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Technical Specification Bases Unit 1 Manual
	ML052910067
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Site:	Susquehanna
Issue date:	10/06/2005
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Oct. 06, 2005 Page 1 of 2 MANUAL HARD COPY DISTRIBUTION DOCUMENT TRANSMITTAL 2005-43208 USER INFORMATAN:

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TO: "-' y.. ww - f 10/06/2005 LOCATION: USNRC FROM: NUCLEAR RECORDS DOCUMENT CONTROL CENTER (NUCSA-2)

THE FOLLOWING CHANGES HAVE OCCURRED TO THE HARDCOPY OR ELECTRONIC MANUAL ASSIGNED TO YOU:

TSB1 - TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL REMOVE MANUAL TABLE OF CONTENTS DATE: 09/27/2005 ADD MANUAL TABLE OF CONTENTS DATE: 10/05/2005 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT 3.6.1.5 REMOVE: REV:0 ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT 3.6.4.1 REMOVE: REV:2

Oct. 06, 2005 Page 2 of 2 ADD: REV: 3 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT 3.8.1 REMOVE: REV:2 ADD: REV: 3 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT 3.8.7 REMOVE: REV:0 ADD: REV: 1 CATEGORY: DOCUMENTS TYPE: TSB1 ID: TEXT LOES REMOVE: REV:63 ADD: REV: 64 UPDATES FOR HARD COPY MANUALS WILL BE DISTRIBUTED WITHIN 5 DAYS IN ACCORDANCE WITH DEPARTMENT PROCEDURES. PLEASE MAKE ALL CHANGES AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX UPON RECEIPT OF HARD COPY. FOR ELECTRONIC MANUAL USERS, ELECTRONICALLY REVIEW THE APPROPRIATE DOCUMENTS AND ACKNOWLEDGE COMPLETE IN YOUR NIMS INBOX.

SSES MANUAL t Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL Table Of Contents Issue Date: 10/05/2005 Procedure Name Rev Issue Date Change ID Change Number TEXT LOES 64 10/05/2005

Title:

LIST OF EFFECTIVE SECTIONS TEXT TOC 7 04/18/2005

Title:

TABLE OF CONTENTS TEXT 2.1.1 1 04/27/2004

Title:

SAFETY LIMITS (SLS) REACTOR CORE SLS TEXT 2.1.2 0 11/15/2002

Title:

SAFETY LIMITS (SLS) REACTOR COOLANT SYSTEM (RCS) PRESSURE SL TEXT 3.0 1 04/18/2005

Title:

LIMITING CONDITION FOR OPERATIO,,,O, -(LCO)'APPLICABILITY TEXT 3.1.1 0 11 2

Title:

REACTIVITY CONTROL SYSTEMS SHUT!Y N MARGIN (SDM)

TEXT 3.1.2 01 11/15/2002 -

Title:

REACTIVITY CONTROL SYSTEMS REACTIVITY ANOMALIES TEXT 3.1.3 .. 1IIL 1 07/06/2005

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD OPERABILITY TEXT 3.1.4 1 07/06/2005

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM TIMES TEXT 3.1.5 1 07/06/2005

Title:

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS TEXT 3.1.6 1 02/17/2005

Title:

REACTIVITY CONTROL SYSTEMS ROD PATTERN CONTROL Pagel~~~.. of 8.eotDt:1/50 Page 1 of 8 Report Date: 10/05/05

lo-SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.1.7 1 08/30/2005

Title:

REACTIVITY CONTROL SYSTEMS STANDBY LIQUID CONTROL (SLC) SYSTEM TEXT 3.1.8 0 11/15/2002

Title:

REACTIVITY CONTROL SYSTEMS SCRAM DISCHARGE VOLUME (SDV) VENT AND DRAIN VALVES TEXT 3.2.1 0 11/15/2002

Title:

POWER DISTRIBUTION LIMITS AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

TEXT 3.2.2 0 11/15/2002

Title:

POWER DISTRIBUTION LIMITS MINIMUM CRITICAL POWER RATIO (MCPR)

TEXT 3.2.3 0 11/15/2002

Title:

POWER DISTRIBUTION LIMITS LINEAR HEAT GENERATION RATE (LHGR)

TEXT 3.2.4 1 07/06/2005

Title:

POWER DISTRIBUTION LIMITS AVERAGE POWER RANGE MONITOR (APRM) GAIN AND SETPOINTS -

TEXT 3.3.1.1 .2 07/06/2005

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) INSTRUMENTATION TEXT 3.3.1.2 0 11/15/2002

Title:

INSTRUMENTATION SOURCE RANGE MONITOR (SRM) INSTRUMENTATION TEXT 3.3.1.3 0 11/22/2004

Title:

