation requirements of IEEE-384 have been observed in designing the expanded capability for this safety system.

Compliance with Appendix R is achieved by installing Channel A and Chanael B equipment in separate fire areas in the NSEB separated by 3-hour fire barriers.

At the 120V ac/125V de level where 4-channel redundancy is provided, Channels A and C are separated from Channels B and D by 3-hour fire barriers. However, Channels A and B are not separt.ted f rom Channels C and D respectively.

1. 4.16 kV Buses Figure 1 shows a single-line of the safety buses after all modifications including the addition of new diesel generators. The expansion is accomplished by maintaining the original two-train system with two offsite power sources. The 4.16 kV "A" train will consist of Bus S4A and the new Bus S4A2. Similarly, the 4.16 kV "B" train has bus S4B and Bus S482. 4.16 kV Bus S4A has its original diesel generator backup and the new 4.16 kV Bus S4A2 will be provided with its own new diesel generator backup.

4.16 kV "B" train has a similar arrangement with the existing S4B Bus backed up by its original diesel generator and the new S4B2 Bus with its new diesel generator backup.

4.16 kV switchgear has a maximum rating of 1200A and 4760V.

The circuit breakers have 350 MVA interrupting capacity.

The calculated fault on the 4.16 kV system is 275 MVA. The new non-segregated phase bus duct is rated for 1200A at 5 kV and braced for 42,000A fault current.

The new 4.16 kV buses can be connected to startup transformer No.1 through the NSST or to startup transformer No. 2.

Each 4.16 kV bus is independent of the existing bus in the same train but not redundant. Loss of a 4.16 kV bus results in an incomplete train, and therefore, from the stand point of redundancy, must be considered as the loss of the complete train.

Each 4.16 kV bus is equipped with a coincident logic undervoltage protection scheme. This scheme using two out of three logic will separate the bus from the system at 3771V (undervoltage) thereby initiating diesel generator start and auto load sequence.

1735d 3

Each bus is squipped with an indsp;nd:nt siqusncing scheme.

The s'.qu;ncers fcr busss S4A and S4A2 (and S48 and S482)

will respond concurrently to an SFAS signal but independently to a loss of voltage at the 4.16 kV bus.

The loading sequence of safety equipment for the train A-A2 and B-82 is shown on Table 6 and 7.

2. 480V Buses The 480V switchgear capacity will be similarly expanded.

Train "A" will have two load centeas, the original 480V load center S3A fed from 4.16 kVA bus S4A and the new 480V load center S3A2 fed f rom the new 4.16 kV Bus S4A2. S3A and 53A2

' have a bus tie connection that can be used for maintenance purposes at the 480V level in event either of the 4.16 kV/480V transformers need to be taken out of service. The B train has a similar setup as shown in Figure 1.

The 480V switchgear is rated for 50,000A interrupting capacity. The calculated 480V bus fault is 36,000A. All motor control center feeder breakers in the 480V switchgear l S3A2 and S382 are equipped with current limiting fuses to limit the fault current at the motor control centers to less than 20,000A. The interrupting rating of the motor control center breakers is 22,000. Without the current limiting fuses the available fault current in the S3A2 and S382 system would be 27,300A. Current limiting fuses are not required in the S3A and S38 system. All MCC feeder breakers

and the other 480V switchgear breakers are equipped with ground fault relays to ensure proper overcurrent coordination in the event of ground fault. Coordination of circuit breaker tripping is such that ground fault

interrupting devices, MCC breakers, 480V switchgear breakers i' operate in proper sequence for all faults outside the related fire areas.

3. 480V Motor Control Centers l New 4 ROV motor control centers S2A2 and S2A3 are fed from l

the new A train switchgear S3A2. New 480V motor control centers S282 and S283 are fed from new B train Switchgear S382.

1

4. 120V ac and 125V dc Systems Figures 2 and 3 show the 120V ac and 125V dc system. The i

125V dc/120V ac distribution system is a four channel sys?.em. Batteries are sized for two hours and battery ,

I chargers are diesel backed. Chargers are sized to carry the normal de system load and float the battery at 2.17 volts / cell with an ac input range of 397-521 V ac. The normal operating voltage of the de system is 130V. The minimum acceptable voltage is 105V dc. During periodic equalizing charges the system voltage will be 140V dc. The 1

i i

. 1735d 4

charg:rs will comp 1;taly rcch rg; o disch rged batt:ry in 12 h:urs. In addition batt ri;s A2 and C2 hava a shared backup charger and batteries 82 and D2 have a shared backup charger. The shared battery charger is a standby unit that can be manually switched into service when necessary for replacement or maintenance of either normal charger.

Inverters rated for 25 kVA each provide a regulated AC supply at 118V ac 12% with input range of 105-140V dc.

B. Operating Voltage Levels and Limits The acceptable operating voltages for the system are 3733V to 4626V at the 4.16 kV level and 385 to 520V at the 480V level.

Undervoltage and overvoltage relays monitor the voltage conditions at the buses, and the following actions are initiated by the relays at the voltages indicated.

Class 1 Bus Voltage Action All 4160V 3771V 38V Trip from offsite or less source All 4160V 4500V i 23V Overvoltage alarm or greater All 480V 420V 4V or Undervoltage alarm less All 480V 504V i SV or Overvoltage alarm greater C. Equipment Location and Environment All new electrical distribution equipment discussed in this l report is located in the new Nuclear Service Electrical Building with the exception of motor control centers S2A2 and S282 and the battery charger H4BN1 which are located in the Auxiliary Building.

The specific ambient conditions for the electrical distribution equipment locations in these buildings are the same:

Normal i

Temperature: 50-80 Deg. F Relative Humidity: 20% at Maximum temperature 95% at maximum temperature Radiation: 1X104 rads 40 year integrated dose 1735d 5

Abnormal Temperature: 102 Deg. F - 10 events of 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months duration each New Class 1 electrical distribution equipment is qualified for these conditions.

The qualified temperature rating of the equipment in the NSEB will not be exceeded while operating with the normal or essential HVAC units available as shown in Calculations Nos. Z-HVS-E007 and Z-HVS-M0279.

IV. Calculations Supporting Auxiliary Power Systems Addition The following calculations were developed and utilized during the design of the auxiliary power system additions described above:

Calculation No. '

Calculation Desci,otion Z-EDS-E0078 Load Study on 120V ac Power Buses Z-DCS-E0079 Load Study on 125V dc buses SOE and SOF Z-EGS-E0080 Load Study on Diesel Generators GEA and GEB Z-DCS-E0081 Load Study - 125V de buses SOA, SOB, SOC, and S00 Z-DCS-E0083 125V dc battery BN1 and Battery Charger Sizing Calculation Z-DCS-E0082 Battery and Battery Chargers BA2, BB2, BC2, and BD2 Sizing Calculation to Support Load Growth on 125 V de buses SOA, 508, SOC, and SOD Z-DCS-E0084 Batteries BGA and BGB and Battery Charger Sizing Calculations to Support Computer Loads Z-EDS-E0120 Short Circuit Study of Auxiliary Power Distribution System Z-EDS-E0076 Class 1E System Voltage Study, and Under/overvoltage Trip Relaying Z-NSE-C0112 Cable Tray Supports i

l l

1735d 6 4

Calculation No. Calculation Description Z-HVS-E0077 Electrical Equipment Heat Load Estimate Z-HVS-M0279 HVAC-NSEB Interim Period Temperature Analysis Z-HVS-N0280 CR/TSC Room Emergency Condition Temperature Analysis and Power Requirement Z-EES-E0110 Loading of GEA and GE8 during Iterim #2 plant operation Z-HVS-E0297 Verification that NSEB Essential HVAC is not required Z-EDS-E0649 Breaker & Relay Settings for S38203 and

$3821 Z-EDS-E0651 UV Relay Settings for 125V DC Panels SOA2, S082, SOC 2 and S002 Z-EDS-E0661 Class 1E System Load Study Z-EDS-E0667 Tripping time in the event of undervoltage operation Z-EDS-E0648 Class 1E HVAC condensing unit voltage regulation Z-EGS-E0658 Size verification of D/G GEA, (B),

GEA2, (B2)

V. Equipment Failure Analysis No new failure modes have been added nor has the probability of failure been increased. See Appendix A for equipment failure analysis tabulation.

l VI. Emergency Power System Interactions A Systems Interaction Evaluation was conducted to determine the effects of loss of one Diesel Generator and associated power distribution system in the two-diesel per train configuration. It

included a review of system components with regard to their power

! supplies, and whether failure of some components within a system could escalate or aggravate an event or present confusing information to the control room operators.

i I

1735d 7

The r;sults cf tha int;racticn evalu ti:n indic&te that n2 unacccpt:ble intsracticns exist. Th:re are only li;ited cas2s whsr2 systems are fed by both GEA and GEA2 or GEB and GEB2 power supplies.

A summary of those cases and their interaction findings follows:

1. The Freeze Protection Circuits of Pipina and Tubina Connected to Auxiliary Feedwater Pumps (P-318 and P-319)

These pumps are powered from the new diesel generators GEA2 and GEB2 while the freeze protection circuits are powered from the old diesel generators GEA, GEB MCC's S2Al and S2Bl. These circuits will not cause system failure.

2. The Control Circuit for the Main Feedwater Pump Turbine Isolation Valve (HV-20565)

The MOV is powered from the old diesel generator GEB, MCC S281, while the EFIC initiated close signals are powered from batteries off the new diesels GEA2 and GEB2. This is not an interaction but a single failure which is addressed in the EFIC Design Basis Report (ECN A-5415; also see Proposed Amendment 152, submitted December 5, 1986). Additionally, the scenario would have happened even in a single diesel generator per train system.

3. H';drogen Monitorina Analyzer Panels (H4HMA. H4HMS)

These panels are powered by the GEA2 and GEB2 diesel generators, while the hydrogen sample pumps are supplied by either the GEA or GEB Diesel Generator respectively. Power failure to each Hydrogen Monitoring System will result in its hydrogen monitor going downscale to zero. This same downscale reading would result even if each system was fed by a single power source.

Consequently, there is no confusing information presented to the control room operators.

Based on the evaluation described above, (see Engineering Report "ERPT-E0179, System Interaction Study of the Two-Diesel Generator per Electrical Train Design"), the design basis for the four (4) Diesel l Generator System includes acceptable system interactions where

! dif ferent power sources have been utilized within a system. Future power assignments to Diesel Generators GEA, GEA2, and GEB GEB2 shall be analyzed to assure that no unacceptable system interaction is I added.

VII. Special Maintenance Requirements None VIII. Special Operating Requirements None l

1735d 8

Table 1 120V AC Vital Power Buses and Inverters Reference Calculation No. 2-EDS-E0078 Bus A B C D Existing Load, KVA 14 15.6 22.7 24.8 Usable Invereter Capacity I kVA 20 18.5 25 25 New Loads Required, kVA 12.8 12.8 8.4 8.4 New Load in Excess of Existing 31 54 24 33 Capacity, %

New Inverter Rating, kVA 25 25 25 25 I Inverter ratings are 25 kVA. Usable inverter capacity assumes all available spare capacity from the battery system is serving inverter load.

Table 2 125V DC IE Buses and battery Sizing 2 Reference Calculation Nos. Z-DCS-E0081 and E0082 Bus A B C D Total Existing Capacity - AH 664 664 580 580

(%) (19) (9) (22) (6)

Existing Spare Capacity AH 128 59 125 33 New Loads Required, AH 540 540 277 277 New Load in Excess of Existing 62 72 26 42 Capacity, %

New Battery Rating - Minimum AH 710 710 350 350

(%) (24) (24) (21) (21)

Spare Capacity New Bat - Min AH 170 170 73 73 2Ampere-Hours at 8-hour discharge rate 1735d 9

Table 3 Motor Control Centers for 1 and Non-1 Service

Reference:

Single-Line Drawings non-1 non-1 non-1 System Description Train A Train B C D E No. of Existing Con Loads 80 69 180 202 124 No. of Existing Spare Pos 7 6 69 36 30 No. of New Connected Loads 37 36 26 29 --

No. of New Spare Positions 28 32 13 12 --

No. of Existing MCCs 1 1 5 6 4 No. of New NCCs Added 33 33 2 2 --

3 0ne MCC per train for pressurizer heater loads is non-1E, but connected to 1E bus.

Table 4 Load Study Reference Calculation Nos. Z-EGS-E0080 Train A Train S kW kVA kW kVA Existing 4.16 kV 2751 3076 2740 3055 New Loads 819 944 819 944 Loads on New 4.16 kV Buses 4 1470 1675 1488 1677 Remaining Loads on Existing 1975 2233 1946 2210 4.16 kV Buses i

4 Includes new loads plus AFW pumps and emergency pressurizer heaters.

l l

1735d 10 l

Table 5 Non-1E 125V DC Buses E, F N and Computer Dedicated Batteries BGA and BG8 Reference Calculation Nos. Z-EOS-E0078, Z-DCS-E0079, E0083 and E0084 Bus Battery E F N BGA BG8 Existing Capacity - AH 9605 18005 _ _ _

Existing Spare None6 None6 Capacity - AH Existing Loads to be 480 543 - - -

Relocated - AH Spare Capacity after 32 10 - - -

Relocation - %

New Battery Rating - AH - -

12787 10505 10505 Spare Capacity - Min. % - -

12 88 88 5Ampere-hours at 8-hour discharge rate 6

Present battery capacities unable to support existing duty cycles 7Ampere-hours at 1-hour discharge rate 8 Spare capacity of new computer batteries is amount in excess of full load ratings of computer inverters 1735d 11 1

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Sacramento Municipal Utility District Rancho Seco Nuclear Generating Station Unit 1 ECN A-3660 Design Basis Report Power Distribution System Addition Appendix A Equipment Failure Analysis 4

A 1738d

APPENDIX A

0. Equipment Failure Analysis As outlined below, a single fault within the system, with postulated loss of offsite power combined with a design basis accident, does not preclude the reactor protective system, safety features, actuation system, and the safety features equipment from performing their safety functions. This failure analysis assunes that a single fault within a two (2) diesel generator train disables that train. System interactions within a two (2) diesel generator train are addressed in Section VI of this Design Basis Report.

Component Malfunction Comments and Consecuences

1. Nuclear Services Short The corresponding 4160- and 480-volt 4160-Volt Bus 4A2 circuit nuclear services switchgears and motor con-or 482 trol centers will be lost. However, each train is redundant and the loss of one train will not af fect the other train.

2. Nuclear Services Short (a) The faulted bus will be isolated by

_ .480-Volt Bus 3A2 circuit protective circuit breaker action so that or 382 4160-volt auxiliaries will not be lost.

(b) One 480-volt nur.iear service switch-gear unit and associated motor control centers will be lost. However, each train is redundant and the loss of equipment on one train will not affect the other train.

The a-c supply to two battery chargers will be lost, but the respective batteries will carry the load. One standby charger can be manually connected to charge either battery. The a-c supply to nonessential computer battery chargers will be lost, but the respective batteries will carry the load.

3. Motor Control Short The faulted motor control center will be Center. Bus 2A2 circuit isolated by protective circuit breaker or 282 action. The a-c supply to two battery chargers will be lost. Sufficient redun-dant heaters will be fed from the motor control center on the redundant train.

The pressurizer heaters are nonclass 1 but are required under certain shutdown condi-tions. The a-c supply to Post Accident Sampling System (PASS) will be lost when MCC 282 is lost. PASS is a nonclass 1 system but requires diesel generator backed emergency power to meet the three hour sampling and analysis time limit as required by NUREG 0737 Item II.B.3.

1738d A-1

. 4. Noter Centrol Short The faulted motor control center will be Center Bus 2A3 circuit isolated by protective circuit breaker or 283 action. The a-c supply to two battery chargers will be lost, but the respective batteries will carry the load. One stand-by charger can be manually connected to charge either battery. No protective function will be lost as each train is-redundant and equipment on one train will not affect the other train. . !

5. Motor Control Short The faulted motor control center will b'e ,

Center Bus 2A4 circuit isolated by protective circuit breaker or 284 action. The a-c supply to diesel genera-

tor auxiliaries will be lost. The conse-quences are identical to those of items 1 and 7. Each train is redundant and the loss of equipment on one train will not 4

affect the other train.

! 6. Any Bus or Open The consequences could, at the most, Feeder circuit result in the loss of one 4160-volt bus and the corresponding 480-volt bus and motor control center. Each train is re-dundant and the loss of equipment on one train will not affect the other train.

7. Diesel Generator Failure The consequences are identical to those of GEA2 or GEB2 Item 1 above. Sufficient redundant valves and auxiliaries are available on the other train and the loss of equipment on one trair, vill rit affect the other train.

8. Any Safety Failure Separate undervoltage detection, relaying, Features Devices and logic are provided for each diesel generator and the corresponding 4160-volt and 480-volt switchgear buses. The maxi-mum result of a failure of any component will be the loss of one diesel generator system. However, each train is redundant and the loss of one train will not affect the other train.

9. Any Load Shedding Malfunction (a) Failure-to-trip incoming circuit or Connecting breakers will result in lockout of the Circuit Breaker corresponding diesel generator. However, i

each train is redundant and the loss of one train will not affect the other train.

(b) Malfunction of a load-shedding cir-cuit breaker results in the inclusion of that load in the first block of equipment started by the corresponding diesel gener-ator. This increased loading could cause 1738d A-2

the effective loss of one diesel genera-tor. The other diesel generator system will not be affected. The other train will not be affected.

(c) Failure-to-close of one diesel gener-ator breaker will result in the effective loss of one diesel generator, as described in Item 1 above. .

10. Battery A2 or 82 Loss of One (a) If the loss of battery A2 or B2 occurred during the first 10 seconds after initiation of diesel-engine starting, the d-c feed to the corresponding 4160-volt nuclear services bus will be lost, thereby preventing automatic closure of the diesel generator breaker. Also, the d-c feed to one inverter and diesel engine and genera-tor control circuits will be lost. How-ever, the redundant train will be avail-able and unaffected. This situation is correctable by manually connecting the standby charger.

(b) If the loss of battery A2 or 82 occurred after the diesel generator breaker was closed, the battery charger will carry the above mentioned loads,

11. Battery C2 or D2 Loss of One (a) If the loss of battery C2 or D2 occurred during the first 10 seconds after initiation of diesel-engine starting, the d-c feed to one inverter will be lost during this period, but would be recovered when the a-c buses re-energize on closing the generator breaker.

(b) If the loss of battery C2 or D2 occurred after the diesel generator breaker was closed, the battery charger will carry the above mentioned loads.

1738d A-3 l _ _ _ _ . . _ _ _ . _ . _

Sacramento Municipal' Utility District Rancho Seco Nuclear Generating Station Unit 1 ECN A-3660 Design Basis Report Power Distribution System Addition Appendix B

, Operation Description for Interim #1 Plant Configuration Changes i

l l 1739d B i

1

---~.- - . . . - - . . - , . . _ _ _ , . _ _ _ . . _ _ . _ _ _ - _ _ . - , _ _ _ - - . . , _ _ . - _ . - _ _ - - . _ _ - _ . - _ _ - - - - _ _ _ - , - _ . _ _ - - , _ _ _ . - - -

TABLE OF CONTENTS

, Page I. INTRODUCTION B-1 II. OPERATION DESCRIPTION B-1 TABLES Table B1 - Automatic Sequence Starting of Safety Equipment "A" Train B-3 Table B1A - Explanation of Item 3, Block 1 from Table 1 B-4 Table B2 - Automatic Sequence Starting of Safety Equipment "B" Train B-5 Table B2A - Explanation of Item 3. Block 1 B-6 from Table 2 FIGURES B1 -

Safety Buses, Cycle 5 System B-7 S2 - Safety Buses, Cycle 6 Configuration B-8 (Interim #1) 1739d B-i

APPENDIX B I. Introduction This appendix describes the plant configuration and the changes during which were incorporated for Interim 1 opera, tion.. Interim 1 operation is defined as Cycle 6 (August 1983 to. March 1985).

II. Operation Description

1. Figure B1 shows the arrangement .of the safety buses at Rancho Seco as the plant existed during Cycle 5. The plant configuration for this Interim 1 was as shown in Figure B2. During this interim period, the required safety related or essential equipment on the '

new switchgear, motor controT centers and 120V ac/125V de systems were supplied by operating with the maintenance bus tie breakers between load centers closed at all times. There were no 4160V loads at that time.

2. In the interim configuration, operation of the safety related auxiliary power system was identical to the description in the FSAR. For "A" train loading sequence the load in Block 1 of Table B1 had been increased by 22 kW. A breakdown of the 197 kW load of item 3 of Block 1 of Table 81 is shown in Table BlA. The auxiliary feedwater pump was moved to Block 3 as documented in ECN A-3653. "B" train loading sequence for the interim period is shown in Tables B2 and B2A. Block 1 load of Table B2A was increased 157 kW.

3. The load capability of the Electrical Distribution System connected as shown in Figure B2 had been carefully studied.

a. Diesel generators GEA and GEB have ratings of 2750 kW at

.8 power factor. This corresponds to 3437.5 kVA with a kVAR capacity of 2063 kVAR. .

For the interim period the load on the diesel generator GEA for emergency conditions was increased by 22 kW and 14 kVAR to a total load of 2737 kW and 1444 kVAR or 3112 kVA. The remaining margin was 13 kW.

For generator GEB under interim period emergency conditions, i 157 kW and 99 kVAR had been added to bring the total loads to 2203 kW and 1171 kVAR or 2495 kVA. This allowed a margin of 547 kW. If it was necessary to operate auxiliary feedwater pump P-318 from generator GEB during the interim, it was i necessary to first shed battery charger loads H4BN1 and I H4BGB. Under these conditions the GEB load was 2733 kW and 1390 kVAR or 3066 kVA. The remaining margin for this l condition was 17 kW.

1 1739d B-1 i

i

b.- The tie connecticn between lead csnters has a capability cf 500 kVA. The load for this connection during the interim period was 198 kVA for non-emergency conditions. During emergency conditions the load on the tie dropped to 25 kVA.

c. The existing 4.16 Kv/480V transformers are rated 1120 kVA.

With loss of offsite power and LOCA during the interim period this load was 974 kVA with the 480V bus tie closed.

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6-3

TABLE B1A -

EXPLANATION OF ITEM 3, BLOCK 1 FROM TABLE B1 KW KVAR A. MCC S2Al

1. Existing loads less RB upper dome circulators 175.77 89.91

2. Added loads ,

a. Battery charger H4BA 2.44 1.51 B. Load Center S3A2 New Loads

1. MCC S2A3

a. Transformer / Distribution Panel, SlA3 5 4

b. Battery fans, EF-554A, C E 2.24 1.21

c. Battery charger H4BA2 7.38 4.57

d. Battery charger H4BC2 0.494 .3

2. Battery charger ll48GA 4.07 2.52 C. Total 197.39 104.02 1739d B-4

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l B-5 l

TABLE B2A EXPLANATION OF ITEM 3, BLOCK 1 FROM TABLE B2 KW KVAR

, A. MCC S2B1

1. Existing loads less RB upper ,

dome circulators 191.61 75.03

2. Added loads

a. Battery charger H4BB 2.44 1.51 B. Load Center S3A2 New Loads

1. MCC S2B3

a. Transformer / Distribution Panel, S183 5 4

b. Battery fans, EF-5548, D. F 2.24 1.21

c. Battery charger H4BB2 7.38 4.57

d. Battery charger H4802 0.494 .3

2. Battery charger H4BGB 45.47 28.18

3. Battery charger H4BN1 93.75 58.1 C. Total 348.38 173.75 l

1739d B-6

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I SAFETY BUSES -

CYCLE 6 , CONFIGURATION ,

(INTERIM # 1)

(August 1983 to March 1983)

FIGURE

8 2 e

j Sacramento Municipal Utility District Rancho Seco Nuclear Generating Station Unit 1 ECN A-3660 Design Basis Report Power Distribution System Addition Appendix C Operation Description for

. Interim #2 Plant Configuration Changes 1740d C

TABLE OF CONTENTS PAGE I. INTRODUCTION C-1 II. ,0PERATION DESCRIPTION C-1 TABLES Table C1 - Expected Loading of S2A1, S2B1 S3A2, C-8 S382. S2A3, S2B3 - For Interim #2 Plant Configuration with LOOP Involved Table C2 - Automatic Sequence Starting of C-9 Safety Equipment, "A-A2" Train -

Interim #2 Plant Configuration Table C3 - Automatic Sequence Starting of C-10 Equipment, "B-B2" Train -

Interim #2 Plant Configuration FIGURES C1 - Safety Buses, Cycle 7 Configuration C-11 Interim #2 1740d C-1

APPENDIX C I. Introduction This appendix describes changes to the plant Electrical Distribution System configuration which were implemented in going from Interim #1 to Interim #2.

II. Operation Description The configuration of the Electrical Distribution System during Interim #2 is shown in Figure C1. The Electrical Distribution System was complete except for the new diesel generators. This configuration was licensed by NRC in Amendment No. 68 to Facility Operating License No. DPT-54, Docket No. 50-312 dated June 4, 1985, and it was used during the first part of Cycle 7 beginning June 1985.

1. The backup diesel generators for the 4.16 kV buses 54A2 and S4B2 were not available following the startup of Cycle 7 During this interim #2 configuration, the safety related or essential equipment on the new load center, motor control centers, and 120V ac/125V dc systems were supplied newer from the startup transformers, through the 4.16 kV buses, dur ag normal operation and emergency operations caused by Safety Features Actuation (sequenced). If the emergency condition was a loss of offsite power (disruption of power to the 4.16 kV buses or under/overvoltage condition below/above the technical specification setpoint) or included a loss of offsite power (LOOP), the existing diesels supplied power, after sequencing the existing loads on S3A(B), S3A(B)2, S2A(B)l, S2A(B)2, and S2A(B)3. The under/ overvoltage sensing was independent, one for each bus (S4A, S4A2, S48, and S482). However, because of only one diesel and a need to repower the S3A2 and S382 buses if an under/overvoltage condition was sensed on S4A2 or S4B2 and, only starting with Cycle 7 and ending when the new diesels became available, the following interactions occurred:

a. Under/overvoltage on either S4A or S4A2 caused both bus S4A and bus S4A2 unloading schemes to operate.

b. Diesel generator GEA breaker closure started both bus S4A and bus S4A2 loading schemes,

c. Under/overvoltage on either S4B or S482 caused both bus S4B and bus S4B2 unloading schemes to operate.

d. Diesel generator GEB breaker closure started both bus S4B and bus S4B2 loading schemes.

Some new loads were added to S3A(B)2 and S2A(B)3. The maintenance bus tie was still used to supply the new buses but during an emergency condition involving a LOOP, the maintenance tie breakers were to be manually closed from the control room for the A train.

1740d C-1

- -,.,..__n - - - , , -

Tha B train maintenance tie breakers were automatically c1cstd.

Tha auxiliary feedwster pumps were not transferred to tha new 4.16 kV buses at that time and consequently, there were still no 4160V loads. MCC S2A(B)2, the pressurizer heaters, were tripped by the new sequencer and were to be manually loaded. There was no immediate time requirement for the loads on S3A2, and S2A3, and

. batteries supplied the 125V dc/120V ac loads. Therefore, the manual application of power to these loads was acceptable. The automatic loading of the B train (S382 and S283) was more conservative. Table C1 is a list of these loads. Once the maintenance tie breakers were closed the essential MCC loads and battery chargers were re-energized.

The diesel generator breakers (52-4A202 and 52-4B202) were being physically isolated from the remaining breakers and bus bar to allow independent diesel generator (GEA2 and GEB2) testing. The separation electrically was complete (bus bar, power, control, instrument and annunciation). The separation p5ysically was by switchgear compartment. With this separation the diesel generator breaker compartment was considered non-lE. When diesel generator testing w s done the created separation was undone and reconnection of the diesel generator breaker to the switchgear bus was to be done under ECN A-3748.

. 2. During non-emergency conditions the new buses S4A2 and S482 were supplied power from startup transformer #1 and #2 respectively as the primary supplies. The maintenance tie was not used. If a Safety Features Actuation (SFAS) occurred all four sequencers were actuated. The existing SFAS initiation signals used to initiate tripping and loading on buses S4A, S48, S3A, and S3B were multiplied within the SFAS cabinets using a spare auxiliary relay module to actuate the existing sequencing and the new sequencing.

The loads sequenced on S3A2 and S382 were the Control Room / Technical Support Center heating, ventilation, and air conditioning (CR/TSC HVAC) condensers (U-545A and B) and the NSEB

HVAC condensers (U-503A and B). Because the maintenance intertie l was not utilized during this condition there was no added burden to the existing generators, station service transformers, or intertie as existed during the 1983 to 1984 interim configuration. The logic of the new sequencers was essentially the same as the existing. The components were purchased to meet IEEE 323-1974 and installed in switchgear S4A2 and S482 in accordance with IEEE 344-1975. The SFAS cabinets S4SFA and HSSFB were modified for the manual SFAS pushbuttons and indications. The new diesel start /stop pushbuttons and indications were also added. These were to be made operational under ECN A-3748. All additions to cabinets H2SFA and H2SFB.were from Master Specialties, complied with existing standards, matched current control room configuration and layout principles, and were within the IEEE 344-1975 seismic qualification of these cabinets. The new sequencing tables for the period following the 1984 outage until the new diesels were available as shown in Tables C2 and C3.

1740d C-2 l

i l

l

l i

3. Emergsncy opsraticns involving a LOOP became more involv:d during the interia.#2 period dua to tha add:d loads on tha new buses S3A2 and S382 and the MCCs S2A3 and S283. The significant loads were i the CR/TSC HVAC and NSEB HVAC essential condensers on load centers S3A2 and S382, the CR/TSC essential filter fans, and the CR/TSC HVAC and NSEB HVAC essential air handlers on MCCs S2A3 and S383. '

The A-A2 train had no loads , removed, but the B-B2 train had the existing control room essential HVAC load deleted. All known loads )

at every voltage / distribution level were considered in the calculation but have not been listed here as their contribution was ;

insignificant from the voltage-current-kilowatt standpoint. l During a LOOP or SFAS and LOOP, the CR/TSC essential HVAC system and NSEB essential HVAC system were blocked from operating on the A2 bus (S3A2 and MCC S2A3) because the auxiliary feed pump P-319 was automctically loaded on bus S3A. This blocking of the essential HVAC' systems will not occur when the new diesels finally become available. This operation inhitition was required due to a lack of capacity of diesel generator GEA. Following automatic i

application of all essential loads, the anticipated manipulation of these loads allowed either, but not both, of the inhibited loads to be re-activated on the A train. The CR/TSC essential HVAC system could be actuated from the control room and the NSEB essential HVAC system could be actuated from the NSEB. With the occurrence of LOOP the CR/TSC essential HVAC system became non-redundant similar to the existing control room essential HVAC system. The diesel backed loads that were connected through the maintenance intertie during the period starting with Cycle 7 and ending with the new diesel generators becoming available were to be powered when the tie breakers were manually closed from the control room. These

loads have been identified in Table C1. The time these loads were required was well after the tie breakers would be closed. The 125V dc/120V ac loads were battery operated until the tie breakers were closed.

, The auxiliary feed pump P-318 was not automatically loaded on diesel generator GEB but was powered by steam via the Terry Turbine. It could be manually loaded onto the diesel but H4BN1 would have to be removed in addition to the two essential HVAC systems (CR/TSC and NSEB). The spare capacity of diesel generator GEB was used to power the CR/TSC essential HVAC and NSEB essential HVAC systems. An automatic circuit was provided (B train only) that would close both intertie breakers (52-3821 and 52-38203) and release the blocking circuit on the CR/TSC essential HVAC systems approximately 3 minutes after the diesel generator breaker closed.

Three minutes assured a large margin from all sequenced loads including the Reactor Building Spray Pumps. The NSEB essential HVAC system could be actuated from the NSEB following this automatic action. ~During the period when no power was available to the new CR/TSC essential HVAC system, the ducts were sealed via dampers (like a chlorine gas condition) which was the most conservative position. The temperature in the control room would increase with no cooling.

1740d C-3

Calculation Z-HVS-M0280 determined that from a normal (mbisnt i temperature of 78'F it would take 30 minutes to reach 120*F. 44.5 '

minutes to reach 140*F and, therefore, approximately 16 minutes to ,

reach 100*F where'some equipment could begin deviation from normal tolerances. The automatic repowering of the S382 bus and unblocking of the B train CR/TSC essential HVAC system at 3 minutes assured that unacceptably high temperatures would not occur. Upon automatic closure of the intertie breakers on the B train (3 minutes) all the loads on S382 and lower buses also became

energized. This repowering was far earlier than required. The pressurizer heaters (S2A2 and S2B2) were manually loaded onto the i load center S3A2 and S382 respectively, as they are today.,

4. 'The load studies for Electrical Distribution System used to justify the interim configuration following the 1983 outage were done.

during the 1979-1982 time period and were updated in new calculations or addendums. The latest information reduced the anticipated loading of the new system and further load additions were restricted until the new diesel generators were available.

a. Diesel generators

1. Diesel generator GEA had no useful spare capacity and the data was essentially unchanged from Appendix B, Paragraph i 11.1.

2. Diesel generator GEB, under Interim #2 emergency condition of LOOP and SFAS, would initially be loaded automatically with 2033 kW, 1220 kVAR or 2320 kVA. The reduction from values of Appendix B, Paragraph II.3.a came mainly from the fact that load center S3B2 was added later in the operation sequence. Additionally, some small individual load values changed.

The above initial load was further reduced to 1835 kW, 992 kVAR, or 2087 kVA, for this discussion only, due to the later starting of the Reactor Building spray pumps (automatically at 300 seconds, worst case). (Note: The automatic loading time of the R. B. spray pumps was not changed). This left a spare capacity of 915 kW, 1071 kVAR or 1409 kVA. Following the closure of the maintenance tie breakers (automatically at 3 minutes),

i the loading was increased by 126 kW, 93 kVAR or 156 kVA.

I jThe load of the CR/TSC essential HVAC system (condenser, air handler, and the filter) was 169 kW,119 kVAR, or

~

206 kVA and is also added automatically at 3 minutes.

,At 300 seconds (worst case), the Reactor Building spray pumps were also added automatically which increased the load by 197 kW,128 kVAR or 269 kVA. This brought the '

total load that was being added automatically following the 1835.kW reference value to 492 kW, 340 kVAR or j 598 kVA. The NSEB essential HVAC system could also be energized manually from the NSEB.

1740d C-4

This HVAC system load (condenser and air handler) was 151 kW,115 kVAR or 189 kVA. This brought the total additional load on GEB following the 1835 kW reference value to 643 kW, 455 kVAR or 788 kVA. This was only 70%

of the spare capacity (915 kW, etc.) of the diesel generator. This loading included the R. B. spray pump '

rather than.the pressurizer heaters which was the larger load. If the auxiliary feed pump P-318 was required on the B-82 train, the CR/TSC essential HVAC system and the NSEB essential HVAC system would have to be removed in addition to H4BN1 which was similar to the post 1983 outage interim configuration (Cycle 6) where load removal

, was also required. The loading on diesel generator GE8 given this configuration was 2746 kW,1654 kVAR, or 3205 kVA.

b. The B train maintenance intertie is rated for 630 amps contin-uous operation at 90*C. Calculation Z-EGS-E0110 documents an emergency rating of 890 amps available for 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months in any twelve months up to a total of 500 hours0.00579 days 0.139 hours 8.267196e-4 weeks 1.9025e-4 months . With worst case loading (both essential HVAC systems, pressurizer heaters and PASS loads in addition to normal loads on S382 and S283)'the current was 865 amps. The rating increase took credit for the 1 inch cable tray fill, the larger actual cable size, and 90*C r operation. This is considered conservative because part of the increased amperage was to run the NSEB essential HVAC 4

which decreased the ambient temperature the cable saw (115*F was assumed), all listed loads were assumed operating simultaneously, and at their full rating. The above conserva-tism combined with the low probability of a LOOP with SFAS occurring during this interim period supported the judgement of acceptability. The circuit breakers had trip settings such that this higher rating was lower than the setpoints minus their tolerances and still provided cable protection. The A train maintenance intertie is rated for 533 amps contin-uous operation at 90*C or 751 amps for 130*C emergency opera-tion. Full loading similar to the B loading in the previous paragraph only required 699 amps which was judged acceptable, even though it did not occur.

l c. The B train station service transformer is currently rated 1120 kVA at an 80*C temperature rise. The transformer is a

1500 kVA transformer with insulation for 150*C temperature l rise. The derating was done to provide a qualified life in l excess of 40 years. Operation at the proposed loading of 1473 kVA (117.l*C temperature rise), worst case, will reduce the qualified life by a factor of 36.36 from 940 years at 50*C ambient, 80*C rise. Because of the limited length of the

, interim configuration and the low probability of a LOOP with l SFAS occurring within the period of the potential the paper i decrease in qualified life was warranted.

i 1740d C-5

- - - . - _ . . . . _ . _ . ~

L The A' train station ssrvice transformer is a 1120 kVA oil !

filled transformer.. Bscause of a 110*C tcp oil tempsrature restriction, this station. service transformer cannot accommo-date both essential HVAC systems operating along with the other safety related loads. It can, however, accommodate operation of one essential (CR/TSC or NSEB) HVAC system. The loading on the transformer would be 1212 kVA and the resulting reduction of life factor was far less than the B train would experience. Paragraph II.4 on the diesel generator GEA, documents the limiting condition (i.e. no essential HVAC systems until other loads were removed).

d. The switchyard voltage minimum level to assure all load terminal voltages were at or above those found acceptable in the NRC Safety Evaluation Report on Adequacy of Station Electrical Distribution System Voltages (Sept. 20, 1982), was .

215 kV for both the interim #2 configuration loads and the final configuration when the diesels and currently anticipated loads are connected. Calculation Z-EDS-E0076 documents the adequacy of the furthest load's voltages with 215 kV in the switchyard and both trains being fed from either startup

. transformer (worst case configuration for the voltage study with the addition of the T&R Building load startup transformer

1 is approximately as heavily loaded as startup transformer

2). Adding the tolerance of the undervoltage relays resulted in the technical specification setpoint of 3771V at the 4.16 kV buses (equivalent to 217 kV at the switchyard). The value of 218 kV currently in the technical specifications under limiting conditions for operations was increased to 219 kV. When the diesels were operating the 4.16 kV buses were at 4160V and voltage at the loads was normal.

i

e. The continued progress toward final plant configuration authorized under the interim #2 provision of this ECN resulted in a marked improvement of the control room habitability.

Additional improvements included: supplying power to the i

redundant NSEB essential HVAC system during normal operations or emergency operations caused by an SFAS; increasing essential HVAC capacity to accommodate the technical support center; making the control room essential HVAC system redundant during normal operations or emergency operations 2

caused by an SFAS; and reducing the use of the maintenance intertie to the period following a LOOP. Control room habitability was improved by the installation of improved radiation detectors and the capability to protect against a toxic gas (chlorine only) incident by transitioning to a closed system (total recirculation mode of operation. The system also isolated the control room given a complete loss of power to the system which is a more conservative condition than the original system.

1740d C-6

The interim #2 plant configuraticn also improved the ovsrall probability of having the control room essential HVAC system.

The system was redundant during all probable events except involving a loss of offsite power. with a loss of offsite

~

power there were still two systems but because of diesel generator, station service transformer, and maintenance intertie capacity only the B train ~ system was automatically ,

powered. The CR/TSC' essential HVAC system on the A-A2 train I was not expected to be manually loaded because the auxiliary )

feed pump P-319 was automatically. loaded on diesel generator. i GEA. The B-B2 train CR/TSC essential HVAC system was l automatically loa'ded at approximately 3 minutes after the I worst case event (LOOP and,SFAS). If the auxiliary feed pump P-318 was required to be motor operated, then the CR/TSC essential HVAC system could not be'run on the B-B2 train until some other safety loads were turned off (function no longer required). P-318 was to be motor operated with a failure of the A diesel (or A train or P-319) and a failure of one main steam line and a failure of one turbine stop valve to close.in the failed steam line. This denied adequate steam to the Terry Turbine through FV-30801. The probability of this event occurring was far smaller than the loss of the B diesel which would leave our existing control room essential HVAC system without power. Without a failure of a diesel or train both CR/TSC essential HVAC systems were available and could be used as soon as loading on the respective diesel generator, station service transformer, and maintenance intertie permitted.

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CYCLE 7 CONFIGURATION (INTERIM # 2 )

(Began June 1985) -

FIGURE # C1 n - _ _ _ _ _

I Sacramento Municipal Utility District l

Rancho Seco Nuclear Generating Station Unit 1

-ECN A-3660 Design Basis Report Power Distribution System Addition Appendix D Operation Description for Final Plant

, Configuration Changes l

l l

l 1741d D

TABLE OF CONTENTS PAGE I. INTRODUCTION 0-1 II. OPERATION , DESCRIPTION 0-1 TABLES D-5 Table 01 - Automatic Sequence Starting of Safety Equipment, "A-A2" Train -

Final Plant Configuration Table 02 - Automatic Sequence Starting of 0-6 Safety Equipment, "B-B2" Train -

Final Plant Configuration FIGURES Figure D1 - Safety Buses, Final Configuration D-7 1741d D-i

APPENDIX D I. Introduction The Design Basis Report Section III describes the final system configuration. This af,pendix describes the changes required to get from interim #2 to the final configuration.