OPRM INSTRUMENTATION TEXT 3.3.2.1 1 02/17/2005

Title:

INSTRUMENTATION CONTROL ROD BLOCK INSTRUMENTATION TEXT 3.3.2.2 0 11/15/2002

Title:

INSTRUMENTATION FEEDWATER - MAIN TURBINE HIGH WATER LEVEL TRIP INSTRUMENTATION TEXT 3.3.3.1 2 07/06/2005

Title:

INSTRUMENTATION POST ACCIDENT MONITORING (PAM) INSTRUMENTATION Report Date: 10/05/05 Page 2 Page 2 of of 8 8 Report Date: 10/05/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.3.3.2 1 04/18/2005

Title:

INSTRUMENTATION REMOTE SHUTDOWN SYSTEM TEXT 3.3.4.1 0 11/15/2002

Title:

INSTRUMENTATION END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT) INSTRUMENTATION TEXT 3.3.4.2 0 11/15/2002

Title:

INSTRUMENTATION ANTICIPATED TRANSIENT WITHOUT SCRAM RECIRCULATION PUMP TRIP (ATWS-RPT) INSTRUMENTATION TEXT 3.3.5.1 2 07/06/2005

Title:

INSTRUMENTATION EMERGENCY CORE COOLING SYSTEM (ECCS) INSTRUMENTATION TEXT 3.3.5.2 0 11/15/2002

Title:

INSTRUMENTATION REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM INSTRUMENTATION TEXT 3.3.6.1 1 11/09/2004

Title:

INSTRUMENTATION PRIMARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.6.2 . 1 11/09/2004

Title:

INSTRUMENTATION SECONDARY CONTAINMENT ISOLATION INSTRUMENTATION TEXT 3.3.7.1 0 11/15/2002

Title:

INSTRUMENTATION CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM INSTRUMENTATION TEXT 3.3.8.1 1 09/02/2004

Title:

INSTRUMENTATION LOSS OF POWER (LOP) INSTRUMENTATION TEXT 3.3.8.2 0 11/15/2002

Title:

INSTRUMENTATION REACTOR PROTECTION SYSTEM (RPS) ELECTRIC POWER MONITORING TEXT 3.4.1 2 11/22/2004

Title:

REACTOR COOLANT SYSTEM (RCS) RECIRCULATION LOOPS OPERATING TEXT 3.4.2 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) JET PUMPS Report Date: 10/05/05 Page33 Page of of 8 8 Report Date: 10/05/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL 9'

TEXT 3.4.3 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) SAFETY/RELIEF VALVES (S/RVS)

TEXT 3.4.4 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS OPERATIONAL LEAKAGE TEXT 3.4.5 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE ISOLATION VALVE (PIV) LEAKAGE TEXT 3.4.6 1 04/18/2005

Title:

REACTOR COOLANT SYSTEM (RCS) RCS LEAKAGE DETECTION INSTRUMENTATION TEXT 3.4.7 1 04/18/2005

Title:

REACTOR COOLANT SYSTEM (RCS) RCS SPECIFIC ACTIVITY TEXT 3.4.8 1 04/18/2005 I

Title:

REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM -

- HOT SHUTDOWN - -

TEXT 3.4.9 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RESIDUAL HEAT REMOVAL (RHR) SHUTDOWN COOLING SYSTEM

- COLD SHUTDOWN TEXT 3.4.10 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) RCS PRESSURE AND TEMPERATURE. (P/T) LIMITS TEXT 3.4.11 0 11/15/2002

Title:

REACTOR COOLANT SYSTEM (RCS) REACTOR STEAM DOME PRESSURE TEXT 3.5.1 1 04/18/2005

Title:

EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ECCS - OPERATING TEXT 3.5.2 0 11/15/2002

Title:

EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ECCS - SHUTDOWN TEXT 3.5.3 1 04/18/2005

Title:

EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM RCIC SYSTEM Report Date: 10/05/05 Page44 Page of of 8 8 Report Date: 10/05/05

I SSES MANUAL

- Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.6.1.1 0 11/15/2 002

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT TEXT 3.6.1.2 0 11/15/2002

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCK TEXT 3.6.1.3 2 08/24/2005

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT ISOLATION VALVES (PCIVS)

TEXT 3.6.1.4 0 11/15/2002

Title:

CONTAINMENT SYSTEMS CONTAINMENT PRESSURE TEXT 3.6.1.5 1 10/05/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR TEMPERATURE TEXT 3.6.1.6 0 11/15/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION CHAMBER-TO-DRYWELL VACUUM BREAKERS TEXT 3.6.2.1 0 11/15/2002 -

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL AVERAGE TEMPERATURE TEXT 3.6.2.2 0 11/15/2002

Title:

CONTAINMENT SYSTEMS SUPPRESSION POOL WATER LEVEL .