II. Operation Description With the " Interim #2" plant configuration, as discussed in Appendix C, 3'

implemented during the Cycle 7 outage, the following summarizes and serve as an aid to further discuss the changes to complete the final plant configuration of the Electrical Distribution System. With the new diesel generators (GEA2 and GEB2) available, the final plant configura-tion will be as depicted in Figure 01 whereby, during a loss of offsite power (LOOP), each 4.16 kV nuclear services bus will be powered by its own diesel generator.

1. The bus unloading schemes for bus S4A and bus S4A2 (S4B and S482) will be independent. The interdependence of bus S4A and bus 54A2 during an under/overvoltage condition that was installed will be deleted. Similarly, the interdependence of bus S4B and bus S482 during an under/overvoltage condition will also be deleted.

In the interim #2 plant configuration, the 4.16 kV buses S4A2 and S482 each have an unloading auxiliary relay which is energized and sealed-in on a bus undervoltage or overvoltage signal. This, when energized, provides a trip signal to the supply breakers from the NSST and Startup Transformer No. 2. The relay is reset only upon closure of the diesel generator breaker. In order for the operator to be able to close the supply breaker from either transformer, assuming offsite power available and with bus initially deener-gized, a modification to the unloading auxiliary relay is

( required. Using an existing spare contact of relay 462UV2, the modification provides an automatic reset of the unloading relay whenever normal voltage is impressed on the bus. This feature is similar to that of buses S4A ar.d S48. See Impell letter No. 0790-225-388.

! Removal of the interdependence of buses S4A and S4A2 (S4B and 54B2) increases the train reliability by allowing each bus to unload irrespective of the condition of the other bus. This feature as well as the added automatic undervoltage reset for the unloader does not require any new device or equipment. The automatic reset 1

enables operator closure of any startup source breaker with the bus initially deenergized and makes the system in accordance with the criteria set forth by IEEE 308-1974. This also makes the operation i

of the buses S4A2 and S482 similar to S4A and S48.

1741d D-1 i

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2. ' Diesel Generator GEA2 (GEB2) breaker cicsura will ' start bus S4A2 (S4B2) LOOP loading schene. Tha intsraction of the existing Dissel Generator GEA (GE8) breaker closure to start bus S4A2 (S482) loading scheme that was installed will be deleted.

The removal of the interdependence between S4A (S48) and S4A2 (S4B2) bus load sequencers increases the train reliability by allowing them to operate independently. No new devices or equipment are required. Wiring changes are all it takes to implement the change.

3. The maintenance tie breakers can be used when either of.the station service transformers of either train ("A" or "B") is out for maintenance, and only when the plant is shutdown. Th'e automatic closure of "B" train maintenance tie breakers (52-3821 and 52-38203) during emergency conditions involving a loss of offsite power (LOOP) that was installed will be deleted.

-The removal of autoclosure of train "B" load center tie breaker is acceptable since buses S3A and S3A2 are to be independent in the final configuration. The tie breaker is strictly for maintenance and is to be used only during plant shutdown. This autoclosure was a necessary feature for the Interim 2 configuration due to the nonavailability of the new diesel generators.

4' This change does not require any new devices or equipment. Wiring changes and a breaker coordination are all that is required to

! implement the change.

4

4. During Cycle 7, blocking circuits have been added on both the CR/TSC essential HVAC and NSEB essential HVAC systems during a LOOP or SFAS and LOOP, due to the limited capacity of the existing diesel generators (GEA and GEB). These blocking circuits will be deleted since the new diesel generators will be availa'le b in the final configuration to power these loads. The loading sequence for the final configuration is shown on Tables D1 and D2.

This change returns the CR/TSC and NSEB essential HVAC's to their designed configuration. No new devices or equipment are required.

Wiring changes are all that is required to implement the change.

S. New loads are being added to the nuclear services load centers S3A3 and S382. The new loads are S2A4 and S284 and are being added under MOD 036 ECN A-3748. These loads are sequentially loaded (Block 3) as shown on Tables D1 and D2. With the new loads being added, the total possible load on the Nuclear Services Transformer (NSST) when it is supplying both the emergency trains "A" and "B"

could be as high as 8.2 MVA (

Reference:

Calculation No. Z-EDS-E0661).

1741d D-2

However, tha NSS transformer could b2 operatId at this leval cf 109.3 parcent of rating for a period in excess of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months without any loss of life (

Reference:

ANSI /IEE C57.92-1981 Table 3a).

During this time period, the operator can take necessary actions to reduce load on NSST to within its rating. Consequently, forced air cooling of the NSS transformer will not be needed.

This change makes the final configuration of the electrical distribution system in accord with the criteria. set forth in IEEE 308-1974. This standard requires that the safety buses have access to two independent sources of offsite power.

6. The auto-close circuit of the essential HVAC condensing units U-545A(B), CR/TSC essential HVAC condenser, and U-503A(B), NSEB essential condenser, have timers which were added to allow closing

.of the load center feeder breakers during emergency condition (i.e.

LOOP or SFAS and LOOP) af ter the maintenance tie breakers closed.

The auto-close circuit will be revised to delete the timers on essential HVAC condensing unit breakers (52-3A210, 52-38210, 52-3A217 and 52-38217) and replace them with electric reset relays to provide a maintained closed permissive for the load sequencer to auto-close the breakers. Interlocks from these breakers will be added to the essential HVAC common controls to reset the HVAC compressor control circuitry. The HVAC compressor circuitry is discussed in ECN's A-3920C and A-4102C.

This change enables the HVAC units to be sequenced by the bus load sequencer without any timers at the load center breakers and with essentially the same hardware as the existing sequenced load center breakers. The addition of the load center breaker interlocks to the condenser units permits the internal circuitry to operate the same after sequencing as upon initial circuit energization.

Quality Class 1 relays are added which are qualified to IEEE 344-1975 and IEEE 323-1974. The seismic qualification of the switchgear is not affected by the above modification.

7. The closing circuit of the load center bus supply breakers l

(52-3A202 and 52-38202) will be revised to add a maintained closed permissive for the load sequencer to auto-close the breakers during LOOP. The circuit will be similar to the existing S4A and S48 feeder breakers to the load center transformers.

This change enables the sequencing of the 480V load center main breakers without the use of timers at the load center. This design is the same as Item 6 above. Quality Class 1 auxiliary relays are ,

needed which are qualified to IEEE 344- and IEEE 323-1974. The seismic qualification of the switchgear is not affected by the above change.

l 8. The existing sequencer loading lights in control room panel

! H2SFA(B) will be removed and holes covered. The sequencer loading I

status indication will be made available to the operator via IDADS.

I 1741d 0-3 i

This changa is rsquir:d fcr tha following reascns:

a. The existing visual indication provided at the control room panel is located in the back panels and below a standing line of sight making it difficult to read.

b. Visual indication is already available for the individual loads, i.e. the on-off (red and green) indicating lights.

c. Indication via IDADS is better as it provides a backup available on demand. Isolation between the Class 1 control circuit and the computer is accomplished via the multiplexer panel. Furthermore, an audible alarm can be generated from the computer.

d. The above scheme is the same as that used for the NSEB buses S4A2 and S482.

The change requires no new devices or equipment. Deletion of the indicating lights, wiring and software changes are all that are needed to implement the change.

9. The DC voltage alarms will be modified to indicate nonfunctioning of the battery chargers. The voltage at the new dc panels will be monitored so that when the voltage drops to 125 volts, it will indicate loss of input from the battery charger. .

l This is a commitment to NRC, Reference CCL #85-0314. The maximum emf of the battery is approximately 125V dc. The battery is floated at around 130V dc. A static undervoltage relay set to 125V de and a 30 second timer alarms via IDADS. The timer in the above circuit prevents undesirable alarms due to transients including the initial stage of the emergency load cycle. The relays are quality Class 1 and qualified to IEEE 344-1975 and IEEE 323-1974. the seismic qualification of the dc panels will be maintained.

f. 10. Due to the limited capacity of the existing diesel generators (GEA l and GEB), an interlock to prevent the Pressurizer Heaters from operating when the Reactor Building Spray Pump is running was added in Cycle 6. This interlock will be deleted since the new diesel generators (GEA2 and GEB2) will be available to power the Pressurizer Heaters.

This change removes a two system interlock caused by an emergency power shortage. Ther' e is no system design basis for this inter-lock. This change improves the availability of the pressurizer, heaters without degrading the diesel driven power supply.

Theabovemodificationsd4notintroduceanynewfailuremodestothe electrical power distribution system other than as already given in Appendix A-1.

1741d D-4

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ATTACEMENT TO DBR I. PURPOSE OF DESIGN CRANGE The purpose of this design change is -to improve the reliability of the vital 120V ac power supplies. The addition of static switches will provide automatic transfer of the 120V ac vital' buses to a backup ac power supply. The addition of manual bypass switches will make the vital 120V. ac system operable during inverter / static . switch outage or maintenance. This design change is not NRC mandated. II. DESIGN CRITERIA USED A.

SUMMARY

OF CHANGE Ihe power to each of the vital 120V ac buses (SLA, S13, 31C, S1D and SLA2-1, $132-1, SlC2-1, $1D2-1) is presently supplied from the associated inverters, without means of automatic transfer to a backup ac supply. This design change relocates the powe r source of buses SlA, 313, SIC and SlD to the corresponding NSE3 inverters, SlA2, S132, SlC2 and SID2. The addition of a regulating transformer, manual bypass switch and power distribution enclosure to each of the NSE3 inverter units and an independent vital 480V ac backup power source for each regulating transformer increases the availability of the vital 120V ac power. The new system will satisfy the following automatic transfer criteria:

                         . Transfer with no power source loss: Uninterrupted
          .              . Transfer time with power source loss: 4 msec. maximum
                         . Transfer time with inverter internal fault: 9 :sec, maximum The manual bypass swit ch ensures vital 120V ac power availability during inverter / static switch outage or maintenance.       The power distribution enclosure with its tap circuit breaker connects each auxiliary building inverter bus to the corresponding NSE3 inverter and provides prctection for its feeder cable.

B. DESIGN BASIS Die following NEP's are used to the design and engineering work of this design change.

1. Design Document Preparation and Control

a. 4109 - Configuration control

b. 4112 - Drawing Change Notice

c. 4106 - Design Calculations

d. 4110 - Interdiscipline Document Review

e. 4118 - Environmental Qualification Program

f. 4119 - Fire' Protection Program 3 4206 - Purchase Requests

essne. e -, Shret 2 of 7

2. Design Critcria

a. 5104.1 - Electriedl Systems Design

b. 5104.2 - Selection and Sizing of Power and control Cables

c. 5104.3 - Raceway Installation

d. 5101.3 - Seismic Classification and Design Criteria

3. Design Guides

a. 5204.1 - Symbols for Single Line and Schematic Diagrams

b. 5204.3 - Cable and Termination Numbering

c. 5204.4 - Standard Interconnecting Wire Numbers and Color Code (

d. 5204.5 - Cable Codes

e. 5204.6 - Raceway Codes

f. 5204.7 - Raceway Numbering

g. 5204.8 - System Single Line Mete-r and Relay Diagra:s

h. 5204.9 - System Design

1. 5204.13 - Preparation of Schematic Diagrams

j. 5204.14 - Preparation of Wiring Diagrams

k. 5204.24 - Cable Derating Practice

1. 3204.54 - Overcurrent Protection Coorditation

m. 5204.55 - low Voltage Circuit Protectior.

C. SCOPE Each inverter, static switch, and manual bypass switch set of NSEB supplies power to the associated vital 120V ac buses (SLA2 to SLA2-1 and SLA; SlB2 to SlB2-1 and SlB; SlC2 to SlC2-1 and S1C; SlD2 to SlD2-1 and SID). This design change provides power suppl'y to each of the listed buses from the following sources (see attached one line sketches):

1. ' DG backed MCC- bus through no rmal batte ry charger and e inverter / static switda to vital 120V ac buses, wnen the associated of f site or DG ac power is available.

2. Battery through inverter / static switch to vital 120V ac buses, in case of loss of the associated of fsi:e power sad DG ac power.

3. DG backed MCC bus through regulating transformer to vital 120V ac buses, in the following cases:

(a) Inverter is inoperable because of internal f ailure. (b) Loss of ac power from MCC to normal battery charger and subsequent depletion of associated battery. (c) Manual bypass switch operated for inverter / static switch outage or maintenance. The manual transfer, if both no rmal and backup power sources are av ailable , is uninterrupted. For automatic' transfer times see Section II/A. l I

~ ' ECN No.- R-0955

Shast 3 of 7 Technical Specifications Section 3.7 (Auxiliary Electrical Systems) contains limiting conditions for operation of the vital 120V ac buses and associated inverters (Page 3-41, Subsection 3.7.1(H) Page 3-43, buses). The limiting conditions are to be adjusted to reflect the changes to the vital 120V 'ac system covered by ECN R-0955.

D. EQUIPENT ' CLASS AND POWER REQUIREMEV. IS The subject vital 120V ac buses are Class I. The related inverters and all associated equipment, in-luding cables and raceways are Class I. All power sources serting the subject vital 120V ac buses

   -                 are also Class I. The static switches,-the associated bypass switches and distribution enclosures will be seis=ically qualified to response spectra at 40'-0" of NSE3 in accordance wita IEEE Standard 344-1975.

E. TESTING Testing will be required to ensure that all equipment functions properly as designed. Necessary test specifications vill be provided for the startup. III. DESIGN INFORMATION AND CALCULATIONS A. DESIGN FEATURES As detailed under II/C this design change enables supply power to the subject vital 120V ac buses through five different paths. The vital 120V ac buses will continue to receive power under any one of the following conditions. e

1. loss of offsite power.

2. Loss of one or both DG's per train concurrent with loss of offsite power.

3. loss of the associated battery or inverter.

4. Associated inverter and/or static switch inoperable (Manual bypass operation).

               .      NOTE:   Power from the battery will be available only ,for the limited period (two hours).                             '

These conditions show definite improvement over the existing . arrangement regsrding availability of power supplies to vital 120V ac buses.

ECN No. R-0955 '., Sheet 4 of 7

                   . Presently, each1 of the subject vital 120V ac buses receives power from its associated inverter.       Inoperability of one irierter results in loss of the related vital 120V ac bus.       The Auxiliary Building inverters were installed at the time of plant construction. These inverters have the history of failures and replacement parts are hard to obtain as the vendor of these inverters has gone out of business. This design change transfers the power feeder of these vital 120V ac buses to the NSEB inverters.        These inverters performed well during their operation over the past three years.

The addition of static switches and manual bypass switches to the NSE3 inverters further increases the availability and reliability of < these inverters and consequently the vital 120V ac buses. In su= mary, the design change ensures increased availa' o ility and ' reliability of the subject vital 120V ac buses.

3. FUNCTIONAL DESCRIPTION -

As described in detail above, the subject vital 120V ac buses will continue to receive power from ef ther the normal or backup source with either automatic or manual transfer, regardless of tne offsite or the DG power availability. The transfer of the power (automatic or manual) by the static switch or bypass switch is bumpless as detailed under II/A. The bus transfer time is within the tolerance limit of the systems serted. The frequency of the inverter ac output is normally synchronized to the backup ac power source. If this source is not .available, the inverter f requency is controlled by a built-in -frequency control oscillator. During bus transfers of the ac power system the exte*nt3 synchronizing si3 nal is temporarily not available and the inverf *r frequency control is automatically taken over by the c built-in oscillator. The frequen'cy adjustment of the inverter during such bus transfer is bumpless. NSAC/INP0 Significant Event Report (SER) 97-31 (OA 34-3) was reviewed for applicability to the operation of the NSE3 inverters, associated with this ICN. The subject SER is not applicable, because these inverters are not equipped with overtoltage protection (actuation / reset). The associated battery chargers have eterroltage alarm, set for 145V dc. This is adequate above the maximum operating voltage of 140V de of the 125V de system. Alarms and indications for each cf the vital 120V ac power systems ; are identical. Loss of power alarms for the NSEB inv~erters, the associated NSE3 inverter buses and the corresponding auxiliary building inverter buses are included in the existing annunciator system and IDADS. Failure of a s.catic switch and loss of backup ac power is automatically included in the inverter /scacic switch

                      " summary" alarm. The existing alarms are adequate, therefore this design change does not add new alarms.

     .           -                                                          ECN No. R-0955

i. . Sheet 5 of 7 I

C. DESIGN CALCULATIONS AND VERIFICATIONS-Load tabulations for vital 120V ac buses SLA, SlB, SlC, . S1D, SlA2-1, S1B2-1, S1C2-1 and SlD2-1 were made to verify that the.NSEB inverters SlA2,' S1B2, S1C2 and SlD2 can carry the additional loads .

                   - assigned to buses SlA, SlB, SIC and S1D, as the result of this design change (Calculation Z-VBS-E0523, Rev.1) .

Calculations were made to verify that batteries BA2, BB2, BC2 and* BD2 have adequate capacity to supply the loads assigned to vital. 120V ac buses SLA, S1B, SlC, SlD,.SlA2-1, S1B2-1, SlC2-1 and SlD2-1 ' (Calculation,Z-DCS-E-0636).' Calculations were made to verify proper coordination of the circuit breakers used in the backup ac power supply circuit,-from MCC main feeder to panel branch circuit (Calculation 2-VBS-E0659).

                   . Calculations were made to verify cable sizes for ampacity and toltage regulation to ensure adequate toltage levels at the tical 120V ac buses, when serted from the inverter or from the regulating transformer (Calculation 1-VBS-E0635).

IV. FAILURE MODES (Typical for buses SlA2. and SLA) Failure Mode , Result Loss of . power -Battery BA2 continues to supply power to the at bus $2A3 inv e rte r. 'On depletion of the battery to a predetermined voltage level, the power supply to the inverter bus will be automatically transferred e by the static switch to bus $2A1. Option: Prior to battery depletion the standby battery charger (H4BA2C2) can be put =anually into operation to provide de power to interter SLA2. This will pre /ent depletion of battery 3A2 when either offsite or DG ac power is available. The loss of ac power at bus $2A3 will also cut off ac power to the normal battery charger (H4BC2) of inverter S1C2. The standby battery charger can feed only one de bus at a time (mechanical interlock). If the option, to prevent battery depletion is used, the operation of the standby battery charger can be sanually alternated between inverters SLA2 and S1C2. (The existing arrangement does not have autocatic transfer to a backup ac supply upon depletion of the batte ry below the acceptable ' voltage level. ]

7- . ECN So. R-0955

  '.                                                                      Sheet 6    of 7 loss of. power at    " Im/erter continues to obtain power through the bus 32A1.               125V de bus from the nor=al battery charger.

(The failure mode of the existing arrangement is the same.] Failure of battery Battery BA2 continues to supply power to the charger H4BA2 inve rter. On depletion of the battery to a predetermined voltage level, the power supply to the inverter bus will be automatically transferred ' by the static switch to bu's S2A1. . Option: Prior i

                 .                    ~to battery depletion the standby (H4BA2C2) battery charger can be put sanually into dperation to provide de power to inverter SLA2. This will prevent depletion of battery 3A2 vnen either offsite or DG ac power-is available.

9 (The existing arrangement does not have automatic transfer to a backup ac supply upon depletion of the battery below the acceptable voltage level. ] Failure of the The static switch will transfer power supply inverter SlA2 for buses SLA and SLA2-1 from inverter to the regulating transformer. [The existing arrangement does not have automatic transfer to' a backup ac su; ply. loss of the inverter causes loss of ac power to the associated inverter bus of the subject channel. ] . Fault in sain feeder This is a single failure of load group A. Re-

                                                                                            -  d cable to buses SLA      dundant load group 3 is available.

and SLA2-1 (21e failure mode of the existing arrangement is the same.] Failure of static Power supply can nanually be transferred f rte switch H8TA3 the inverter to the regulating transformer with the sanual bypass switch. (This failure mode is not applicable to the existing arrangement, it is introduced by this design change.] Failure of manual This is a single failure of load group A. Re-bypass switch. d'undant load group 3 is available. (This failure mode is not applicable to the existing arrangement, it is introduced by this design change.]

 .i       ..                                                            ECN N:. R-0955

- Shest 7 of 7 A c6mparison between the f ailure modes of the existing-arrangecent and the changed design as covered by ECN R-0955 shows that, excluding the cases in which the two f ailure modes are the same, the addition of static switch sets improves the overall reliability and the availability of the vital 120V ac buses. The failure modes associated with the failures of the static switch or the manual bypass switch are additional (introduced with this design change), but the transferability of the inverter bus to the standby power source by the static switch and the system operating capability during inverter / static switch outage or maintenance, sade possible by the use of manual bypass switch, core than compensate for the addi: ion - of the two failure modes. V. SPECIAL MAINTE'IANCE REOUIREMENTS None. , VI. SPECIAL OPERA 1ING REOUIREME'CS There will be a change in the Technical Specifications as a result of this design change. Operator training will be required. Relevant operating procedures will need revision. Nuclear Training Department should arrange for the operator training at a suitable time af ter the Technical Specifications and operating procedures are revised, and the design change is implemented. VII. VERIFICATION CRITERIA

None. VIII. COMMENTS Inte rf ace This ECN interfaces with ECN R-0927, regarding the operation of vi:21 120V ac buses SIC and SlD. ICN R-0927 recoves the loads associated vi:h

ne ICS, NNI-X and NNI-Y cabinets from buses SIC and S13. Ihis ' oad reduction on buses SIC and SlD sust be taken into consideration in the sizing of the feeders for these buses, a design change covered by ECN R-0955 System Interaction Each inverter bus can receive power froc ei:her one of the two diesel 3enerators of the associated train. Normal power is supplied f rom the second diesel generator through the normal . battery charger and the inv e rte r. Standby power is supplied from the first diesel generator of the associate'd train ei:her through the standby battery charger and :he inverter or through the regulating transformer and static switch or through the regulating transformer and the manual bypass switch (see sheet 4 of the attached single line sketches). Tais arrangement ensures that n,o interacion is caused between the diesel generators of dilferent trains.

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DESIGN BASIS REPORT I. PURPOSE OF DESIGN CHAPGE The purpose of making the changes described in the ECN No. R1045, is to modify existing 4160V Class 1 bus overvoltage and undervoltage alarm and trip relaying schemes for the following: A. 1. Overvoltage: The purpose of the change is to assure that the diesel generator will not be started automatically due to tran-sient overvoltage associated with starting the reactor coolant pumps or grid high voltages of short duration, thus preventing unnecessary challenges to the plant's safety features in the 4160V Class 1 buses.

2. Undervoltage:

The purpose of the change is to assure that the operation of the 4160V Class 1 bus undervoltage trip relays will always be in compliance with technical specification limits. B. Due to contact chatterings to replace overvoltage and under- . voltage alarm relays, GE-IAV type, in 4160V Class 1 bus 4A and 48. C. To resolve the conflicts in the existing name tags in the plant switchgear and various electrical drawings for undervoltage alarm and trip relays. D. To replace the ITE-27 undervoltage relays, type 21181175 with 211R1175. This is to eliminate proolem associated with the type 211B1175 relay's target operation on persistent under-voltage. II. DESIGN CRITERIA t A. Summary of Chance

1. Overvoltage:

Tne overvoltage trip relays will be removed to delete the requirements of overvoltage tripping. Overvoltage alarm relays will also be removed. Voltage transducers will be installed to provide analog signals to the computer for logging and alarming bus overvoltages at 10 ADS computer, s 1644v Page 1 of 9

Actual work to be performed will be as follows: Remove existing overvoltage trip relays with tag

-              s                 no's. 459-A1, A2, A3, 459-B1, B2, B3, 459-1A, 2A,        .

3A and 459-1B, 2B, 3B, in 4160V Class 1 switchgears S4A, S4B, S4A2 and S4B2, from compartment 4A11, 4B12, 4A200 and 4B200 respectively. O Remove existing overvoltage alarm relays with tag no's, 459FA, 459FB, 459FA-A and 459FA-B in 4160V. Class 1 switchgears S4A, S4B, 4A2 and 4B2, from compartment 4A00, 4B03, 4A200 and 4B200 respec-tively.

Install voltage transducers, l'estinghouse model no. 237300-32-VLS, tag no's. TD-V-4A, TD-V-4B, TD-V-4A2, TD-V4B2, across phase 1-2 of bus PT's in each of 4.16kV Class 1 switchgear S4A, S4B, S4A2 and S4B2 in compartment 4A11, 4B12, 4A200 and 4B200 respectively. o The following computer inputs will be assigned. Computer Initiating Point Description Device Remarks E1502 Bus S4B Voltage T'aV-4B Alarm and logging (Note 1) Alarm setpoint i E1503 Bus S4A Voltage TD-V-4A . 4500 Volts (Note 1) Scale Range: E1504 Bus S4B2 Voltage TD-V-4B2 E1502; 0-6000 Volts (Note 2) E1503; 0-6000 Volts E1505 Bus S4A2 Voltage TD-V-4A2 E1504: 0-5250 Volts (Note 2) E1505: 0-5250 Volts Note 1: Voltage transducer: input: 0-15-V AC; output: 0-SV DC: Bus PT ratio: 40:1 2: Voltage transducer; input: 0-15-V AC; output: 0-SV DC: Bus PT ratio: 35:1 o Delete existing computer points E1420, OV bus 4B2 and E1421,OV alarm bus 4A2 from IDADS Computer. 1 Remove bus overvoltage alarm signals from Control Room Annunciator window H2ES, bus 4A trouble and H2ES bus S4B trouble. 1644v Page 2 of 9

2. Undervoltage:

Install an additional ITE-27N, type 211T4175, undervoltage trip relay in each trip channel (number of channel / bus is

3) of 4160V Class 1 switchgear across the existing ITE-27, type 211R1175, undervoltage relay as described below:

o Connect the following ITE-27N undervoltage relays in parallel with existing ITE-27 relays: Relay Tao No. Location 427-4A, 5A, 6A SWGR. 54A, Compt. 4All 427-48, 58, 6B SWGR. S48, Compt. 4B12 427-4A, SA, 6A SWGR. 54A2, Compt. 4A200 427-4B, 58, 6B SWGR. S482, Compt. 48200 o Install above relays in the openings formerly occupied by the 459 trip relays. ' o Connect output contact 10,11 of ITE-27N relays in series with output contact 9,10 of ITE-27 relays.

3. From switchgear S4A, compt. 4A00, remove existing relays with tag no's. 42751,* S2, and 427FA. Install ITE-270, ~

type 211R4175, relays.

4. From switchgear S48, compt. 4803 remove existing relays with tag no's. 427S1, 427S2, and 427FB. Install ITE-270, type 211R4175, relays.

5. Replace the existing tags for the following relays with new tags:

Switchgear Existing Tag New Tag S4A, compt. 4All 427A1, A2, A3 427-1A, 2A, 3A S4A, compt. 4A00 427FA 427FA-A S48, compt. 4812 42781, 82, B3 427-18, 2B, 3B S48, compt. 4803 , 427FB 427FA-B S4A2, compt. 4A200 427FA 427FA-A S482, compt. 48200 427FB 427FA-B . 1644v Page 3 of 9

                                                                                ,, A                                                                 e T
         ,             t

6. s From switchgear S4A, compartment 4All, replace existing dsre1Ay's ITE-27 (type 21181175) tag no's. 427A2 and 427A3

                                \n '              with ITE-27, type 211R1175, relays.
                       \

o g 7. From switchgear S48, compartment 4812, replace existing s relays ITE-27, type 21181175 and 211 (modified B) 1175,

                         ,                        tag no's./ 2sB2      4         and 42783 with ITE-27, type 211R1175,
                         ;                        relays.6 ,;

I~ B. Desian Basis

1. The implementation of ECN R1045 is per the following documents:

IEEE Standards 323 - 1974 Standard for Qualifying Class IE Equipment for Nuclear Power Generating Stations. 344 - 1975 Recommended Practices for Seismic Qualification of Class IE Equipment for . Nuclear Power Generating Stations. Electrical installation for this modification shall be Class 1 Seismic Category 1 and in accordance to the following Nuclear Engineering Procedure, Design Criteria and Guides. . .. NEP 4104 Drawings NEP 4106 Design Calculations NEP 4109 Configuration Control NEP 4110 Interdiscipline Document Review NEP 4112 Drawing Change Notice NEP 4114 Design Basis Report Design Criteria 5104.1 Electrical System Design Parameters Design Criteria 5104.7 Control and Protective Relaying Design Criteria 5204.3 Cable and Termination Numbering Design Criteria 5204.9 System Design Design Criteria 5204.26 Cable Terminations i Design Criterie 5101.3 Seismic Classification and Design Criteria i 1644v Page 4 of 9 c..-- e .. .------_y. w.---,--w- --

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                                                                                                                    ---4               - - - --- ---

9

2. The design modification of overvoltage and undervoltage protection schemes per ECN R1045 is in full compliance with the requirements in NRC Staff Position 1 (second level undervoltage protection with a time delay) of NRC's Robert W. Reid letter to district's J. J. Mattimore, dated June 3, 1977.

C. Scope Scope of work in ECN No. R1045 is already discussed in A above, under the actual work to be performed. o The scope of this ECN is also to install and terminate the following instrumentation cables: From To Cable No. 4.16kV Switchaear Mux. Cabinet lYlXA2000 S4A200 H4CDAR7 lYlXB2000 S4B200 H4CDAR9 lYlXB04A S4B12 H4CDARS lYlXA01A S4All H4CDAR3

o The changes in the computer software to include the com-puter input numbers E1502, E1503, E1504, E1505 will be , done as per analog / digital sof tware change request. o Plant Technical Specification Section 3.7, Auxiliary Electrical Systems, Table 3.7-1 and 3.7-2 shall be revised - to include changes as per ECN R1045 and Section III of this DBR. o Addition of two separate and independent TDI diesel generators, A2 in train A and B2 in train B (Reference ECN-A 3660), will not have any interaction on the operation of undervoltage/overvoltage trip and alarm devices. D. Eauipment Class and Power Recuirements All the devices to be covered by this DBR will be Class 1 and Seismic Category 1. All cabling and raceways shall be installed as Quality Class 1 and Seismic Category 1. 1644v Page 5 of 9

E. Testing The cables installed shall be tested for continuity and proper termination before acceptance. Relays shall be tested in accordance with 8196A, M196B, m198A and m198B. III. CALCULATIONS AND DESIGN INFORMATION A. Design Features

1. Overvoltage:

The decision to alarm only for overvoltage conditions instead of trip is . based on the following:

                              .1   The need to reduce the probability of inadvertent actuation of the Standby Diesel Generator from overvoltages that are transient in nature.
                              .2   To give the      operator an opportunity to bring the     1 Class 1, 4160V ESF bus voltage to the acceptable limit by following plant operating procedures. If the operator cannot reduce the overvoltage to the normal operating range of the 4160V Class 1 bus after the alarm,   ~

then the operator must start the diesel generator, paral-lel it with the offsite source, reduce the load on the 4160V ESF bus to allowable limit of diesel generator loading and then trip the offsite power circuit breaker. 1 Operator must transfer from offsite power to diesel gen-erator before 4626V ESF bus voltage (244kV switchyard voltage) is reached.

                              .3   The high voltage alarm is set at 4500 volts. The          I allowable operating range for 4160V Class 1 buses is 3733 to 4626 volts. This corresponds to a switchyard voltage range of 214kV to 244kV. This range of switchyard voltage encompasses the normal operating           ,

range of 221 to 239kV. 4500 volts at the 4160V Class 1 bus corresponds to a switchyard voltage of 237.5kV. The operator starts taking action at 4500 volts and completes transferring load to Diesel y Generator before bus voltage reached 4626V.

2. Undervoltage:

                              .1   For each undervoltage trip channel the existing ITE-27, inverse time delay, relay is supplemented with an additional ITE-27N, definite time delay, relay. The ITE-27 relay is used for first level of 1644v                                       Page 6 of 9

protection, loss of of f site power (70% of trip set-point or less). In this zone the characteristic of the ITE-27 relay is well defined and repeatability is predictable. The ITE-27N relay is used for the second level of protection, long time degraded bus voltage (98% of trip setpoint). The ITE-27 relay is set at a time dial setting of 3 which results in the character curve attached. The ITE-27N relay is set at the time dial setting of 4 which will provide a definite time delay of 5 1 0.5 secs. Both relays are set to dropout at 3771 1 38 volts. With this selection of time delays, ITE-27N will always operate faster than the ITE-27 relay above 90% of trip setpoint thus eliminating the dependence on the ITE-27 relay for operating in the steep portion of the time delay curve for which the relay is less defined. On a complete loss of voltage, the existing ITE-27 relay will trip within 3.5 sec. with the time dial set at 3.

3. ITE-27N relays:

MFR: BBC Brown Boveri, Inc. Type: 211T4175, definite time delay of 1-10 sec. Dropout is adjustable from 70 to 99% - Tolerances are as follows: o Picker and dropout settings, repeatability at constant temperature and constant control voltage =

                                                                    +/- 0.2% (See Note) o Pickup and dropout settings, regeatability over de control power range of 100-140 volts      =
                                                                    +/- 0.2% (See Note) o Pickup and dropout settings, repeatability over tempera-ture range -20 to +550C           =   */- 0.4%

8 0 to 400C =

                                                                    +/- 0.2% (See Note)

Time delay: 10% Note: The three tolerances shown should be considered independent and may be cumulative. Output contacts are rated at 5 amps continuous and 0.3A break inductive. Burden (VA) less than one (1) VA at 120VAC. 1644v Page 7 of 9

4. The burden of ITE-27N relays is less than the ITE-59D relays (burden of ITE-590 is 1.2VA). The size and weight of the ITE-27N is same as ITE-590 as such change is mini-mized.

Other relays ITE-27 (type no. 211R1175), ITE-270 (type no. 211R4175), used in this modification are already in use in Rancho Seco Unit 1.

5. Voltage transducers:

MFR: Westinghouse Model No.: 237300-32-VLS Input: 0-150V ac, 60HZ , Output: 0-SV de Burden: 2.0VA With the addition and deletion of relays and voltage transduc-ers per ECN No. R1045 the burden on some potential transformers will increase; however, the increase will be very small and total burden will be wall within potential transformers' ratings. 's s B. Functional Description x s Overvoltage protection: The analog input to the IDADS computer system from the bus voltage transducer exceeding equivalent bus voltage of 4580 volts will cause an alarm in the control room at IDADS computer system. Computer will log bus voltage continuously, as such bus voltage values will be available to the operator at any time. Undervoltage protection: For undervoltage protection the total number of protection channels is 3/ bus and the number of relays per channel is 2. Both undervoltage relays ITE-27N and ITE-27 in each trip channel are connected to the same bus Potential Transformer. Output contacts that open when the input voltage drops below the relay dropout setting are connected in series to operate an auxiliary relay. The auxiliary relays are deenergized for an undervoltage detection by either ITE-27N or ITE-27. The auxil-

iary trip relays and bus tripping logic,is exactly the same as the existing scheme; that is the contacts from the auxiliary relays are arranged in a two-out-of-three logic. This logic string is used to operate *a bus unloading relay with a 0.5 sec. time delay on energization. The 0.5 sec. time delay is used to i prevent an accidental bus unloading when the logic circuit is initially energized. s l l 1644v Page 8 of 9 L

Setpoints: Overvoltage ala,rm: 4500 volts I Undervoltage alarm: 3960 volts Undervoltage trip: 3771 38 volts Time delay for 98% of trip setpoint is 5.5 sec. or less. (In this zone the ITE-27N will trip faster than the ITE-27.) Time delay for 70% of trip setpoint 3.5 sec. or less. (In this zone the ITE-27 will trip faster than the f ITE-27N.)

        -N         x  C. Design Calculations Relay setpoints and time delay are selected based on the calc.

no. Z-EDS-E104 (A.5.08.2.123) UV and OV Relay Settings ESF

            .        ,-      Swgr. Rev. 1.

IV. FAILURE MODE A single failure of any of the following new devices listed below to be installed per this modification will not prevent the scheme from , operating properly or cause it to operate when it is not required. Voltage transducers , , Undervoltage relays 427-4A, 5A, 6A in switchgear 4A and same in switchgear 4A2. 427-4B, 5B, 6B in switchgear 4B and same in switchgear 4B2. The two-out-of-three logic used in the design, to detect undervoltage condition allows a single failure of the above mentioned undervoltage relays without any effect or the operation of the system. V. SPECIAL MAINTENANCE REOUIREMENTS None. VI. SPECIAL OPERATING REOUIREMENTS . The 4160V Class 1 voltage system shall be operated per Section 3.7 1 of Rancho Seco Unit 1 Technical Specifications and as described in Section III.A.1 of this DBR. 1644v Page 9 of 9

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. ~,.< RANCHO SECO UNIT 1 TECHNICAL SPECIFICATIONS _ _ __ . TABLE _3.7-2 l l Total l No. of l l Minimum j l l Functional l Number of l Relays / l Channels l Channels l Action l l Unit l Channels l Channel l To Trip l Operable l (Note 1) l - l_ l I l I l l . . I I I I I 1 I l Undervoltage l 3/ Bus l 2 l 2/ Bus l 2 l A l 1 l l 1 1 I I I I l 1 I I I l l l l l l l l 1 l l 1 l l ACTION STATEMENTS Action A - With the number of OPERABLE channels one less than the total Number . of Channels operation may proceed until performance of the next required CHANNEL FUNCTIONAL TEST provided the Inoperable Channel is placed in the tripped condition within one hour. _ Note 1: The " Action A" is not applicable when the plant is in cold shutdown.

Proposed Amendment 1475d

                                                                                           -              -.a

i Enclosure 6 Standard Review Plan Comparison l l

1 SRP 3.7.1 EEQUIREMENTS SYSTEM DESIGN

1. Design Ground Notion

a. Design Response Spectra Design response spectra for the OBE and SSE for all damping la. Complies with the acceptance criteria as given in subsection JI of values are checked to assure that tha spectra are in accordance SRP 3.7.1. Refer to Bechtel Design Oulde C-2.44, Rev. O, August 1980 with the acceptance criteria as given in subsection II. Any dif ferences between the regulatory guide spectra and the proposed response spectra which have not been adequately justified are ,

identified and the applicant is informed of the need for additional technical justification,

b. Design Time History Methods of defining the design time history are reviewed to Ib. Complies with subsection II.2 of SRP 3.7.1. Refer to Bechtel Design ascertain that the acceptance criteria of subsectior.11.2 of this Outde C-2.44, Rev. O, August 1980 SRP Rection are met.

2. Critical Damping values The specific percentage of critical damping values for the OBE and 2. Same as above SSE used in the analyses of Category I structures, systes., c.;

components are checked to assure that the dssping values are in accordance with the acceptance criteria as given in subsection II.2 of this SRP nection. Any differences in damping values which have not been adequately justified are identified and the applicant is informed of the need for additional technical justification.

3. Supporting Media For Category I Structures The description of the supporting media is reviewed to verify that 3. Refer to Bechtel calculation AS.08.3.15.

suf fic ient information, as specified in the acceptance criteria of subsection 11.3 of this SRP section is included. Any deficiency in the required information is identified and a request for additinnal information is transmitted to the applicant. I 1

SRP 3.7.2 REQUIREMENTS SYSTEM DESIGN

1. Seismic Analysis Methods For all Category I structures, systems, and cosponents, the 1. Compiles with subsection 11.1 of SRP section 3.7.2. Refer to applicable methods of seismic analysis (response spectra, time Bechtel Calculations AS.08. 3.15. Refer to Bechtel Design Cuide history, equivalent static load) are reviewed to ascertain that the C-2.44, Rev. O. August 1980 techniques employed are in acordance with the acceptance criteria as given in subsection II.1 of this SRP section. If empirical methods .

or tests are used in lieu of analysis for any Category I structure, these are evaluated to determine whether or not the assumptions are conservative, and whether the test procedure adequately models the seismic response.

2. Natural Frequencies and Response Loads For the operating license review, the summary of , natural f requencies 2. Compiles with subsection II.2 of SRP section 3.7.2. Refer to ani response loads is reviewed for compliance with the acceptance Bechtel Calculations A5.08.3.15.

criteria in subsection II.2 of this SRP section.

3. Procedures Used for Analyticel Modeling The procedures used for modeling for seismic system analyses are 3. Complies with subsection 11.3 of SRP section 3.7.2. Refer to reviewed to determine whether the three-dimensional characteristics Bechtel calculation A5.08.3.15. Refer to Bechtel Design Cuide of structures are properly modeled in accordance with the acceptance C-2.44. Rev. O. August 1980 criteria of subsection II.3 of this SRP section, and all significant degrees of f reedom have been incorporated in the models. The criteria for decoupling of a structure, equipment, or component and analyzing it separately as a subsystem are reviewed for conformance with the a .eptance criteria given in subsection II.3 of this SRP section.

4. Soil-Structure Interaction The methods of soil-structure interaction analysis used are examined 4. Complies with subsection 11.4 of SRP section 3.7.2. Refer to to determine that the techniques employed are in accordance with the Bechtel calculation A5.08.3.15. Refer to Bechtel 9esign Cuide acceptance criteria as given in subsection 11.4 of this SRP section. C-2.44. Rev. O. August 1980 Typical mathematical models for soil-structure interaction analysis are reviewed to ensure the aiequacy of the representation in accordance with subsection II.4 of this SRP section. In addition, the methods used to assess the effects of adjacent structures on

structural response in soil-structure interaction analysis are reviewed to establish their acceptability.

5. Development of Floor Response Spectra Procedures for developing the floor response spectra are reviewed to 5. Complies with subsection 11.5 of SRP section' 3.7.2. Refer to verify that they are in accordance with the acceptance criteria Bechtel Calculation A5.08.3.15. Refer to Bechtel Design Cuide specified in subsection II.5 of this SRP section. If a model C-2.44. Rev. O, August 1980 response spectr im method of analysis is used to develop the floor response spectra, its conservation compared to that of a time history approach is reviewed. The applicant is requested to provi*-

additional technical justification for any procedure considered not adequately justified. I 2

1 SRP 3.7.2 REQUIREMENTS SYSTEM DESIGN

6. Ihree Components of Earthquake Moth The procedures by which the three components of earthquake action 6. Complies with subsection 11.6 of SRP section 3.7.2. Refer to are considered in detezeining the seismic response of structures, Bechtel Design Guide C-2.44, Rev. O, August 1980 systems, ami components are reviewed to determine compliance with the acceptance criteria of subsection II.6 of this SNP section. Any other procedures that are considered not adequately justified are so identified, and the applicant is asked to provide additional justification.

7. Combination of Model Responses The procedures for combining model responses (shears, moments, 7. Complies with subsection II.7 of SRP section 3.7.2. Refer to stresses, deflections, and accelerations) for closely spaced models Bechtel Calculation AS.08.3.15. Refer to Bechtel Design Oulde are reviewed to determine compliance with the acceptance criteria of C-2.44.

subsection II.7 of this SRp section, when a response spectrum model analysis method is used.

8. Interaction of Non-Category I Structures with Category I Structures The design and analysis criteria for interaction of non-Category I 8. Complies with subr.ection II.8 of SRP section 3.7.2. Refer to structures with categ>ry I structures are reviewed to ensure Bechtel Calculation A5.08.3.15 compliance with the acceptance criteria of subsection II.8 of this SRP section.

9. Ef fects of Parameter Variation on Floor Response Spectre The setemic system analysis is reviewed to determine whether the 9. Complies with subsection 11.9 of SRP section 3.7.2.

analysis considered the effects of expected variations of structural Refer to properties, dampings, soil properties, and soil-structure Bechtel Calculation A5.08.3.15 interaction on floor responses spectra (e.g., peak width and period coordinated) and to determine compliance with the acceptance criteria of subsection II.9 of this SRP section.

10. Use of Equivalent Static Factors Uae of constant static factors as response loads in the vertical 10. Refer to Bechtel Calculation A5.08.3.15 direction for the seismic design of any Category I structure, system or component in lieu of a detailed dynamic method is reviewed to determine that constant vertical static factors are used only if the structure is rigid in the vertical direction.

11. Methods Used to Account for Torsional Ef fects The methods of seismic analysis are reviewed to determine that the 11. Refer to Bechtel Design cuide C-2.44.

torsional effects of vibration are incorporated by including the Refer to Bechtel Calculation A5.08.3.15 torsional degrees of freedom in the dynamic model. Justification ' provided by the applicant for the use of any approminate method to , account for torsional effects is judged ta assure that it results in ' a conservative design. If such justification is deemed inadequate, it is identified 'and the applicant requested to provide additional

justification.

1 3

~-

SRP 3.7.2 REQUIREMENTS SYSTEM DESIGN

12. Comparison of Responses Where applicable, the responses obtained f rom both response spectrum 12.

and time history methods at selected points in major Category I The responses are obtained using time history methods aal equivalent

,          structures are compared to judge the accuracy of the analyses                  static loads are thus obtained. Refer to Bechtel Calculation A3.08.3.15 conducted. Large differences in the results obtained by use of the two methods are identified and the applicant is asked to discuss the reasons for the large dif ferences.

13. Analysis Procedure for Damping The analysis procedure to account for damping in dif fere t c'64ents 13. Complies with subsection II.13 of SRP section 3.7.2. Refer to of the model of a coupled system is reviewed to determine that it is ' Bechtel Design Guide C-2.44.

in accordance with the acceptance criteria of subsection II.13 of i this SRP section. .I

14. Determination of Category I Structure Overturning Hosents Methods to determine Category I structure overturning moments are 14. Complies with subsection II.14 of SRP mection 3.7.2. Refer to reviewed to determine compliance with the acceptance criteria of Bechtel Design Oulde C-2.44.

i subsection II.14 of this SRP section. AS.08.3.15. Refer to Bechtel Calculation 4 4 4 I ? 1 4 e 4 4

t SRP 3.8.4 REQUIREMENTS SY. TEM DESIGN '

1. Description of the Structures 1.

Af ter the type of structure and its functional characteristics are Refer to Design Basis Report (DBR) for ECN A-3748, Section III.4.s identified, iaformation on similar and previously licensed plante is obtained for reference. Such information, which is available in safety anilysis reports and amendments of previous license applications, enables identification of dif ferences for the case under review. These dif ferences require additional scrutiny and evaluation. New and unique features that have not been used in the past are of particuler interest and are thus examined in greater detail. The information furnished in the SAR is reviewed for completeness in accordance with the " Standard Format . . . ." (Ref. 4). A dectaton is then made with regard to the sufficiency of the descriptive information provided. Any additional required information not provided is requested from the applicant at an early stage of the review process. l

2. Applicable codes, Standards, and Spec ti trations 1

The list of, codes, standards, guides, ami specifications is compared 2. Refer to DDR for FCN A-3748, Section II.4.B.1

with the list in subsection II.2 of this SRP section. 1he reviewer

, assures himself that the applicable edition and stated effective addenda are acceptable.

3. Loads and Loading _ tnations The reviewer verifies that the loads and load combinations are as 3. Complies with subsection II.3 of SRP section 3.8.4. Refer to conservative se those specified in subsection 11.3 of this SRP Rechtel Calculations A5.08.3.15 sec tion. Any deviations from the acceptance criteria for loads and ,

load combinations that have not been adequately justified are identified,as unacceptable and transmitted to the applicant.

4. Desf gn and Analysis Procedures The reviewer assures himself that for the design and analysis 4. Complies with SRP section 3.8.4. Refer to Bechtel csiculations ,

t procedures, the applicant is utilizing the ACI-349 Code (Ref.1) and A5.08.3.15. Also refer to DBR for ECN A-3748 Section III.4.5 ) i the ASIC Specifications for concrete and steel structures (Ref. 3), respectively. , Ank computer programs that are utilized in the design and analysis of the structure are reviewed to verify their validity in accordance with the acceptance criteria delineated in subsection II.4.e of SRP section 3.8.1. 2 The reviewer assures that the provisions specified in subsection II.4 of this SRP section regarding design report, structural audits , a and design of spent fuel pool and racks are met. i 5 l

                                                .                            4 g

SRP 3.8.4 REQUIREMENTS SYSTEM DESIGN J

5. Structural Acceptance Criteria The limits on allowable *. tresses and strains in the concrete, 5- Coma-reinforcement, structural steel, etc., are compared with the with subsection 11-5 of SRP section 3.8.4. Refer to corresponding allowable stresses specified in Section II.5 of this Bechte- Jalculations A5.08.3.15.

SRP section. If the applicant proposes to exceed some of these limits for some of the load combinations and at some localized points on the structure, the justification provided to show that the structural integrity of the structure w!!! not be affected is , evaluat ed. If such justification is determined to be inadequate, the proposed deviations are identified and transmitted to the i applicant with a request for the required additional justification and ba res. ,

6. Materials. Quality Control, and Special (bnetruction Techniques The materials, quality control procedures, and any special 6. Complies with subsection II.6 of SRP section 3.8.4.

construction techniques are compared with those referenced in subsection II.6 of this SRP section. If a new material not used in prior licensed cases is utilized, the applicant is requested to provide sufficient test and user data to estabitsh the acceptability of such a material. Similarly, any new quality control procedures or construction techniques are reviewed and evaluated to assure that there will be no degradation of structural quality that might affect the structual integrity of the structure. [ 7. Testing and Inservice Surveillence Requirements , Any testing ani inservice surveillance programs are reviewed on a 1. Refer to DBR for ECN A-1748, Section 11.4.B.1.1. ca se-by-ca se ba si s.

8. Masonry Walls The reviewer should assure that the requirements identified in 8. The masonry wall has been designed in accordance with UBC APPenlix A to this SRP section are met.

requirements and seismic / wind-missile requirements as specified in 1 the USAR for Rancho Seco. Refer to Bechtel calculation A5.08.3.15. i / 4 i 4 l i 6

I SRP 8.3.1 REQUIREMENTS SYS1F.M DESIGN III. REVIEW PROCEDURES The primary objective in the review of the ac power system is to determine that this system satisfies the acceptance criteria stated in Subsection II and will perform its design functions during plant normal operation, anticipated operational occurrences and accident cond itions. In the CP review, the descriptive information, including the design bases and their relation to the acceptance criteria, preliminary analyses, electrical single-line diagrams, functional logic diagrams, preliminary functional piping and instrumentation diagrams (PSIDs), and preliminary physical arrangement drawings are examined to determine that there is reasonable assurance that the final design will meet these objectives. At the OL stage, these objectives are verified during the review of final electrical schematics, functional P&TDs, and physical arrangement drawings and are confirmed during a visit to the site. To ensure that acceptance criteria stated in Subsection II are satisfied, the review is performed as detailed below. The primary reviewer will coordinate this review with the other branch areas of review as stated in Subsection I. The primary reviewer obtains and uses such input as required to ensure that this review procedure is complete.

1. System Redundancy Requirements General Design Criteria 33, 34, 35, 38, 41, and 44 set forth 1. Two new redundant diesel generators are being added. Each of these requirements with regard to the safety systems ttae *"-t be diesel generators is designed to supply power to one train of new supplied by the ac onsite power system. Also, these equipment required for safe shutdown. SK-078-E-1, One Line Diagram, criteria state that safety system redundancy should be such shows the connection of the diesel generators and also lists the t tat for onsite power system operation (assuming of f site loads supplied by each diesel generator on loss of of fsite power.

power is not available), the system safety function can be SK-078-E-2, 125V de and 120V de Distribution System, shows the two accomplished assuming a single failure. The acceptability redundant control and instrumentation power distribution systems of the onsite power system with regard to redundancy is which supply control power to the two diesel generator systems. based on conformance to the same degree of redundancy of Also refer to DBR for ECN A3748 Sectione I and II.B.I.a and Drawing safety-related components and systems required by these E104 Sheet 8 general design criteria. The descriptive information, including electrical single-line diagrame (CP and OL stage), functional P& ids (CP and OL stage), and electrical schem tics (OL stage), is reviewed to verify that this redundancy is reflected in the standby power system with regard to both power sources and associated distribution sy st ems. Also, it is verified in coordination with other branches that redundant safety loads are distributed between redundant distribution systems, and that the instrumentation and control devices for the Class IE loads and power system are supplied f rom the related redundant distribution systems. 7

I e SRP 8.3.1 REQUIREMENTS gISTEM DESIGN

2. Conformance with the Single Failure Criterion i As required by General Design Criterion 17, the onsite ac power 2. The two new redundant diesel generators being added are'available to i system must be capable of performing its safety function assuming a supply emergency power to egulpment required for safe shutdown of single failure. the plant. Loss of one train of diesel generators, will still leave sufficient onsite power capability for equipment required for safe Im evaluating the adequacy of this system In meeting the single shutdown.

fatlure criterion, both electrical and physical separation of reduwlant power sources and distribution systems, including their Compliance to the single failure criteria is accomplished by connected loads, are reviewed to assess the iMerendence between maintaining complete separation between the two additional diesel redundant portions of the system. generators such that the effects of fire or flooding generated from within one of the new diesel generator eystems will not prevent the-To ensure erlectrical independence, the design criteria, analyses. other train f rom performing its safety related functions. description, and implementation as depleted on funcetonal logic - diagrams, electrical single-line diagrams, ant electrical schematics The associated power distribution equipment, required by the are reviewed to determine that the design meets the requirements set additional diesel generators, is independent of the redundant forth in IEEE 308 and satisfies the positions of Regulatory Guide poggjons of the distribution system, and meets the single failure 1.6. Additional guidance in evaluating this aspect of the design is criterion by maintaininq both electrical and physical separation of derived f rom IFER 379, " Guide for the Appitention of the power trains. Single-Failure Criterion to Nuclear Power Generating Station

Protection Systems," as augmented by Reguistory cuide 1.53 Reference E-104, Sheet 8, Diesel Generator One Line Diagram "Apriteetton of the Single-Fallure Critetton to Nuclear Power Plant SK078-E-1, Electrical power System Single Line Diagram Protec tion Systems." other aspects of the design where special SK078-E-2, 125V de and 320v ac Distribution review attention is given to ascertain that the electrical Layout Drawings of Diesel Generator Building .

independence and physical separation has not been compromised are as fattows:

a. Should the proposed design provide for sharing of the ac onette a. 100t applicable since Rancho Seco is a one-unit plant.

power system hetween units at the same site, the criteria of IEFE 308 governing the sharing of this system between units are not specific enough to be used as the Mats for assessing the adequacy of the design in meeting the requirements of beneril Design Criterson 5 and satisfying the single fatture criterion. Therefore, the acceptability of such a design is determined by reviewing the proposed system design criteria and electrical schematics and analyses substantiating the adequacy of the design to withstand the consequences of electrical , faults arvi fattures in one unit with respect to others. I Cenerally the PSB is guided by the requirements set forth in Position 2 of Regulatory Culde 1.81, " Shared Emergency and Shutdown Electric Systems for Multi-Unit Nuclear Power Plants," for CP applications docketed before June 1,1973 aws for OL applications. Position 3 of this regulatory guide prohibits the sharing of onsite power systems between nuclear units for const ruction permit applications docketed af ter June 1,1971. Further details of the review with regard to Position 2 on sharing of the onsite power system between units are covered in item 4 helow. f f 8 I l i m

SRP 8.3.1 REQUIitEMENTS SYSTEM DESTCN

b. The interconnections between redundant load centers through bus b.

No extra redundant loads connectable to both th d I*""" ** tie breakers and multifeeder breakers used to connect extra are being added No int " * **" "'" redundant loads to either of the redustant distribution systems the two redundant trains " are examined to assure that no single failure in the between the 480V switchge o r gin ta an ad interconnections will cause the paralleling of the standby power center of the new A2 train and between the 480V switch supplies. To ensure this, the control circuits of the bus tie original B train and the load center of the new B2 tra "* ReI'T E0 breakers or multifeeder breakers must preclude automatic SR-078-E-1. transferring of load centers or loads f rom the designated supply to the redundant counterpart upon loss of the designated supply These ties can only be closed manually when the final f (Position 4 of Regulatory Culde 1.6). Regarding the is completed. Additionall . each tie b k interconnect!ons through bus tie breakers, an acceptahle design both of the main feeder breakers to its I v u e P' - will provide for two tie breakers connected in series and physically separated from each other in accordance with the These ties are to be used for maintenance purposes only when the acceptance criteria for separation cf the onsite power system, plant is shut down. whhh in discussed below. Further, the interconnection of redunlant load centers must be accomplished only manually. With respect to the interconnections C rough the multifeeder breakers supplying power to extra redundant loads, the review relates to the use of the extra redundant unit as one of the required operating units (if the substituted-for-normal unit is inope rable) . If this is the selected mode of operation prior to an accident concurrent with the loss of off site power, it is verified by reviewing the breaker arrangement and associated control circuits that no single failure in the feeder breaker which is not connecte,i to the extra redsviant unit could cause the closing of this breaker resulting in the p.iralleling of the power supplies. To ensure againe.t compromising the Independence of the redundant power systems under this situation, an acceptable design for connecting extra teduplant loads to either distribution system will provide for at least dual means for connecting and isolating each load f rom each redundant bus. Such a degign must also meet the acceptance criteria for electrical and physical separation of the onsite power system. In addition, the provision of the design to automatically break No provision to break all interconnections etc. is required since all the interconnections (e.g., open tie and multifeeder there are no ties between redundant portions of electrical a7 stem

breakers) between redundant load centers immediately following an accident condition concurrent with the loss of offsite power are reviewe:d to ascertain that the indepentence of the redundant portions of this system is established given a single fatture.

9

m i SRP 8.3.1 REQUIREMENTS SYSTEM DESICN

c. To assure physical independence, the criteria governing the c. Complete physical independence' between the two redundant' diesel physical separation of redundant equipment, including cables and

generators, their distribution system and their essential raceways, and their implementation as depicted on preliminary auxiliaries is provided. Regulatory cuide 1.75 and IEEE 384 have (CP stage) or final (OL stage) physical arrangement drawings are been utilized as guides in estahtishing the separation criteria for reviewed to determine that the design arrangements satisfy the the installation of these equipment. The raceway system in the requirements set fort!. In IEfE 384 as augmented by Regulatory Diesel Generator Building is designed to meet the requirement of Guide 1.75. This standard and regulatory guide set forth ' single failure criteria as per IEEE 279. Refer to the separation acceptance criteria for the separation of circuits and criteria and design and routing procedure for raceways for Rancho electrical equipment contained in or associated with the Class Seco Nuclear Flant which meets the intent of Regulatory Guide 1.75 IE power system. To determine that the independence of the . and IEEE 384, and cable string and selection procedure and criteria redundant cable installation is consistent with satisfying the for Rancho Seco Project.

requirements set forth tu IEEE 384 as augmented by Regulatory Guide 1.75, the proposed design criteria governing the Wherever the separation requirements prescribed by Regulatory cuide separation of Class IE cables and raceways are reviewed, 1.75 and IEEE 384 cannot be met by the new system,' an analysis is including such criteria as those for cable deratin63 raceway Performed to justify any deviations and thereby prove compliance filling; esble routing in containment, penetration areas, cable with the single failure criteria as per IEEE 279. spreading rooms, control rooms and other congested areas: sharing of raceways with nonsafety-related cables or with cables of the same system or other systemsg prohibiting cable splices in raceways; control wiring and components associated with Class IE electric systems in control boards, panels, and relay racks; and fire hirriers and separation between reiundant raceways.

3. Onsite ami of f site power System Independence In ascertaining the independence of the onsite power system t;*th 3. Startup transformer No. 1 (through the Nuclear Service' Supply respect to tie offsite power system, the electrical ties between Transformer) is the preferred source of power for train A2 and these two systems, as well as the physical arrangement of the Startup transformer No. 2 is the preferred source of power for train interface equipment are reviewed to assure that no single failure B2. The diesel generator breaker for Train A2 Diesel Generator CEA2 will prevent separation of the redundant portions of the onsite is electrically interlocked in such a way that it cannot be closed power system from the off site power system when required. The scope manually during test or otherwise when the incoming breaker from of the review for independence estends from the supply breakers Startup tra,sformer No. 2 is closed. Similarly, the diesel connected to the low side of the unit auxiliary transformers and generator Breaker am Train 52 blesel Cenerator CEB2 is electrically startup transformers (referred to as the offsite or preferred power interlocked in such a way that'it cannot,be closed manually during supplies) to the station safety-related distribution system. The test or otherwise when the incoming breaker from Startup Transformer number and capability of electrical circuits f rom the of f site power No. 1 is closed. This prevents the simultaneous connection of the rystem to the safety buses are to be consistent with satisfying the two diesel generators (one diesel generator from each train) to one requirements of G neral Design Criterion 17. Then, downstream of iransformer (off-site source).

the of f site power breakers et the safety buses, the design must sTtisfy the requirements for redundancy and independence of General Administrative procedures permit testing of only one diesel Dealgn Criteria 34, 35, 38, 41, and 44; that is, for onsite power generator at any one time. rystem operation (assuming of fsite power is not available), the rystem safety function can be accomplished assuming a single failure. l 10

1 SRP 8.3.1 REQUIREMENTS SYSTEM DESIGN To determine that the physical independence of the preferred ,we- No provision exists for automatic connection of the offsite' wer to circuits to the Class IE buses is consistent with satisfying the the buses. The power to the husses <m be restored by manua rrquirements of Ceaeral Design Criterion 17 and IEEE 308, the operation only. physical arrangement drawings are examined to verify that each circuit is physically separate and independent from its redundant cou nte rpa rt s. In addition, the final feeder-isolation breaker in orch circuit through which preferred power is supplied to the safety buses must be designed awl physically separated in accordance with the requirements for the onsite power system. Following the loss of preferred power, the safety buses are powered solely from the standby power supplies. Under this situation, the design of the freder-isolation breaker in each preferred power circuit must i preclude the autor atic connection of preferred power to the respective safety bus upon the loss of standby power. In this regard, an acceptable design will include the capability of restoring preferred power to the respective safety bus by manual actuation only. In assessing the adequacy of the electrical ties between the onsite 220kw system protective relaying consist of primary relaying, backup sai of f site power systems, aal the capability of the preferred power relaying and breaker fatture relaying. 220kv circuit breakers each circuits to deliver power to the safety-related buses, both primary have two separate trip coils, and have their own DC control power. l and secostary backup protective relaying schemes and their coordinat ion, relay settings, and assigned control power supplies No single failure of active components will negate the ability to are reviewed by PSB to assure that in the event of an electrical provide offsite power to the engineered safety features. With i fruit occurring between the preferred power transformer supply respect to passive aponents, there are certain areas where a breakers an1 the safety buses, no single f ailure will result in single occurence could affect cables used in control and relaying reducing the number of preferred power circuits to less than the for all of the 220kv breakers. Itoweve r , should offsite power be minimum required for safety or preveat the separation of the lost due to false tripping, the breakers could be reclosed by use of af fected circuit f rom the respective redualant portion of the onsite local manual controls. powe r sy st em. In addition, it is verified that no single protective relay or interlock f ailure will prevent separation of the requited Protection against offsite power system faults affecting the safety redundant portions of the onsite power system f rom the preferred buses is provided in the Rancho Seco offsite/onsite power protective power system upon loss of the latter. relaying system such that no single failure in either system will prevent isolation of the required redundant portions of the onsite !, power system from the offsite system after its failure or result in reducing the number of preferred power circuits to less than the minimum required for safety or prevent the separation of the affected circuit from the respective redundant portion of the onsite

;                                                                             power system.

i i l 11 9

 ~ _ . . _ . . - _ _ .__ _ ._                               _    _~___m    _

I e i SRP 8.3.1 REQUIREMENTS STSTEM DESIGN In reviewing the mode of operation where both power systems are With the availability of both sources of off' site A2 being operated in parallel (such is the case during full load powered from Startup Transformer No. I and B2 tra testing of stasiby power supply diesel generator sets), the Startup Transformer No. 2. Electrical interlocks rat s interlock scheme, incluling electrical protective relay coordination A train diesel generatcre through Startu T f and settings, are closely esamined to verify that the independence of B train diesel generators through Sta tu ans me .2 of the required redundant portions of the onsste power system is only. This precludes the possiblitty of paralleling of the diesel established upon a failure in the off site power system. 1he event generators of one train to the 4.16 kV bus of the redundant train at of concern under this mode of operation is an accident concurrent the 4.16 kV level, with a loss of of f site power and a single failure preventing the ~ opening of the feeder-isolation breaker through which the , paralleling of the power systems was being accomplished. Because the signal to start the diesel generator sets is normally derived from undervoltage relays, and under this situation the voltage is maintained above the trip relay settings by the diesel generator under test, the remaining redundant diesel generators will not be commanded to start running. Consequently, the added capacity resulting f rom the connection of non safety-related loads to the diesel generator under test will cause the tripping of this diesel due to overload. The end result could be the total loss of power to the safety buses. However, thle power interruption could be of momentary duration if the remaining reduniant diesel generators are comma.wied automatically to start by undervoltage relay action immediately af ter total power is lost. The diesel generator under , test will be l'noperable due to the self-locking feature, preventing restarting af ter an overload trip condition. The reviewer ascertains ti e %e time delay introduced in making power availsble to the safety buses as a result of this event is wthtin the response time limits assumed in the accident analyses. Included is verification that subsequent failures such as those resulting from improper electrical relaying coordination an! self-locking features will not impair the automatic starting of the remaining redundant diesel generators required to meet minimum safety requirements. If the time delay introduced in making power ava!!able to the safety buses is not tolerable, it must be demonstrated that either the probability of occurrence of this event is low when compared to the f requency and duration of testing each diesel, or the design must provide diverse automatic signals, other than undervoltage, to ensure the availability of standby power to the safety buses. As an outcome of reviewing the parallet operation of the of f site and The District does not propose / plan to utilize the emergency diesel onsite power systems, the use of the stasiby power supply diesel generators to supply peak loads. Refer to DBR for ECM A3748 Sectior* generator sets to supply power to the electrical system during peak II.1.B.I.P. ! load demani periods was foumi by the staf f to be unacceptable. The i basis'for this conclusion is that the required frequent i interconnections of the off site and standby power supplies do not minimize the probability of their coincident loss (General Design Criterion 17) nor can the :lesign be made immune to common failure ' modes (Section 5.2.1.(5) of IEEE 308). Further details amplifying the basis for this conclusion are included in Branch Technical l Position JCSB 8 (PSB) which sets forth the basis for prohibiting the use of diesel generator sets for purposes other than emergency A1 { standby power supplies. l I l 12 L

O I

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_ s .. SRP 8.3.1 REQUIREMENTS SYSTEM DESIGN . StealSy Power Supplies In ensuring that the requirements of General Design Criterion 17 and 4 The new diesel generators are rated at 3500 kw each with a quellfied - load rating of approximately 3300 kw. This quellfied load rating has IEEE 308 have been met with regard to the staalby power supp1T -been established through a ' program conducted by the long Island Lighting, diesel generator sets having sufficient capacity awl capability to Company (Ref: NRC Supplemental Safety Evaluation Report - Shoreham supply the required distribution system loads, the design bases,- Nuclear Power Station - Reliability of Standby Emergency Diesel Generator, design critera, analyses, description, and implementation as Dockett 50-322, Deeceber 18, 1984)-, and is consistent with the BRC Safety drpicted on electrical drawings and functional P&lDs, the diesel gInerator sets are reviewed to verify that the bases for their Evaluation Report of 'the TDI Diesel Generator Ouners Croup Program Plan, dated August 13, 1984 selection satisfy the positions of Regulatory Culde 1.9. Specifically, the reviewer first becomes familiar with the purpos' The new diesel generators will be loaded with approximately 1600 kw, and cperation of each safety system, inclisting system component , leaving a margin of 51%. Loads to be connected are listed on arrangtment as depicted on functional P&lDs, espected systes SK-078-E-1, electrical power single line diagram. ' perforsance as established in the accident analyses, modes of system operation and their interactions between systems. Following this, Diesel generator load profile data that show the characteristics of ' it is verified that the tabulation of all safety-related loads to be ' connected to each diesel generator is consistent with the loads for which the diesel generators have been designed are - available for review. Inforsstion establishing the safety-related systees and loads and - their required redundancy. The characteristics of each load (such This load profi.le data indicates the expected drop in the voltage; as sotor horsepower, volt-amp rating, inrush currnet, starting volt-asps and torque), the length of time each load is required, and frequency and the time to recover to values specified in Regulatory the basis used to establish the power required for each safety load Cutde 1.9 from a postulated full sequential laoding of the diesel gen erators. (such as motor nameplate rating, pump run-out condition, or estinsted load under eq,ected flow and pressure) are used to verifv the calculations establishing the combined load demand to be Reference (1) DBR for ECN A-3748 conarcted to each diesel during the " worst" operating condition. In (2) DBR for ECM A-3660 applying this combined load demand to the selection of each diesel generator capacity, an acceptable design must satisfy Positions I snd 2 of Regulatory Guide 1.9.

 . To ensure that each diesel generator is capable of starting and accelerating to rated speed all the connected loads in the required sequence and within the mintmus time intervals established by the accident analyses, the PSB reviewer examines for each diesel gsnerator the loading profile curves, voltage and f requency recovering characteristic curves, and the response time of the excitation system to load vartettons. This examination must verify that the capability of each diesel generator to respond to voltage sci frequency variations satisfies Position 5 of Regulatory Guide 1.9. In addition, the adequacy of the circuit design for starting, disconaceting and connecting safety loads from and to each diesel asnerator is checked. This includes a review of the starting initiating circuits; manual and automatic sequential loading and unloading circuits; interrupting capacity of switchgear, load canters, control centers, and distribution panels; grounding requireients; and electrical protective relaying circuits including their coordination, relay settings, and assigned control power supplies for each load and each diesel generator. In reviewing the criteria governing the design of the thermal overload protection for sotors of motor-operated, safety-related valves, the reviewer is guided by Regulatory Guide 1.106.

i 13

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1 s SRP 8.3.1 REQUIREMENTS SYSTEM DESIGN Regarding the review of the electrical protective trip circuits of the diesel generator sets, Positions 8 and 9 of Regulatory Guide 1.9 On sustained undervoltage on the nuclear service bus all running are used as an evaluative guide. The capability of the automatic loads are tripped and the sequencing circuit is automatically reset. This prevents simultaneous arplication of all loads on the sequential loading circuits to reset during a sustained low voltage diesel generator on closing of the diesel generator breaker. condition on the diesel generators is reviewed to ensure that, upon restoration of normal voltage, the safety-related loads can be connected in the prescribed sequence. Otherwise, the reconnection The 4.16kV and 480 volt switchgear breakers are capable of being reclose after restoration of power. of all loads at the same time could result in an overload condition causing the trip of the respective diesel generator. In ensuring that those safety-related loads being powered through latched-type breakers are capable of being reconoected to their respective buses af ter restoration of power, the design must provide for resetting the breaker anticycle feature when there is an under-voltage condition. The normal function of this feature is to prevent immediate reclosure of a breaker following a trip. Where the proposed design provides for the sharing of diesel Rancho Seco is a single-unit plant. The capacity of diesel generators between units at the same site, ani connection and generators exceeds the total of connectable class 1E and non-cises disconnection of non-Class IE loads to end from the Class 1E lE loads. distribution buses, particular attention is given in the review to ensure that the implementation of such design provisions does not compromise the capacity or capability of standby power supplies. General Design Criterton 5 prohibits sharing unless it can ba eh?wn Rancho Seco is a single unit plant. that the diesel generators are capable of performing all required asfety functions in the event of an accident in one unit and an orderly shutdown and cooldown of the remaining units. In enmiring that the proposed design for sharing diesel generators between units meets the requirements of General Design Criteria 5 and 17 as supplemented by General Design criteria 34, 35, 38, 41 and 44 and - satisfies the positions of Regulatory Guide 1.9, the PSB reviewer is guided by Regulatory Guide 1.81. This guide sets fotth two principal positions. Position 3 applies to those construction permit applications docketed af ter June 1,1973, and prohibits the shtring of onsite power systems between units. Conformance of the design with Position 3 is verified by reviewing the descristive information including electrical drawings, to ensure that the onsite power system of each unit is electrically independent with respect to the onsite power system of other units. i 14

I SRP 8.3.1 REQUIREMENTS A SYSTEM DESICN Position 2 of Regulatory Guide 1.81 establishes acceptable bases Rancho Seco is a single-unit plant; therefore, sharing of onsite. umiar which sharing of onsite power systems between units is power supplies between units is not applicable. per:itted. Conformance with Position 2 with regard to the adequacy of diesel generator capacity and capability under the shtring mode of oparation is verified by following the procedure discussed ab,,,e for tabulating and summing all loads. In particular, the load tabulation and calculations establishing the diesel generator crpacity are examined to ensure that the selected capacity is sufficiant to power the minimum ESF loads in any unit and safely shut down the remaining units in the event of an accident in one unit and a single failure of spurious or false accident signal from another unit and loss of preferred power to all the units. In eddition, the physical arrangement of instrumentation and control devices on control room panels and consoles in one unit with respect to other units is examined to ensure that the design minimizes the ' coordination needed between unit operators to accomplish sharing of the standby power systems. In the absence of specific criteria in IEEE 308 governing the Battery chargers for non-Class IE batteries and pressurizer heater connection and disconnection of non-Class IE loads to and f rom the MCCs are the only non-Class IE loads assigned to these new diesels. Class 1E distribution buses, the review of the interconnections will Battery chargers are Class 1E and qualify as isolation devices. Class consider isolation devices as defined in IEEE 384 auf augmented by IE raceway is utilf red for feeding these chargers. Pressurizer heater Reguistory Guide 1.75 to determine the adequacy of the design. In MCCs are tripped on accident signals. They can bh manually connected ensuring that the interconnections between non-Class IE loads and only af ter a minimum time delay which is selected to ensure that all Class IE buses will not result in the degradation of the Class 1E safety-related loads have been started hefore these MCCs are connected. syttec, the isolation device through which stasiby power is supplied to the con-Class IE load, including ' control circuits ami connections to the Class IE bus, must be designed to meet Class IE requirement s. Should the standby power supplies not have been sized to secommodate the added non-Class IE loads during emergency conditions, the design must provide for the automatic disconnection of those non-Class IE loads upon the detection of the emergency condition. This action must be accomplished whether or not the laod was already connected to the power supply. Further, the design must , also prevent the automatic or manual connection of these loads during the transient stabiltration period subsequent to this event. Tha description of the qualification test program (CP stage) and the The diesel generators being added are of a design that has been rstults of such tests (OL stage) for demonstrating the suitability previously qualified for use in nuclear power plant applications. of the diesel generators as standby power supplies are judged to be receptsble if they satisfy the acceptance criteria stated in Subsection II. in the event that diesel generators have not been selected for a particular plant, a commitment from the applicant to cbtain diesel generators of a design that has been previously qu.211fied for use in nuclear power plant applications, or to perform qualific(tfon tests on diesel generators of a new design in accordance with the acceptance criteria, is considered acceptable at the CP stage of review. The raview of the diesel generator auxiliary systems in contained in SRP Ssctions 9.5.4 through 9.5.8. 15

a g SRP 8.3.1 REQUIREMENTS STSTEM DESIGN To assure that diesel generator reliability ami operation will not be degraded, the reviewer evaluates the diasel generator descriptive information and the results of failure modes and effects analyses in the SAR and using engineering judgment verifles the following items:

a. Provisions have been made in the facility design and in the a. The engine and generator control panels are located in a room design and installation of electrical equipment associated with separated from the engine and these control rooms are ventilated by-the starting of the diesel generators to minimize engine failure air handling units using filters. (Refer to DBR for ECN A-3748' to start on demand due to accumulation of dust and other Section III.2.s) ,

deleterious material ingested via the ventilation system or generated in the diesel engine room during normel plant operation on the electrical starting equipment, e.g. auxiliary relay contacts, control switches, etc., panel or individually mount ed.

b. The diesel generator sets are capable of operation at less than b. 'Ihe diesel generator units are capable of operation at low load for full load without degradation of performance or reliability and extended periods without degradation of performance or reliability.

operating procedures limit no load operation. (Refer to DBR for ECN A-3748 Section III.l.B.1)

c. A complete formal training program is provided for all c. The present training program will be revised to include the mechanical and electrical maintenance, quality control and requirements for the new diesels, operating personnel, including supervisors, who are responsible for the maintenance and availability of the diesel generators.

d. A preventive maintenance program is provided which encompasses d.

The preventive maintenance program is currently under review by the investigative testing of components and a replacement plan as TDI Owners Croup and the District. As a member of this Group, the specified in subsection II. District will incorporate applicable recommendations of this Group to their preventive maintenance program.

e. The repair and maintenance procedures provide for a final e. The present repair and maintenance procedures will be revised to equipment check and test procedures provide for returning the include the requirements for the new diesels.

diesel engine to automatic standby service and under the control of the control room operator. h 16

I A SRP 8.3.1 REQUIREMENTS SYSTEM DESIGN

f. Operating experience at certain nuclear power plants which have ta cycle turbocharged diesel en61nes manufactured by the f. There are no mechanical gear drives for the turbo chargers on the Electromotive Division (EPO) of General Motors driving emergency TDI engines supplied for Rancho Seco.

gsne-ators have experienced a significant number of turbocharger mechanical gear drive fallo-es occurring as the result of running the emergency diesel generators at no-losd or ligl t-load cos!!tions for extended periods. When this equipment is / cperated unter no-load cos!!tions, insufficient exhaust gas volume is generated to operate the turbochstgars as a result, the turbocharger is driven mechanically from a gear drive in order to supply enough combustion air to the engine to maintain reted speed. The turbocharger and mechanical drive gear - normally supplied with these engines are not designed for , trandby servi,ce encountered in nuclear power plant application j where the equipment may be called upon to operate at no-load or I' light-load coalition aol full speeds for the engine and generator are much lower than full-load speeds. The locomotive turbocharger diesel hardly ever runs at full speed except at full load. EPD has developed heavy duty turbocharger mechanical drive gear assemblies for installation on their diesel engines. EPD diesel engines drives proposed for driving emergency generators for nuclear power plants should be provided with heavy duty turbocharger mechanical drive gear assembly as recommended by the manufacturer. The reviewer verifies that the DO diesel engine is provided a heavy duty turbocharger techanical gear drive assembly to assure optimum availability of the emergency generators on demani.

g. Except for sensors and other equipment that must be mounted directly on the engine or associated piping, the controls and g. Engine and generator control panels are installed in a separate control room. The panels are seismically qualified. (Refer to DBR monitoring instruments are installed on a free-staoling floor for ECN A3748 Section it.l.B.f and II.1.A.3).

mounted panel located on a vibration free floor area. If the l floor is not vibration f ree, the panel should be equipped with vibration mounts. In the event that the instruments ami controls cannot be removed f rom the engine skid, due to plant dacign, the controls an! instrumentation should be environmentally qualified for vibration service. Until the environmental qualification of the components is completed, the applicant has implemented sai augmented inspection, test, ami calibration program. Verify that this program has been elequately described in the SAR, t 17

i i SRP 8.3.1 R5QUIRLMENTS SYSTEM DESIGN

5. Idtntification of Cables. Raceusys. and Terminal Equipment The identification scheme used for safety-related cables, raceways, 5. The identification scheme used for cables, raceways, and terminal and terminal equipment in the plant and internal wiring in the , equipment in the plant and internal wiring in the control boards is control boards is reviewed to see that it is consistent with IEEE designed to differentiate betweens (a) safety-related cables and 384 as augmented by Regulatory cuide 1.75. This includes the nonsafety-related cables, and (b) dif ferent channels or divisions of criteria for dif ferentiating between (a) safety-related cables, the safety-related cables. No nonsafety-related cables are run in riceways and terminal equipment of different channels or divisions, the Diesel Cenerator Butiding safety-related raceways. The design (b) nonsafety-related cable which is run in safety raceways. (c) provides for separation to meet the requirements of the single nonsafety-related cable which is not associated physically with any failure criteria of IEEE 279.

safety division, and (d) safety-related cables, raceways, and terminal equipment of one unit with respect to the other units at a multiunit site.

6. Vital Supporting Systems Thi PSB will review those auxillary systems identified as being 6. Instrumentation, control, and electrical aspects of vital supporting vital to the operation of safety-related loads and systems. The PSB systems have been addressed in amendment 68 of the Rancho Seco reviews the instrumentation, control, and electrical aspects of the operating Itcense for the electrical power distribution system vital supporting systems to ensure that their design conforms to the supporting the diesels. One class 1 and one non-class 1 Motor saEe criteria as those for the systems that they support. Hence, the control Center is added under ECN A-3748. These meet the same review procedure to be followed for ascertaining the adequacy of the independence, redundancy, and separation requiremects as their vital supporting systems is the same as that discussed herein Ivr diesel generator systems and the specific design requirements of the the onsite systems. In essence, the reviewer first becomes fastliar electrical distribution addition licensed by amendment 68. Other.

with the purpose and operation of each vital supporting system, diesel generator vital supporting systems are included in the including its components arrangement as depicted on functional following sections p& ID s. Subsequently, the design criteria, analyses, and description amt implementation of the instrumentation, control and electrical Fuel oil system SRP 9.5.4 equipment, as depicted on electrical drawings, are reviewed to cooling water system SRP 9.5.5 verify that the design is consistent with satisfying the acceptance Starting air system SRP 9.5.6 criteria for Class IE systems. In addition, it is verified that the Lubrication system SRP 9.5.7 vital supporting system redundant instrumentation, control devices, Ventilation system for and loads are examined to verify that they are powered from the same diesel generator butiding SRP 9.4.5 redumlant distribution system as the system that they support. The PSB will also verity that the vital supporting systems which are associated with the emergency diesel engine such as the fuel oil storage and transfer system, cooling water system, starting air system amt lubrication system are in accordance with the acceptance criteria.