TEXT 3.6.2.3 0 11/15/2002

Title:

CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL COOLING TEXT 3.6.2.4 0 11/15/2002

Title:

CONTAINMENT SYSTEMS RESIDUAL HEAT REMOVAL (RHR) SUPPRESSION POOL SPRAY TEXT 3.6.3.1 1 04/18/2005

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT HYDROGEN RECOMBINERS TEXT 3.6.3.2 1 04/18/2005

Title:

CONTAINMENT SYSTEMS DRYWELL AIR FLOW SYSTEM Report Date: 10/05/05 Pages5 Page of of 8 8 Report Date: 10/05/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL Jy TEXT 3.6.3.3 0 11/15/2002

Title:

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT OXYGEN CONCENTRATION TEXT 3.6.4.1 3 10/05/2005

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT TEXT 3.6.4.2 2 01/03/2005

Title:

CONTAINMENT SYSTEMS SECONDARY CONTAINMENT ISOLATION VALVES (SCIVS)

TEXT 3.6.4.3 2 11/09/2004

Title:

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT (SGT) SYSTEM TEXT 3.7.1 0 11/15/2002 -

Title:

PLANT SYSTENIS RESIDUAL HEAT REMOVAL SERVICE WATER (RHRSW) SYSTEM AND THE ULTIMATE HEA.T SINK (UHS)

TEXT 3.7.2 1 11/09/2004

Title:

PLANT SYSTEMS EMERGENCY SERVICE WATER (ESW) SYSTEM TEXT 3.7.3 0 11/15/2002

Title:

PLANT SYSTEMS CONTROL ROOM EMERGENCY OUTSIDE AIR SUPPLY (CREOAS) SYSTEM TEXT 3.7.4 0 11/15/2002

Title:

PLANT SYSTEMS CONTROL ROOM FLOOR COOLING SYSTEM TEXT 3.7.5 0 11/15/2002

Title:

PLANT SYSTEMS MAIN CONDENSER OFFGAS TEXT 3.7.6 1 01/17/2005

Title:

PLANT SYSTEMS MAIN TURBINE BYPASS SYSTEM TEXT 3.7.7 0 11/15/2002

Title:

PLANT SYSTEMS SPENT FUEL STORAGE POOL WATER LEVEL TEXT 3.8.1 3 10/05/2005

Title:

ELECTRICAL POWER SYSTEMS AC SOURCES - OPERATING Report Date: 10/05/05 6

Page 6 of of 88 Report Date: 10/05/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.8.2 0 11/15/2002

Title:

ELECTRICAL POWER SYST'EMS AC SOURCES - SHUTDOWN TEXT 3.8.3 0 11/15/2002

Title:

ELECTRICAL POWER SYST'EMS DIESEL FUEL OIL, LUBE OIL, AND STARTING AIR TEXT 3.8.4 0 11/15/2002

Title:

ELECTRICAL POWER SYST'EMS DC SOURCES - OPERATING TEXT 3.8.5 0 11/15/2002

Title:

ELECTRICAL POWER SYST'EMS DC SOURCES - SHUTDOWN TEXT 3.8.6 0 11/15/2002

Title:

ELECTRICAL POWER SYSI'EMS BATTERY CELL PARAMETERS TEXT 3.8.7 1 10/05/2005

Title:

ELECTRICAL POWER SYSI'EMS DISTRIBUTION SYSTEMS - OPERATING TEXT 3.8.8 0 11/15/2002

Title:

ELECTRICAL POWER SYSI'EMS DISTRIBUTION SYSTEMS - SHUTDOWN TEXT 3.9.1 0 11/15/2002

Title:

REFUELING DPERATIONS REFUELING EQUIPMENT INTERLOCKS TEXT 3.9.2 0 11/15/2002

Title:

REFUELING OPERATIONS REFUEL POSITION ONE-ROD-OUT INTERLOCK TEXT 3.9.3 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION TEXT 3.9.4 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD POSITION INDICATION TEXT 3.9.5 0 11/15/2002

Title:

REFUELING OPERATIONS CONTROL ROD OPERABILITY - REFUELING Report Date: 10/05/05 Page77 Page of of 88 Report Date: 10/05/05

SSES MANUAL Manual Name: TSB1 Manual

Title:

TECHNICAL SPECIFICATION BASES UNIT 1 MANUAL TEXT 3.9.6 0 11/15/2002

Title:

REFUELING OPERATIONS REACTOR PRESSURE VESSEL (RPV) WATER LEVEL TEXT 3.9.7 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - HIGH WATER LEVEL TEXT 3.9.8 0 11/15/2002

Title:

REFUELING OPERATIONS RESIDUAL HEAT REMOVAL (RHR) - LOW WATER LEVEL TEXT 3.10.1 0 11/15/2002

Title:

SPECIAL OPERATIONS INSERVICE LEAK AND HYDROSTATIC TESTING OPERATION TEXT 3.10.2 0 11/15/2002

Title:

SPECIAL OPERATIONS REACTOR MODE SWITCH INTERLOCK TESTING TEXT 3.10.3 0 11/15/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - HOT SHUTDOWN TEXT 3.10.4 .0 11/15/2002 -

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD WITHDRAWAL - COLD SHUTDOWN TEXT 3.10.5 0 11/15/2002

Title:

SPECIAL OPERATIONS SINGLE CONTROL ROD DRIVE (CRD) REMOVAJL - REFUELING TEXT 3.10.6 0 11/15/2002

Title:

SPECIAL OPERATIONS MULTIPLE CONTROL ROD WITHDRAWAL - REFUELING TEXT 3.10.7 O 11/15/2002

Title:

SPECIAL OPERATIONS CONTROL ROD TESTING - OPERATING TEXT 3.10.8 0 11/15/2002

Title:

SPECIAL OPERATIONS SHUTDOWN MARGIN (SDM) TEST - REFUELING Report Date: 10/05/05 Page 8 of 8 8 Report Date: 10/05/05

SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

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- Page TS I B 2.0-2 2 PageTS/B2.0-3 3 Pages TS/ B 2.0-4 and TS I B 2.0-5 2 Page TS/B 2.0-6 I Pages B 2.0-7 through B 2.0-9 0 B 3.0 LCO AND SR APPLICABILITY BASES Pages B 3.0-1 through B 3.0-4 Pages TS / B 3.0-5 through TS I B 3.0-7 Pages TS / B 3.0-8 through TS I B 3.0-9 Pages TS / B 3.0-10 through TS I B 3.0-12 i 2 Pages TS I B 3.0-13 through TS I B 3.0-15 Pages TS I B 3.0-16 and TS / B 3.0-17 1

B 3.1 REACTIVITY CONTROL BASES 0 Pages B 3.1-1 through B 3.1-5

, I Pages TS / B 3.1-6 and TS I B3I1-7

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'IMWF ags' B'3.1-15 through B 3.-2~2- 0 Page TSI B 3.1-23 1 Pages B 3.1-24 throu'gh B 3.127 2 Page TS I B 3.1-28 I Page TS I B 3.1-29 0 Pages B 3.1-30 through B 3.1-33 - O Pages TS / B 3.3-34 through TS I B 3.3-36 0 Page TS /fB 3.1-37 Page'TS I B 3;.1-38 Pages 5 3.1-39 through B 3.1-44 PageTSlB3.1-45 Pages B 3.1-46 through B 3.1-51 4 ,'Ii B 3.2 POWER DISTRIBUTION LIMITS BASES Page TS I B 3.2-1 I Page TS lB 3.2-2 2 Page TS / B 3.2-3 1 Page TS I B 3.2-4 2 Pages TS I B 3.2-5 and TS I B 3.2-6 1 Page B 3.2-7 0 Pages TS / B 3.2-8 through TS I B 3.2-10 1 Page TS I B 3.2-11 2 Page B 3.2-12 0 2

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SUSQUEHANNA - UNIT 1 TS / B LOES-1 Revision 64

SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

Section Title Revision Pages B 3.2-14 and B 3.2-15 0 Page TS / B 3.2-16 2 Pages B 3.2-17 and B 3.2-18 0 Page TS / B 3.2-19 3 B 3.3 INSTRUMENTATION Pages TS / B 3.3-1 through TS B 3.3-4 1 Page TS / B 3.3-5 2 Page TS / B 3.3-6 1 Pages TS / 2 3.3-7 through TS I B 3.3-11 2 Page TS / B 3.3-12 2 Page TS / B 3.3-13 1 Page TS I B 3.3-14 2 Pages TS / B 3.3-15 and TS /B3.3-16 1 Pages TS / B 3.3-17 and TS I B 3.3-18 2 Pages TS / B 3.3-19 through TS / B 3.3-27 1 Pages TS / B 3.3-28 through TS / B 3.3-31 2 Pages TS I B 3.3-32 and TS / B 3.3-33 4 Pages TS / B 3.3-34 through TS / B 3.3-43 1 Pages TS / B 3.3-43a through TS I B 3.3-43i 0 Pages TS / B 3.3-44 through TS / B 3.3-50 2 Pages TS / B 3.3-51 through TS / B 3.3-53 1 ITS