18. .

g SR.P 8.3.1 RgOUIREMENTS

                                                                                                                  -PSiniDECIcw The ASB reviewed the other aspects of the vital supporting systems               . Heating and ventilating systems (HVAc) covering areas where vital to verify that the design, capacities, and physical independence of              'anpporting systems are located, have been reviewed in amendment 68.

these systems are adequate for their intewled fun?tions. 1 1.Jed . to the operating license for Rancho Seco, is a review of the heating and wentilation (H&V) systees identified as necessary to Class IE systees, such as the H&V systems for the The diesel generator building is equipped with a normal electrical switchgear and diesel generator rooms.. The ASB will (non-essential) VAC system backed by an essential ventilating system verify the adequacy of the H&V systes design to maintain the assuring temperature and humidity control under all postulated temperature aux! relative humidity in the room required for proper conditions. operation of the safety equipment during both norest and accident conditions. It will.also verify tlwt redundant H&V. systems are located in the same enclosure as the reduntant unit they serve, or are separated in accordance with the same criteria as those for the systems they support.

7. System Testing and Surveillance In ensuring that the proposed periodic onsite testing capabilities 7. The design and installation of modifteations te.the auxiliary of the ac onsite power system satisfies the requirements of General electrical equipment facilitate inspection and testing which will be.

Design Criterion 18 and the positions of Regulatory Guides 1.108 and performed to comply with the guildelines of General Design criteria 1.118, the descriptive information (CP and OL stages) functional 18 as described below logic diagrams (CP and OL stages), ani electrical schematics (OL stage) are reviewed to verify that the design has the built-in a. During equipment shutdown, periodic inspection and testing of capability to permit integral testing of Class IE systems on a wiring, insulation, connections, and relays to assess the periodic basis when the reactor is in operation, continuity of the systema and the condition of components. The descriptive information (CP and OL stages) and the design b. During normal plant cperation, periodic testing of the implementation as depicted on electrical drawings (OL stage) of the operability --4 functional performance of onsite power supplies means proposed for automatically indicating at the systee level a including Diesel Cenerators, circuit breakers and associated bypassed or deliberately inoperative status of a redundant portion control circuits, relays and buses. of a safety-related systes are reviewed to ascertain that the design is consistent with Regulatory Guide 1.47 and Branch Technical c. During plant shutdow% testing of the operability of the Class . Position ICSS 21 (PSB). This position establishes the basis to be IE system as a whole. Under conditions as close to design as considered in arriving at an acceptable design for the inoperable Practical, the full operational sequence that brings the system status in11 cation system. into operation, including operation of signals of the engineered safety features actuation system and the transfer of . power between the offsite and onsite power system, will be, tested.

d. Preoperational Testing.

Regulatory Guide 1.47 required bypassed,and inoperable status indication for nuclear power plant safety systems required to be tinken out of service more frequently than once per year during plant operation. .The schedule established for testing and servicing of all of the new electrical equipment will-result in bypassed and inoperable conditions occuring no more than once per year. Consequently, based upon the criteria established 1.i Regulatory cuide 1.47,' bypassed and inoperable status indications are not required for any of the electrical equipment recently added at Rancho Seco. l 19 i _

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                                                                                           - 9; SRP 8.3.1 REQUIREMENTS                                                        SYSTEM DESIGN

8. Fire Protection for Cable Systems In ensuring that the requirements of General Design Criterion 3 have - 8. Cables are purchased to comply with the requirement of IEEE 383.

been set, CMEB will review the design of the fire stops and seals, Cables are sized conservatively ani raceway fills are limited to incitsiing the materials, their characteristics with regard to ensure compliance with the industry practice. For more details on flammability and fire retardancy, earl their fire ursierwriters rating fire protection of cables, see comparison of SRP Section 9.5.1. In accordance with SRP Section 9.5.1. All cable and cable tray penetrations through walls and floors sol any other types of cable ways or conduits should have fire stops installed. PSB will review cable derating sol raceway fill to ensure compliance with accepted industry practices. i i l } l 20

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SRP 9.4.5 REQUIREMENTS CYRTF.M DESIQE

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gg III. Review Procedures ,

1. The Design Basis Report includes the system description,

1. The SAR is reviewed to verify that the system description and performance requirements and the temperature limits for the ESFVS e piping and instrumentation .11agrams (P51Ds) show the ESF7S (refer to Tet for Ect A3748 Sect um 111.2.3), 4 equipment used for normal operation, and the amt.I.nt temperature - ' ,

limit s for the areas serviced. The system perfotmance requirements .

are reviewed to determine that they 11=tt allowable co'eponent operational degradation (e.g., joss of function, damper leakage) and describe the procederse that w!!! be followed te detect wt

correct these cowlitions. The reviewer, using resulte from felture males and ef fects analyses as appropriate, will determine that the l

 !                 safety-related portion of the system is capable of sustaining the                                                                                      -

, f atture f.f any active component. M ( .., I 2. The system P& ids, layout drawing, and component der tir*lons and' . characteristics are then reviewed to determine that:

                                                                  '                                       2a. The RVAC system P& ids and drawings shew that the eschatfsl ventilation system is physically separete from the normal system

a. F.asentiel portions of the ESPVS are correctly identified and (refer to P&ID M-505 and Drawina M-442 Sheets 14). - The HVAC -

are teolable from nonessential portiona of tie system. The , system operational sales and damper positions are indicated in the P&lDs are reviewed to verify that they clesrly in!!cate the Design Basis Report (refer to DflR for eof A3748 Section III.2.A.3). l- ,g physical dtilstens between such portions and indicate design . classificattoc changes. System drsvings are also reviewed to 5

                                                                                                                                                                                                              .Q v nee that they Show the means for accomplishing isolation, and l                         the system description la reviewed to identify stalmum                                       )'

performance requirements for the isolation daepers. ~ For the typical system, the drawings and description mia reviewed to ' verify that two automatically operated iso 1*t ton dampera in sortes separate nonessential portions ard sponents from th* esgential portions. 2b. The essentist ventilation system components and ductwork are , Seismic Category I (refer to DBR for ECN A3748 Section II.2.C.2). l Essentist portions of the ESFVS, including the toolation q i b. seismic classifications are noted en P&tDe (refer to P&iD M-505). j dampers separc. ting essential f rom nonessentiti portions, are classified Setamic Category I. Component and system descriptions in the SAR that identify mechanical on1 performance characteristics are reviewed to verify that the _ above classif tentions have been in:1uded, and that the P& ids indicate points of change in design clasntiteation. 2c. A flow switch is installed to provide e low air ficir slarm for the essential air handling system aerving the DC cont:o1 room. Access

c. Design provisions have been made that permit a:gropriate han been allowed for innervice Inapection of the equipment (refer inservice inspection and functions 1 testing of synten to P4ID H-505).

componenta important to safety. It to acceptable if the SAR l' information delineates a testing and inspection program enrl if , ^, , i the system drawings show the necessary test recirculation loops around fans or isolation dampers that wow 14 be required by this program.

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                                                                                                                                                                     ;.                   s SPP 9.4.5 REQUIREMENTS                                                                                - STSTUftWSicN
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3. The reviewer verifies that the system has been designed so that

                                                                                                                                                , i,                                              .

system function will be maintained es req stred in the event of 4- - ! adverse environmental phenomena or loss of of f stte power. The * . reviewer evaluates the system, using engineering judseent and the result s of f at ture modes and ef fects analyses, to determine thats l

a. The f ailure of ntnessential portio:ss of the system or of other nonecteste systees, components, or structures located close to 3a. Fattore of non-Setsete Category I systema or equipment will not ,

essential portions of the system will not preclude operation . prevent sativfactory operatton of the essentiet ventilation systems i of the essential portions of the ESFVS. Reference to san (refer to DBR for Eul A1748 Seetton II.2.A.6). sections describing site features and the general arrangement l~ 3 j and layout drawings will be necessary, as well as the SAR 2 tabulation of setsete desten claastf tcettons for structurem and systems.

b. The essential portions of the ESFVS are protected f rom the ~

ef fects of floods, hurricanes, tornadoes, and internally and 3b. .The essential ventilation systems are located in a Setemic rategory esternally generated stastles. Flood protection ael miestle i structure designed to withstand the effects of wind-generated , protection criteria are discussed and evaluated in detatt etssiles as defined in the DBR (refer to DBR for EQt A)748 Section 1 unter the Section 3 settee of the SRP. The location and the i III*0.81. design of the system, structures, and f an rooms (eetcles) are i resteved to determine that the degree of protectfu. Provided j is adequate. A statement to the ef fect that the system is , located in a Setssic Category I structure that is tornado etsalle and *lood protected, or that components of the system i vilf be located in individual cubicles or rooms that util withstarwl the ef fects of both flooding ant etsstles is acceptable. l f c. The totr.1 system has the capability to detect and contro* 1eakage of airborne contamination from the system. It is acceptable if the following con!!tions are mets (1) The capahtlity for isolating nonessential portions of the ESIVS by two automatically actuated isolation dampers in series is shown on the p6 ids. W ESFVS h %W e N N MMM mW h $n W to be isolated to perett the essential system to perform its (2) The ESFVS has provietone to actuate ventilation equipment funct ton (refer to P&ID M405). In the engineered safety feature areas before ashtent temperatures exceed design rated temperatures of g *

                       ***P""*"                                                                         an ESFAS af anal and controlled by teeperature switches. The essential ventilation system for the control room to controlled by a tengerature switch (refer to r&1D M-505).

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I bk SRP 9.4.5 REQUIREMENTS STSTEM DESIGN

d. Essentist components ami subsystems can function as reqda red 34. Each diesel generator train has its own independent essentist in the event of loss of offsite power. The system design w!!! ventilation system with l's own smsree of aust11ary electric power he acceptable if the ESFVS meets minimum system requirements (refer to P&ID M-505 and one-l.ine Disaram FIOS, Sheets 31 and 32).

as stated in the SAR assuming's failure of a single e:tive component within the system itself or in the auntitary electric power source which supplies the system. The SAR is reviewed to see that for each ESFVS component or subsystem affected by the loss of off atte power, the resulting system performance will not af(ect the capaht!!ty of any engineered safety feature equipment. Statements in the SAR sol results of f at ture modes and ef fects analyses are considered in verifying th.st the system meets these requirements. This wit! , he an acceptable verification of system functional reliability. '

4. The descriptive information, P&lDs, ESFVS drawings, and f ailure 4 the essential ventilation systess for each t rain are physically modes and ef fects analyses in the SAR are reviewed to assure that separated. A single active failure in one t rain will not prevent essential portions of the system can function following design settsf actory operation of the ESFVS in tip redundant train (refer basis accidents assuming a concurrent single active fatture. The to DBR for ECM A3748 Section 12.1. A,5).

l , reviewer evaluates the analyses presented in the SAR to assure function of requi red componente, traces the availability of these components on system drawings, and checks that the SAR contains vertiteetion that minimum system isolation or filtration requirements are met for each accident sitaation for the required time spans. For nach case the design will he acceptable if minimum system requirements are met.

5. The ESFVS is rewteved to assure that adequate means is provided in 5. The bottom of the engine room f resh air intake is located at grade the system design for control of strhorne particulate material level to provide the required air flow distribution for cooling the (dust) accumulation. The system arrangement is restewed to verify equipment (refer to Drawing M-442 Sheet 3),

that a etntmum of 20 feet exists f rom the bottom of all fresh air intakes to grade elevation, or that electrical cabinet s are The bottom of the fresh air intake for the control room essential provided with autt:able seats or gaskets. ventilstion system is approsisately 20 feet above grade elevatios. Medium-ef ficiency filters are provided in the essential air handling antts (refer to Drawing M-442, Sheet 1). 23 t

SRp 9.5.1 REQUIREMENTS *

                                                                                               '                                 SYSIIM DESIGN

5. General Plant Guidelines (1) The Train A and Train B diesel generator units are separet~f by a oli having .

Q. Building Desion a minimum fire resistance of 3 hours. The train A and train B radiator fans are in outdoor areas separated by the diesel generator building, and (1) Fire barriers with a minimum fire resistance rating of 3 hours should surrounded on the remaining three sides by a high concrete block wall. The be provided to: train A and train B diesel oil fuel tanks and fuel oil transfer pur;rs are underground in a yard area separated by the DG building and radfator fan: (a) Separate safety-related systems from any potential fires in non- enclosures. safety-related areas that could affect their ability to perform Barrier posts and administrative procedures are provided where necessary their safety functioni to preclude damage in toth trains from any potential fires in non-safety . (b) Separate redundant divisions or trains of safety-related systems related areas. from each other so that both are not subject to damage from a single fires (c) Separate individual units on a multiple-unit site unless the -(2) No credit is taken for interior walls as fire areas are deffned for only requirements of General Design Criterion 5 are met with respect the same safety division. and include only components for the diesel to fires. generator system. (2) Appropriate fire barriers should be provided within a single safety division to separate canponents that present a fire hazard to other (3) Fire barrier penetration seals having the same fire rating as the fire . safety-related components or high concentrations of safety-related barrier are provided for pipe, conduit and cable trays that pass through cables within that division. openings in the fire barrier. Penetration seal designs are tested and (3) Openings throogh fire barriers for pipe, conduit, and cable trays qualified under ASTM E-119 standards. Only noncombustible materials are which separate fire areas should be sealed or closed to provide a fire used for fire barrier penetration seals and seals inside condult. resistance rating at least equal to that required of the barrier' itself. Openings inside conduit larger than 4 inches in diameter for openings inside conduit that are 4 Inches or less in diameter, conduit should be sealed at the fire barrier penetration. Openings inside extending at least 5 feet on each side of the barrier is sealed either at conduit 4 inches or less in diameter should be sealed at tne fire both ends or at the fire barrier to prevent the passage of smoke and hot barrier unlees the conduit extends at least 5 feet on each side of the gases. Openings inside conduits that are larger than 4 inches in diameter are provided with a fire seal rated the same as the barrier. fire barrier and is sealed either at both ends or at the fire barrier with noncombustible material to prevent the passage of smoke and hot gases. Fire barrier penetrations that must maintain environmental isolation or pressure differentials should be qualified by test to maintain the barrier integrity under such conditions. penetration designs should utilize only noncombustible materials and should be qualified by tests. The penetration qualification tests should use the time-temperature exposure curve specified by ASTM E-119, " Fire Test of Building Construction and Materials." The acceptance criteria for the test should require thatt (a) The fire barrier penetration has withstood the fire endurance test without passage of flame or ignition of cables on the unex-posed side for a period of time equivalent to the fire resistance rating required of the barrier. 24

4 SRp 9.5.1 RECCIRD(ENTS I hadic.14 DESIGH l (b) The temperature levels recorded for the unexposed side are anal-

                        / zed and demonstrate that the maximum temperature does not exceed 325 degrees F.

(c) The fire barrier penetration remains intact and does not allow projection of water beyond the unexposed surface during the hose stream test. The stream shall be delivered through a 1-1/2-inch nozzle set at a discharge angle of 30% with a nozzle pressure of . 75 psi and a minimum discharge of 75 gpm with the tip of the . nozzle a maximum of 5 f t f rom the exposed f aces or the stream shall be delivered through a 1-1/2-inch nozzle set at a discharge angle of 15% with a nozzle pressure of 75 psi and a minimum discharge of 75 gym with the tip of the nozzle a maximum of 10 ft from the exposed faces or the stream shall be delivered through a 2-1/2-inch national standard playpipe equipped with 1-1/8-inch tip, nozzle pressure of 30 psi, located 20 ft from the exposed 3 face. (4) Penetration openings for ventilation systems should be protected by [' (4) There are no penetration openings for the ventilation fire dampers having a rating equivalent to that required of the bar- { systems in the fire-rated barrier separating the two trains. rier (see NFPA-90A, " Air Conditioning and Ventilating Systems"). Flexable air duct coupling in ventilation and filter systems should be noncembustible. l l (5) Door openings in fire barriers should be protected with equivalently (5) There are no door openings in the fire-rated barrier rated doors, frames, and hardware that have been tested and approved separating the two trains. by a nationally recognized laboratory. Such doors should be self- ] closing or provided with closing mechanisms and should be inspected ; j semiannually to verify that automatic hold-open, release, and closing

.              mechanisms and latches are operable. (See NFPA 80, " Fire Doors and 1               Windows.")

one of the following measures should be provided to ensure they will j protect the opening as required in case of fires d (al Fire doors should be kept closed and electrically supervised at a 7 continuously manned locations t , ~ (b) Fire doors should be locked closed and inspected weekly to verify that the doors are in the closed positions (c) Fire doors should be provided with automatic hold-open and re-1 lease mechanisms and inspected daily to verify that doorways are

free of obstructions or .

(d) Fire doors should be kept closed and inspected daily to verify that they are in the closed position. 3 The fire brigade leader should have ready access to keys for any locked fire doors. I I 25 l t 1 i

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SRP 9.5.1 REQUIREMENTS ' SYSTDI DESIGIf ' ~l 1 Areas protected by automatic total flooding gas supprassion systems (5) There are no gas suppression systems in the Diesel-Generator should have electrically supervised self-closing fire doors or should Building. I satisfy option (a) above. (G) Personnel access routes and escape routes should be provided for each fire area. Stairwells outside primary containment serving as escape (6) The DG Building is a single story building with a messanine level which is accessed by a open spiral stair case. There

,i        routes, access routes for firefighting, or access routes to areas                       are two ground level exits from each side of the DG containing equipment necessary for safe shutdown should be enclosed in                  Building.

i masonry or concrete towers with a minimum fire rating of 2 hours and self-closing class B fire doors. t (7) Fire exit routes should Ye clearly marked. (7) Exit locations from all building areas are clearly

                                                                                                 ' identified.

d (Q) Each cable spreading room should contain only one redundant safety (6) The Train "A" and train "B" cables are separated by a 3 hour' I division. Cable spreading rooms should not be shared between reac- fire-rated barrier and are routed underground in separate j tors. Cable spreading rooms should be separated from each other and cable tunnels to the NSEB. from other areas of the plant by barriers having a minimum fire resis- . tance of 3 hours. 3 (9) Interior wall and structural components, thermal insulation materials, radiation shielding materials, and soundproofing should be nonccmbus-(9) All materials and finishes used in the Diesel-4 Generator Building are of the listed acceptable l tible. Interior finishes should be non-combustible. . types and are noncombustible. Materials that are acceptable for use as interior finish without evidence of test and listing by a nationally recognized laboratory are the following:

           .      Plaster, acoustic plaster, gypsum plasterboard (gypsum wall-        7 1                 board), either plain, wa11 papered, or painted with oil- or water-  -                                                                       .

! base paints ]-

           .      Ceramic tile, ceramic panels
           .      Glass, glass blocks; i
           .      Brick, stone, concrete blocks, plain or painted
           .      steel and aluminum panels, plain, painted, or enameled
           .      Vinyl tile, vinyl-asbestos tile, linoleum, or asphalt

. tile on concrete floors. ] , (lo! Metal deck roof construction should be noncombustible and listed as (10) The Diesel-Generator Building roof is a noncombustible rein-4 " acceptable for fire" in the UL Building Materials Directory, or forced concrete roof. listed as class I in the Factory Mutual System Approval Guide. (11) Suspended ceiling and their supports should be of noncombustible (11) There are no suspended ceilings in DG $uilding. construction. Concealed spaces should be devoid of combustibles ex-cept as noted in Position C.6.b. i . r l I 26 i t e i

-r

SRP 9.5.5 REQUIREMENTS ' SYSTEM DESIGN - t (12) Transformers installed inside fire areas containing safety-related

(12) There are no transformers in the DG Building. systems should be of the dry type or insulated and cooled with noncom-bustible liquid. Transformers filled with combustible fluid that are located indoors should be enclosed in a transformer vault (see Section-450(c) of NFPA 70, " National Electrical Code"). (13) Outdoor oil-filled transformers should have oil spill confinement (13) from outdather oil-filled transformers are located at least 50 feet features or drainage away from the buildings. Such transformers Diesel Generator Building. should be located at least 50 feet distant from the building, or by ensuring that such building walls within 50 feet of oil-filled trans-formers are without openings and have a fire resistance rating of at. least 3 hours. - 114) Floor drains sitei to remove expected firefighting waterflow without .(14) Floor drain capacities are adequate to prevent flooding flooding safety-related equipment should be provided in those areas ' damage to safety-related equipment due to discharge of where fixed water fire suppression systems are installed. Floor suppression systems or pipe break conditions in building drains should also be provided in other areas S r.ere hand hose lines areas where fixed water fire suppression systems or piping may be used if such firefighting water could cause unacceptable damage are installed. Consequences of. inadvertent operation or to safety-related equipment in the area (see NFPA-92, " Waterproofing pipe rupture are evaluated for affected areas in the 83-41 and Draining of Floors"). Where gas suppression rystems are instal- analysis report supporting the Diesel Generator Fire Nazards' led, the drains should be provided with adequate seals or the gas Analysis. suppression system should be sized to compensate for the loss of the suppression agent through the drains. Drains in areas containing combustible liquids should have provisions for preventing the backflow of combustible 11gulds to safety-related areas through the inter-connected drain systems. Water drainage from areas that may contain radioactivity should be collected, sampled, and analyzed before dis-charge to the environment.

b. Safe Shutdown Capability (1) Fire Protection features should be provided for structures, systems, (1) Redundant trains of safety-related equipment and cable and components important to safe shutdown. These features should be installed inside the Diesel Generator Building are separated .

capable of limiting fire damage so that by a 3-hoair fire-rated barrier. In addition, automatic fire suppression and fire detection systems are provided for the engine, control & mezzanine rooms for each train. The fire protection features provided limit fire damage so that (a) One train of the systems necessary to achieve and (al One train of systems necessary to achieve and maintain hot shut- maintain hot shutdown conditions from either the down conditions f rom either the control room or emergency control control roon or emergency control station (s) is free of station (s) is free of fire damages and fire damage. (b) Systems necessary to achieve and maintain cold shutdown from (b)' No repairs are required for the diesel generator to either the control room or emergency control station (s) can be achieve and maintain cold shutdown. repaired within 72 hours. . (2) To meet the guidelines of position C5.b.1, one of the following means of ensuring that one of the redundant trains is free of fire damage s should be provided (a) Separation of cables and equipment and associated circuits of (a) Equipment, cables and associated circuits of redundant-redundant trains by a fire barrier having a 3-hour rating. diesel generators are separated by a fire barrier having a' Structural steel forming a part of or supporting such fire 3-hour rating. There is no building structural steel barriers should be protected to provide fire resistance equiva- supporting or forming fire barriers in the Diesel Generator lent to that required of the barriers Building. l 27 s t i

SRP 9.5.1 REQUIRENENTS l~ SiSIEH DESIGN l

   '        (b) Separation of cables and equipment and associated circuits of redundant trains by a horizontal distance of note than 20 feet with no intervening combustible or fire hazards. In addition, fire detectors and an automatic fire suppression system should be                                                         (r installed in the fire areas or (c) Enclosure of cable and equipment and associated circuits of one redundant train in a fire barrier having a 1-hour rating. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area.

(3) If the guidelines of Positions C$.b.1 and C5.b.2 cannot be met, then (3) Guidelines have been complied with. alternative or dedicate 5 shutdown capability and its associated circuits, independent of cables, systems or components in the area, room, or zone under consideration should be provided. .

c. Alternative or Dedicated Shutdown capability (c) Alternative or dedicated shutdown capability is not addressed since the fire protection features described above (1) Alternative or dedicated shutdown capability provided for a specific satisfy the guidelines of Positions C5.b.1 and C5.b2 as fire area should be able to achieve and maintain suberitical noted.

reactivity conditioas in the reactor, maintain reactor coolant inven-I tory, achieve and maintain hot standby

conditions for a PWR (hot shutdown
for a BWR) and achieve cold shutdown
conditions within 72

hours and maintain cold shutdown conditions t!+reaf ter. During the

,           postfire shutdown, the reactor coolant system process variables shall I

be maintained within those predicted for a loss of normal ac power, and the fission product boundary integrity shall not be affecteds i.e., there shall be no fuel clad damage, rupture, or any primary coolant boundary, or rupture of the containment boundary. i I (2) The performance goals for the shutdown functions should be ta) The reactivity control function should be capable of achieving and maintaining cold shutdown reactivity conditions. 1 b) The reactor coolant makeup function should be capable of maintaining i the reactor coolant level above the top of the core for BWRs and be within the level indication in the pressurizer for PWRs. (c) The reactor heat removal function should be capable of achieving and , , maintaining decay heat removal. (d) The process monitoring function should be capable of providing direct readings of the process variables necessary to perform and control the above functions. , s l l 28

       *As defined in the Standard Technical Specifications.

2- 1

                                                                                                       -i w,

SRP 9.5.1 fEQUIRENDrfS (e) The supporting functions should be capable of providing the process cooling, lubrication, etc., necessary to permit the operation of the equipment used for safe shutdown functions. . (3) The shutdown capability for specific fire areas may be unique for each such area, or it may be ene unique combination of systems for all such areas. In either case, the alternative shutdown capability shall be independent of the specific fire area (s) and shall accommodate post-fire conditions where offsite power is available and where offsite power is not available for 72 hours. Procedures shall be in effect to implement this capability. ,. l (4) If the capability to achieve and maintain cold shutdown will not be l available because of fire damage, the equipment and systemr comprising the means to achieve and maintain the hot Trandby or hot shutdown condition shall be capable of maintaining doch conditions until cold shutdown can be achieved. If such equipment and systems will not be capable of beirig powered by both onsite and offsite electric power .e systems because of fire damage, and independent onsite power system shall be provided. The number of operating shift personnel, exclusive of fire brigade members, required to operate such equipment and sys-tems shall be onsite at all times. . (5) Equipment and systems comprising the means to achieve and maintain cold shutdown conditions should not be damaged by fires or the fire damage to such equipment and systems should be limited so that the ' systems can be made operable and cold shutdown achieved within 72 hours. Materials for such repairs shall be readily available onsite and procedures shall be in effect to to implement such repairs. , r If such equipment and systems used prior to 72 hours after the fire will not be capable of being powered by both onsite and offsite elec- i tric power systems because of fire damage, and independent onsite 4 power system should be provided. Equipment and systems used af*ter 72 hours may be powered by offsite power only. .! (6) Shutdown systems installed to ensure postfire shutdown capability need not be designed to meet seismic category I criteria, single failure criteria, or other design basis accident criteria, except wtere re-quired for other reasons, e.g., because of interface with or impact on existing safety systems, or because of adverse valve actions iue to fire damage. (7) The safe shutdown equipment and systems for each fire area should be . known to be isolated from associated circuits in the fire area so that hot shorts, open circuits, or shorts to ground in the associated circuits will not prevent operation of the safe shutdown equipment. The separation and barriers between trays and conduits containing associated circuits of one safe shutdown division and trays and con-duits containing associated circuits or safe shutdown cables from the safe shutdown equipment, should be such that a postulated fire involving associated circuits will not prevent safe shutdown. i 29 R I i i

i sue 9.3.1 PZOUIREMENTS I' SYSTEM DESIGN

d. Control of Combustibles (1) Safety-related systems should be isolated or separated from -

combustible materials. When this is not possible because of the (1) . Each train is provided with a diesel fuel oil day tank nature of the safety system or the combustible material, special having a capacity of 550 gallons. Each tank is located . protection should be provided to prevent a fire from defeating the inside the building in a diked enclosure that can contain safety system function. Such protection may involve a combination of 110% of the tank capacity. Automatic fire detection and automatic fire suppression, and construction capable of withstanding suppression systems are provided in the area where the day and containing a fire that consumes all combustibles present. tanks are located. Examples of such combustible materials that may not be separable from the remainder of its system ares (a) Emergency diesel generator fuel oil day tanks. (b) Turbine-generator oil and hydraulic control fluid systems. (c) Reactor coolant pump lube oil system. (2) Bulk gas storage (either compressed or cryogenic), should not be permitted inside structures housing safety-related equipment. Storage (2) Diesel-generator air starting system has two air receivers of flammable gas such as hydrogen should be located outdoors or in in each train that are pressurized to 250 psig. The separate detached buildings so that a fire or explosien will not receivers are provided with safety relief valves to prevent overpressurization. adversely affect any safety-related systems or equipment. (Refer to NFPA 50A, " Gaseous Hydrogen Systems.") Care should be taken to locate high pressure gas storage containers with the long axis parallel to building walls. This will minimize the possibility of wall penetration in the event of a container failure. Use of compressed gasses (especially flammable and fuel gases) inside buildings should be controlled. (Refer to NFPA 6, " Industrial Fire Loss Prevention.") (3) The use of plastic materials shculd be minimized. In particular, (3) The use of plastic materials has been minimized. halogenated plastics such as polyvinyl chloride (PVC) and neoprene should be used only when substitute noncombustible materials are not available. All plastic materials, including flame and fire retardant materials, will burn with an intensity and BTU production in a range similar to that of ordinary hydrocarbons. When burning, they produce heavy smoke that obscures visibility and can plug air filters, especially charcoal and HEPA. The halogenated plastics also release free chlorine and hydrogen chloride when burning which are toxic to humans and corrosive to equipment. (4) Storage of flammable 11gulds should, as a minimum, comply with the (4) Complies with NFPA 30 - 1973. requirements of NFPA 30, " Flammable and Combtstible Liquids Code." (5) Hydrogen lines in safety-related areas should be either designed to (5) There are no hydrogen lines in the Diesel Generator seismic Class I requirements, or sleaved such that the water pipe is Building. directly vented to the outside, or should be equipped with excess flow valves so that in case of a line break, the hydrogen cane-.tration in the affected areas will'not exceed 2%. . 30

r

e. Electrical Cable Construction. Cable Trays, and Cable f Penetrations j

(1) only metal should be used for cable trays. Only metallic tubing (1) All class IE cables are run in metallic cable trays or in should be used for conduit. Thin-wall metallic tubing should not be rigid steel conduits. Thin-wall metallic tubing is used for used. Flexible metallic tubing should only be used in short lengths lighting and for non-Class 1E cables. Flexible metallic to connect components to equipment. Other raceways should be made of conduit is used only to make connections to the equipment. noncombustible material. (2) kedundant safety-related cable systems outside the cable spreading (2) Train A and Train B safety-related cable systems are room should be separ.ted from each other and from potential fire separated by a barrier having a minimum fire rating of 3 exposure hazards in nonsafety-related areas by fire barriers with a hours. Cable trays are accessible for manual fire fighting. minimum fire rating of 3 hours. These cable trays should be provided Line type heat detectors are not used. An automatic pre- . with continuous line-type heat detectors and should be accessible for action sprinkler system and detection system is provided for manual fireflohting. Cables should be designed to allow wetting down the Diesel Generator Building. Manual hose stations and with fire suppression water without electrical faulting. Manual hose portable extinguishers are provided at the access points stations and portable hand extinguishers should be provided. into the Diesel Generator Building. Cable systems are designed to allow wetting down with fire suppression water Safety-related cable trays of a single division that are separated without causing electrical faulting. from redundant divisions by a fire barrier with a minimum rating of 3 hours and are normally accessible for manual firefighting should be protected from the effects of a potential exposure fire by providing

automatic water suppression in the area where such a fire could occur.

Automatic area protection, where provided, should consider. cable tray , arrangements and possible transient combustibles to ensure adequate water coverage for areas that could present an exposure hazard to the cable system. Manual hose standpipe systems may be relied upon to provide the primary fire suppression (in lieu of automatic water suppression systems) for safety-related cable trays of a single division that are separated from redundant safety divisions by a fire barrier with a minimum rating of 3 hours and are normally accessible for manual firefighting if all of the following conditions are met (a) The number of equivalent

standard 24-inch-wide cabla trays (both safety-related and nonsafety-related) in a given fire area is six or less; (b) The cabling does not provide instrumentation, control or power to systems required to achieve and maintain hot shutdowns and (c) smoke detectors are provided in the area of these cable routings, and continuous line-type heat detectors are provide in the cable trays.

Safety-related cable trays that are not accessible for manual fire fighting should be protected by a zoned automatic water systcm with open-head deluge or open directional spry nozzles arranged so that

Trays exceeding 24 inches should be counted as two trays trays exceeding 48 inches should be counted as three trays, regardless of tray fill.

31 I I

                                                                                    -g  ~

SRP 9.f.1 REQUIREMENTS SYSTEM DESIGN adequate water coverage is provided for each cable tray. Such cable trays should also be protected from the effects of a potential expo-

   .      sure fire by providing automatic water suppression in the area where such a fire could occur.

In other areas where it may not be possible because of other overriding design features necessary for reasons of nuclear safety to separate redundint safety-related cable systems by ,, 3-hour-rated fira barrierp, cable trays should be protected by an automatic water system.with open-head deluge or open directional spray nozzles arranged so that adequate water coverage is provided for each cable tray. Such cable trays should also be protected from the effects of a potential exposure fire by providing automatic water suppression in the area where such a fire could occur. The capability to achieve and maintain safe shutdown considering the effects of a fire involving fixed and potential transient combustibles should be evaluated with an without actuation of the automatic suppression system and should be justified on a suitably defined basis. (3) Electric cable construction should, as a minimum, pass the flame test (3) The cablec in the Diesel Generator Building co~ ply with the in the current IEEE Std 383. (This does not imply that cable passing i requirements of IEEE Standard 383. this test will not require fire protection.) 6 (4) Cable raceways should be used only for cables. (4) Cable raceways are used for cables only. (5) Miscellaneous storage and piping for flammable or combustible liquids (5) There is no storage and piping for flammable or combustible or gases should not create a potential exposure hazard to safety- liquids or gases other than the. diesel generator day tanks.

related systems.

i

f. Ventilation (1) The products of combustion and the means by which they will be removed (1) Separate ventilation systems (both normal and essential)

I from each fire area should be established during the initial stages of with separate ducting and air handling units are provided plant design. Consideration should be given to the installation of for each train. The essential system can be used to e automatic suppression systems as a means of limiting smoke and end discharge smoke and combustion gasas directly to the 1 heat generation. Smoke and corrosive gases should generally be dis. outside. Automatic suppression systems that are installed 4 charged directly outside to an area that will not affect safety. thre'aghout the building will provide a means of limiting I' related plant areas. The normal plant ventilation system may be used heat geaeration. for this purpose if capable and available. To facilitats manual

 !        firefighting, separate smoke and heat vents should be provided in specific areas such as cable spreading rooms, diesel fuel oil storage areas, switchgetr rooms, and other areas where the potential exists

, for heavy smoke conditions (see NFPA 204 for additional guidance on smoke control). (2) Release of smoke and gases containing radioactive materials to the f (2) Radioactive materials are not present in the Diesel Generator environment should be monitored in accordance with emergency plans as Luilding, described in the guidelines of Regulatory Guide 1.101, " Emergency , Planning for Nuclear Power Plants." Any ventilation system designed to exhaust potentially radioactive smoke or gases should be evaluated 0 32 w* **- 3

                                                                                        '                      SiSIEM DESIGN SRP O.5.A REQUIREMENTS to ensure that inadvertent operation or single f ailures will not violate the radiologically controlled areas of the. plant design. This                   .

requirement includes containment functions for protecting the public and maintaining habitability for operations personnel. g3) Special protection for ventilation power and control cables may be (3) Power and control cables for ventilation systems are routed required. The power supply and controls for mechanical ventilation outside the area served to the extent practical. Fully independent and redundant HVAC systems are provided for each systems should be run outside the fire area served by the system where practical. train so that the loss of one system leaves the other system unaffected to supply necessary ventilation. (4) Engineered safety feature filters should be protected in accordance (4) HVAC filters are made of fire-resistant glass fiber ' with the guidelines of Regulatory Guide 1.52. Any filter that in- materials that do not support combustion. cludes combustible materials and is a potential exposure fire hazard that may affect safety-related components should be protected as determined by the fire hazards analysis. (5) The fresh air supply intakes to areas containing safety-related equip- (5) Intake supply and exhaust ducts are located to minimize the ment or systems should be located remote from the exhaust air outlets possibility of recycling smoke and combustion products from and smoke vents of other fire areas to minimize the possibility of one fire area into another unaffected area. contaminating the intake air with the products of combustion. Stairwells should be designed to minimize smoke infiltration during a (6) There are no stairwells.in building. (6) fire. (7) Where total flooding gas extinguishing systems are used, area intake (7) There are no total flooding systems. and exhaust ventilation dampers should be controlled in accordance with NFPA 12, " Carbon Dioxide Systems," and !!FPA 12A, "Halen 1301 Systems, " to maintain the necessary gas concentration. g.L_1.ghting and Communication Lighting and two-way voice communication are vital to safe shutdown and emergency response in the event of fire. Suitable fixed and portable emergency lighting and communication devices should be provided as follows: (1) Fixed self-contained lighting consisting of fluorescent or sealed-beam (1) 8-hour emergency lighting is provided for access and egress units with individual 8-hour minimum battery power supplies should be routes. provided in areas that must be manned for safe shutdown and for access and egress routes to and from all fire areas. Safe shutdown areas include those required to be manned if the control room must be evacuated. (2) Suitable sealed-bean battery-powered portable hand lights should be (2) Sealed-beam battery powered portable hand lights are provided for emergency use by the fire brigade and other operations provided. personnel required to achieve safe plant shutdown. (3) Fixed emergency communications independent of the normal plant commu- (3) A sound-powered communication system is provided, nication system should be installed at preselected stations. 33

7

                                       .                                   - - , ,                                                                .j SRP 9.5.1 REQUIRENDITS                                                            SYSTEM DESIGIt (4) A portable radio codununications system should be proveded         (4) A portable radio communication systein is provided with a for use by the fire brigade and other operations personnel                fixed repeater ampilfying unit which has a 120-VAC supply required to achieve safe plant shutdown. This system should                backed by the plant emergency diesel generator. The fixed -

not interfere with the conusunications capabilities of the repeater an*plifier is installed in the comununication room, plant security force. Fixed repeaters installed to permit which is protected by a carbon dioxide fire suppression use of portable zadio comununication units should be protec- system. The frequency of the portable radio comununication tad from exposure fire damage. Preoperational and periodic system is different from the plant security force testing should demonstrate that the frequencies used for comununications. sortable radio conununication will not af fect the actuation of protective relays. l I i i

t 9 9 9 34

l SRP 9.5.1 REQUIREMENTS SISTEM DESIGN bN

6. Fire Detection and Suppression 1

j a. Fire Detection , (1) Detection systems should be provided for all areas that contain or 1 present a fire exposure to safety-related equipment. w F e Detectors are provided for the Diesel Generator Buildings j e) ' Ionization detectors are provided in the diesel generator control room and the mezzanine.

b) Infrared detectors are provided in the engine room and the mezzanine. c) Photoelectric detectors are provided in the engine room. I (2) Fire detection systems should comply with the requirements of Class A systems as defined in NFPA 72D, " Standard for the Installation, (2) The firr detection system la designed in compliance with NFPA Maintenance, and Use of Proprietary protective Signaling Systems,".and 72D - 1919. It is a Class B systems however, the detectors are Class I circuits as Jefined in NFPA 70, " National Electrical Code. supervised and the design is consistent with the original plant ] detection system design. ! (3) Fire detectors should be selected and installed in accordance with NFPA 72E, " Automatic Fire Detectors." Preoperational and periodic (3) Fire detectors b:79 been selected and installed in accordance testing of pulsed line-type heat detectors should d.aonstrate that the with NFPA 72E. Pulsed line-type heat detectors are not used, frequencies used will not affect the actuation of protective relays in other plant systems. (4) Fire detection systems should give audible and visual alarm and annun-ciation in the control room. Where zoned detection systems are used Detector actuation (fire condition) and detector system in a given fire area, local means should be provided to identify which (4) a) detector zone has actuated. Local audible alarms should sound in the trouble conditions are alarmed and annunciated on the local panel (114 F CP6 ) and visual alarm in the main control fire area. room. b) Fire Zone number 105 is assigned for Train A and fire Zone 106 for Train B within the Diesel Generator Building. I c) A Manual Fire Alarm Station (MFAS) is provided at each exit from the building. MFAS are located and mounted per NFPA 72A. (S) Fire alarms should be distinctive and unique so they will not be The fire detection system provides for a local fire alare and a confused with any other plant system alarms. (5) visual fire alarm in the control room. It was elected to annunciate the diesel generator building fire detection system through the IDADS (Interim Data Acquisition Display System) until the plant integrated computer is installed. The fire alarm in the control room is distinctive in that a separate group status block flashes on the CRT in case of a fire. 15

9 SRP 9.5.1 REQUIRBENTS SYSTEM DESIST (6) Primary and secondqry power supplies should be provided for the fire (6) The fire detection system is powered from an offsite power detection system and for electrically operated control valves for supply and receives backup power supply from a station automatic suppression systems. Such primary and secondary power battery of at least 4 hours' capacity. The battery charger supplies should satisfy provisions of Section 2220 of NFPA 72D. This can be accornplished by using normal offsite power as the primary can be manually connected to the Class 1E emergency bus. supply with a 4-hour battery supply as secondary supplys and by provi-ding capability for manual connection to the Class 1E emergency power bus within 4 hours of loss of offsite power. Such connection should follow the applicable guidelines in Regulatory Guider 1.8 1.32 and 4 1.75. L

b. Fire Protection _ Water _ Supply _ Systems (1) An underground yard fire main loop should be installed to furnish (1) The, fire protection water supply system is not evaluated for anticipated water requirements. FyPA 24, " Standard for Outside this. response. The water is supplied from the plant fire Protection," gives necessary guidance for such installation. It protection water supply, which has been previously reviewed references other design codes and standards developed by such organi- l and approved by the NRC in accordance with Amendment No. 19, sations as the American National Standards Institute (ANSI) and the ,

dated 2/8/78, to the Facility Operations License No. DPR-54. American Water Works Association (AWWA). Type of pipe and water i treatment should be design considerations with tuberculation as one of The existing yard fire main has been extended to the diesel the parameters. Means for inspecting and flushing the systems should generator building to supply the water for hydrants, be provided, automatic pre-action sprinkler system, and manual hose stations. Adequate capacity is available from the existing-fire pumps. Since a simultaneous fire in isore than one structure is not postulated, the addition of the DG fire

                                -                                                       protection system does not degrade the existing Fire Protection and Water Supply System. Separate lead-ins will be provided for the automatic and manual fire water extinguishing system. The existing yard fire mains system is assured operable by testing defined in Section 4.18.2 of
                                                                                       .the Rancho Seco Unit 1 Technical Specifications. The (2) Approved visually indicating sectional control valves such as post-                outside fire protection is provided per NFPA 24 - 1970.

indicator valves should be provided to isolate portions of the main for maintenance or repair without shutting off the supply to primary and backup fire suppression systems serving areas that contain or expose safety-related equipment. (3) Valves should be installed to permit isolation of outside hydrants from the fire main for maintenance or repair without interrupting the ' water supply to automatic or manual fire suppression systems in any area containing or presenting a fire hazard to safety-related or, safe shutdown equipment. . (4) The fire main system piping should be separate from service or sanitary water system piping, except as described in Position c.5.c.(4). I 36

T SRp 9.5.1 REQUIREMENTS 1 siSTEM DESIGN (S) A comon yard fire main loop may serve multiunit nuclear power plant sites if cross-connected between units. Sectional control valves should permit maintaining independence of the individual loop around [

each unit. For such installations, corunon water supplies may also be utilized. For multiple-reactor sites with widely separated plants (approaching 1 mile or more), separate yard fire main loops should be used. (6) Tf pumps are required to meet system pressure or flow requirements, a; sufficient number of pumps should be provided to ensure that 100% capacity will be available assuming failure of the largest pump or less of offsite power (e.g.,three 50% pumps or two 100% pumps). This can be accomplished, for example, by.providing either: (a) Electric motor-driven fire pumpts) and diesel-driven fire pumpts), or (b) Two or more seismic Category I Class IE electric motor-driven fire pumps connected to redundant class IE emergency power buses (see Regulatory Guides 1.6, 1.32, and 1.75). Individual fire pump connections to the yard fire main loop should be separated with sectionalising valves between connections. Each pump and its driver and controls should be located in a room separated from the remaining fire pumps by a fire wall with a minimum rating of 3 , hours. The fuel for the diesel fire pump (s) should be separated so that it does not provide a fire pumps by a fire wall with a minimum rating of 3 hours. The fuel for the diesel fire pump (s) should be separated so that it does not provide a fire source exposing safety-related equipment. Alarms indicating pump running, driver availability, failure to start, and low fire-main pressure should be provided in the control room. The fire pump installation should conform to NFPA 20, %taunard for e

   ,      the Installation of Centrifugal Fire Pumps."

(7) outside manual hose installation should be sufficient to provide and effective hose stream to any onsite location where fixed or transient combustibles could jeopardise safety-related equipment. Hydrants should be installed approximately every 250 ft on the yard main sys-tem. A hose house equipped with hose and conbination nozzle and other auxiliary equipment reconumended in NFPA 24, "Outside Protection,"

!- should be provided as needed, but at least every 1,000 ft.

j Alternatively, mobile means of providing hose and associated equip-3 ment, such as hose carts or trucks, may be used. When provided, such , mobile equipment should be equivalent to the equipment supplied by

three hose houses.

4 (0) Threads compatible with those used by local fire departments should be provided on all hydrants, hose couplings, and standpipe risers. 4 . 37 . l l 1 . i k u-

SRP 9.5.1 REQUIREMENTS ,

I SibtLH DESIGN (9) Two separate, reliable freshwater supplies should be provided. saltwater or brackish water should not be used unless all freshwater supplies have been exhausted. If tanks are used, two 100% tminiram of 300,000 gallons each) system capacity tanks should be installed. They should be so interconnected that pumps can take suction from either or both. However, a failure in one tank or its piping should not cause both tanks to drain. Water supply capacity should be capable of refilling either tank in 8 hours or less. (10) common tanks are permitted for fire and sanitary or service water l storage. When this is done, however, minimum fire waterstorage I' requirements should be dedicated by passive means, for example, use of a vertical standpipe for'other water services. Administrative ,' controls, including locks for tank outlet valves, are unacceptable as the only means to ensure minimum water volume. (11) The fire water supply should be calculated on the basis of the largest expected flow rate for a period of 2 hours, but not less than 300,000 gallons. This flow rate should be based (conservatively) on 500 gpm for manual hose streams plus the largest design demand of any sprinkler or deluge system as determined in accordance with NFPA 13 or NFPA 15. The fire water supply should be capable of delivering this design demand over the longest route of the water supply system. , (12) Freshwater lakes or ponds of sufficient sise may qualify as sole source of water for fire protection but require separate redundant suctions in one or more intake structures. These supplies should be separateo so that a failure of one supply will not result in a failure of the other supply. (13) When a common water supply is permitted for fire protection and the ultimate heat sink, the following conditions should also be satisfied:- (a) The additional fire protection water requirements are designed into the total storage capacity, and (b) Failure of the fire protection system should not degrade the function of the ultimate heat sink. (14) Cther water systems that may be used as one of the two fire water supplies should be permanently connected to the fire main system and should be capable of automatic alignment to the fire main system. Pumps, controls, and power supplies in these systems should satisfy the requirements for the main fire pumps. The use of other water systems for fire protection should not be incompatible with their functions required for safe plant shutdown. Failure of the other system should not degrade the fire main system. e l 38

f . i SRP 9.5 1 REQUIREMENTS SYSTEM DESIGN.

c. Water Sprinkler and Hose Standpipe Systems (1) Sprinkler systems and manual hose statien standpipes should have (1) The sprinkler system and the manual hose station standpipes

  !        connections to the plant underground water main so that a single i

are provided with separate supplies, line 99639 -6" - HE3, active failure or a crack in a moderate-energy line cannot impair both and line 99640 - 6" - HE3 respectively, and the mpply lines l the primary and backup fire suppression systems. Alternatively, are separated by a supervised PIV (refer to PEID N-594). {, headers fed from each end are permitted inside buildings to supply both sprinkler and standpipe systems, provided steel piping and fit- U.L.-listed OS&y gate valves are provided.

 }'        tings meeting the requirements of ANSI B31.1, " Power Piping," are used for the headers up to and including the first valve supplying the                  Safety-related equipment that does not itself require sprinkler systems where such headers are part of the seismically                   sprinkler water fire protection is not exposed to water from analyzed hose standpipe, system. When provided, such headers are                   a water spray or sprinkler system.

considered an extension of the yard main system. Each sprinkler and

  !        standpipe system should be equipped with OS&y (outside screw and yokel j        gate valve or other approved shutoff valve and waterflow alarm.

Safety-related equipment that does not itself require sprinkler water fire protection but is subject to unacceptacle damage if wet by sprinkler water discharge should be protecteu by water shields or baffles. (2) Control and sectionalizing valves in the fire water systems should be (21 PIVs are electrically supervised and they may be monitored electrically supervised or adminstrative1y controlled. The electrical in the control room through the computer (refer to PGID M-supervision signal should indicate in the cortrol room. All valves in 594). All fire protection system valves are peridocally the fire protection system should be periodically checked to verify checked to verify position. position (see NFPA 26, " Supervision of Valves").

13) Fixed water extinguishing systems should conform to requirements of j (3) An automatic pre-action sprinkler system is installed for appropriate standards such as NFPA 13. " Standard for the Installation protection of both diesel generator building trains, of Sprinkler Systems," and NFPA 15 " Standard for Water Spray Fixed. including the engine rooms, control room, and messanine Systems.* areas. The sprinkler system is designed in accordance with NFPA 13 - 1980.

(4) Interior manual hose installation should be able to reach any location (4) Standpipes and hose stations meeting the requirements of that contains, or could present a fire exposure hazard to, safety- NFPA 14 - 1980 are provided in the engine room, mezzanine, related equipment with at least one effective hose stream. To accom- and control room. Each hose station consists of a fire

    .      plish this, standpipes with home connections equipped with a maximum               hose, hose reel, nozzle, and angle valve. The manual hose of 100 feet of 1-1/2-inch woven-Jacket, lined fire hose and suitable               stations have 100 feet length fire hoses. The line size for nozzles should be provided in all buildings on all floors. Individual              the standpipes is 6 inches and the hose connections are 1-       "

standpipes should be at least 4 inches in diameter for multiple hose 1/2 inch. connections and 2-1/2 inches in diameter for single hose connections. These systems should follow the requirements of NFPA 14. " Standpipe and Home Systems," for siting, spacing, and pipe support requirements. Hose statims should be located as dictated by the fire hazard analysis to facilitate access and use for firefighting operations. Alternative hose stations should be provided for an arns if the fire hazard could block access to a single hose station serving that area. I 39

10 SRP 9.6.1 REQUIREMENTS 8% Provisions should be made to supply water at least to standpipes and For the standpipes and fire hose connections, the piping is purchased to meet the requirements of ANSI B31.1, ' Power hose connections for manual firefighting in areas containing equipment Piping." The supports are Seismic Cate ory Is the piping is required for safe plant shutdown in the event of a safe shutdown analyzed for SSE loading, but is not Se amic Category I, since earthquake. The piping system serving such hose stations should be it is galvanized piping with screwed M.I. fittings. The fire analyzed for SSE loading and should be provided with supports to protection water supply system is not evaluated for this ensure system pressure integrity. The piping and valves for the response. The water is supplied from the plant fire portion of hose standpipe system affected by this functional require- protection water supply, which has been previo1 sly reviewed ment should, as a minimum, satisfy ANSI B31.1, "Powt: p_;.ng." The and approved by the imC in accordance with Amendment No.19, water supply for this condition may be obtained by manual operator dated 2/8/78, to the Facility Operations License No. DPR-54. actuation of valves in a connection to the hose standpipe header from a normal seismic Category 1 water system such as the essential service water system. The crots connection should be (a) capable of providing flow to at least two hose statior.s (approximately 75 gpm per hose station), and (b) designed to the same standards as the seismic Category I water systems it should not degrade the performance of the seismic Category I water system. (5) Fog nozzles with a 30 to 90 degree spray pattern are provided l (5) The proper type of hose nozzle to be supplied to each area should be for all hose stations. They are acceptable for Parard types based on the fire hazard analysis. The usual combination within the building. spray / straight-stream nozzle should not be used in areas where the straight stream can cause unacceptable mechanical damage. Fixed foo The nozzles have integr:l shutoff capability. nozzles should be provided at locations where hi;h-voltage shock hazards exist. All hose nozzles should have shutoff capability. (Guidance on safe distances for water application to live electrical equipment may be found in the "NFPA Fire Protecticn handbook.") (6) Fire hose should be hydrostatically tested in accordance with the (6) Refer to technical specification 4.18.5. recommendations of NFPA 1962, " Fire Hose - Care, Use, Maintenance." Hose stored in outside hose houses should be tested annually. Interior standpipe hose should be tested every 3 years. (7) Certain fires, such as those involving flammable liquids, respond well (7) N t applicable. to foam suppression. Consideration should be given to use of mechani-cal low-expansion foam systems, high-expansion foam generators, or aqueous film-forming foam (AFFF) systems, including the AFFF deluge system. These systems should comply with the requirements of NFPA 11, NFPA IIA, NFPA 11B, and FFPA 16, as applicable.

d. Halon Suppression Systems () er aen a n pp essi n ya ems n B ding.

Halon fire extinguishing systems should comply with the requirements of NFPA 12A and NFPA 12B, "Halogenated Fire Extinguishing Agent Systems - Helen 1301 and Halon 1211." Only UL-listed or FM-approved agents should be used. Provisions for locally disarming automatic Halon systems should be key locked and under strict administrative control. Automatic Halon extin-guishing systems should not be disarmed unless controls as described in Position C.2.c. are provided. In addition to the guidelines of NFPA 12A and 12B, preventive maintenance and testing of the systems, including check-weighing of the Halon cylin-ders, shculd be done at least quarterly. 40 I m __

                                                                                                                                            %       1 SRP 9.5.1 REQUIREMENTS                                         I                     SYSTEM DESIW Particular consideration should also be given tos (1). Minimum required Halon concentration, distribution, soak time, and ventilation controls (2) Toxicity of Halons (3) Toxicity and corrosive characteristics of the thermal decomposition products of Halong and (4) Location and selection of the activating detectors.

e. Carbon Dioxide Suppression Systems (e) There are no carbon dioxide suppression systems in DG Building.

Carbon dioxide extinguishing systems should comply with the requirements of NFPA 12, " Carbon Dioxide Extinguishing Systems." Where automatic carbon dioxide systems are used, they should be equipped with a predischarge alarm rystem and a discharge delay to permit personnel egress. Provisions for locally disarming automatic carbon dioxide systems should be key locked and l undet strict administrative control. Automatic carbon dioxide l extinguishing systems should not be disarmed unless controls as descr'ibed in Position C.2.c. are provided, l i Particular consideration should also be given tos (1) Minimum required CO2 concentration, distribution, soak time, and ven-tilation controls (2) Anoxia and toxicity of CO2 (3) Possibility of secondary thermal shock (cooling) damage . (4) Conflicting requirements for ventkng during CO2 injection to prevent overpressuritation versus sealing to prevent loss of agents and (5) Location and selection of the activating detectors.

f. Portable Extinguishers (f) Portable carbon dioxide extinguishers are provided in Fire extinguishers should be provided in areas that contain, or could accordance with NFPA 10 - 1981.

present a fire exposure hazard to, safety-related equipment in accor-dance with guidelines of NFPA 10, " Portable Fire Extinguishers, Installation, Maintenance and Use." Dry chemical extinguishers should be installed with due consideration given to possible adverse effects on safety-related equipment installed in the area.

7. Guidelines for Specific Plant Areas

                                                                     >         41 l

l SPP 9.5' 1. REQUIREBENTS - SYSTEN DESIWI

1. Diesel Generator Areas Diesel generators should be separated from each other and from other (1) The Building is designed for separation between the Train A areas of the plant by fire barriers having a minimum fire resistance and Train B diesel generators and auxiliary systems. The rating of 3 hours, separation barrier has a fire rating of 3 hours.

Automatic fire suppression should be installed to combat any diesel Automatic fire detection and suppression systems are generator or lubricating oil firess such systems should be designed installed. Remote alarms in the control room and local fire for operation when the diesel is running without affecting the diesel. alarms are provided. . Hose stations and portable Automatic fire detection should be provided to alarm and annunciate in extinguishers are provided. the control room and alarm locally. Hose Stations and portable extin-guishers should be readily available outside the area. Drainage for The drainage system is adequate for the sprinkler system. firefighting water and means for local manual venting of smoke should be provided. Day tanks with total capacity up to 1100 gallons are permitted in the Each day tank has a capacity of 550 gallons,' and is loca'ted diesel generator area under the following conditions: inside the building in a diked enclosure that can contain 110% of the tank's capacity. (1) The day tank is located in a separate enclosure with a minimum fire resistance rating of 3 hours, including doors or penetrations. These enclosures should be capable of containing the entire contents of the day tanks and should be protected by an automatic fire suppression system, or (2' The day tank is located inside the diesel generator room in a diked enclosure that has sufficient capacity to hold 110% of the contents of the day tank or is drained to a safe location. . J. Diesel Fuel Oil Storage Area Diesel fuel oil tanks with a capacity greater than 1,100 gallons The 60,000 gallon fuel oil storage tanks are located outside the~ should not be located inside building containing safety-related equip- building and are totally buried. ment. If above-ground tanks are used, they should be located at least 50 feet from any building containing safety-related equipment, or if located within 50 feet, they should be housed in a separate building with construction having a minLmum fire resistance rating of 3 hours. Potential oil spills should be confined or directed away from buildings containing safety-related equipment. Totally buried tanks are acceptable outside or under buildings (see NFPA 30, " Flammable and Combustible Liquids Code," for additional guidance). 42 l l . l

b l g y e a

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e t u h , n t af o f i .tni o e o e c d ht a l ra noi rset hIh i t es cor d e t eti c t td nsh mawne l f e nmwa vl ce n eog i s p aoec uip sof aitii n omsm ane t nin sevI osf s t ef n wio et e lSR eah vt a l rat hh e rui ic sa Arcc ege t pre . d s venidS i ua m, i vy ee t es ot n eff fi l wl eit wl ti rbi naeri o d ee . ahti eb am ut a has e h vn ort al iah r 8 srsCt ss ndt eo t u l i vt t e ep p E Mnpepnel n os sat i e li t ec gt g t d a . ra ren i uil ci , nant a ens f cio e l go t os g ,l ee elit r h ecat hd anrssppe ed oe h e rat t eiiC niu c l ru p isith anrs t t t oroya e ll o ses t uet cn d a n a yi ernf T sd ce essr s mese ncert tt gar aisaipc e N ennud d aien E iaif e s bmdi i esan o t u d s pl i ayet aneearrt t n M d t saop E n ,gp i nd gene sd *.i s sucaiai qshl c R eonnu yct m s o asas t ecais I hi oir mit oc U t ti rr esaca tdc bahedd eqnn udt Q pt oe t er l noe t ve E ti at t sd el p y nl enne e i h r

                                                                              . nn   gosaf end l i sc i e n

R arrin h ceni sreis wl mti ii evit anso 4 t spon egwa tl a a st r ssmaDp 5 yd eomu eh ht yss eixd p bwene eaunsyr d c soasoc& o I m f sd r t ol et ur i sil fiPc 9 i meno t ,ll aie n sseo nerrd cf at cdrm ii a neses ret af P et vsys asnsn oraan a msBl e a pi h m ssS or et e R ,d ht rso i u S ysge t neip tl sd iapsasd s t t os fii nr svx et mm o cige , eand e el sce i t n snaeay t s d e rol u ef soe l q i eeed c f ct tf e nfii c n oeaoa wvn ht eeDhene onl ot ti toab vh s r s wserr ii mao cvrrn t e . pcat o m/ e endt rmar rid pe sngrmi r u t aons srmoa es viyno en et t cd nn t st onoonead w e ii pC a h n d et c el ei naeei estd htd a e r l e rsl gt i t ea i cul c e c dl ,r e a a eab m vd el a . etd s snagu ensciI nt maumt o vf nyt dli ngcs , r i a ns eorl n anoa g ra pinyyt ct l e P eis t el e R et t e wst ai i sh n B yR erf ns w A gaar et nnr gss i Et SS s o i yi y i e S accp rii rciro e e n it aen ca Si S sgtf l sF eenin s v eoddd ef dtd paeae eaiE nt eree e ht nnn hf nnn Teaia ihh pl PtTsc h TqtuhDoad E nCivbt eeh R T siia I I . . . . I 1 2 3 4

g , Say 9.5.4 REQUIREMFMT SYSTDI DESIGN

5. The restever verifles that the destga is auch as to stataire the 5. The tressfer pumps are provided utth inlet screens ami discharge creattom of turbulence of the sediment at the bottom of the feel oft stroiners to prevent the entry of deletertous materials into the storage tank or the chance of deletertoon material entering the sy st em. Provision has been made for emoval of water from the system during recharging, or by operator error, or due to natural storage tanks amt day tanks.

phenomene. The reviewer will ascertain that provtstees or a program . have been incorporated to assure that the quality of the stored fuel ot t meets stalmum requirements at all times.

6. The desertptive taformation and drawings la the SAR are reviewed to vertf y that:

a. Each storage tank is equipped with an outside fill and vent a. The tank fill connection is located at grade la a concrete vault and line, located amt protected so es to etntatre the chance of has a loded cap. The porttoo of the vent If ne above grade is damage f rom vehicles, tornado, tornado missiles, and floods, protected by steel guard posts. Each tank is provided with a stick the fill amt veat potat should be located higher than the IWF gauge commection (refer to DDR for FrN A3748 Section 31.1.3.2 amt g flood level. Each tank is also provided with a stick gauge p6ED M-547).

connection for deterstains fuel level in the tank.

b. The minimum onette leventory of fuel oil for each rederlant b. The feel ott storage banks have suf fletent capacity for 7 days of diesel-generator system to suf fletent to enable the diesel full lad cocrettoo plus 15 percent margin (refer to DDR for ECN g nerators to power required engineered safety features for a I A3748 Section II.I.B.2).

perted of seven days following any destan basis ac etdent and loss of of f atte power.

c. The physical locattom of the day tank associated with each c. The day taak to located at so elevstton auttable to provide positive diesel-generatsr set to located at an elevattne to assure a pressure to the fuel ett pump (refer to Drawing M-923, Sheets 1-6).

altsht positive pressure at the engine-driven fool oil pump ( s). Where this requirement to contrary to manuf acturers' recommendattom, fastification amt a detailed system description . shall be provided to the SAR. Additionally, the justification for locating the day tank other than stated above shall assure that the diesel-generator unit can start automatically amt attata the required voltage amt frequency within acceptable ' limits amt time. If a booster pump to required, it shall be powered from a reliable power mapply and arranged to operate when the enstne receives a start signal amt it shall operate during the engine starting cycle or until system feel ett pressure is estabitehed by the engine-driven fuel oil pump.

4. A day or integral tank overflow 11ae is provided to return d. A day tank overflow Itne is provided to retura excess oil to the emeens fuel oil delivered by the transfer pump back to the fuel fuel ett storage tank (refer to p61D +547 est M-585).

oil storage tank.

e. A low-level alare is provided to enable the operator to e. A low-level alarm is provided on the day tank, is indicated on the accomplish minor repairs or matetenance before all fuel in the local control panel and la the mata cont rol room computer as a day or integral tank to consumed (assuming full-power trouble alarm (refer to DDR for ECN A1748 Section 11.1.B.2). I operation).

f. The day or integral tank amt storage tanks associated M ech f. A drata conacction is provided for witer removal on the day tanks.

diesel-generator sat include provisions for removal of A sump is provided in the storage tanks to permit removal of accumulated water. accumulated water (refer to DDR for FIN A3748 Section 11.1.B.2), l i , 44 1 l i

                                 ,                                                    I b

Sap 9.5.4 RgGUll:DemT SYSTEM DESicu

7. The reviewer verifles that suitable precautions will be taken, once 7. The fuel ott storage tanks are located underground and the above the fuel oil tank has been filled, to esclude sources of ignition grade vent 1tnes have flee, arrestor. The majority of .% piptog is such as open flames or hot surfaces, and that pro *ective seasures underground. The fuel oil day tanks'are located inside e ae butiding such as compartmentattom of redundant elements are used to ministre in a diked enclosure that will contain the volume of fe . oll in a the poteattat causes and consequences of fires and explostoms. full tank (refer to DBR for em A.3748 Section 11.1.B.2 and Drawing l" M-923, Sheet s 1-6).

8. The reviewer verifles that the system function will be maintained as 8 The f attore of any non-Category I system will mot af fect the ability required la the event of fatture of sensetsmic Category I systems or of the diesel-generator fuel att system to perform its fumetton structures located near the' system. Reference to the SAR sections (ref er to f*R f or FCE A1748 Section it.1. A). l describles site features and the general arrangement and layout drewtess util be necessary la this determination. Plant arrangement features, is conjunction with the protection obtained by location and the destga of the systee anni structurce, are considered in determining the ability of the system to malatata function la the event of such failures.

9. The diesel engine fuel all storage and transfer system is reviewed 9. There are no high energy pfplag systems loc'ated close to the feel to verif y that protection free the effects of breaks la high and ett system (refer to Fqntpoent Incation Drawing M-923, Sheet s 1-14) .

enderate energy If nes has been provided. I.myout drawings are reviewed to assure that no high- or moderate-energy piptog systems ate located close to the fuel ett system or that protection from the ef fects of f attere will be provided. The means of providing such protection vt!! be gives la sectica 3.6 of the SAR, and the procedures for reviewtag this information by ASB are given in the corresponding SRp sections.

10. The descrQtive taformation, related system drawings, and the 10 The fuel ott systems for each train are physically separated, A resulta et f attere modes and ef fects analyses in the SAR are single act tre component f at tare in one train will act prevent the reviewed to verify that stalmum system requirements will be met redundant trate from meet tag system requirements (refer to DDR for folinwing destga basis accidents assuming a concurrent single active Eat A3748 rection IT.I.A 5). l component fatture. For each case the deatsa vill be acceptable if minteese system requirements are met.

45

     . _ _ - _ . _ _            . _ _ _ .                       - m . _m -- -       . _ _ _ _ _ _ , . .._.. -... _                                -      ._ . _ .                          4 ,.          . ,

I 4

                                                                      *                                                 =                                                                                       .

g Lg SYSTEM DESIGN SRP 9.5.5 REQtflREME;fT III. Raview Fracedures "1. De SAR is reviewed to establish that the DECWS description and related diagraes clearly delineate system operation, individual and i total heat removal rates required by components, and the margin in i the design heat removal rate capability. The reviewer verifies the fs11oving:

a. P&lDs indicate seismic and quality classifications at change points:

a. We SEB reviews the seismic design baws and the MEB reviews in the system (refer to PalD H-585), essential portions of the the quality and seismic classification as todicated in system meet the requirements of Quality Group C and Seismic Category

, subsection 1 of this SRP section. The PS3 assures that g*

;                    essential portions of the DECWS including the isolation valves l                    separating essential and nonessential portions are classified i                     Quality Croup C and seismic Category I. Components and system descriptions in the SAR that identify mechanical and 4

performance characteristica are reviewed to verify that the above seismic and quality classifications have been included j and that the P& ids indicate any points of change at the systems j anrt/or systems components interf aces. i b. Failure of a piping interconnection between subsystems in one train Failure of a piping interconnection, as shown on system piping will not cause any degradation of the EDECWS in the other train

b.

and instrumentation diagrams (P& ids), between subsystems does (refer to DBR for ECN A3748 Section II.1.A.4). l1 s not cause total degradation of the DECWS. %e results of I fatture modes and ef fects analyses are used as a hesis of acceptance. Provisions have been made to permit inspection of components of the a c. Provisions have been made to permit inspection of components, system (refer to Drawing M-923). 4 c. as shown on system layout drawings. g g is acceptable to the enoine manufacturer's recommendation. A chemical

d. The performance and water chemistry of the DECWS is in feed tank is provided for the jacket cooling water system to enable the conformance with the engine manufacturer's recommendations. operator to adjust the system chemistry when needed. The inlet and outlet connections of the tank are coupled to the outlet and inlet of the 1 keep-warm pump, respectively. The tank is isolated from the system with a pair of shutoff valves. . A sample connection is provided at the chemical addition tank (refer to P&!D !!-585),

a

e. The cooling water system includes a keep-warm circulating pump and a j jacket water heater to circulate water through the system when the

e. ne engine "first try" starting reliability has been increased by providing an independent loop for circulating heated wateg engine is in standby mode (refer to Pa!D M-585)

I I while the engine is in the standby mode. A three-way bypass temperature centrol valve is provided to control i

f. '

j f. A three-way, bypass-type, thermostatically controlled valve has water flow to the jacket water radiators to maintain proper coolant been provided to control water flow through the Jacket water temperature to the engine inlet (refer to PalD M-585). 4 coolers or radiators so that proper coolant temperature is maintained at the engine inlet, as specified by the 3 manufacturer. I l l 46

                                                                                    .- . y b'

SRP 9.5.5 REQUIREMDIT SYSTTM DESYCN

g. Temperature sensors have been provided to alert the operator g. High and low Jacket temperature alarms are provided. A high when cooling water temperatures exceed the limits recommewled temperature trip will automatically shot down the unit at by the manufacturer. Protective interlocks in this system are 200F. This trig is blocked during emergency operation (refer acceptable if the SAR todicates that the interlocks are in to P&ID M-5R5 and DDR for ECN A1748 Section 4 conformance with Branch Techntest position ICSB-17 (pSS),

II.1.B.4). l t

  !  2. The reviewer verifles that the EDECWS can be vented to assure that           2. A vent is provided on the standpipe to vent the system during system all spaces are f t!!ed with water. Statoents in the SAR to the                    operation (refer to P&lD M485). High point vents are provided to
 ;       effect that the system design satisfies the above requirement are                  vent the system during startup.

e acceptable, j

3. The reviewer verifies that system functinn will be maintained in the event of adverse environmental phenomena awi loss of of f site power.

The reviewer evaluates the system, using engineering judgment and the results of f a!!ure modes and ef fects analyses to determine that t

a. Failures of nonessential portions of the systee or the other systees not designed to seismic Category I reqairements owl a. Failure of nonessential systems will not prevent satisf actory Incated close to essentist portions of the system, or of ;seration of the EDFWS (refer to DBR for EOE A1748 Section monseismic Category I structores that house, support, or are IT.I.A).

close to essential portions of the FDECWS, will not preclude l essentist f unctions. Reference to SAR sections describing site features and the general arrangement and layout drawings will be necessary, as well as the SAR tabulation of setsele destga classifications for st ructures and systems. Statements in the SAR to the ef fect that the above conditions are met are seteptable.

h. The eascattal portions of the system are protected from time ef fects of finode, hurricans, tornadoes, awi internally and b. The engines and sesociated components of the EDECWS are etternally generated missiles. Fload protection and missile installed in a Seismic Category I structure that is designed to protection criteria are discussed ant evaluated in detall undet withstand the ef f ect s of site wind missiles, as defined in DBR the SRP sections for Gapter 3 of the SAR. A statement et the Section 111.4.5 1he air cooled radiators are located within a effect that the system is located in a Section setseic Category reinforced co screte block wall enclosure designed to withstand I st ructure that is tornado missile and flond protected, or the ef fects of site wind as defined in DBR for ECN A3748 that camponents of the system w!!! be located in individual Section 111.4.B.

cubicles or rooms that will withstawl the ef fects of both flooding and missiles. is acceptable.

4. The reviewer verif tes that there are no high- or moderate-energy piping systees located close to the FDECWS or that the FDECWS is 4 There are no 1.lgh-energy piping systems in the Diesel-Cenerator protected f ram the ef fects of postulat ed bresk s in these systems. Building. A failure in the moderate energy piping system could The means of providing such protection are given in Chapter 3 of the - result in the loss of one train, but would not prevent satisfactory SAR swt procedures to review the information presented are given an operation of the other train trefer to DBK f,r E(J A1748 Section the SRP sections for the chapter. II.1.A.4).

l 47 C

                                                                                           ., _ .y .                                                               .~

b SRP 9.5.5 REQt71REMF.NT SYSTEM DESTCN

5. The descrf pttve information, p4 ids, onsite emergency power supply 5. Each train is physically separated from the other. A single active dramtrqr s, awl system analyses are reviewed to asmare that essential failure in one train will not prevent satisfactory weration of the portions of the system util function following design basis 7 EpECWS in the other train (refer to DRR for ECN A37aB Section acetients, assuming a concurrent single active component fatlure. ,

gy,y,3,5), g The reviewer e aluates the result s of f a!!are andes and ef fects ' analyses presented is the SAR to ensure the fuectioning af requ'M portions of the system.

6. The perf ormance requirement e of the dies engine a re reviewed t" 6. The jacket water is circulated through the radiat$ by an determine the time available to provide cooling water to the diesals engine-driven pump. The radiator f ans are started with1n 1 minute arma the otf er systees that have to/, perate to asmsre onet te power after engine start wt.fch fa acceptable. '. '

capahtlfty. ; " "

7. .

7 The diesel-generator $ an operate at no-load for 7 days without The reviewer verifles that the DECWS antg'% dienel generator can -

perform for entended periods when less tL f ull electrical pot.r degradation per engine manuf actnrer's statement (refer to DBR for generation is required without degradation of performance or FCN A3748 Section II.1.B.I.C).

reliability. A statement to the ef fect that operating procedures _ l e' vill be provf 41 requiring loading of ttee engte > up to e staf etna nf a 25 percent of full load for 1 hour af ter 3 houb o' continuous ~, - nn-lavi operat.an or as recommended by the mamsf acteer will W - acceptable. -

                                                                                                              .s, N

N

SYSTr21 DES 1CN SRP 9.5.6 REQUIREMENT III. Raview Procedures

1. The SEB reviews the seismic d sign bases and the HEB reviews the .

The essential portions of the starting air system are Seismic -- 1. quality and seismic classification as indicated in subsection I of Category I and Quality Class 1. TFe P& ids indicate points of change this SRP section. The PSB assures that essential portions of the in the system (ref er to P&1D H-585). EDESS including the isolation valves separating essential and nonessential portions are classified Quality Croup C and seismic ,, Category I. Components and systes descriptions in the SAR that N- - idantify mechanical and performance characteristics are reviewed to - ' varify that the above seismic sui quality classifications have been included ami that the P& ids indicate any points of change at the systems and/or systems component interfaces.

2. Then reviewer establishes that the IDESS description and piping and 2. A low starting air pressure alana is provided for each train. There instrumentation drawings (P&lDs) clearly delineate all modes of is no interconnecting piping between trate s for the air start operation and include the means for monitoring, indicating, and syeten. The building layout provides adequate space around controlling receiver air pressure as required by the engine starting corponents for inspection and maintenance (refer to P&1D M-585 and se rvice. The p& ids are reviewed to determine that the receiver (s) Equipment location Drawing H-923, Sheets 1-13). .

has been provided with a pressure gauge, relief valve, drain valve, and automatic means of maintaining the receiver pressure within an allowable range, and suitable low pressure alarms. If there are piping interconnections between the dedicated air start systems, they are reviewed to verify that a failure in the interconnectin* , l piping could not lead to the loss of starting of more than one j diesel engine. The building layout drawings are examined to . l ascertain' that sufficient space has been provided around the I corponents to permit inspection. The reviewer verifles that the air starting system meets the specific criteria given in subsection II, i item 4 of this SRP section.

3. Tha SAR is reviewed to assure that each diesel engine air start 3. The air compressor is sized to recharge both air receivers in each sytten has its own compressor and that the compressor capacity is train in approximately 30 minutes (refer to DBR for Em A3748 sdaquate with respect to the air receiver capacities of the Section 11.1.B.3). l dedicated air starting system.

4. The reviewer verifles that the system has been designed tr. be 4 The starting air cystem is installed in a Seismic Category I operated and maintained in the event of adverse endtormental structure tlut is designed to withstand the ef fects of s!te wind conditions such as hurricans, tornadoes, or floods, and'le protected missiles as defined in DBR for Em A3748 Section 111.4.8 the again st the ef fects of internally or externally generated missiles. trains are physically separated which provides adequate protection against flooding (refer to DRR for Em A3748 Section II.1.A.4). ll I

5. The reviewer determines that the f ailure of non-Seinstr. Cautory I Failure of non-Seismic Category I systems will not prevent

5. ,

systems, structures, or components located clone to the EDESS will satisfactory operation of the essential portions of the starting air I not preclude operation of the system. system (refer to DBR for Em A3748 Section 11.1. A). -g l l l l k 49 l

t A SRP 9.5.6 REQUIREMENT SYSTDt DESTQt

6. Tha reviewer determines that measures have been taken in the dessin 6. An air dryer is installed upstream of the air receivers (refer to of the EDESS to preclude the fouling of the air start valve or PsID M-585),

filter with moisture and contaminants such as oil and rust carryover. An air dryer (s) should be installed upstream of the air receiver (s) for the removal of entrained moisture.

7. The reviewer determines that essential portions of the EDESS are 7. There are no high energy piping systems in the Diesel-Cenerator protected f rom the ef fects of high- and moderate-energy line Building. A f ailure in a moderate energy systra in one train would breaks. Layout drawings are reviewed to assure that no high- or not prevent satisfactory operation of the other tra!n (refer to der modarate-energy piping systems are close to the system, or that for ECM A3748 Section it.1.A.4). l protection f rom the ef fects of failure are provided. The means of providing such protection are discussed in Station 3.6 of the SAR and the procedures for reviewing this information are given in the corresponding SRP sections. .

8. Tha 3AR information, T5 ids, related system drawings, and failure 8 Each train is provided with a complete starting air system. A modas and ef fects analyses are reviewed to assure that minimum ningle failure in one train would not prevent operation of the requf rements of the system will be met following design bases redundant train. Two air start receivers per train provide' accidents, assuming a concurrent single active fatture and loss of suffielent capacity for ten engine starts (refer to DBR for ELN offsite power. The analyses presented in the SAR are reviewed to A3748 Section 11.1.B.3). l sasure function of required components following postulated accidents. Utilizing the descriptions, related drawings, and analyses, the reviewer verifies that minimum system requirements are met for each degraded situation over the required time spans. For esch cane the design is considered acceptable if minimum system j requirement s are met.

I 1 I l l l l l 50 s

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s e - A; } } SYSTEM DEstal SRF 9.5.y REQUIBEMENT j; i JII. Review Procedures ,

1. a. De SEB reviews the seismic design bones awl the ME5 reviews a. All essential system components are Seismie Category I and Quality

,1 the quality and seismic classification en twitcated la . Class 1. P&lDe indicate paints of classification chse.ge and provide

                                . subsection 1 of this SRP section. De FSB essures that                                                     material code class (refer to P&ID M-585).

I i essential pertions of the EDE!S including the toolstion velvee saparating essential auf nonessential portions are classified , . Queitty Croup C and Seismic category 1. Cougnnents sad systee j f descriptions in the EAR that identify mechanical and 4 performance chsrecteristics are reviewed to verify that the above selenic emi quality claselfications have been f actuded

awl that the P&lDe imilcate any points of change et the systeme and/or systems components interf aces.

] l b. Failure of a piping interconnection, as shown on the systee b. There is no piping interconnection between Train A and Train B 1mba piping amt instrumentatios disgree (P& ids) hetween subsystems ott systems (refer to p&Ip M-5A5). ! will not cause total degradation of the Wbe oil system function. The results of fatture modes c d ef fects analyses I will be used in this determination. j c. Tbr system layout drawings are examined to eseertain that c. Adequate access has been inclu.ied to allow for inspection of aufficient space has been provided to perett inspection of components (refer to Drawing N-923. Sheets 1-13). components.

d. The system has been designed to preclude the entry of d. The total engine lubricatime system is located within the diesel i deleterious material into the system due to operator error or generator Seismic Category I hu11 dings, yetty into the tmtiding is

! estreme natural phencaena during rechersing or normal administratively controlled (refer to DDR for Eat A37&S Section i operation. The system is acceptable if it is shown in the SAR II.1.A). .l t ha t the syntes is acceptable if it is shown in the SAR that , the system te locked closed, or if entry is administratively } cent rolled. i

e. De design contains an independent circulation loop to maintain e. There is a keep-warm gump and heater to keep the lobe ett at the the temperature of the ersakease oil above a minimur. value engine manufseturer's recommended temperature during the standby during the standby mode. mode (refer to P&lp M-5R5).

f. The system p& ids imilcate the temperature, pressure, and level f. Pressure sad temperetnre alarms are provided. A local level j sensors which slert the operator when these parameters exceed indicator for the luhe oil smer tank to provided (refer to P&lp the rane,es recommended by the engine manuf acturer. M-585 and DBR f or' EfN A1F&R Mection 11.1.5). l .

2 i J s 51 .i l }' l --W__ ,

g SRP 9.5.7 REQUIREMENT STSTEM DESIGN b

g. The system has been designed to minimize the potential fire g. A metering valve is installed in the lube oil line to the harard f rom tube ot t leaking and accumulating on the engine turbocharger bearing to optimize prelubrication but prevent exhaust manifold and in the turbocharger housing as a result of excersive oil flow f refer to Delaval tube Oil Piping Schematic excessively long prelubrication of the engine prior to Drawing No. 09-820-81015).