3. B 3.3-54 - 2

.sF9 through 2 3.3-63 3.3-55 - 0 Pages TS / B 3.3-64 and TS I B 3.3 - 2 Page TS / B 3.3-66 . 4 Page TS / B 3.3-67 3 Page TS / B 3.3-68 4 Pages TS I B 3.3-69 and TS / B 3.3-70 3 Page TS /B3.3-71 3 Pages TS I 3.3-72 through TS / 3.3-75 2 Page TS / B 3.3-75a 4 Pages TS / B 3.3-75b and TS / B 3.3-75c 4 Pages B 3.3-76 through 3.3-77 0 PageTS/B3.3-78 1 Pages B 3.3-79 through B 3.3-89 0 Page TS / B 3.3-90 1 Page B 3.3-91 0 Page TS / B 3.3-92 through TS / B 3.3-1 00 1 Pages B 3.3-101 through B 3.3-1.03 0 Page TS / B 3.3-104 1 Pages B 3.3-105 and B 3.3-106 0 Page TS /B3.3-107 1 Page B 3.3-108 0 Page TS / B 3.3-109 1 Pages B 3.3-110 and B 3.3-111 0 Pages _.3-1 nT -912

- o NTI1 T/LE- eiin6 SUSQUEHANNASUSQUEHANN

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SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

_ Section Title Revision Pages TS / B 3.3-113 and TS/ B 3.3-114 1 Page TS I B 3.3-115 1 PageTS/B3.3-116 ' 2 PageTS/B 3.3-117 1

- Pages B 3.3-118 through B 3.3-122 0 Pages TS/B3.3-123 and TS/B3.3-124 - I Page TS / B 3.3-124a 0 Page B 3.3-125 0 Page TS / B 3.3-126 1 Page TS / B 3.3-127 1 Pages B 3.3-128 through B 3.3-130 0 Page TS / B 3.3-131 1 Pages B 3.3-132 through B 3.3-137 0 Page TS / B 3.3-138 1 Pages B 3.3-139 through B 3.3-149 0 Page TS / B 3.3-150 through TS / B 3.3-162 1 Page TS / B 3.3-163 2 Pages TS I B 3.3-164 through TS / B 3.3-177 1 Pages TS / B 3.3-178 and TS I B'3.3-179 2 Page TS / B 3.3-179a 2 Page TS / B 3.3-179b 0 Page TS / B 3.3-179c 0

'"PageTS/B3.3-180 - 1 PagTS I B 3.3-181 2 Pages TS I B 3.3-182 through TS / B 3.3-186 - - 1 Pages TS lB.3.3-187 and TS / B 3.3-188 2 Pages TS / B 3.3-189 through TS / B 3.3-191 1 Pages B 3.3-192 through B 3.3-204 0 Page TS / B 3.3-205 1 Pages B 3.3-206 through B 3.3-219 0 B 3.4 REACTOR COOLANT SYSTEM BASES Pages B 3.4-1 and B 3.4-2 0 Page TS / B 3.4-3 and Page TS /B 3.4-4 3 Pages TS / B 3.4-5 through TS / B 3.4-9 2 Pages B 3.4-10 through B 3.4-14 0 Page TS / B 3.4-15 1 Pages TS / B 3.4-16 and TS / B 3.4-17 2 Page TS /B3.4-18 1 Pages B 3.4-19 through B 3.4-28 0 Page TS / B 3.4-29 1 Pages B 3.4-30 and B 3.4-31 0 Page TS / B 3.4-32 1 Pages B 3.4-33 through B 3.4-36 0 Page TS / B 3.4-37 1 Pages B 3.4-38 through B 3.4-40 0 t _

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TS/BLOES-3 Revision 64 SUSQUEHANNA - UNIT 1I TS / B LOES-3 Revision 64

4U SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

- Section ~Tite -Revision Pages B 3.4-42 through B 3.4-48 0 Page TS / B 3.4-49 2 Page TS / B 3.4-50 1 Page TS / B 3.4-51 2

- Pages TS / B 3.4-52 and TS / B 3.4-53 1 Page TS / B3.4-54 2 Page TS I B 3.4-55 2 Page TS I B 3.4-56 1 Page TS / B3.4-57 2 Pages TS / B 3.4-58 through TS/ B 3.4-60 1 B 3.5 ECCS AND RCIC BASES PagesB 3.5-1 and B 3.5-2 0 Page TS /B3.5-3 2 Page TS /B 3.5-4 1 Page TS / B 3.5-5 2 Page TS / B 3.5-6 1 Pages B 3.5-7 throughB 3.5-10 0 Page TS /B3.5-11 1 PagesB 3.5-12 throughB 3.5-15 0 Pages TS /B 3.5-16 through TS /B 3.5-18 1 Pages B 3.5-19 through B 3.5-24 -_- 0 age TS/B3.5-25 -