(tarting. The prelube time interval prior to manual starting of the engine should be limited to 3 to 5 minutes unless otherwise recommended by the diesel engine manuf acturer.

h. The system has been designed to preclode dry starting of the diesel engine during emergency starts, that is, the momentary lack of lubrtcation at the various moving parts or bearing surf aces resulting from the tendency for the lube oil syates to '

drain during long periods of rtandby. It is necessary for the system to establish as quickly as possible an oil film on ene wearing parts of the diesel engine; otherwise, damage to the ' bearing surface will result causing unavailability of the engi ne . To remedy this situation, any one of the following may be used ami should be confirmed with the diesel engine manufacturer: (1) An electrically driven lubricating oil pump powered from a (1) Not applicable, reliable DC power supply, and installed to operate in parallel with the engine-driven main lube oil pump. The electric-driven prelube pump should operate only during the engine cranking cycle or until satf ofactory lube oil pressure is established in the engine main lube oil distribution header. (2) Installation of a continuously operated prelube system (2) A keep-warm tube oil pump and thermostatically-controlled which would provide lube oil to all moving parts and heater are provided (refer to P&lD M-585). bearing surf aces during the standby condition of ope ra t ion. Appropriate alarms should be provided to alert operators to pump failure or low system pressure. (3) Installation of an intermittently operated prelube system (3) Not applicable, whic'h would provide lube oil to all moving parts and bearing surfaces during the standby condition of ope rat ion. This system would operate automatically for a minimum of 5 minutes per day to prelube the moving parts. Appropriate alarms should be provided to alert operaters of pump fatture to start.

1. The design provides for the total heat removal rates required 1.

The heat f rom the lobe oil is removed by the Jacket coo 11og water by the system and the margin in the design heat removal rate system, which also cools the engine ami intercooler. A 10 percent capability. margin was added to the total heat load for design of the aircoolant radiators (refer to DBR for ECN A3748 Section 11.1.B.4). l 9 52

I

SYSTEM DESIGN SRP 9.5.7 REQUIREMENT

2. ha reviewer determines that the system is designed to maintain its function under adverse environmental phenomers. The reviewer, using engineering judgnent and the results of f ailures modes and ef fects taalyses, determines that

                                                                          .a. Failure of non-Seismic Category I system will not ptevent

a. De failure of systems not designed to Scissic Category I requirements or of non-Seismic Category I structures that satisf actory operation of the essential portions of the hou se , support, or are close to the DELS will not preclude diesel-engine lubrication system (refer to DBR for ECN A3748 Sections II.4.E and .II.4.F). I functioning of the system. Chapters 2 and 3 of the SAR describe related site features and provide the general structural arrangement and layout drawings and a tabulation of seismic design classifications for the structures and systems.

Statements in the SAR to the effect that the above design requirements are met are acceptable,

b. The essential portions of the eystem are protected from the b. The lubrication system is located in a Seismic category I betiding ef fects of floods, hurricanes, tornadoes, and internally and that is designed to withstand the ef fects of site wind missiles as -

extenally generated missiles. defined in DBR for ECN A3748 Section III.4.5. Physical separation of trains provides adequate protection against flooding (refer to - DBR for ECN A3748 Section II.1.A.4). l

3. The reviewer verifies that the DELS is protected f rom the ef fects 3. There are no high er.ergy piping systems in the Diesel-Cenerator Building. A failure in a moderate energy system in one train would of breaks in high- and moderate-energy lines. The system not af fect the other train's ability to perform its safety-related description in the SAR is reviewed to verify that there are no high.

or soderate-energy piping systems close to the lube oil system or function (refer to DBR for ECN A3748 Section II.l.A.4). g that protection f rom ef fects of failure will be provided. The means of providing such protection are given in Chapter 3 of the Sidt and procedures to review the information presented are given in the corresponding SRP sections.

4. A single active failure in one train will not prevent satisfactory

4. na descriptive information, P& ids, related system drawings, and operation of the redundant train (refer to DBR for ECM A3748 Section system analyses in the SAR are reviewed to assure that essential portions of the system will function following design bases II.I.A.5). l accidents, assuming a concurrent single active component f ailure.

The reviewer evaluates the results of failure modes and ef fects analynes presented in the SAR to assure functioning of required , compone nt s, traces the availability of these components on system drawings, and checks that minimum system requirements are met for each degraded situation over required time spans. For each case. the design is acceptable if minimum system requirements are met. 53

SRP 9.5.8 REQUIREMENT SYSTEM DESIGN III. Review Procedures

1. De SAR is reviewed to determine that the EDECAIES is a dedicated 1. Each train includes an independent combustion air intake and exhaust system and that the description and related diagrams clearly sy stem. Essential components are classified Seismic Category I ami delineate the system components and the modes of system operation. Quality Class 1. All points of change in clasaf fication are The SEB reviews the seismic design bases and the MES reviews the identified on the P& ids (refer to P&ID M-585).

quality and seismic classification as indicated in subsection I of this SRP section. The PSB assures that essential portions of the EDECATIES are classified Qua,*ity Croup C and Seismic Category I. Components and system dese& dons in the SAR that identify mechanical and performance efaracteristics are reviewed to verify that the above seismic awl quality classifications have been included and that the P&lDe indicate any point of change at the ( eystem an /or system component interfaces.

2. %e SAR is reviewed to ascertain that sufficient space has been 2. Space has been slowed to permit inspection of the system components provided around the components to permit inspection of the system (refer to Drawing M-923, Sheets 1 and 13).

components.

3. De SAR is reviewed to assure that the arrangement and lecation of 3. Arrangement of air intake ani exhaust were considered in design.

the combustion air intake and exhaust are such that dilution or The exhaust elevation is approximately 36 feet higher than the - contamination of the intake air by exhaust products, fire centerline of the combustion air inlet (refer to Drawing M-923, extinguishing (gaseous) medium, or other gases that may Sheets 4 amt 6). Intentionally or accidentally be released on site will not preclude operation of the diesel engine at rated power output, or cause engine shutdown as a consequence of any meteorological or accident comit t ion.

4. De SAR is reviewed to verify that if the intake air flow or engine 4. There are no louvers or dampers requiring actuation devices in the exhaust is depentent upon the actuation of flow control devices intake air or exhaust system (refer to P61D H-535).

(louvers, dampers), the EDECAIES will function if there is a failure of an active component.

5. De SAR is reviewed to assure that system components exposed to L The combustion intake air system contains a fixed louver to divert stmospheric conditions (dust storms, rain, ice, snow) are protected rain, and an intake air filter protects the system against dust f rom possible clogging during standby or operation of the system. (refer to P&lD M-585 ami D u1pment i Location and Layout Drawing M-923, Sheet 6).

t f l 54

1 t , SYSTEM DESIGN SRP 9.5.8 REQUIREMENT 3 We tsviewer verifies that the system will function as required in the event of other adverse naturel phenomena. The reviewer e;valuates the system, using engineering judgment an! f ailure modes end af fects analyses to determine thats

c. Se failure of nonessential portions of the system or of uther 6. a. Failureofnon-SeismicCategoryhsystemswillnotprevent tystems not designed to Seismic Category I requirements and satisf actory operation of the EDEDCAIES in the redundant train located close to essential portions of the system, or of (refer to DBR for FCN A3748 Sections II.1. A). l non-Seismic Category I structures that house, support, or are close to essential portions of the IDECAIES, will not preclude oparation of the system. Reference to SAR sections describing tite features and the general arrangement and layout drawings will be necessary, as well as the SAR tabulation of seismic design classifications for structures and systems. ' Statements in t he SAR that verify that the above conditions are met are seceptable.

b. We essential portions of the system are protected f rom the b. The Diesel-Cenerator Butiding is located above the maximum ef fects of floods, hurricanes, tornadoes, ani internally or flood level and is designed against wind-generated missiles.

externally generated missiles. Flood protection and missile The Diesel-Cenerator Butiding is designed as Seismic Category I protection criteria are discussed ani evaluated in dets11 under and all the components of the combustion air intake and exhaust the SRP sections for mapter 3 of the SAR. The location and system are located in the building except the exhaust silencer the design of the systems and structures are reviewed to and stack, which nre located on the roof. The loss of the determine that the degree of protection provided is adequate. silencer or stack would not prevent the system from perforring A state eent to the ef fect that the system is located in a it s safety funct ion. The separation vs11 between trains Seismic Category I structure that is tornado missile and flood provides adequate protection against flooding (refer to DBR for protected, or that components of the system will be located in eof A3748 Section TT.I.A.4). l infividual cubicles or rooms that will withstand the ef fects of both flooding and missiles is acceptable.

c. We essential portions of the system are protected from the c. There are no high energy piping systems in the Diesel-Cenerator ef fect s of high- and moderate-energy line break s. Layout Building. Failure of a moderate energy system in one train drawings are reviewed to assure that no high- or would not affect the other train's ability to perform its roderate-energy piping systems are close to the essential function (refer to DBK for ECN A3748 Section II.1.A.4). l portions of the system, or that protection f rom the ef fects of failure will be provided. We means of providing such protection will he given in Section 3.6 of the SAR and -

procedures for reviewing this information are given in the co responding SRP sections.

7. The drscriptive information, p&lD s, EDECAIES layout d rawings, and 7. A single active f ailure '.n one train will not prevent satisfactory failure amies ani ef fects analyses in the SAR are reviewed to assure operation of the EDECAIFS in the other train (refer to DBR for ECN th1t functional requirements of the system will be met following A3748 Section II.1.A.5). l dulgn ba ser accident s assuming a concurrent strgle active component ftilure. The reviewer evaluater the effects of f ailure of components, traces the availability of redundant components on systos drawings, and checks that the SAR contains verification that the tcystem functional requirement are met.

I 55

i a r , 4 A S8P 9.5.8 REQUIREMDIT SYSTDI DESTG -

8. The FAR is reviewed to assure that provisions have been made in the 8. The diesel-generetnr combustion air intake system contains a dry diesel generator conhustion air intake design to ministre the type air filter to remove airborne particulate material (refer to ingestion of airborne particulate materlat over the entire time P&lD M-585, prawing 79-923. Sheet 6 and DDR for EG A1748 Section period that emergency power is required. The reviewer also verifies II.1.A.5). l the followtunt . .

That the intake design is reviewed to assure that the bottom of a. The bottom of the ensbustion air intake openings are located a. the intake opening is located a minimum of 20 feet above grade. only 11 feet-6 inches above grade. This height was necessary'- to preclude drawing in warm air that is discharged free the radiator stacks at elevation 17 feet-7 inches (refer to Drawing M-923. Sheets 6, 7 and 10 and Calculation M17.08),

b. That the SAR is reviewed to assure that provisions have l'een b. Asphalt cor. crete is provided around the Diesel-Cenerster made to minimize the generation of dust, particularly in Building, and in addition. there is a 17'-8" high masonry wall multionit plants when one unit is operatina and the other is on each side of the building which will minintre ground dost under construction (abnormal generation of dust). (refer to civil Prawing C-757 Sheet 15).

6

56 i

                                                                                               -                                                                         , , ..w.-

                                                                                                                         ' Enclosure 7                                           . .

Diesel Generator Fire Hazard - Analysis Report e O O S e o l ,

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AMMEN0 MENT TO FIRE PROTECTION PROGRAM MANUAL APPENDIX F DIESEL GENERATOR BUILDING FIRE HAZARDS ANALYSIS REPORT RANCHO SECO NUCLEAR GENERATING STATION , Sac:amento Municipal Utility DistMct Revision 4A - July 1986 i i 3

                              ~ ~ -          4 .e ..-m

TABLE OF CONTENTS Section 3 age 1 INTRODUCTION 1 -1 2 METHODOLOGY 2-1 2.1 Criteria 2 -1 2.2 Development of the 1985 Updated Fire Hazards Analysis 2 -2 3 FORMAT AND DESCRIPTION OF THE DETAILED FIRE HAZARDS ANALYSIS 3-1 3.1 Fire Analysis Matrix Explanatory Notes 3 -1 3.2 Detailed Fire Hazards Analysis Explanatory Notes 3-5 4 FIRE AREA DESCRIPTIONS 4-1 5 DETAILED FIRE HAZARDS ANALYSIS 5-1 Diesel Generator Building -

                                                                          .                                 DGB I 6       FIRE AREA DRAWINGS                                                                     6-1 7       REFERENCES                                                                             7-1 1                                                                                                          .

l. 7/86 i . REVISION 4A 1000g

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i APPENDIX F UPDATED FIRE HAZARDS ANALYSIS RE? ORT

1.0 INTRODUCTION

The Updated Fire Hazards Analysis Report (UFHAR) has been prepared by the Sacramento Municipal Utility District - Rancho Seco Nuclear Generating Station to support the evaluation of compliance to the applicable sections of 10CFR50, Appendix R. The WFHAR considers potential fire hazards and the consequences of fire on the ability of the plant to be safely shut down. The analysis considers measures for fire detection, g suppression, extinguishment, and alternate shutdown capability. Each [ area containing safe shutdown components is . considered in accordance with - [ NRC guidelines and regulations. The UFHAR is a reevaluation of the fire areas described in the 1977 Fire Hazards Analysis Report based on the requirements of 10CFR50, Aapendix R Sections III.G. III.0, and III.L. The modifications which have been incorporated into the 1985 UFHAR are as follows: (1) The fire areas designated in the 1977 Fire Hazards Analysis Report' (numbered 1-74), have been reevaluated against the requirements of Appendix R and subsequent guidance documents for fire area boundaries. As a result, severa.1 of the original Auxiliary Building fire areas have been combined into the following Appendix R fire areas: RB1, RB2, RG1, RG3, RM1, and RT1. The area designations reflect both the Revision (R) and the floor {Selow. Grade, Grade, Mezzanine, or Turbine level) . The reevaluation of revised' fire area l

            +                            RG2 indicated that this area should be addressed as two separate fire areas (18, 31) .                      The original fire areas wnich form a part of each Appendix R area are designated as sub-fire areas of the Appendix R area. TaDies 4-1 and 4-2 provide descriotions of eacM Appendix R fire area and their respective sub-fire areas.

(2) Comoustible loading changes have been incorocrated. For Accendix R fire areas, the comoustible loading is calculated on tne basis of the- sub-fire area, as well' as on the basis of the Aapendix R fire area, to assure that any localized higher comoustible loadings within the sub-fire area are recognized and evaluated. (3) Changes in fire protection equipment have been incorporated. (4) Detailed fire hazards analyses for the Nuclear Services Electrical Building have been added to this report.

              ,                 (5)       Detailed fire hazards analyses for the Diesel Generator 3uiloing have been added to tne report.

II 6 1-1 REVISION 4A 1000g _

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(5) Safe Shutcown t.cgic Diagrams incorporating the ecuipment r:cuired for safe snutdown in the event of fire have oe:n :recarca. These are provicec as Section 3 to this recort. (5) The format of the Fire Hazarcs Analysis uatrix crov'Oec 'or eacn fire area nas been revisec. This report is tne 1985 Update of ne 1977 FPAR. Incivicua! Fire nazards analyses will be performed as required for future design mocifications and other plant changes per Analysis Guide NEP 5503.2. The Detailec Fire

              , Hazards Analysis, Section 5, will be updatec periccically to incorporate these changes using NEP 4119, Fire Protection Program Control.

O e

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O e , 7/86 . 1-2 REVISION 4A 1000g P GwM , y _wy w e-+ + .,,

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2.0 METHODOLOGY This section includes tne criteria usec to cer'orm the fire 7azards analysis, the steos neecec to ceveico tne analysis, ano ne actual o rma t of the detailec fire nazarcs analysis locatec in Se'c tion 5 of nis report. . Definitions af the terms usec in :nis section are founc in :ne g Glossary of \he Fire Protection Program Manual. , 2.1 Criteria o The criteria used to update the Fire Hazards Analysis are as follows: (1) The Auxiliary-Building, Reactor Building, Fuel Storaga Building, Turbine Building, and Yard Areas of the Rancno Seco Nuclear Generating Station shall be evaluated against the requirements of the following sections of 10CFR50, Appendix R. , , (a) SectionIII.G,FireProtectionofSafeShutcownCapaciliky . (b) Section III.0, 011 Collection System for Reactor Ocolant 9umo (c) Section III.L,# Alternative or Geoicated Shutdown Cacaoility (2) The Nuclear Service Electrical Building (NSE3) and the Diesel Generator Building (DG) shall be ' evaluated against the requirements of the following sections of 10CFR50, Appendix R: (a) Section III.G, Fire Protsetion of Safe Shutdown Capability (b) Section III.L. Alternative or Dedicated Shutdown Capability (3) The analysis shall be limited to establishing the effect of * - postulated plant fires on~ components and systems required to safely

                   . shut down the plant from-full power to a hat shutdown condition through to a cold shutdown condition concurrent with the loss of fsite power.            This must be done wnile minimiting the' release of radioactivity to the environment.

(4) Fires snall not ce postulated to occur simultaneously witn other plant accidents or design basis events, sucn as a loss of coolant accident or a safe snutcown earthquake. (5) For all areas of the plant, except the Reactor Building, total reliance for fire protection shall not be placed on a single fire suppression system. Backup fire suppression capability shall be provided. (6) Simultaneous fires in separate fire areas shall not be postulated. 2-1 REVISION 4A 7/86 1000g

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      . . 2.2 Develooment of the 198$ Vodated Fire Hazards Analvsis Recort The fire hazards analysis draws upon all cisciolines to            rovice a complete evaluation of' ne effects of a :ostaiatec # ire.           *he inf ormation required as a basis for the # ire hazarcs ana'.ysis can ce 04vicea into three principal areas:                                                        ,

1) Safe shutdown considerations, discussec in sections 2.2.1 through 2.2.5, ,

Features to prevent fire propagation, discussed in sections

2) 2.2.6 through 2.2.8,

3) Combustibles available to feed the design basis fire, discussed

   ,.                      - in sections 2.2.9 and 2.2.10.

Data from these three areas provides the input for evaluating the consequences of a fire in an area, discussed in section 2.2.11. . 2.2.1 Identification of Safe Shutdown Equipment and Circuits , Safe shutdown equipment was derived from the Sabcock & Wilcox Appendix R Evaluation. Information on safe shutdown circuits was obtained f rom plant circuit routings. Using the list of components required for safe shutdown, a " shutdown flowpath" was identified using plant system piping and instrument diagrams. For the purposes of. the fire hazards analysis the equipment was categorized as required for either hot or cold shutdown, high/ low pressure interfac.e,

or as a spurious operator, based on the following definitions:

Equipment required for hot . shutdown - Components, including passive mechanical equipment (eg steam generators) which are in the

 .                    shutdown flowpath and will be required to bring the clant to hot

. shutdown. Components which' are normally in the position required for hot shetdown are not included here. These comoonents are , addressed as spurious operators. The term " hot shutdown" in this report means that the reactor is succritical ~by at least one percent k/k and the average reactor coolant temoerature is at or greater than 525'F. Equipment required for cold shutdown - Comoonents, including passive mechanical equipment (eg. tanks) wnich are in the shutdown flowcath and will be required to cool down from hot shutdown to cold snutdown or to maintain cold shutdown. Components which are normally in the position required for cooldown to cold shutdown are not included here. Those components are addressed as spurious operators. High/ Low pressure interface - Equipment which maintains the integrity of the high/ low pressure boundary interface between the reactor coolant system and other plant systems. Comoonents on a high/ low pressure boundary which are not in the shutdown flowcath but are required to be in a specified position for hot or cold 7/86 2-2 REVISION 4A 1000g w es -w s - %--,g -*

shutdown are included in this category. Fail'uro of hign/ low pressure interface components coulc result in a ioss of cooiant accident. Sourious coerator - Equi: ment wnose anexoectec oce-at'on c:uic adversely affect safe snutcown system operation or tne acity to maintain the integrity of tne fission proouct 3cuncary. 2.2.2. Circuit Analysis . The evaluation of required circuits includes two pnases. First, circuits associated with equipment required for hot or cold shutdown, nigh/ low pressure interface, and spurious operation components were identified and listed by fire area. Each circuit was then analyzed to determine if the loss of the circuit due to a fire induced snart, short to ground, or ocen circuit would af fect the operation of the comocnent.

2.2.3 Evaluation of Spurious Goeration Equipment whose unexpected operation due to a fire induced short, hot short, or short to ground could adversely af fect safe snutdown system operation or the ability to maintain the integrity of the fission product boundary was addressed as a spurious operator. Offsite power was assumed to be available for those spurious operations wnich could adversely affect the safe shutdown of the plant. No' credit was taken for of f site power availability if the spurious actuation would result in assisting . safe shutdown. Hot shorts to 120V AC and 125V DC are considered credible causes of spurious operation of eqdipment. A three-phase 480V AC phase-to-phase hot short between two power cables is not considered credible and was not analyzed. 2.2.4 Common Power Supply Evaluation - The following approach was taken to address caoles for associated equipment which have a common power source with shutdown ecuipment. Criteria used for the design of the plant power system recuire a completely coordinated Class lE electrical power system. If comotete .

coordination could not be achieved for any cart of the system (venoor supplied equipment, use of commercially availaole cevices, etc.), a detailed analysis was performed to determine that, as a minimum, complete ~ coordination is provided for f'aults outside the ' fire area in . which the protective device is located. To accomolish this, all Class 1 power sources were studied. Circuits required for safe snutdown ano those not required for safe shutdown (associated circuits) were clearly identified. Protection on feeders to non-safe shutdown circuits and on - the main source was checked for coordination, to ensure that any fire induced short on a non-safe shutdown circuit will not cause a trip of the main source breaker. Feeders required for safe shutdown were further investigated to determine whether there were any sub-feeds to non-safe shutdown circuits. If there were any such sub-feeds, these were further analyzed for coordination. The process was repeated until no further sub-feeds were found. . O 2-3 REVISION 4A 7/86 . 1000g .

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Cases of high impedance, fire-induced multiple faults of associated circuits wero also evaluatcc. This evaluation confirmec that multiple faults will not case a trip of the main incoming <eecer creakers anc will not prevent safe shutdown.

 .           The results of the evaluation incicatec that all circuits connectec to required power supplies (i.e., power supplies for instrument control, and power caDies of hot and cold shutcown equipment anc of associatec circuit equipment) have coordinated circuit prutection. Thus, associatec                                                          -

circuits which share a common power source with safe shutdown equipment are not included in the detailed analysis of each fire area.

       ' A coordination study calculation (12) was completed to confirm the evaluation of associated circuits with common power supply.

2.2.5 Common Enclosure Evaluation . Associated circuits which share the same enclosure with tafe snutdown circuits require consideration of the following: (1) Ooes the circuit have protection? . (2) Will the circuit allow fire to propagate from one F're area to another? The first question was investigated by calculation (12) to prove that the associated circuits with a common power supply have adequate protection. The second question was evaluated assumtng the following: (1) If the circuit passes through a fire rated wall or barrier, fire propagation. will be precluded. (2) If a cable is routed in conduit and passes througn a wall, floor, or ceiling, and the external area around the conduit is fire sealed at the penetration, no fire propagation is asstmed. However, the caule can be damaged by the design basis fire. , The results of the evaluation indicated that all circuits of concern l fit into the two categories described. Thus, the associa:ec circuits which share common enclosures with safe snutcown circuits

will not af fect safe shutdown and are not included in the detaileo analysis of each fire area.

           - 2.2.6       Verification of As-Built Plant Configuration A walkdown was performed to.obtain the as-built plant configuration of l

the following: 1) in-situ combustible loading; 2) available fire i protection equipment: 3) fixed openings; and 4) doors. -This information' l was collected by comoleting a plant walkdown checklists. This - information is summarized in the matrix and text for each fire area. 7/B6 2-4 REVISION 4A 1000g

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(1) En-situ camoustibles are broken down into the following categories: oil and groase, cable, Class A comoustibles (i.e., wooo, sacer, and cloth), enarcoal, plastics /PVC, and miscellaneous :obous:ibles. These comoustibles are acco.untec for by type ano :ua'nti:y. This. infomation is used to determine tne comousticle loacing, as described in Section 2.2.9. Taole 2-1 lists the var'ous items considered and the heat of comoustion for eacn mater'al. . (2) Fire protection equipment consists of detection and luceression systems, hose stations, and portable extinguishers. JExtinguisner and hose station availability is based on NFPA 10 and NFPA 14 . Requirements (19, 31 and 32). (3) Fixed openings include penetrations such as hatches, open stairways, and ocenings in walls, floors, or ceilings. The typ'e, location and adjacent fire area of each of these were verified by a physical survey of the plant. See also Section 2.2.7, " Construction Review." (4) All doors which make up part of the coundary for a fiire area were inspected for door position switch, door location, adjacent fire area, fire resistance rating, and security status (locked or unlocked). 2.2.7 Construction Review The purpose of this review (7, 35) was to determine the fire resistance rating of the barriers defining each fire area. The rating of the barrier is determined by the compon.ents that make up the barrier: walls, penetration seals, and doors. Doors are addressed in the Door Walkdown Calculation (8), doors in the diesel generator building are addressed in the construction review calculation (35). The construction review consists of a listing of penetrations and a wall /ficor/ ceiling construction sunimary based on a drawing review. A concrete wall with a thickness of 6-1/2 inches or greater was assigned a fire rating of 3 hours, based on Figure 5-aF of the NFPA Fire Protection Handbook (15th Ed.) . The fire resistance rating of walls constructed of materials other than concrete was evaluated using the UL Suilding Construction Fire Resistance Directory (9), the NFPA Fire Protection Handbook (5), vendor data, ratings noted on soorovec drawings, or from the construction features section of the 1977 Fire Hazaros Analysis Report. The penetration listing includes electrical penetrations, piping and HVAC duct penetrations, and hatches. Grouted penetrations were assumed to be sealed with grout to the same thickness as the wall, and were not l included. Penetration information was based on the electrical and l mechanical firestop schedules and drawings, HVAC layout drawings, the i-architectural and civil drawings, and walkdown information for fixed openings. - i 7/86 - 2-5 REVISION 4A 1000g

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2.2.8 Area / Volume Calculations The area and volume for each fire area were cetermined using tne dimensions from architectural and civil drawings, catn oian anc section views (23). The calculated area provices information for cetermining tne fire loading for each fire area. The volume of eaca fire area is provided for reference. 2.2.9 Combustible loading Calculations Considerations for determining the combustible loadings were as follows: (1) The combustible inventory due to cable insulation and cable jacket in trays within the fire area was determined by calculation ( 4, 21, 29) . Since fires in conduits and inside enclosures will not be sustained, cables in concuits and in panels and equipment are not considered as comoustibles, and were not includec in the calculation.

         .                      (2)                                    Oil or grease in totally enclosed bearing housings in wnicn the oil or grease is not pressurized or recirculated was not included in the comoustible loading.

The results of the combustibles walkdowns and calculations were inout to the Fire Protection Data System (FPOS), which calculates the comoustible loading for each -Appendix R fire area and sub-fire area. . 2.2.10 Design Basis Fire , The design basis fire is charactertzed by these parameters: (1) Fire Loading. .The amount of each combustible is multiplied by its heat of comoustion yielding the heat released. Typical heats of combustion are shown in Table 2-1. The total heat released _(8tu) from-all combustible materials in the fire area is then divided by . the floor area (square feet), yielding the fire loading for the fire area, in BTU per square foot. This is calculated internally in FPOS. (2) Fire Duration. The exoected duration of the' fire is calculated . using FPOS, wnich divides the fire loaoing in the fire area by 80,000 Stu/sq. ft. This value corresponds to the 1-nour fire l loading for the standard (E) time-temoerature curve in Figure 5-9E , of the NFPA Fire Protection Handbook (15th ed.) (5). (3) Maximum Permissible Fire Loading. The maximum permissible fire loading-defines the maximum fire loading which may be contained in the area without exceeding the ability of the area boundaries to contain the fire. The maximum permissible fire loading is based on the in-situ Toading, the use of the area, the protection of redundant safe shutdown equipment"or circuits, and the location of

           -                                                                 fixed openings or otherwise nonrated construction (14, 33).
              -7/86
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2-6 . REVISION 4A 1000g ., h O

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2.2.11 Evaluating the Consequences of the 00 sign Basis Fire l The consequences of a design basis fire are based on tne following: (1) All safe snutdown ecuicment or circuits in the fire area will De ! lost as a result of the design casis fire, unless tne equivalent ' I level of fire protection specifiec by Accendix R, Section III.G is provided or an exemotion has been requested. (2) The fire loading within the fire area. (3) The construction / fire resistance .of the fire area boundaries. (4) The availability of fire suppress' ion and detection available to the fire area. (5) The manual actions which may be reouired to mitigate the consequences of the design basis fire. , l l m e D. .

e l t I REVISION 4A 7/86 2-7 1000g

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TABLE 2-1 COMBUSTIBLE CHARACTER!57:CS Units / Uni: Stu/ Unit (cmoustible Cable Insulation - 0.33 lb/sq in-ft 12250 Stu/lb 155040 Stu/ gal Grease 7.04 lb/ gal Diesel Fuel 7.43 lb/ gal 148600 Stu/ gal Lube Oil 7.4 lb/ gal 132800 Bru/ gal Gasoline 6.15 lb/ gal 127700 Stu/ gal . Snubber Oil 8.95 lb/ gal 116440 Stu/ gal , I Transformer 011 7.48 lb/ gal 143000 Btu / gal Plastic (avg) 12000 Stu/lb Respirators (Neopre,ne) 9000 Stu/lb' PVC

7730 Stu/lb Battery Cases (Polyethylene) . l 20000 Btu /lb Plastic Bags (Polye~thylene) ; 20000 Stu/lb Charcoal (enclosed-derated) 33 lb/CF 12920 Stu/lb Acetylene 1451 Stu/C:- - Hydrogen 4 319 Stu/CF Propane 2480 Stu/CF Powdex Resin 79 lb/CF 140 Btu /lb Rubber (Natural) 94 lb/CF 19400 Btu /lb Paint 7.86 lb/ gal 20000 Stu/lb Solvent (Acetone & other) 6.6 lb/ gal 13250 Stu/lb EHC Fluid 7.0 lb/ gal 16000 Stu/lb

     ' Methanol                                                    4 6.68 lb/ gal                              9758 Btu /lb Hydrazine                                                         6.7 .lb/ gal                ,         8380 Stu/lb Paper                                                           58.0     lb/CF                          7800 Stu/lb Wood 36.3     lb/CF                          8000 Stu/lb Wood Pallet                                                     65        lb/ Pallet                    8000 Stu/lb Plank (2 x 4)                                                     2.02 lb/LF                            8000 Stu/lb 5.04 lb/LF                            8000 Stu/lb Plank (2 x 10)

Plank (2 x 12) _ 6.05 lb/LF 8000 Stu/lb Plywood (1/2" x 4' x 8' sht) , 48.4 lb/snt , B000 Stu/lb Plywood (3/4" x 4' x 8' sht) 72.6 lb/sht 8000 3tu/lb Plywood (l' x 4' x 8' snt) 96.8 lb/snt 8000 Stu/lb C1cth (includes rags) 5 lb/ gal 7800 Stu/lb Clothes 5 lb/ gal 9000 Stu71b Carpet 1.98 lb/sa'ft 13300 Stu/lb Tape (cloth) 37.4 lb/CF 7800 Stu/lb Trasn (compacted paper) 58 lb/CF 7800 Btu /lb Cardboard 63 lb/CF 7200 Btu /lb Desks 300 lb/ desk 8000 Btu /lb Files (std. S'-derated) 750 lb/ file 8000 Btu /1b Ladders (wood) 40 lb/ ladder 8000 Stu/lb' Bookcases (metal-derated) 58 lb/CF paper B000 Btu /lb 7/86 2-8 REVISION 4A 1000g -

                                                                                        -A         _     S___    "1_____a

3.0 FORMAT AND DESCRIPTION OF THE DETAILED FIRE HAZARDS ANALYS!$ The detailed fire hazards analysis providec for ecen fire area is located in Section 5 of this report. The information is presenteo in t.o ways. - The first page of each analysis is a Fire Area Matrix f rom F:05 .nica is a summary of _the pertinent information for eaca fire area. The pages that follow tne matrix make up the text of the analysis. The format of

             . the Fire Area Matrix is discussed in Section 3.1. The topics coverec in the text section are discussed in the order given in Section 3.2.

3.1 Fire Analysis Matrix Exclanator/ Notes , This section explains the use of abbreviations and information provided in the fire area matrix. An example matrix is shown in Figure 3.1. For detailed discussion of the information contained in the matrix, see Section 2.0, Methodology. . Fire Area

The fire area designator is shown here. A description-of eaca fire area is included in Section 4.0.

               - Area / Volume The floor area and volume of thti fire area is listed on the matrix.'

Descrintion , A brief description of the fire area is -provided. Cosbustibles e The combustibles in each fire area are listed in the matrix. Comoustible i gases are considered as potential combustibles under the miscellaneous category. . Desion Basis Fire . Three parameters that characterize tne fire area are listec in this section of the matrix: (1) Fire loadino , The fire ' loading is calculated automatically by the Fire Protection Data System (FPOS) program. The program multiplies the quantity of combustibles entered by the proper heats of combustion. The heat release values are totalled and then divided by the floor area of the fire area to yield the fire loading. l 1 3-1 REVISION 4A 7/86 1000g

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(2) Maximum Permissible Fire lead'ing The maximum permissible fire loading cofines tne maximum

ire loading wnica m'ay oe containec in tne fire area witnout exceecing tne capaoility of the fire area councaries to contain :ne # ire.

t (3) Fire Ouration The fire duration is based on the in-situ fire loading in the fire area or suD-fire area. Fire Protection . The fire suppression and detection systems available in the fire area are listed in tabular form in this section of the matrix. (1) Sucoression. The type of fixed suppression in the fire area is noted. Suppression is area-wide unless noted as local or partial coverage. (2) Hose Stations . The nwnber of hose stations in the fire area is noted. Hose station (s) available outside the fire area are also noted. (3) Portable Extinouishers .. The number and rating of portable. extinguishers are provided. Extinguishers available in adjacent areas are also noted, when app ropriate. (4) Detectors The type of fire detection is indicated. Detection listed is area-wide unless noted as local or partial coverage. Fire Resistance Rating ? - (1) Actual - The actual fire resistance rating of the construction of the walls, floor, and ceiling is noted. (2) Penetrations The minimum fire resistance of the mechanical seals, electrical seals, and fire dampers through each of the area boundaries (walls, floor, and ceiling) is listed. The following abbreviations are used: l . o 7/86 3-2 REVISION JA 1000g - I t _ 9 - .. . . ., -w

MIchanical/ Electrical Penetra' tion Seals 3hr - 3 hour rated penetration seal 2hr - 2 nour ratec penetration seal ihr - 1 hour rated penetration sea! NR - Non-ratec penetration seal

                                         --- - No penetrations /all penetrations are sealec with grout thickness equivalent to the thickness of the wall.                                               d HVAC Penetrations 3hr        - 3 hour rated fire damper                                             1 1.She 1/2 hour rated fire damper                                             l NR         - Ventilation penetration with no damper or a
                        .                                 non-fire rated damDer installed                                 l
                                         ---       - No ventilation penetrations (3)     Fixed Goeninos                                                             ,

Penetrations such as metal hatches, open stairwells, and openings in walls, floors, or ceilings are listed as fixed openings in the fire area boundaries. The following abbreviations are used: , 05 - Open stairwell 00 - Open doorway - OP - Opening

LV - Louver ,

MH - Metal hatch - SG - Seismic gap (4) goori The doors that serve the fire area are listed in the following form: door identification numoer/ adjacent fire area /UL listing. The following abbreviations are used: A - UL Class A Fire Door, 3 hour fire resistance rating 8 - UL Class 8 Fire Door,1-1/2 hour fire

                                             -     resistance rating C - UL Class C Fire Door, 3/4 hour fire resistance rating NR - Non-rated door                                                      _

The door ratings listed are the actual ratings of the installed door assemblies in the plant, which must meet or exceed the rating

                      .      required based on the fire hazard analysis.

S e m 3-3 REVISION 4A - 7/86 _ 1000g

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f Safe Shutdown Systems Systems to be used for the safe shutcown of tne plant are listed on .ne

Fire Analysis Mat'rix. The systems cesignated as recuirec for safe shutdown are as follows: Reactor Coolant System Instrumentation

                                    -Makeup and Pu'rification System
                                   '.Nain Steam System
                                   " Steam Gener-ator Instrumentation
                                     -Auxiliary Feedwater System Decay Heat System Nuclear Service Cooling Water System            "

Nuclear Service Raw Water System Essential HVAC Systems Emergency Generator Systems [

The-pafe shutdown systems are suodivided in the matrix into the following categories: Equipment - Circuitry Motor Control Centers (MCC's) or Switchgear Redundant Components present in the same fire area The entries in this section of the fire analysis matrix are made by entering the letter identifier for the train (s) of the safe shutdown system (s) present in the area in t6e . appropriate column of the matrix. i' rains are designated by the letters'A or 8, which coordinates with the electrical. power supply to the' component Thandesignations are as follows:

                                    'A-        Component's power can be traced to 480V switchgear S3A, 53A2 or 125V DC distribution panel SOA, SOA2 or SOC, SOC 2 B-      Comoonent's power can be traced to 480V switchgear S38, 5382 or 125V OC distribution panel 508, 5082 or 500', S002 N-      Comconent's power can be traced to 125V DC cistribution panel SON 1 Non-nuclear instrumentation from NNI cabinet "X" is designated as Train A; instrumentation from NNI cabinet "Y" is designated as Train 8.

l The safe shutdown' systems are summarized in the " Redundant Component" i column as well as the " Summary" line.- When redundant cocoonents are l identified in the safe shutdown matrix in the same fire area (i.e., A, 8), an asterisk is entered in the " Redundant Component" column. The

            ~
                             " Summary

line is used to highlight potent.ial systems interactions.

' Entries in this line of the matrix are made by recording in the l appropriate column the letter identifier for the trains of each type of l comp #onent (equipment, circuitry, etc.) present. , 7/86 3-4 REVISION 4A 1000g

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Wh;n safe shutdown cables have been wraoped/orotected with a material wnich constitutos a 1-nour fire barrier, the train identifier is snown as a lowar case letter. Electrical Distribution Svstems Equipment associated with the electrical cistribution systems is 'isted in this section of the matrix. Eacn of the electrical distribution systems is subdivided into the following categories: Equipment Circuitry Motor Control Centers (MCC) or Switchgear Redundant Components present in the same fire area Entries in this section of the fire analysis matrix are made by entering in the appropriate columns on the matrtx the train (s) of eacn electrical distribution system present in the fire area. The existence of redundant components is noted by entering an asterisk in the " Redundant- Comoonents' column of the matrix. Where electrical distribution system cables have been wrapped with a material wnich constitutes a 1-hour rated fire barrier, the train identifier is shown as a lower case letter. - 3.2 Fire Hazards Analysis Text _ This section explains the topics cdvered in the text of the fire hazards analysis, Section 5. For definitiens of the ' terms used in this section, see Section 2.0,, Methodology. 3.2.1 Location . This topic includes the title of the buildings in which the fire area is

located, the floor elevation, and the numbers of the rooms contained in the fire area. For Appendix R fire areas, the suo-fire areas .wnicn compose the. Appendix R areas are also listed. This information is obtained f rom the structural, general arrangement, and architectural drawings. 3 . 2*. 2 Appendix R, Section III.G Evaluation Scusary This topic.is a summary of the results of the Aopendix R Section III.G evaluation for each fire area. 3.2.3 Combustible Material This topic covers the type and quantity of each combustible material in the fire area. The fire loading (BTU / square foot) and fire duration for the fire area are also given. For Appendix R lire areas, this 7/86 - 3-5 REVISION 4A 1000g h* O O # h ,__ _. K . .* ** , g,_ _ __ _ - _ ,

information is detailed on the basis of cach suc-fire area in separate tables. This information comas, f rom the FHAR walkdown, the cable tray comoustible loaoing calculations, and tne resulting calculations discussed in Sections 2.2.5, 2.2.9. 2.2.10, ano 2.2.11. 3.2.4 Fire Protection Equipment This topic includes the elements of the fire protection system availaole . to mitigate the effects of a fire within the area. Fire' protection equipment consists of. automatic suppression systems: carcon dioxiae systems, sprinkler systems, hose stations, portable extinguishers, and fire detectors. This information was collected by FHAR walkdown, Section 2.2.6. 3.2.5 Construction This topic includes a description of the fire area construction, . : consisting of the following: . (1) Wall, floor, and ceiling construction (material, thickness, anc rating). (2) Doors (rating and adjacent fire area). . (3) Description of fixed openings. (4) Description of penetration seqls (type, rating). The collection of this data is desfribed in the Construction Review, Section 2.2.8. 3.2.6 Equipment Required for Hot Shutdown . This topic contains a listing of all components-(equipment, cabling, MCC/Switchgear) within the fire area whicn are required to achieve or maintain hot shutdown in the event of a fire. The equipment is listed by system and by its respective train. Sections 2. 2.1 - 2. 2. 5 discuss the . deve,lopment of this information. 3.2.7 Equipment Required for Cold Shutdown This tooic contains a listing of all components (equioment. cabling, MCC/Switchgear) within the fire area .shich are only requirec to cool down from hot shutdown to cold shutdown or to maintain cold shutdown. The equipment is listed by system and by its respective train. Some of this equipment is also required for high/ low pressure interface and is noted with an asterisk. Sections 2. 2.1 - 2. 2. 5 discuss the development of this information.

7/Bb 3-6 REVISION 4A 1000g .