Pages TS/ B 3.5-26 and TS / B 3.5-27 1 Pages B 3.5-28 through B 3.5-31 - - 0 B 3.6 CONTAINMENT SYSTEMS BASES Page TS /B3.6-1 2 Page TS/ B 3.6-1a 3 Pages TS / B 3.6-2 through TS/ B 3.6-5 2 Page TS/ B 3.6-6 3 Pages TS / B 3.6-6a and TS/-B 3.6-6b 2 Page TS / B 3.6-6c 0 PagesB 3.6-7 throughB 3.6-14 0 PageTS/B3.6-15 2 Pages TS / 8 3.6-15a and TS B / 3.6-15b 0 PageB 3.6-16 0 Page TS /83.6-17 1 Page TS B/ 3.6-17a 0 Pages TS B/ 3.6-18 and TS B / 3.6-19 0 Page TS B/ 3.6-20 1 Page TS /B3.6-21 2 Page TS B/ 3.6-22 1 Page TS / B 3.6-22a 0 Page TSB/ 3.6-23 1 Pages TS / B 3.6-24 through TS f B 3.6-25 0 WI . _ _ __ _ _ Page iS /7193626 _ _

LOES-4 TS/ IBBLOES-4 Revision 64 SUSQUEHANNA - UNIT UNIT I1 TS Revision 64

SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

, Section Title Revision Page TS / B 3.6-27 2 Page TS / B 3.6-28 5 Page TS / B 3.6-29 1 Page TS I B 3.6-30 1

- Page TS / B 3.6-31 3 Page B 3.6-32 0 Page TS / B 3.6-33 1 Pages B 3.6-34 and B 3.6-35 0 Page TS / B 3.6-36 1 Page B 3.6-37 0 Page TS/B3.6-38 1 Page B 3.6-39 0 Page TS / B 3.6-40 3 Pages B 3.6-41 through B 3.6-43 0 Pages TS / B 3.6-44 and TS / B 3.6-45 1 Page TS / B 3.6-46 2 Pages TS / B 3.6-47 through TS / B 3.6-51 1 Page TS / B 3.6-52 2 Pages B 3.6-53 through B 3.6-63 0 Page TS / B 3.6-64 1 Pages B 3.6-65 through B 3.6-72 0 Rage TS / B 3.6-73 - 1 Pages B 3.6-74 through B 3.6-77 - 0

--Page TS / 83.6-78 1 Pages B 3.6-79 through B 3.3.6-83 - - 0 Page TS / B 3.6-84 3 Pages TS / B 3.6-85 and TS / B 3.6-86 2 Page TS / B 3.6-87 1 Pages TS / B 3.6-88 and TS / B 3.6-88a 2 Page TS / B 3.6-89 3 Page TS / B 3.6-90 1 Page TS / B 3.6-91 3 Pages TS / B 3.6-92 through TS I B 3.6-96 1 Page TS / B 3.6-97 2 Pages TS / B 3.6-98 and TS / B 3.6-99 1 Page TS / 8 3.6-100 2 Pages TS / B 3.6-101 and TS / B 3.6-102 1 Pages TS / B 3.6-103 through TS / B 3.6-105 2 Pages TS /B 3.6-106 and TS /B3.6-107 1 B 3.7 PLANT SYSTEMS BASES Pages TS / B 3.7-1 through TS / B 3.7-6 2 Page TS/B3.7-6a 2-Pages TS /B3 3.7-6b and TS /B 3.7-6c 0 Page TS /B3.7-7 2 Pages TS / B 3.7-8 through TS / B 3.7-11 1 aesTS T. = -ndTS73-5 T13-TS/BLOES-5 Revision 64 SUSQUEHANNA - UNIT -

UNIT I1 TS I B LOES-5 Revision 64

No SUSQUEHANNA STEAM ELECTRIC STATION LIST OF EFFECTIVE SECTIONS (TECHNICAL SPECIFICATIONS BASES)

~ Section Title Revision Pages TS f B 3.7-14 through TS f B 3.7-18 2 Page TS f B 3.7-18a 0 Pages TS I B 3.7-19 through TS f B 3.7-23 1 Pages B 3.7-24 through B 3.7-26 0