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~ p i 3 .,2. 8 High/ Low Pressure Enterfaci L This topic lists the comDonents/ circuits located in tne # ire area nicn are associatec witn the nign7 low 3ressure in~terf ace. The scui: ment is presented by system and by its resoective train. Some of Inis ecui ment is also required for cold snutdown anc is notet witn an asterisk. . Sections 2. 2.1 - 2. 2. 5 discus: the d,evelopment .of tnis inf ormati,on.p i s , 3.2.9 SpuriousOpergtion ,. * . 1 i n) This topic cor.tains a listi' gn of the components / circuits locatec in 'the fire area with a potential for spurious operation. The equipment is list'ed by system and by its respective train. Sections 2. 2.1 -' 2. 2. 5 discuss the deve'lopment of this 11 formation. 5.2.10 Ef fectr of Fire on Hot Shutdown capability y

     .          ,               i.                                              i
     !        This section discusses the consequences of the loss ofiacuipment and I

circuitry required-for hot shutdown as a result of a fire. Operator actions are identified as a part of the discussion.

     .        3.2.11     Effects of Fire on Cold Shutdown Capability This section discusses the consequences of the loss of equipment and circuitry required for cold shutdown as a result of a fire.                Operator actions are identified as a part;of the discussion.

3.2.12 Effects of Fire on High/ Low' Pressure Interface This section discusses the consequences of the loss of equipment , associated with. the high/ low pressure interface as a result of a fire. Operator actions are identified as a part of the discussion. 3.2.13 Consequences of Spurious Operation '

               ' his T     section discusses the consecuences of the inadvertent equicment operation, associated with components wnose sourious operation' coula adversely af fect safe shutdown. Operator actions are identified as a                               .

part of the discussion.

         . 3.2.14 Conclusions This'section contains the conclusions and recommendations wnich result                               ~

from the analysis of the effects of the design basis fire on hot and cola shutdown capability. 7/86 3-7 REVISION 4A

1000g m.wsee e- m 6 -- 2 -e -ew e

 .                 -              am.           b   w                  s                                                      --
                                                                                                            - - +
                                                                                                                                   -m

Figure 3-1 . \ Fire Area Matrix 0 t h *. 4 7/86 3

                                                                             -8                          REVISION 4A 1000g
                                ,,,     w owq                                                                          -_
                                              'mWv'9"     MWW V^N"*           '#
                       ' ,. . _       ,s              ._m                        -

4.0 FIRE AREA DESCRIPTIONS This section provices three taoles for the cescription of the 31 ant firo areas: l s Tacle 4-1 Fire Area Descriptions, This table cross-references the fire area numoer, descrip' tion, and room numoers. Tabl'a 4-2 Sub-Fire Area Descriptions This table provides a listing of the fire areas from the 1977 Fire Hazards Analysis Report which.were combined to form the Appendix R fire areas. e

                                                                                                                                                                       ~              .

7/86. 41 REVISION 4A 1000g i

     ***"'**"4            __
                                 --        **-*=%w.we.-                                                                                                    . . ~ . .           , . . , , , , , , _ ,                        , _  _                   ,
                             '                                                       &                                                                                    ~ '                        * 'n_-__x

_. ___.n____________ _ _ _ _ _ e __ _ _ _ _ __ _ _ _ _ __ n______ __

TABLE 4-1 - FIRE AREA'0ESCRIPTICNS Fire Area Descriotion Room No. AUXILIARY SUILDING , 1 Control and Computer Room 338-344 , 2 Technical Support Center 333-336 6 Chemical Storage Room 326 15 West Station Battery Room 220 16 - West AC/DC Panel Room. . 218, 219 17 West 480 Volt Switchgear Room 217 18 West Cable Shaft 055, 123, 216 19 East Cable Shaft 054, 122, 215 20 East 480 Volt Switchgear Room 21 4 21 East AC/DC Panel Room

212, 213 27 Ventilation Equipment /Eleet'rical - 208, 211 Penetration Area 28 Electrical Penetration / Radiation 209 Monitoring Area . 30 West Nuclear Service Batterf Room 125, 126

                                                                                                             ~
                                                                                       ~

31 West 4160 Volt Switchgear Room 124 32 East 4160 Volt Switchgear Room 121

33 East Nuclear Service Battery Room 119, 170 36 Main Corridor - Grade Level 103, ,v,, 105 37 North Diesel Generator Room - 132 . 38 South Diesel Generator Room 130 47 Corridor and Stair to (-47') Level 010, 056, 127, 138 m 7/86 4-2 REVISION 4A 1000g

                                     ** ~^""#*          *"N*- "* hee.

sump- e- ._,

       -         7

TABLE 4-1 , FlRE AREA DESCRIPTIONS

                                                -(Continued)

Fire Area Descriotion . Room No. , AUXILIARY BUILDING (Cont.) 48 Train A High Pressure Injection Pump Rocm 053 56 Train A Decay Heat Pump Room 001 57 Train 8 Decay Heat Pump Room 002, 003 6i Elevator No. I 115, 203, 315 62 Stairwell No. 2 - 131, 222, 345

              .64        Toilet - Ground Floor                               135 67        Stairwell No. 1                                 -

101, 201, 301 72 Stairwell No. 3 116, 210, 318 A Auxjliary Building Roof 74 RBl Appendix R Fire Area - North Auxiliary Building - BeloC Grade --- RB2 Appendix R Fire Area - South Auxtliary Building - Below Grade --- RG1 Appendix R Fire Area - Auxiliary Building Grade Level --- RG2 Number Deleted RG3 Appendix R Fire Area - Auxiliary Building Elevator No. 2 and Machinery Room - - - RMI Appendix R Fire Area - Auxiliary Building Mezzanine Level RTl Appendix R Fire Area - Auxiliary Building Turbine Deck -- REACTOR BUILDING 68 Reactor Building . e e e 4-3 REVISION 4A 7/86 1000g m

                                                                                    ^
                                                                " "~
   "   ~

nF ~

9 i TABLE 4-1 - i FtRE'A42A DESCRIP.T CNS (Continuec) Fire Area OescMotion Room No. TURBINE BUILDING l 71 Turbine Building --- f FUEL STORAGE BUILDING i 73 Fuel Storage Building --- YARD AREA .. 69 Reactor Yard Area , o . 110 Nuclear Service Raw Water Pump Area -- NUCLEAR SERVICE ELECTRICAL BUILDING'(NSEB) 75.1 Train 8 Switchgear. Room 146 75.2- Train 8 Battery Room , 142 Channel 0 ' Battery Room 143 75.3 }^ _ 76.1 Train A Switchgear Room. 147 76.2 Train A Battery Room 145 76.3 Channel C Battery Room 144 77.1 Channel O Electrical Ecuipment 232 Room . 77.2 Train B Electrical Equipment Room 234 . 78.1 Channel C Electrical Equipment 233 Room 78.2 Train A Electrical, Equipment Room 235 79- Battery Room G8 371 80 Battery Room GA 370

      -      81      Train 'S Cable Shaf t and Tunnel         061, 148, 238              -

l l l ' . 4-4 REVISION 4A 7/86 , l 1000g wm

TABLE 4-1 FIRE AREA DESCRIPTIONS (Continued) Fire Area Desc ri otion Room No. NUCLEAR SERVICE ELECTRICAL SUILDING (NSEB) (Con't.) C

                  ~
                 ~82              Train A Cable Shaft and . Tunnel                       062, 149, 239 83.1           Corridor at Elevation l'-6"                            141 83.2           Stairwell No. 11                                       151, 240, 366, 403 84.1          Corridor att Elevation 21'-6"                          231 84.2      - Train 8 Mechanical Equipment Room                        236 84.3          Train 8 Macnanical Equipment Room                      237 85.1          Corridor at Elevation 40'.-0"                          361 85.2          Train A Cable Room        _

364 365 85.3 Train 8 Cable Room [. , 85.4 NSES Access Bridge 368, 369. 85.5 , Elevator and Hachinery Room 150, 241, 367,'

                                                                                     . 401 86            Number Not Used 87            Computer Room 8              ,

362 88 Number Deleted 89 Computer Room A . . 363 , 90.1 Number Deleted 91.1 Vestibule-at Elevation 60'-0" 402 91.2 NSEB Roof --- 7/Be 4-5 ~ REVISION 4A

1000g -

 %             q     q
                       *              .            q

~~ TABLE 4-1 FIRE AREA DESCRIPT.ONS ( Co~n t i n ued )

        .fre    Area   Oescriotion                                                            3com No.
      ~01ESEL GENERATOR BUILDING (OG)                                             -

105_ OG8 "A2" Diesel Generator _ Rooms 161,162,251 4 106 OG8 "B2" Diesel Generator Rooms 163,164,251 120 OG8 "A2" Radiator Fan Area -- 121 OG8 "A2" Diesel Oil Pump Vault --- 122 OG8 "92" Radiator Fan Area --- 123 OG8 "S2" Diesel Oil Pumo Vault ---- 124 OG8 - Building Roof ,

7/86 4-6 REVISION 4A 1000g

                             *-   9   "* M -     -  C

TABLE 4-2 - SUS-FlRE AREA'0ESCRIPTIONS Fire Area Descriction Room No. AUXILIARY BUILDING , The following are sub-fire areas of Appendix R fire area RB1: R81 -49 West Containment Penetration Valve Area 052 R81 -50 ~ East Containment Penetration Valve Area 045, 051 R81 -51' Radwaste Air Supply Fan Room 050 RB1-52 Seal eturn Cooler Room 046, 049 R81 -58 MakendPumpRoom 044 R81 -60 . Spent; Resin Tank Room 047, 048 The fc11owing are sub-fire areas of Appendix R fire area RS2: RE2-40 Waste Gas Compressor Room 022 R82-41 WasteGasDecayTankRoom] 018 RS2-42 Miscellaneous Waste Gas Condensate Tank Room 021 R82-43 Deboration Ion Exctiange and Miscellaneous 019, 059 Wasts Condensate Domineralizer Room . R82-44 Miscellaneo'us Waste Concentrator Room - 023, 024 R82-45 Boric Acid Eyaporator Room 025 RB2-46 Main Corridor - Below Grade 011, 012, 013,

                                                    -                       015, 016, 020, 036, 057, 058, 107, 111 RS2-53      Ion Exchange Valve Area                             027-035 R82-54      Miscellaneous Waste Filter Room                     026 R82-55      Tank Rooms - Below Grade                            037-042 R82-59      Train 8 High Pressure Injection Pump Room           043 R82-66      Miscellaneous Waste Tank Room                       014, 017 4-7                                 REVISION 4A 7/86 1000g                                     .

O

   ~~                                                        '
                            - - L 1 .._.- :    _~__    _         _T - nn   ___      . . _    _ _ _ . _ . -. -

TABLE 4-2 SUB-FIRE AREA DESCRIPTIONS Fire Area DescM otion Room No. AUXILIARY BUILDING (Cont.) The following are sub-fire areas of Appendix R fire area RG1: RG1-22 Air Conditioning Equipment Room 202, 204, 228 RG1-34 Electrical Penetration Area / 106, 109, 11Q, Chemical Storage Balcony 114, 117, 118, 133, 136 Hot Machine Shop RG1-35 134 - RG1-39 Waste Solidification Area- 112 RG1-65 Makeup Tank Room 113 The following are sub-fire areas of Appendix R fire area RG3: . . RG3-63 Elevator No. 2 129, 221, 346 Elevator Machinery Room 128 RG3-70

The following are sub-fire areas of Appendix R fire area RM1:

RM1-23 Sample Cooler Chiller Rcom 225 RM1-24 North Communication Room 224N, 227 RM1-25 South Comunication Room 2245 RM1-26 Storage Room . 223 l RM1-29 Main Corridor - Mezzanine Level . 206, 207, 22E The following are sub-fire areas of Appendix R fire area RT1: RT1-3 Health Physics Office 330, 331, 332 RT1-4 Clean Locker Room 304, 308, 305, 306, 353 RT1-5 Conference Room ,349, 352 RT1-7 Storage Room 325 7/86 . 4-8 . REVISION 4A 1000g m .O._9_ _m___________ ______ _ __ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , ___

                           .                                TABLE 4-2 SUB-FIRE AREA DESCRIPTICNS

Fire Area Oescriotion Room No.

AUXILIARY BUILDING (Cont.) The following are sub-fire areas of Appendix R fire area RT1 (Cont.): - RT1-8 Chemical Laboratory 327, 328 RT1-9 Radiological Chemistry Laboratory 319, 320, 321 RT1 -10 Calibration and Source Storage Room 324 RT1-11 Che.mical Storage Room 323 RT1 -1 ?. Fuel Storage Building Access Corridor 322W RT1 -13 Reactor Building Access Area 309, 314, 316, 317, 350, 351, 322E RT1-14 Main Corridor - Turbine Deck 302, 303, 329

      %                                                           he       o e

e e

l i 7/86 49 REVISION 4A l 1000g. j :. -

                                                                                            ~
                  - - ~
 <      - -                  . .     .. .              .              .                                _    _'~       ,

OETAfLED FIRE HAZARDS ANALYSIS The analysis section is diviced into the Jolicwing suosections by plant area / building: AB - Auxiliary Building R8 - Reactor Building YD - Yard Area TB - Turbine Building FS8 - Fuel Storage Building NSEB - Nuclear Service Electrical Building OGB - Diesel Generator Building e W 4 e a s e l [ l

I \ l 7/86 5-1 REVISION 4A l n -e - - ~ . .-- e -- -- ..~s , en

                       ~.-~_.*-wew==
                                           =~                w-e. _ w.m , .      e.

eo -.

FIRE AREA: 105 AREA: 2654 sq.ft. OESCRIPTICN: OG5 "A2" OIESEL GENERATCR RCCMS VOLUME: 35592 cu.f . CCMBUST!3LES 011 & Grease ~_337 gals. Cable 31~ irs. Actual % fill Class A 0 lbs. 0 lbs. Charcoal Plastics 16 lbs. Miscellanecus 0 lbs. . DESIGN BASIS FIRE . Fire Loading 72229 BTU's/sq.ft. Max. Permissible Leading 240000 BTU's/sq.ft. Fire Duration 0.90 hrs. FIRE PROTECTION (AVAILABLE) Suppression (type) cre-action sprinklers Hose Stations 3 within area ~ Portable Extinguishers (1) 2A:20B:c, (5) 10B:C

.       DOtactors (type)                                       ionization, photoelectric and infrared e

FIRE RESISTANCE RATING WALLS N S E- W FLCCR CEILING Actual Rating NR/ NR/ 3 hr 3 hr NR/ 3 hr ext ext grd Pcnetrations

                - Mechanical                                       ---      ---

3 hr ~

                                                                                                     ---        ---          NR
               - Electrical                                        ---      ---               - -    ---        ---          NR
               - EVAC                                             NR    ,

NR --- NR --- NR Fixed Openings , LV ' LV --- LV --- Doors DG-171/ ext /NR, DG-106/120/NR, hatch door /124/NR SAFE SHUTDOWN SYSTEMS ..___. eQUIm.______C.3CU,.T3v.___.e'd..Eu@.Ec E Mw . A.2 h M.h-RCS Instrumentation ____________1_____________1___________1______ Makeup System (SIM/PLS) ____________1_____________1___________1 _____ 4 Main Steam System ____________1_____________1___________1______ Steam Generator Instr. ____________1_____________1___________1______ Feedwater Sys. - AFW Train __,_________1_____________i___________1______ D: cay Heat System ____________1.____________1___________1______ l Nuclear Cooling Water _________ __1.____________i___________1______ i Nuclear Raw Water ____________1_____________1___________1______ Ecsontial EVAC (EvS) _____A2_____1 _____&2_____1___________1______ Emergency Generator System _____A2_____1______A2_____1 ____a2____i_______ j

SUMMARY

4_____&2_____1______A2_____1_____&2____1______i

                                                                                          -                MCC CR         REDUNDANT ELECTRICAL DISTRIBUTION SYSg_EQUIE.______CIRCUITEY___5'dITCHGEAE_CCMECNENT 4160 v (AC)                                ____________1______A2_____1___________1._____

f 480 v (AC) .___________1______&2_____1_____a2____1______ 120 v (AC) ____________1______A2_____1_____A2____1______ 125 V (DC) , ____________1_____________1___________1_______

SUMMARY

____________1______A2_____1_____AZ____1._____1

ASSOCIATED CIRCUITS High/ Low Pressure Interface: No l

Spurious operation : No 7/86 DGB-1 REVISION 4A e

  *  .V'88*    _

q=egs ww opw e- e se_--,-. , . - .

FIRE AREA 105 ko. cation Diesel Generator Building - El . O'-0" and 18'-6 A2" Diesel Generator Rooms Rooms 161, 162 and 250 ADDendix R. Section III.G Summary The fire protection features provided for the protection and separation of, safe shutdown systems within the fire area meet the requirements of 10CFR50, Appendix R, Section III.G. , Ouantity Combustible Mater 4al 011 & Grease: . Diesel Fuel 637 gals Lube Oil 700 gals Cable: 317 lbs Plastics: Plastic 16 lbs Fire Loading - 72, 229 Stu/sq ft - Fire Duration - 0.90 hrs ,' Fire Protection Eouioment - The area contains a pre' action sprinkler system for are'a-wide suppression ' coverage. Manual fire fighting equipment is available in the area. , Ionization smoke detectors,' photo-electric smoke detectors and infrared flame detect' ors, located within the area, actuate the preaction valve and provide annunciation in the control room. Construction The walls and ceiling of the area are of 3 hour rated construction except the non-rated exterior walls. The walls adjoining the diesel generator *B" room (106) and the radiator area (120) are concrete with an approximate thickness of 24 inches. The exterior walls are ' concrete with an approximate thickness of 24 inches. The ceiling of the area is concrete with an approximate thickness of 27 inches. The floor is a concrete base slab. Access to the area is through non-rated double doors in the north wall. Non-rated double doors cmnnunicate with the radiator area (120) and a non-rated steel hatch door opens to the roof (124). Two louvered ventilation 1 openings in the north wall and one in the south wall, opening tr, the exterior are not provided with fire dampers. The louvered diesel air irtake opening in the west wall adjacent to the radiator area is not provided with a fire damper. Three ventilation penetrations to the roof are not provided with fire l dampers. Mechanical penetration seals in the east wall are 3 hour rated. Electrical and mechanical penetration seals in the ceiling to the roof (124) are not fire rated. 7/86 068-2 REVISION 4A

_ _ _____u._____.m_.__.__'_____m___m_. . - __-_ . _ ,

FERE AREA 105 EauiDment Required for Hot Shutdown Emergency Generator Systems- (EGS/Dio)

             .         Train A2 Diesel Generator Control Panel                     H2DGA2 H20EA2 Diesel Engine           G-100A
                ~

Oiesel Generator GEA2 Power Cable: H20GA2 ~ H20EA2 - -

                                . Control Cable:         GEA2                   :
                                                                                 ~

G-100A . l , H20EA2 j Fuel Oil: Pump (Engine Driven) P-100A

                  ,                            Strainer N10002A                                                 . s, Pressure Control Valve PCV-10021 Filter F-100A                          -

Level Switch LSHL-10003 Power Cable: P-108A P-108C Control Cable: P-108A - P-108C Lube 011: Cooler E-102A -

                                              . Filter F-102A Strainer N-10202A Pump P-102A Tank T-102A Cooling Water:        Intercooler E-105A                               '

Pumo P-104A Standpipe T-104A Temperature Control valve TCV-10402 Power Cable: OG A2 Radiator Fan E-104A-Fi E-104A-F2 E-104A-F3 E-104 A-F4 E-104 A-F5 E-104A-F6 Starting Air: Control Valve SOL.1 A( A)

SOL.18(A) Receiver V-101 A V-101 C Intake Air Filter F-106A Intake Air Silencer Y-106A Exhaust Air Silencer Y-107A Power Cable: SOL.1A(A) SOL.18( A) 07/86 OG8-3 REVISION 4A

                                                         -FIRE AREA 105 Ecuicment Recuired for Hot Shutdown (cont'd)

Essential HVAC (HVS): Train A2 DG A2 Essential . Air Hancling Unit AH-0G-1 A OG A2 Essentiai Exhaust Fan EF-556A OG A2 Control Room Supply Damper HV-55711 OG A2 Control Room Exhaust Damper HV-55713 OG A2 Room Fan High Temp. Switch TSH-55701 TSH-55707 Power Cable: AH-0G-1A EF-556A ^ TSH-55701 TSH-55707 - Control Cable: AH-0G-1A

     -                                                       EF-556A HV-55711 HV-55713 Electrical Distribution Systems:

480V AC Train A2 Motor Control Center 52A4 120V AC Train A2 Distribution Panel 51 A4 Power Cable: 4160V AC Switchgear 54A2 480V AC Motor Control Center 52A4 120V 'AC Distribution Panel S1 A4 Control Cable: 480V-AC Motor Control Center S2A4

   .      Eauinment Reauired for Cold Shutdown
                                              ~
       ,Nona Hich/ low Pressure Interface None Sourious Ooeration None Effects of Fire on dot Shutdown Caoability Emergency          Loss of equipment and cables for the train A2 emergency generator Generator          systems is to be expected. ~ Equipment and cables for the Systems             redundant train 82 emergency generator systems are located                 .

outside the fire area and will remain available. Essential Loss of equipment and cables for the train A2 emergency generator HVAC air . handling unit AH-0G-1 A, exhaust f an EF-556A, control room dampers HV-55711 and HV-55713, and high temoerature switches

           .                   TSH-55701 and TSh-55707 is to be expected. Equipment and cables for the redundant train 32 emergency generator essential HVAC                -

are located outside the fire area and will remain available. 7/86 OG8-4 REVISION 4A

N**"**'* , , . . . _

                --W'M -

L O- a m - - ,

FTRE AREA 105 Ef fects of Fire on Hot Shutdown Cacaoili? / (cont'd) . Electrical Loss of train A2 480V motor control center 52A4 and 120V AC Distribution distribution panel 51 A4 is to be expectec. ' Loss of power caules s'ystems to 4160V switcngear 54A2 is to be expected resulting in loss of S4A2. Equipment and cables for the redundant train 32 electrical distribution system are located outside the fire area and will remain available. Effects of Fire on Cold Shutdown CaDability There are no cables or equip' ment in the area which are required to achieve or

maintain cold shutdown only. Effects of Fire on High/ low Pressure Interf ace There are no cables or equipment in the areas which are required to maintain the high/ low pressure interface. Consecuences of Sourious Ooeration There are no cables or equipment in the area for components whose spurious operation would adversely af f ect saf e, shutdown. , Conclusions . - - , r The fire protection features prov-ided preclude the propagation of the fire beyond the boundaries defining the fire area. Damage resulting from the fire will be limited to one train of systems c'equired for hot shutdown. E e 4 e e a 7/86 OG8-5 REVISION 4A

  ,gge       __

_vg..-e== - - = - - - - =*- --

AREA: '2654 sq.ft. DESCRIPTICN: DGB "32" DIESIL GENERATCR RCCMS .

   , VOLUME            83592 Ou.ft.
   -CCMBUST!3LES Cil & Grease                                           ~337 gals.

Actual % fi_,1

Cable 304 1.:s.

Class A 0 'bs. _ Charcoal 0 lbs. Plastics 16 lbs. Mircellaneous 0 lbs. DESIGN BASIS FIRE 72168 STU's/sq.ft. Fire Loading Max. Permissible Leading 240000 BTU's/sq.ft. Fire Duration 0.90 hrs. FIRE PROTECTION (AVAILABLE) Suppression (type) pre-action sprinklers Hose Stations 3 within area (1) 2A:20B:C, (5)10B:C Portable Extinguishers Datectors - ( type-). ionization, photeelectric and infrared FIRE RESISTANCE RATING WALLS N

                                                                . . . . - . -        .S . . . . . .E._- - . . .W- . .. FLCCR CEILING Actual           Rating                                       NR/           NR/                3 hr    3 hr      'NR/       3 hr ext           ent                                   grd Pcnetrations                                                   ---          ---                ---     3 hr       ---

NR

            - Mechanical
            - Electrical                                              ---           ---               ---     ---        ---       NR            .
            - HVAC                               -

NR- NR NR --- --- NR Fixed Openings LV LV LV --- --- -- Decrs DG-ld2/ ext /NR, DG-103/122/NR I I I t SarE SauTDewN SYSTEMS .___ .cur,.______c,acuI:s____ w.S.C CBU.sor.aa.RJ.DgNDANT c g cussT l RCS Instrumentation ___________.i ____________1 __________1._____ Makeup System (SIM/?LS) ____________1_____________1__________ i______ Main Steam System ____________1_____________1_____._____1______ Steam Generator Inser. ____________1_____________1.__________1______

      .Fcedwater Sys. - Arw Train ____________1____________ 1__________.1______

Decay Heat System .___________i_____________i.__________i______ Nuclear Cooling Water ____________1_____________1.....______1______. Nuclear Raw Water ____________1. ___________1._______ ._i___.._ Essential. HvAC (HvS) _____32_____1___;__32_____1___________1._____ Emergency Generator System

SUMMARY

                                       ,U____32_____.'______32______'_____5.2_____'______._'

_ _ _ _3 2_ _ _ _ _1__ _ _ _ _3 2_ _ _ _ _ i._ _ _ _3 2_ _ _ ELECTRIC.AL DISTRIBUTION SYS"..E_M__v. . QUI 2. _____cIacuITar.__swhhghEur Mc h 4160 v (AC) ____________1______B2_____1___________1______ 480 v (AC) ___________.1..... 52_____1____.52.___1______ 120 V (AC) _..________.1______32____.1_____32____1______ ._ 125 v (DC) . ___________1_ _____ .___1.__________i.______

SUMMARY

                                      +___________.!...___*.2______*_____2.2_____'_______

ASSOCIATED CIRCUITS High/ Low Pressure Interface : No Spurious Operation : No 7/86 DGB-6 , REVISICN 4A

                      =                                                                                                                              l l
                                                                                         .                                                           l

__ _ ___ _ _ _ _ l

FEREAREAjl06 Location "iesel Generator Building - El. O'-0" and 18'-6* *S" Diesel Generator Rooms

s 163, 164.and 251 Anoendix R. Section III.G Summary .

The fire protection features provided for the protection and separation of safe shutdown systems within the fire area meet the requirements of 10CFR50, Appendix R, Section III.G. Quantity Combustible Material 0 Oil & Grease. r Diesel Fuel i 637 gals Lube Oil 700 gals Cable: 304 lbs Plastics: Plastic - - 16 lbs Fire Loading - 72,168 Stu/sq ft - - ~ Fire Duration - 0.90 hrs , Fire Protection Eauipment The area contains a pre-action sprinkler system for area-wide suppression coverage. Manual fire' fighting equipment is available in the area. Tonization smoke detectors, photo-electric 'snmke detectors and infrared flame detectors, located within the area, actuate the preaction valve and provide annunciation in the control room. Construction The walls and ceiling of the area are of 3 hour rated construction except the non-rated exterior walls. The walls adjoining the diesel generator "A" room (105) and the radiator area (122) are concrete with an approximate thickness of 24 inches. The exterior walls are concrete with an approximate thickness ! - of 24 inches. The ceiling of the area is concrete with an approximate ! thickness of 27 inches. The flocr is a concrete base slab. f Access to the area is through non-rated double doors in the north wall. ! Non-rated double doors communicate with the radiator area (122). Two louvered ventilation openings in the north wall and one in the south wall open to the exterior and are not provided with fire dampers. The louvered diesel air intake opening in the east wall adjacent to the radiator area is not provided with a fire damper. Three ventilation pene,trations to the roof are not i ' provided with fire dampers. Mechanical penetration seals in the east wall are ! '3 hour rated. Electrical and mechanical penetration seals in the ceiling - (124) are not fired rated.

! 7/86 068-7 REVISION 4A d m _

FIRE AREA 106 Eouicment Reouired for Hot Shutdown . Emergency Generator Systems (EGS/DFO) Train 82 Diesel Generato.r Control Panel H20G82 H20E82 Diesel Engine G-1008 Diesel Generator GE82 Power Cable: H20G82 H20E82 Control Cable: GE82 G-1008 ,

                                                                    - H20E82 Fuel 0.11:       Pumo (Engine Driven) P-1008 Strainer N-102028
           -                                                  Pressure Control Valve PCV-10020 Filter F-1008 Level Switch LSHL-10002 Power Cable:           P-1088 P-1080 .

Control Cable: P-1088 P-1080 Lube Oil: Cooler. E-1928 - Filter F-102s Strainer N-102028 - Pump P-1028 , Tank T-1028 , Cooling Water: Intercooler E-1058 Pump P-1048 Standpipe T-1048 Temperature Control valve TCV-10402 Power Cable: OG B Radiator Fan E-1048-F1 E-1048-F2 E-1048-F3 E-1048-F4 E-1048-F5 E-1048-F6 Starting Air: Control Valve 50L.1 A(8) SOL.18(B) Receiver V-1018 V-1010 Intake Air Filter F-1068 Intake Air Silencer Y-1068 Exhaust Air Silencer Y-1078 Power Cable: 50L.1A(B) 50L.18(8)

                                                           '                                       ~

0G8-8 ' REVISION 4A 7/86 ., D

                                           *~' *

e -

W$ NN

FIRE AREA 106 Ecuicment Reouired for Hot Shutdown (cont'o) Essential HVAC (HVS): Train B2 OG B2 Essential Air Handling Unit AH-0G-18 . DG B2 Essential Exhaust Fan EF-5568

DE B2 Control Room Supply Oamoer HV-55712 DG B2 Control Room Exhaust Damper HV-55714 -

06 82 Room Fan High Temp. Switch TSH-55702 TSH-55708 - a Power Cable: AH-0 G-18 EF-5568 TSH-55702 TSH-55708 - Control Cable: AH-0G-1B EF-5568 HV-55712 HV-55714 > Electrical Distribution Systems: 480V AC Train 82 Motor Control Center S284 120V AC Train 82 Distribution Panel S184 - Power Cable: 4160V AC Switchgear S482 480V AC Motor Control Center S284 120V 'AC Distribution Panel S184 Control Cable: 480V AC Motor Control Center S284 Eauioment Reouired for Cold Shutdown None - Hioh/ Low Pressure Interface None Sourious Ooeration None Effects of Fire on Hot Shutdown Caoability Emergency Loss of equipment and cables for the train B emergency generator Generator systems is to be expected. Equipment.and cables for the Systems redundant train A emergency generator systems are located outside the fire area and will remain availaole. Essential Loss of equipment and cables for the train A2 emergency generator HVAC air handling unit AH-0G-18, exhaust fan EF-5568, control room - dampers HV-55712 and HV-55714, and high temperature switches TSH-55702 and TSH-55708 is to be expected. Equipment and cables for the redundant train 32 emergency generator essential HVAC are located outside the fire area and will remain available. 068-9 REVISION 4A 7/86

                             ~*                 **HMmAW9w+%-** mom                    y

FIRE' AREA 106 Effects of Fi e on Hot shutcown Cacacilitv (cont'd.) Electrical Loss of train 32 480V motor control center 52B4 and 120V AC Distribution distribution panel S184 is to be excectec. Loss of power cacies Systems to 4160V switengear S482 is to be expected resulting in loss of 5482. Equipment and cables for the redundant train A2 electrical distribution system are located outside' the fire area - and will remain available. Effects of Fire on Cold Shutdown Capability

There are 40 cables or equipment in the area which are required to achieve or maintain cold shutdown only. -

   .                                                                             i                                                                       '

Effects of Fire on Hich/ Low Pressure Interface There are no cables or equipmentein the areas which are required to maintain the high/ low pressure interface. Consecuence's of Sourious Goeration There are no cables or equipment in the area for components whose spurious I operation would adversely af fect safe shutdown. _ Conclusions

                                                                                            ~        .

The fire protection features provided preclude the propagation of the fire" beyond the boundaries defining the fire area. Damage resulting from the fire will be limited to one train of systems required for hot shQtdown. , e e 7/86 OGB-10 REVISION 4A e

 '                                                                                 -        .              . _____  n   _ _ _ _     ,  _ _ _ _ _       __

L{L9h5RM*MRSM AREA: 4773 cq.ft. DESCRIPT!CN: DGB "A2" RADIATCR FAN AREA VOLUMEt N/A COMBUST!3LES Cil & Grease 0 gals. Cable 0 _bs. Class A 0 lbs. Chsrcoal 0 lbs. Plastics 0 lbs. Miscellanecus 0 lbs. DESIGN BASIS FIRE Fire Loading Max. Permissible Loading 0 BTU's/sg.ft. 80000 STU s/sq.ft. Fire Duration 0.00 hrs. FIRE PROTECTION (AVAILABLE) Suppression (type) none Hose Stations - none, (1) in 105 Portable Extinguishers none, (1) 10B:C in 105

     . Detectors (type)                                          none                                                                                    -

FIRE RESISTANCE RATING WALLS N S E W FLCCR CEILING ! Actual Rating NR/ NR/ 3 hr NR/ NR/ --- , ext ext ext grd Penetrations --- --- ---

              - Mechanical                                                ---         ---               ---
              - Electrical                                                ---         ---               ---            ---
              - HVAC                                                      ---         ---              ---             ---          ---              ---

Fixed dpenings , LV- --_ -_- ___

Doors DG-lb6/105 DG-109/ ext /'NR, DG-110/extj'NR

SAFE SHUTDOWN SYSTEMS . __. eQdI2.__...CI.3CUITEY._S*d..huhE- % sAE_ TC-CHh RCS Instrumentation ________ __ i_____________1. _________1._____

Makeup System (SIM/PLS) ____________1_____________1___________1_ ___ i Main Steam System ________..__1._________. _1.__________1______ Steam Generator Instr. ...... _____1______....___1.__________1______ Feedwater Sys. - AFW Train ..__________1_______....._i__________.i____ . Decay Heat System ____________1.____________1___________i______ l Nuclear Cooling Water __.________1._________.._i___________i______-- Nuclear Raw Water _.. ________i._ ...._____.i_ ..____.._i_____. Essential avAC (avS) ___________.1_____________1._________.i...___ Emergency Generator System .... 32..__ 1_ ... 32_..__1.____......i..____._

SUMMARY

4. .. _ _ &2_ _ _ _ 1. _ _ _ _ .12 _ _ _ _1_ _ _ _ _ _ . . . _1_ _ _ _ _ _.L ELECTRICAL DISTRIBUTION SYS 3 _ EQUI 2.._____CIRCUITEY___SW5hbHb b b 4160 v (AC) __ _ _______1..___________1___________1.____.

480 v (AC) - __ __________1.___________.i.....______1______ 120 V (AC) __ __________1_...._______.i.__________1______ 125 V (DC) ...________1__ ._________1___________1.._____

SUMMARY

9

                                                               ,____________1_____________1.__ .______1_______

ASSOCIATED CIRCUITS . High/ Low Pressure Interface : NO-i Spurious Operation. : NO l- . 7/86 DGB-ll REVISION 4A i x

me _ meg y e- g e e-@wem -N-6=<pu-aws-w c.r- *...m. eW---*WWw w

_._i4 _ _ . _ _ . _.._,_._u.*. p_,_____+_---geam,-._ _ _ ___.___.,_a._.___,.___..____,,2

FZRE AREA 120 -

Location Oiesel Generator Building - El . O'-0* A2" Radiator Fan Area Accendix R. Section II .G Summary The fire protection features provided for the protection and separation of safe shutdown systems within the fire area meet the requirements of 10CFR50, . Appendix R, Section III.G. Ouantity Combustible Material + ,None Fire- Loading - 0 Btu /sq ft Fire Duration - 0.00 hrs , Fire Protection Eauioment

Manual fire fighting equipment is available in adjacent area 105. No fire suppression or detection equipment is provided within the area. Construction 'The fire area consists of the enclosed yard area located west of the diesel generator building. The periteeter of the araa is defined by a block wall and the adjoining diesel building, wall. The wall adjoining the* diesel generator room "A" (105) is of 3 hour rated construction. The block walls are of ' reinforced masonry approximately 12 inches thick and 18 feet tall. The east wall adjoining area 105 is concrete with an apprcximate thickness o'f 24 inches. The floor of the area is asphalt on grade. There is no roof over the area. . Access to the area is through non-rated double doors from the diesel generator room (105). A bulletproof door in the south wall and a large steel double door in the south wall open to the exterior. The louvered diesel air intake in the west wall to area 106 is not provided with a fire damper. Eauionent Recuired for Hot Shutdown Emergency Generator Systems (EGS) Train A2 Cooling Water: 06 A2 Radiator E-104A 06 A2. Radiator' Fans E-104A-F1 E-104A-F2 E-104A-F3 E-104A-F4 E-104A-F5 E-104A-F6 e OG8-12 REVISION 4A 7/86 O

FERE AREA 120 i l Equioment Recuired for Hot Shutdown (Cont'd) Power Cable: OG A2 Radiator Fan E-10aA-Fi E-104A-F2 E -104 A-F3 , E-104A-F4 4 E-104A-F5 / E-104A-F6 {ouioment Raouired for Cold Shutdown

  ;           None l            Hich/ Low Pressure Interf ace None Sourious Ooeratidn 1

None , Effects of Fire on Hot Shutdown Canas111tv Emergency loss of equipment and power cables for-the train A2 diesel generator radiator system'is to be expected. Equipment and

~,

Generator Systems , cables for the train 82 61esel generator system are located outside the fire area.and will remain available. . iffacts of Fire on Cold Shutdown Canability There are no cables or equipment in the fire area which are required to

achieve or maintain ccid shutdown only.

Effects of Fire on Hio5/ Low Pressure Interface

 !            There are no cables or eqa1pment in the fire area which are required to
           , maintain the high/ low pressure interface.

Consecuences of' Sourious Ooeration l ' There are no cables or equipment in the fire area for components whose spurious operation would adversely affect safe shutdown. i . I I { i

7/86 068-13 REVISION 4A

ensues Tassostso l AREA: 192 sq.ft. DESCRIPTION: IGB "A2" DIESEL FUEL PUMP VAULT

VOLUME: 1347 cu.ft. COMBUSTIBLES Cil & Grease Cable Class A Charecal Plastics Miscellaneous DESIGN 3 ASIS FIRE Fire Leading Max. Permissible Leading STU's Fire Duration FIRE PROTECTICN (AVAILABLE) Suppression (type) w____ Actual Ra ng grd grd Electrical EVAC Fixed Openings ME Doors SAFE SHUTDOWN SYSTEMS RCS Instrumentation Makeup System (SIM/PLS) Main Steam System Steam Generator Instr. Feedwater Svs. Decay Heat System Nuclear ccoling Water Nuclear Raw Water Essential HVAC (HVS) Emergency Generator l 1 O cals. 0 '.bs. 0 lbs. 0 lbs. ' 0 lbs. 0 lbs. ft. 0 2000 STU's/sq/sq.ft. 0.00 hrs. none Hose Stations none Portable Extinguishers none Detectors (type) none FIRE RESIS CZ RATING WALLS N' g..S - -,. .-.-.E...--..-.-..-.W-..- FLOOR CEILING ~ NR/ NR/ NR/ NR/ - NR/ NR/ grd grd grd gri Penetrations NR Mechanical --- ' " -. --- --- --- --- DG-1.5.4/ ext /NR (Access Hatch Door) ecu:, ,.._ _ __ _ _cyECuv.TEv._ __ swW..Lu@.Er.aE_ M~ y_ .___ . ____________1_____________1___________1______ ____________1_____________1___________1______ ____________i_____________1___________1______ ____________1_____________1___________1______ - AFW Train __________'___'______________'____________'______ ____________1_____________1___________1______ _____~_______.________________________________ ____________i_____________1___________1______ ____________1_____________1___________1__'____ System _____&2_____1______&2_____i___________1_______.

SUMMARY

                                                              +_____ AZ_____"_______A2______'____________'_______'

MCC OR REDUNDAN'"

   -ELECTRICAL DISTRIBUTION SYS g _EQUIE.______CIECuITEY___SWITCEGEAE_CCMECNE39 4160 v (AC)                                                ____________1_____________1___________1______t 480 v (AC)                                                 ____________1_____________1___________1______.                                                       !