- Pages TS I B 3.7-27 through TS f B 3.7-29 4 Page TS / B 3.7-30 2 Pages B 3.7-31 through B 3.7-33 0 B 3.8 ELECTRICAL POWER SYSTEMS BASES Pages TS / B 3.8-1 through TS I B 3.8-4 2 Page TS / B 3.8-5 4 Page TS l B 3.8-6 3 Pages TS / B 3.8-7 through TS/B 3.8-8 2 Page TS / B 3.8-9 4 Page TS / B 3.8-10 3 Pages TS / B 3.8-11 and TS B 3.8-17 2 Page TS / B 3.8-18 3 Pages TS / B 3.8-19 through TSl B 3.8-21 2 Pages TS / B 3.8-22 and TS / B 3.8-23 3 Pages TS I B 3.8-24 through TS I B 3.8-37 2 Pages B 3.8-38 through B 3.8-53 0 Pages TS I B 3.8-54 through TS I B 3.8-61 1 Page TS/B3.8-62 - 2 Page TS / B 3.8-63 2 Page TS / B 3.8-64 - 1 Page TS/B3.8.65 - 2 Pages B 3.8-66 through B 3.8-80 0 Page TS /B3.8-81 1 Pages B 3.8-82 through B 3.8-90 0 B 3.9 REFUELING OPERATIONS BASES Pages TS /B3.9-1 and TSB 3.9-1a I Pages TS / B 3.9-2 through TS / B 3.9-4 1 Pages B 3.9-5 through B 3.9-30 0 B 3.10 SPECIAL OPERATIONS BASES Page TS / B 3.10-1 1 Pages B 3.10-2 through B 3.10-31 0 Page TS /B3.10-32 1 Pages B 3.10-33 through B 3.10-37 0 Page TS / B 3.10-38 1 gr _TSBtextLOES T .. _t --- -- ---

4 N.-.- ~---- - -- ~ 2'4-434- -

TS/BLOES-6 Revision 64 SUSQUEHANNA - UNIT -

UNIT II TS /B LOES-6 Revision 64

PPL Rev. I Drywell Air Temperature B 3.6.1.5 B 3.6 CONTAINMENT SYSTEMS B 3.6.1.5 Drywell Air Temperature BASES BACKGROUND The drywell contains the reactor vessel and piping, which add heat to the airspace. Drywell coolers remove heat and maintain a suitable environment. The average airspace temperature affects the calculated response to postulated Design Basis Accidents (DBAs). The limitation on the drywell average air temperature was developed as reasonable, based on operating experience. The limitation on drywell air temperature is used in the Reference 1 safety analyses.

APPLICABLE Primary containment performance is evaluated for a spectrum of break SAFETY ANALYSES sizes for postulated loss of coolant accidents (LOCAs) (Ref. 1). Among the inputs to the design basis analysis is the initial drywell average air temperature (Ref. 1). Analyses assume an initial average drywell air temperature, which bounds the allowed drywell air temperature of 1350F. This limitation ensures that the safety analysis remains valid by maintaining the expected initial conditions and ensures that the peak LOCA drywell temperature does not exceed the maximum allowable temperature of 340 0F (Ref. 1). Exceeding this design temperature may result in-the degradation of the primary containment structure under accident loads. Equipment inside primary containment required to mitigate the effects of a DBA is designed to operate and be capable of operating under environmental conditions expected for the accident.

Drywell air temperature satisfies Criterion 2 of the NRC Policy Statement. (Ref. 2)

LCO In the event of a DBA, with an initial drywell average air temperature less than or equal to the LCO temperature limit, the resultant peak accident temperature is maintained below the drywell design temperature. As a result, the ability of primary containment to perform its design function is ensured.

t- m (continued)

SUSQUEHANNA - UNIT 1 TS /B 3.644 Revision 1

PPL Rev. 1 Drywell Air Temperature B 3.6.1.5 BASES (continued)

APPLICABILITY In MODES 1, 2, and 3, a DBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these--- ------ , -- -

MODES. Therefore, maintaining drywell average air temperature within the limit is not required in MODE 4 or 5.

ACTIONS A.1 With drywell average air temperature not within the limit of the LCO, drywell average air temperature must be restored within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . The Required Action is necessary to return operation to within the bounds of the primary containment analysis. The 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Completion Time is acceptable, considering the sensitivity of the accident analysis to variations in this parameter, and provides sufficient time to correct minor problems.

B.1 and B.2 If the drywell average air temperature cannot be restored to

-within limit within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months ; The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.6.1.5.1 REQUIREMENTS Verifying that the drywell average air temperature is within the LCO limit ensures that operation remains within the limits assumed for the primary containment analyses.

Drywell air temperature is monitored in the following areas:

(continued)

SUSQUEHANNA - UNIT I TS I B 3.6-45 Revision I

PPL Rev. I Drywell Air Temperature B 3.6.1.5 BASES . . _._o SURVEILLANCE SR 3.6.1.5.1 (continued)

REQUIREMENTS Temperature Substitution Areas Access at Elevation Element Nos. Value Top 794' 4" TE 15791A 150OF TE 15791B 150OF Middle 752' 2" TE 15790A 150OF TE 15790B 150OF Bottom 719' 1" TE 15798A 150OF TE 15798B 150OF Pedestal 704' 0" TE 15799A 130OF TE 15799B 130OF and is the arithmetical average of all valid temperatures from the above sensors. The location of the Drywell Temperature Elements ensures the Drywell Average Temperature is obtained. In the event a sensor becomes l inoperable, the "substitution value" will be used in the calculation.