120 V (AC) ____________1_____________1___________1______; 125 v (DC) .____________ 1_____________1___________1______..

SUMMARY

                                                  .l.____________1_____________1___________1_______

ASSOCIATED CIRCUITS High/ Low Pressure Interface : NO Spurious Operation . : NO . DGB-14 REVISICN 4A . 7/86 , e

                             * **-M-"* * -*hma+.gm.-w.p.,i                    p_e     -,ee,                    ,,,_ , , ,,,                          _       ,
 -   -w   -w*gp                        qO                              ,w,gi.,)                -,G."-4v-e                   Q$

FZRE AREA 121 Location Diesel Generator Building - El . (-)8'-0" "A2" Diesel Fuel Transf er ?umo Vault ADoendix R. Section III.G Summary , The fire protection f eatures provided for the protection and separation of safe shutdown systems within the fire area meet the requirements of 10CFR50, Appendix R, Section III.G. . Quantity Combustible Material None Fire Loading - 0 8tu/sq. ft. Fire Duration - 0.00 hrs. Note 1: An underground diesel fuel storage tank (60,000 gallon capacity) is located underneath the vault. . Fire Protection Eauioment No fire suppression or detection equipment is provided within the area. Fire hydrants located on the yard main art available. , Construction - The area is underground and is located approximately 15 feet west of the radiator area (120) wall. The walls, floor and ceiling are of non-rated construction. - The walls and ceiling of the area are concrete with an < approximate thickness of 12 inches. The floor is concrete with an approximate minimum thickness of 6 inches. Access to' the area is through a non-rated steel hatch door in the ceiling. This door is normally locked and is electrically supervised. A 14 inch diameter core drill covered with a steel plate and a mechanical penetration in the cei. ling are non-rated. Eauipment Reauired for Hot Shutdown Emergency Generator System (EGS70FO) Train A2 Fuel 011: Fuel oil transfer pump P-108A l P-108C l Fuel oil storage tank T-108A Power cable: P-108A P-108C l . Eauioment Reauired for Cold Shutdown None I Hich/ low Pressure Interf ace , None

 .               7/86                                                 OG8-15                                                                             REVISION 4A
   '"                                  *-----w-=           en   -       ._             .e..

I -eh - A 9 g j $ # --- m,- $ -- $ g--m, - - --*r-E -w-e- - - - - wa- *-* - " -ttr---- 'pM$ -----wy-d tw w eg--.- 4 F

FERE AREA 121 Sourious Ooeration None gf fects of Firs on Hot Shutdown Cdoability Emergency Loss of equipment and power cables of train A2 fuel oil

       - Generator         transfer pumps P-108A and P-108C is to be expected. Equipment Systems            and cables for the train B2 diesel generator system are located
                               ~

outside the fire area and will remain available. Effects of Fire on Cold Shutdown Caoability - There are no cables or equipment in the fire area which are required to achieve or maintain cold shutdown only. Effects of Fire on Hicn/ low Pressure Interface There are no cables >or equipment in the fire area which are required to maintain the high/ low pressure interface. . gansecuences of Sourious Operation There are no cables or equipment in the fire area for components whose spurious operation would adversely affec,t safe shutdown. Conclusions -- . The fire protec' tion features provided preclude the propagation of -the fire beyond the boundaries defining the area. Damage resulting from the fire will be limited to one train of systems required for hot shutdown. . Y e l I e OG8-16 REVISION 4A

        ~7/86
   ~ ~
              '^- . ^

                                               - FIRE LSLA: ' f&1 AREA:    4773 sq.ft.              DESCRIPTION: OGB                      "32" RADIATCR FAN AREA VOLUME: N/A                -

COMBUSTI3LIS Cil & Grease 0 gals. Cable C _bs. - Class A 0 'bs. 5 Charcoal 0 lbs. .

           -Plastics                                           0  lbs.

Miscellanecus 0 lbs. DESIGN BASIS FIRE Fire Loading Max. Permissible Leading 0 STU's/sg.ft. 80000 STU s/sq.ft. Fire Duration 0.00 hrs. FIRE.PROTECTICN (AVAILABLE)

           . Suppression (type)                                none Hose stations                                      none, (1) in 106                                    .               '

Portable Extinguishers none, (1) 10B:C in 106 Detectors (type) none . FIRE RESISTANCE RATING WALLS N S E W FLCOR CEILING Actual Rating NR/ NR/ NR/ 3 hr NR/ --- ext ext" - ext grd Penetrations --- --- --- --- --- ---

               - Mechanical                                         ---       ---          ---       ---         ---          ---
               - Electrical-                                                               ---       ---         ---          ---
               - EVAC                                               ---       ---

Fixed Openings -- - --- --- LV -- ' --- Dcors DG-l03/106/NR, DG-107/ ext /NR DG-LO8/ ext /NR

                                                         .___. ,QF.e..___ _ _ _C +*E7J.r3v_ _ _ _          U S.d _, b_nuE SAFE SHUTDCWN SYSTEMS                 .     .         .                                            w. d _ww           .

RCS Instrumentation ____________1.____________i___________1______ Makeup System (SIM/?LS) ____________i.___________ i___________1______ Main Steam System .___________1_____________i___________1______

, -          Steen Generator Instr.                         ____________1___________.._i___________1._____.

Feedwater Sys. - AFW Traih ___________ i_____________1__________.i______ Decay Heat System ____________i____________..i___________i______. Nuclear Cooling Water ____________1_____________1___________;___ ._' Nuclear Raw Water ____________i_____________1___________1______ Essential EVAC (HvS) ___________ i.____________1___________1______ Emergency Generator System &____.32___ .i_____32.____ i__________.i_______

SUMMARY

4.... 32_____i.____32._____1.__________1______i. , MCC OR REDUNDAN7' ELECTRICAL ~ DISTRIBUTION SYSEEQUIE._.___.CIECUTIRY.__S'drIGHGEM_CCM2QUd 4160 V (AC) ....._______1_..__________1._________.i______ 480 V (AC) ____________1____________.1._________.i______ l ____________i_____________1________;._1._____ 120 v (AC) ' ' 125 V (DC) .____________!

SUMMARY

_ +_..__________'______________'___ l ASSCCIATED C*RCUITS' Eigh/Lew Pressure Interface : NC. Spurious operation : NO _ l \ l ( 7/86 - DGB-17 REv!SICN 4A l

F FIRE AREA 122 Location Diesel Generstar Suilding - E1. O'-0" "B2" Raciator Fan Area Aooendix R. Section III.G Summary The fire protection features provided for the protection and separation of -

     - safe shutdown systems within the fire area meet the requirements of 10CFR50, Appendix R, Section III.G.

Combustible Material Quantity

     - None Fire Loading - 0 Stu/sq f t.

~ c Fire Duration - 0.00 hrs Fire Protection Eouioment Manual fire fighting equipment is available in adjacent area 106. No fire suppression or detection equipment is provided within the area. Construction , The fire area consists of the enclosed 9ard area located east of.the diesel generato'r building. The pecimeter of the area is defined by a block wall and the adjoining diesel building wall. The wall adjoining the diesel generator room "B' (106) is of 3 hour rated construction. The block walls are of reinforced masonry approximately 12 inches thick and 18 feet high. The west wall adjoining area 106 js concrete with an approximate thickness of 24 inches. The floor of the area is asphalt on grade. There is no roof over the-area. Access to the area is througn non-rated double doors from the diesel generato'r room (106) . A bulletproof door in the south wall and a large steel double door in the south wall open to the . exterior. The louvered diesel air intake in the west wall to area 106 is not provided with a fire damper. . [ouioment Reouired for Hot Shutdown Emergency Generator Systems (EGS): . Train 82 Cooling Water: OG 82 Radiator E-1048 DG B2 Radiator Fans E-1048-F1 E-1048-F2 E-1048-F3 ' E-1048-F4 E-1048-F5 E-1048-F6

OG8-18 REVISION 4A 7/86 8 ^- a A_

F~

  -                                                       FTRE AREA 122

{quioment Recuired for Hot Shutdown (cont'd) Power Cable: OG 32 Radiator Fans E-1048-F1 E-1048-F2 E-1048-F3 E.-1048-F4 E -1048-F5

                                            .                                 E-1048-F6 Eauioment Reauired for Cold Shutdown None                                                              .
         ~ High/ Low Pressure Interface                       -

None Sourious Ooeration None Effects of Fire on Hot Shutdown Canability Emergency loss of equipment andlower cables for the train 8 diesel Generator generator radiator systed is to be expected. Equipment System and cables for the train-A diesel generator system are located outside the fire aret and will- remain available. Ef fects of Fir's on Cold Shutdown Canability There are no cables or equipment in the fire area which are required to achieve or maintain cold shutdown only. Effects of Fire on High/ low Pressure Interface There are no cables or equipment in the fire area wnica are requireo to maintain the high/ low pressure interface. . Consecuences of Sourious Ooeration

There are no cables or equipment in the fire area for components wnose spurious operation would adversely af fect safe shutdown. e s DG8-19 REVISION 4A 7/86 ,

                                                                                                  ,_a ,   .

Ny_ 6 4 e m W h w W- g e

    *G    .                          m                            9

c' . ense n u esw Sue, AREA: 192 sq.ft. DESCRIPTICN: DGB "32" DIESEL FUEL PUMP VAULT VOLUME: 1347 cu.ft. i

      - CCMBUSTI3LES                       .

Cil & Grease' O gals. Cable 0 .b s .

          ' Class A                                   0  lbs.

Charcoal 0 lbs. Plastics 0 lbs. . Miscellahecus 0 lbs. ! DESIGN SASIS FIRE Fire Loading .ft. Max. Permissible Leading 0 BTU's/sq/sq.ft. 2000 BTU's Fire Duration 0.00 hrs. FIRE PROTECTICN (AVAILABLE) Suppression (type) none Ecse Stations none, fire hydrant en yard main Portable Extinguishers none Detectors (type) none p-t

      ' FIRE RESISTANCE RATING                                           WALLS, N          S                       E   __ __ ___

W FLCCR CEILING Actual Rating NR/ NR/ NR/ NR/ NR/ NR/ grd gri gri grd grd grd Penetrations NR

               - Mechanical                              ---
               - Electrical                                        ---                      ---                  ---            ---          ---
               - HVAC                                    ---

Fixed Openings . - , --- --- --- --- ME Decrs DG-li4/ ext /NR (Access Hatch Door) MCC CR REDUNDANT SAFE SHUTDCWN SYSTEMS . ._ __ EGEZa _ __ _ _ .CIBGEM_ _ _ S'dEC3GEhE.CCHEGUQE2 RCS Instrumentation ____________1___ ._...____1___________1__..__ Makeup System (SIM/PLS) ____________1. ___________1._.._ ____1______ Main Steam System ___ ________1_______....._1.__. ______1._____ Steam Generator Instr. .._________ 1.___________.i. ..____...i______ reedwater Sys. - AFW Train _ .______.._i_____________1___________1______ Decay Heat System ___________.i_____________1___________1______ Nuclear Cccling Water ____________1..___________1.__________;.____. Nuclear Raw Water ___________.1 _....__ ....i___________1...___ Essential HVAC (HVS) ......___...i________ . . 1_ ...______1....__ Emergency Generator System..__.. 32.....i.. __32______1.__________1.______

SUMMARY

                                                +____.32.....'__.._3'______.'__.._______.'_______'

4 CC CH__ ANy ELECTRICAL DISTRIBUTION SYST..E_M__ EQUI 2.._____CI ' M I M ___ ICHG M . ' W. l 4160 V (AC) ____________ ' .________.___*____.... ' 480 V (AC) _____.___.._______________________.._____.._. 120 V (AC) ____________..' ...__... ....______ ' 125 V (DC) . I___....

SUMMARY

                                +.._________.....___..________...._____......__-

i ASSOCIATED CIRCUITS High/Lcw Pressure Interface : NC Spurious Operation : NC ,

                                                                                         ,s                                                                       :

7/86

DGB-20 REVISICN 4A I

  ~ m  mmae_ - , ._              , . - -                            - . - . . . - ~ ~ .

A-m-, ~e,,*m wr

r FIRE AREA 123 . Location Diesel Generator Building - El. (-)8'-0* *B2" Diesel Fuel Transfer Pumo '/ault t Aooendix R. Section III.G Summar/ The fire protection features provided for the protection and separation of safe shutdown systems within the fire area meet the requiremen,ts of 10CFR50, Appendix R, Section III.G. Ouantity Combustible Material None Fire Loading - 0 Stu/sq f t Fire Duration - 0.00 nrs Note 1: An underground diesel fuel storage tank (60,000 gallon capacity) is located underneath the vault. Fire Protection Eouioment . No fire suppression or detection equipment is provided within the area. Construction . The area is underground and is located approximately 15 feet east of the radiator area (122) wall. The walls,. floor and ceiling ,are of non-rated construction. The walls and cei. ling of the area are concrete with an approximate thickness of 12 inches. The floor is concrete with an approximate minimum thickness of 6 inches. Access to the area is through a non-rated steel hatch door in the ceiling. This door is normally locked and is electrically supervised. A 14 inch diameter core drill covered with a steel plate and a mechanical penetration in the ceiling are not fire rated. [ggioment Reouired for Hot' Shutdown

               . Emergency Generator Systems (EGS/0FO):
                       . Train 82 Fuel 011:     Fuel oil transfer pump P-1088 P-1080 Fuel oil storage tank          T-1088 Power cable: P-1088 P-1080 Eouiement Recuired for Cold Shutdown None 7/86                                     0G8-21                         . REVISION.4A i                                                     ..

I . I. . t _

F8RE AREA 123 Hion/ Low Pressure Interface None Sourious.0oeration . None , Effects of Fire on Hot Shutdown Canability . Emergency Loss of equipment and power cables of train B fuel oil transfer Generator pumps P1088 and P1080 is to be expected. Equipment and cables Systems for the train A diesel generator system are located outside the fire area and will remain available. Effects of Fire on Cold Sh'utdown Canability There are no cables or equipment in the fire area which are required to

achieve or mmintain cold shutdown only.

Effects of Fire on Hioh/ Low Pressure interface There are no cables or equipment in the fire area which are required to maintain the high/ low pressure interface. Consecuences of Sourious Goeration . . There are no cables or equipment. in the fire area for components whose spurious operation would adversely af fect safe shutdown. go.nclusions The fire protection features provided preclude the propagation of the fire beyond the boundaries defining the fire area. Damage resulting f rom the fire would be limited to one train of systems required for hot shutdown. l f l OG8-22 REVISION 4A 7/86 "N*N--

             .__ ^N**     - **
                      ^ '           ^  Ok     la

AREA 5785 sq.ft. DESCRIPTICN: OG3 - SUILDING RCCF VOLUMES N/A CCMBUST!3LES

       .Cil & Grease                                         0 gals.

Cable 0 _bs. Class A 0 '_b s . Charecal 0 lbs. 0 lbs. Plastics Miscellanecus 0 lbs. DESIGN BASIS FIRE ' Fire Leading .ft. Max. Permissible Leading 02000 BTU's/sq/sq.ft. BTU's gAre Duration 0.00 hrs. FIRE PROTECTICN (AVAILABLE)

       . Suppression (type)                          .        none                       .

Hose Stations none, (1) in 105 - Portable : Extinguishers none - Detectors (type) - none ' ' 1 FIRE RESISTANCE RA D G WALLS N ..5.. E. ..W FLCCR CIILING Actual Rating - - .

                                                                                   ---       ---      ---         3 hr       ---

Penetrations ~ NR --- Mechanical ---

                                                                                                      ---         NR         ---

Electrical --- --- --- --- NR --- EVAC Fixed openings %e , Doors Hatch . door /105/NR SAFE SHUTDCWN SYSTEMS ..___.,QUI 2 ... _C,.ECU,u:,3v.___SW... N G "M _.. 4 u - RCS Instrumentation' . ..__________1 ____________i___________1 ____. Makeup System (SIM/PLS) ____________1_____________1________;__1. ____ Main Steam System ..._________iL.___________1.__________1 _____

                                                    - .....___....is______......i___________1._____

Steam Generator Instr.

Feedwater Sys. - AFW Train ...________ i___ _________1___________1______

Decay Heat System ___________ 1 _________ ..i._________ i______ Nuclear Ccoling Water . ____._____1_____________1_ ....____.1______ Nuclear Raw Water _______...__i.__.._____...i___ _____..i___... Essenciar EVAC (Hv5) ..__________1.____________1___________1______ Emergency Generator Systemu ____&2.32...i____....__...i.__________1__!..._

SUMMARY

 -                                     +.___&2.32___.'.________..__.'____________'__*_*____'

ELECTRICAL DISTRIBUTION SYSTpj EQUII.______ CIRCUITRY ___ ____________.i...._________ .. ______... 4160 V (AC1 ___ 480 v (AC) ________ ...i.____________1___________1..____ 120 V (AC) .___.__...__.__..____....__.__.______________ 125 V (DC) f..___________'___________..._____

SUMMARY

                                          ...         ________1_____________1___________1_______

ASSOCIATED CIRCUITS High/ Low Pressure Interface : No

Spuricus Operation : No 7/86 DGB-23 REV,ISICN 4A
- - - w A$ 0 -- =_

                                  -~. . - - -
                                                                                                                                        =   &h_

FERE AREA 124 Location Diesel Generator Builcing - El. 34'-6' - Diesel Generator Suitaing Roof Anoendix R. Section III.G Summary The fire protection features provided for the protaction and< separation of - safe shutdown systems within the fire area meet the requirements of 10CFR50, Appendix R Section III.G. , Combustible Material Quantity None Fire Loading - 0 Stu/sq ft Fire Duration - 0.00 hrs Fire Protection Eauinment

      ' Manual fire fighting equipment is available in adjacent area 105.       No fire
       -  suppression or detection equipment is provided within the area.

Construction . The area is the roof of the diesel genefator building. The floor is of 3 hour rated construction. The floor adjoins both diesel generator areas (105 and . 106) and is concrete with an approximate thickness of 27 inches.

                                             ~
         . Access to the area is through a non-rated steel hatch door from the diesel generator 'A' area (105). Ventilation penetrations to the diesel generator areas (105.and 106) are not provided with fire dampers. Electrical and mechanical penetrations to the fire areas below are not fire rated.

Eauinment Reauired for Hot Shutdown Emergency Generator Systems (EGS/0FO) Train A2 Diesel Generator Exhaust Silencer Y-107 A Train 82 Diesel Generator Exhaust Silencer Y-1078 Eauipment Recuired for Cold Shutdown None Hieh/ Low Pressure Interface , None Sourious Ooeration t None OG8-24 REVISION 4A 7/86

FIRE AREA 124 . Effects of Fire on' Hot Shutdown Caoability The diesel generator exnaust silencers Y-107A ane f-1073 are passive mechanical equipment only and will r.emain availaole. Effects of Fire on Cold Shutdown Caoability There are no cables or equipment in the fire area which are required to achieve or maintain cold shutdown only. Effects of Fire on Hioh/ Low Pressure Interface There are no cables or equipment in the fire area which are required to maintain the~high/ low pressure interface. Consecuences of Sourious Goeration There are no cables or equipment in the fire area for components wnose spurious operation would adversely af fect safe shutdown. Conclusions The fire protection features provided preclude the propagation of the fire beyond the boundaries defining the fire area. Damage resulting from a fire would not result in the loss of either train A2 or 82 capability. e e e e 4 7/86 OG8-25 REVISION 4A e

r REFEREN'CES

1. Generic Letter 81-12, Information Neeced for NRC Review of Mooifica:icns .

for Alternative Shutacwn Cacaoility, Feoruary. 20, 1981 anc Aoril 7.1982.

2. Generic Letter 33-33, NRC Positions on Cartain Requirements of 10CFR50, Appencix R. October 19, 1983.

3. IE Notice 84-09, Lessons Learned From NRC Inspections of Fire Protection .

Safe Shutdown Systems, Revision 1. 4 Cable Insulation Fire Loading, Calculation AS.08.2.135, Se~chtel Power Corporation.

5. Fire Protection Handbook, Fifteenth Edition, National Fire Protection

          -        Association, Quincy, MA, 1981.

6. Fire Resistance Directory, Underwriters Laboratory, January 1985.

7. Construction Review, Ca'lculations 142-7-201 taru 142-7-276 Revision 1, July 1985, Impell Corporation.

8. Fire Door Walkdown, Calculation 142-7-358 Revision 1, July 1985, Impe11 Corporation. _

9. Underwriters Laboratory WalkdownIReport No. NC776, 84WK26151.

10. Required Equipment and Instruments Table Listing, Calculation A5.08.2.141, Bechtel Power Corporation.

11. Circuit Analysis, Calculation 142-7-402, Revision 0, May 1985, Impell Corporation.

12. Coordination Study, Calculation A5.08.2.120, Sechtel Power Corporation (Oraf t) .

13.. Common Enclosure, Calculation AS.08.2.121, Becatel Power Corporation (Oraf t) . 14 Maximum Permissible Loading Calculation, Calculation 142-7-108 Revision 1. July 1985, Impe11 Corporation.

15. Hose Station Availability / Coverage, calculation 142-7-102, Revision.1, July 1985, Impe11 Corporation.

        . 16.      Fire Extinguisher Availablity, Calculation 142-7-103, Revision 1, July 1985, Impell Corporation.

7-1 REVISION 4A 7/86

   .. .         =_

17. 32fo 5'iutcown Iauicment Location, Calcuiatica 7 2-7-4C;, tavi,si:n i, ;.*y ,

l 1985, Imo]11 Corporation.

18. Ccmoustiole Summary Calculation, Calculation 142-7-104 Revision *. Ju'/

isos. Imoeil Corcoration.

19. MF8A coce verifiertion, NFPA 10-1981, Por sole Pire Extinguisners. Re:cr-Nc. 01 -0700-1402, Rev. A, Imcell C:r:crati:n.

L.

20. Area / Volume Calculation, Calculation 142-7-101, Revision 1. July 1985, .

Immell Corporation. 21 . 45ES Cable Calculation, Calculatten 142-7-106, Revision 0, May 1985, Empe11 Corporation.

22. Main Steam Isolation Calculation, Calculation 142-7-404, Revision 0, May 0 1985, Impell Corporation. '

p ' 23!. Area / Volume Calculation I-789-M18al , Rev. 2, April,.1986.

23. ECN Review, Calculation 142-7-106, Revision 0, May 1985, Imnell .

             ' Corporation.

25. FHAR Upgrade Puncalist, Calculation 142-7-107 Revision 1 July 1985, Lapell Corporation. . ,, ,

26. FMAR Walkdown Calculations Calculations 142-7-301 through 142-7-357, Revision 1, July 1985, Espell Corporation.

27. Non-Rated Per.etration/8arrier Analysis, C"alculation 142-7-109 Revision T, September 1985, Impe11 Corporation.

28. Containment Su11 ding Penetration Evaluation, Calculation 145-070 Revision 0, Sectemoer 1985, Impe11 Corcoration.

29. Diesel Generator Building - Cable Insulation Fire Leading - Calculation No. L-FPP-M1926, Rev. O, April 1986. . .

30. Diesel Generator Building - Comoustibles Summar/ - Calculation No.

I-FPP-M1921, Rev. O, April 1986. 11 . Diesel Generator Building - Fire Extinguisher Ava.ilability - Calculation No. I-FPP,41922, Rev. O. April T986.

32. Diesel Generator 8uilding - Hose Station AvaiTability - Calculation No.

I-FPP-M1923, Rev. O, April 1986. .

33. Diesel Generator auilding - Maximum permissible Fire loading -

Calculation No I-FPP-M1924 Rev. O. April 1986.

34. Diesel Generator Building - Walkdowns - Calculation No. Z-FPP-M1925. Rev. ,

j 0, April 1986.

35. Diesel Generator Buildin9 - Construction Review - Calculation No.

I-FPP-M1837, Rev. O. April 1986. 7/86 7-2 REVISION 4A w-hN-*#* '

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Enclosure 8 Drawings for Diesel Generator

;IST OF DRAWINGS FOR D.G. LICENSING SUBMITTAL Drawing No. .tev . Title A-262 6 Diesel Generator Bldg. Grade Level Plan at El. O'0" A-263 5 Diesel Generator Bldg. Mezzanine Level Plan at El .18'6" A-264 7 Diesel Generator Bldg. Roof Plan and Details A-265 1 Diesel Generator Bldg. Exterior Elevations A-266 5 Diesel Generator Bldg. Building Sections A-267 7 Diesel Generator Bldg. Finish and Door Schedules and Details A-268 5 Diesel Generator Bldg. Door Plan and System Schedule A-269 4 Diesel Generator Bldg. Site Plan C-757, Sht.15 6 Diesel Generator Bldg. Finish Grading and Paving Plan C-757, Sht. 20 4 Diesel Generator Bldg. Concrete Outline Plan at El. O'0" C-757, Sht. 21 5 Diesel Generator Bldg. Concrete Outline Plan at El .18'6" C-757 Sht. 22 4 Diesel Generator Bldg. Concrete Outline Plan at El. 34'0" E-601, Sht. 2 1 Station Grounding E-857, Sht. 1 1 Diesel Generator Bldg. - Lighting and Communication Plan El. O'0" E-857, Sht. 2 5 Diesel Generator Bldg. - Lighting and Communication Plan El. 18'6" E-857, Sht. 3 5 Diesel Generator Bldg. Lighting and Communication Plan El 34'6" E-857, Sht. 6 6 Lighting and Communication Plan Radiator Yard Area I-208, Sht. 1 2 Control Logic Diagram Diesel Generator Radiator Fans I-208, Sht. 2 1 Control Logic Diagram Diesel Generator System Lube 011 Keepwarm Pumps 1

Drawina No. Rev. Title I-208, Sht. 3 1 Control Logic Diagram Diesel Generator System

                                 .lacket Water Keepwarm Pumps I'      I-1086             3      Control Logic Diagram New Diesel Fuel Oil

System Alarms I-1111 3 Control Logic Diagram Diesel Generator 81dg.

HVAC Building Exhaust Fans I-1112 3 Control Logic Diagram Diesel Generator Bldg. HVAC Essential Control Room AHV l 'I-1114 3 Control Logic Diagram Diesel Generator Bldg. HVAC Normal AHU M-505 7 P&I Diagram Diesel Generator Bldg. HVAC Systems M-547. Sht. 1 7 P&I Diagram New Diesel Fuel Oil Systems t M-585, Sht. 1 0 P&I Diagram Diesel Generator System-Train "A" M-585, Sht. 2 0 P&I Diagram Diesel Generator System-Train "A"

   . M-585, Sht. 3              P&I Diagram Diesel Generator System-Train "B" i

M-585, Sht. 4 P&I Diagram Diesel Generator System-Train "B" M-594, Sht. 2 5 P&I Diagram NSEB, TSC and Diesel Generator

B1dg. Fire Protection Water System M-923 Sht. 1 4 Diesel Generator Bldg. Equipment Location Plan at Grade 4

l M-923, Sht. 2 4 Diesel Generator Bldg. Equipment Location Plan at Mezzanine M-923. Sht. 3 4 Diesel Generator Bldg. Equipment Location Plan j at E1. 34'6" l M-923, Sht. 3 4 Diesel Generator Bldg. Equipment Location j Section "A" M-923, Sht. 4 4 Diesel Generator Bldg. Equipment Location Section "B" f M-923, Sht. 5 4 Diesel Generator Bldg. Equipment Location Section "C" M-923. Sht. 6 5 Diesel Generator Bldg. Equipment Location i East Radiator Plan at Grade l l

m ; Drawing No. Rev. Title M-923. Sht. 7 3 Diesel Generator Bldg. Equipment Location East Radiator Section D M-923, Sht. B 3 Diesel Generator Bldg. Equipment Location West Radiator Plant at Grade M-923, Sht. 9 3 Diesel Generator Bldg. Equipment Location West Radiator Plant "E" H-923, Sht.10 3 Diesel Generator Bldg. Equipment Location East Diesel Fuel Tank Plan at Grade M-923, Sht. 11 3 Diesel Generator Bldg. Equipment Location West Diesel Fuel Tank Plan at Grade M-923, Sht. 13 3 Diesel Generator Bldg. Equipment Location West Diesel Fuel Tank Plan at Grade M17. 02.1 -10 7 Exhaust Intake and Crank Case Vacuum Piping M17.02.1-11 B Jacket Water Piping Schematic M17.02.1 -12 9 Lube Oil Piping Schematic M17.02.1 -l l 5 6 Installation Drawing for Diesel Generator.r M17.02.1 -48 5 170 AC Generator (outline) M17.06-32 4 General Arrangement (Radiators) M17.06-33 4 General Arrangement (Radiators) M31.07A-2 11 Fire Detection Diesel Generator Bldg., Sheet 1 M31.07A-3 13 Fire Detection Diesel Generator Bldg., Sheet 2 H.31-07A-62 11 Diesel Generator Bldg. Pre-Action Sprinkler System E-327, Sht.23 0 Wiring Diagram DG Fire Protection System SK-E132-1 0 Main One Line Diagram SK-E132-2 0 One Line Diagram 125Vdc and 120Vac Distribution System SK-E132-3 0 One Line Diagram Diesel Generators GEA2 and GEB2 4

OVERSIZE DOCUMENT PAGE PULLED SEE APERTURE CARDS NUMBER OF OVERSIZE PAGES FILMED ON APERTURE CARDS b en APERTURE CARD /HARD COPY AVAILABLE FROM RECORD SERVICES BRANCH,TIDC FTS 492-8989 t l l l

Enclosure 9 Response to NRC Question from November 25, 1986 Conference Call

1. NRC Question: Soil Bearing Allowables - What is the basis for using 8 KSF for static loads and 16 KSF for transient loads of short durations?

District Response: A separate DG building soil report was done. Attachment "A" includes the requested sheets of calculation -DGB-C0125. Sheet 5 lists the design soil pressures considered. t

2. NRC Question: Cable Tray 154 Damping - Why is it higher than R.G. 1.617 ,

District Response: R.G. 1.61 allows higher values if supported by test data. The ANCO Engineer'Is Test results apply to the diesel generator building (DGB) based on the followings a) Same cable that was used (Husky-Burndy Through Tray). b) Bolted unistrut supports were used in the test and DGB. c) DGB cable tray system frequency ranges are within the test frequency ranges.

3. NRC Question: Ductility Ratios - Were they considered?

District Response: The DBR in Section III, 48, page 41 states: " Ductility ratios for shear were not considered in the design. Flexural response governed missile impact design."

4. NRC Question: HVAC Damping - Were the same damping values used for both duct work and supports?

District Response Calculation Z-DGB-C0132 does include ductwork calculations. For the main ductwork, damping values of 4% and 7% were used since the transverse joints are bolted (Bechtel design guide C 2.39, Section 6.0, Seismic Analysis). For some miscellaneous portions of the HVAC system where transverse joints were welded, damping values of 2% and 44 were used. 1

5. NRC Question: Static Analysis Coefficients -Why was H = 1.0 and V = 0.4 used in lieu of R.G.?

District Response Attachment "B" includes Appendix J of BC-TOP-4, Revision 4 which demonstrates the component factor method is more conservative than the combined response by the SRSS method. Appendix J is an addition to the guide which was not submitted to the NRC for general approval. However, the methodology in Appendix J has the NRC's acceptance on the following projects: a) Arizona Nuclear Power Plant (ANPP) b) San Onofre, Units 2 and 3 (SONGS) c) South Texas Project (STP) d) Vogtle Nuclear Plant

6. NRC Question: Tornado Criteria - Were vertical missiles considered?

District Responses Attachment "C" includes a copy of the requested Diesel Generator Building'is Tornado PRA. 2

ATTACHMENT A CALCULATION COVER SHEET , c - 663 -7 4235E7J,if5 arCT T2ANct10 s I:rd N U CL. STATIOQO. NO. I'2 2,3 4 -659 ,NE,1 1 0, 64

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    ,,                                                                                                    . _ _ _ . _ _ _                  u 29 BASEt^4A T                   Pfo pER TIES 31

. y "' Fleea = '9 2 x 6 9 = 6 m 1 ".' ,

             $2chen IYIcdulu 5 ab:uiY- Y a.vi = 5 bd' = 5 " 9E

b4 ~ 131 .

S~ec hon /Vio duIvs oi: cut X- X a x is = g b d ' = g x69 < m = 99+6 q ',. n su J

     /'T'1                       CALCULATION CHEET L     'O                                                                 CALC. NO. C E9~7 S NATURE              NM          DATE  b /C       !    CHECKED

b" DATE ! 8#

PROJECT bbllS0' 5 CD blUll* SI I* JOB No. 0 N~b50 Su: JECT M/ESEL GENEP4 TOE BL D G, SHEET 3 or 44 SHEETS BAS &rn A T 1

  '                          BASEMAT             LoeOS (reference calc no. C659-4)

B+al Dead Load = @e.35 +to3.ae +a96 bo]<3a.a

  *                                            =
                                                   /6667*

7

Tc+al L;ve Load = C i.u 7 + a.o e t e. gGx + 13a. p

'                                            =     /553*

11 l2 SSE Oes 14

"                                    IK                                    IW y              E n o = li k o 6 9                       Enc = 59,131

[ horizon tc< l ove <+arnir,c) n,oment due +c earacpokei 18 Ev = 5Bos" E'v == 3c73" 21 (verkcal ear # 9uake {o ec e) 22

*'                                lo o din a      Ccn oina / ions      /$nd     l o a d Fa^r k s

[O SP {0r,$ide r e$ 2s 20

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14,

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4 /

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PROJECT FHCHO SE C O NUC L . STA T. sog no. M3 W -6 % SUBJECT O/E S E L G EA/ EPA 70P ML DG. SHEET 4 op 44 SHEETS EasEra r UNPACTORED OSE SO!L PRESSURES Coll PRESSURES (kSF) 166,e 7 , (L) D. L. Pr e ssu re = w xd : B.60 KSF l t IJ vJ.60 5 6 1553 1. g + (i.i) L.L. Pressure = e x e9 = . a y- kS F , . T (iii.) . u- x Ev = . + x MD = .19 k S F p.l9 12 ( Eso = (59.ta l73t96 +*

29181\99'F6'i,* $0* N l.04 W liv) 7, O+

    ),, .
      "                                                                 Al.qq
                                                              >                                 w a 40 + .a+ +.(9 + i.o A= 't.07 Tobe l = f a. 6 0 + . 34- +.19-I.0                I        4) = l . f'O   2,99 21 l      12 l

23 l 2< 25 26 21 i j 28 29 30 l 31 32 33 35 e .

                                 )                                         )                          me .. n .. n s                             CALCULATION CHEET d                                                                                cal C. NO. d b 9 ~7 SIGNATURE       A      I           DATE        ;
                                                      /O ;  !      CHECKED         b  DATE PROJECT    RANCHO'SECO AIUCL . 5 TA T.                          sob NO. /535 $ -S59 SUBJECT   b/bbEb b NEkA70k Obob.                               SHEET       5   OF  44       SHEETS BASEM A T 1

UNFACTo2ED SSE Soll P PE SSURE S SctL PRESSURES (KSF) x c

  *       (d    D.L. Pressure        =       /66xsg ga     21 = a 60 ksP                             :.a w 5
                                            /553 lii)   L. L . Prescu<e = 93xia = M k$F                                  ,              , L .gy.
  .                                                                                               T (Lu)   4 x Ev =           -q3    9    =.36 tsF                         ,

3r.% 12 (i v) Euo (l.O Eno olvuf Y-Yaxic + . y Eno ;_q, abouf X- K a xis ) TW 3

 "                   =    //Q 069 , . ex / /B069 = l. 97 kS F                          N1/97 73796            4 9 u-6 4 1.a31 To 4a I = Ca 60 + . a4 + .364 I 9 7] = 5.17 WSF             T                        g,g g
 "                                                                                               x
                       = Ca. b o + . a q + . 3(, - I. 9 7] =I A 3 ksF 20
   '                                                                        SOIL PRESSURES [KSF]

FACTORE O O6E* Soll PR ESSUEES n .. (i) D. L. P< essure = 1. + x a.60 = 3. 64 ks F l3. GH-24

4l KSF (h) L. L . Pr e s s u re = l.'7 x 94 = \ q .gf (lii) 4 x l.9 x Ev = . 4 x't.9x q?lsq = 4 kSF , , t .36 i.q1 (tv) I.9 Eno= l.9 59. t 3 I y . u. x 59, \ ;;I =I.97 K5F --

73796 99+(a+ 2, \xLIU To tal = [ 3.6 + + + I + 3G + I 9 '1]= 6.3 B ks F R"+ .. 1

                         = [3.64 +. u l t % -1 97] = 2.+RSF                                            ,3g a
                     ' CY fA

ATTActMENT B BC-TOP-4 Rav. 4

 /                                       Appendix J VALIDITY OF THE COMPONENT FACTOR METHOD          ,

(New Addition to Rev. 4) This appendix presents a demonstration of the adequacy of the component factor method expressed by Eq. (4-7a). First, consider a combined response, R' defined as follows: R' = Rg + 0.414R3 + 0.318Rk I#~1) in which Rg1R$ 1Rk 10 (J-2) Let ( R 3 = K) + R k IKj = 0 if R$=R) k Rg=Eg+R$=Eg+K3+Rk (i= fRg = R)) (J-3) According to Eq. (4-7), the SRSS method gives: i 2 2 2 1/2 R = ((R1+K3+RI k *I j+R) k +RI k 2 2 2 1/2

               = {3Rk+2R3+Kg + 2Kg (R) + Rk) + 4Kjk           R)         (J-4) i 1

l s J-1 l t . >

                       ~
                                              .                    BC-TOP-4
   .                                                               Rsv. 4 According to Eq. (J-1),

R' = (Ri+R$+Rk) + 0.414(E 3 + Rk) + 0.318Rk R' = 1.732Rk

1*414 j*Hi = { [1.732Rk + 1.414R3 + Rg ]2}

2 2 2 1/2 R' = (3Rk+2E3+Kg + 2Rg (1.414E3 + 1.732R k I

4*9 j Rk} (J-5)

Comparing Eqs. (J-4) and (J-5), it is obvious that the combined response calculated according to Eq. (J-1) is always more conservative than the combined response by the SRSS method. In the special case that Rg=R.=R,k they become identical to each other, i.e., R = R' = R k' For convenience of engineering applications, Eq. (J-1) can be ' simplified by replacing the factors 0.414 and 0.318 by a common factor of 0.4. This reduces Eq. (J-1) to Eq. (4-7a). I By inspection, the maximum probable error of Eq. (4-7a) with respect to the SRSS method is less than 1%. This maximum error occurs when Rk = 0 and Rg=R. In this special case, the SRSS method gives R = 1.41R g and Eq. (4-7a) gives R = 1.4R g. l l l J-2

ATTACHMENT C

         '~') OMUD                                          CALCULATION COVER SHEET SACRAMENTO MUNICIPAL UTILITY DISTRICT O 6201SStreet.P.O. Box 15830.SacramentoCA 95852-1830(9161452-3211 Nt                LSe_l:%M                 h L_TN Ma        h6 '

hc..ree w ed CRA-rysNow % e: - Z-tc.s -cces2 FILE NO. QUALITY CLASS SEISMtC CATEGORY SMFFT l CF .5'b K/A RECORD OF ORIGINAL ISSUE AND REVISIONS SMUD ORIGINATED CALCS N LEAR " C(p E R NO' REVISION DESCRIPTION DATE ORIG. CKR. fEV W DE SE o b n Fre_ % % ecs A TVS RESULTS OF CHECKER REVIEW REVISION NO. ITEM DESCRIPTION ISSUE FINAL RESULT NUMERICAL DIFFERENCES ARE NOT i gyg SIGNIFICANT: NO CORRECTIONS NECESSARY. INITIAL jjo FINAL RESULT NUMERICAL DIFFtRENCES ARE INITIAL { SIGNIFICANT NECESSARY CORRECTIONS ARE MADE. CHECK MADE BY ATTACHED ALTERNATE INITIAL l CALCULATIONS. SHEETS DATE i l l l C ORIGINATOR lQ gg;g CHECKER gQgpy, T M Wg Q g { ,gygL , l [][3/ggn

~ #

SUPVY. REVIEW fg $ gg i PR'INTED 5AME SIGNATURE ' I INITIAL i DISCIPLINE I D ATE SYUD-1418 6 85 J

CALCULATION SHEET

             $SMUD           SACRAMENTO MUNICIPAL UTILTTY DISTRICT O 6201SStreet,P.O. Box 15830.SecrementoCA9585218301916) 452-3211 o

ORIGINATO MA D - DATE b l 9 b CALC.NO. *-- b bb SUBJECT Wi- N6 bRh0CS h CHECKED b MCTT N W AL1 ;

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                                                 .D STONE C DE8 STER ENGINEERING COEPOR TlON a                                              !

C4LCULATION TITLE PAGE l

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APP ROVA LS - S IGN ATUR E E D ATE ' REV.NO. SUPERSEDES CON FIRM ATION INDEPENDENT OR NEW
CALC. NO.
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v t e Letter Sequence Other
TAC:63030, (Approved, Closed)
Initiation Request, Request, Request, Request, Request, Request, Request, Request, Request, Request Acceptance... Supplement, Supplement, Supplement, Supplement Administration Meeting Questions Answers Results Approval, Approval, Approval, Approval, Approval, Approval Other: A11745, Evaluation of DSR-48 Emergency Diesel Generator Crankshafts at Rancho Seco Nuclear Generating Station, ML20126J866, ML20126J973, ML20135E867, ML20149D631, ML20149F003, ML20196E677, ML20196E697, ML20206H162, ML20212B420, ML20214K863, ML20215G661, ML20234C529, ML20234C558, ML20234D524, ML20234D615, ML20234D649, ML20235M565, ML20235Q511, ML20236L543, ML20236N639, ML20236N713, ML20236S088, ML20237B265, ML20237B279
MONTHYEAR1987-12-29 [Table View]

ML20212B420

Text

SUMMARY

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SUMMARY

1.0 INTRODUCTION

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SUMMARY

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SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

SUMMARY

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