Satisfying the surveillance requirement with less than 6 of the above listed 8 sensors operable shall not be done without an engineering evaluation.

Note that inoperable sensors should also be evaluated against LCO

- f~Z~t.

,,lI GIRS_II~el 3.3.3.1.

Te24 hour Frequency of the SR was developed based on operating experience related to drywell average air temperature variations and temperature instrument drift during the applicable MODES and the low probability of a DBA occurring between surveillances. -Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal drywell air temperature condition.

REFERENCES 1. FSAR, Section 6.2:

2. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).

I

~- - - - .- , - - - O -- 1-- - - --- - -

SUSQUEHANNA - UNIT 1 TS / B 3.6-46 Revision 2

PPL Rev. 3 Secondary Containment B 3.6.4.1 B 3.6 CONTAINMENT SYSTEMS B 3.6.4.1 Secondary Containment BASES BACKGROUND The secondary containment structure completely encloses the primary containment structure such that a dual-containment design is utilized to limit the spread of radioactivity to the environment to within limits. The function of the secondary containment is to contain, dilute, and hold up fission products that may leak from primary containment into secondary containment following a Design Basis Accident (DBA). In conjunction with operation of the Standby Gas Treatment (SGT) System and closure of certain valves whose lines penetrate the secondary containment, the secondary containment is designed to reduce the activity level of the fission products prior to release to the environment and to isolate and contain fission products that are released during certain operations that take place inside primary containment, when primary containment is not required to be OPERABLE, or that take place outside primary containment (Ref. 1).

A. Be-. -. The secondary containment is a structure that completely encloses the primary containment and reactor- coolant pressure. boundary components.

This structure forms a control volume that serves to hold -up and dilute the fission products. It is possible for the pressure in the control volume to rise relative to the environmental pressure (e.g., due to pump and motor heat load additions).

The secondary containment boundary consists of the reactor building structure and associated removable walls and panels, hatches, doors, dampers, sealed penetrations and valves. The secondary containment is divided into Zone I, Zone II and Zone ll, each of which must be OPERABLE depending on plant status and the alignment of the secondary containment boundary. Specifically, the Unit 1 secondary containment boundary can be modified to exclude Zone II. Similarly, the Unit 2 secondary containment boundary can be modified to exclude Zone I. Secondary containment may consist of only Zone IlIl when in MODE 4 or 5 during CORE ALTERATIONS, or during handling of irradiated fuel within the Zone IlIl secondary containment boundary.

W, (e ntint ued)

SUSQUEHANNA - UNIT 1 TS / B 3.6-84 Revision 3

PPL Rev. 3 Secondary Containment B 3.6.4.1 BASES BACKGROUND To prevent ground level exfiltration while allowing the secondary (continued) containment to be designed as a conventional structure, the secondary containment requires support systems to maintain the control volume pressure at less than the external pressure. Requirements for the safety related systems are specified separately in LCO 3.6.4.2, "Secondary Containment Isolation Valves (SCIVs)," and LCO 3.6.4.3, "Standby Gas Treatment (SGT) System." When one or more zones are excluded from secondary containment, the specific requirements for support systems will also change (e.g., required secondary containment isolation valves).

APPLICABLE There are two principal accidents for which credit is taken for secondary SAFETY containment OPERABILITY. These are a loss of coolant accident (LOCA)

ANALYSES (Ref. 2) and a fuel handling accident inside secondary containment (Ref. 3). The secondary containment performs no active function in response to either of these limiting events; however, its leak tightness is required to ensure that the release of radioactive materials from the primary containment is restricted to those leakage paths and associated leakage rates assumed in the accident analysis and that fission products

,nitrappedwit i h the secondary containment structure will be treated b

-* the SGT System prior to discharge to the environment.

Secondary containment satisfies Criterion 3 of the NRC Policy Statement (Ref. 4).

LCO An OPERABLE secondary containment provides a control volume into which fission products that bypass or leak from primary containment, or are released from the reactor coolant pressure boundary components located in secondary containment, can be diluted and processed prior to release to the environment. For the secondary containment to be considered OPERABLE, it must have adequate leak tightness to ensure that the required vacuum can be established and maintained. The leak tightness of secondary containment must also ensure that the release of radioactive materials to the environment is restricted to those leakage paths and associated leakage rates assumed in the accident analysis. For example, secondary containment bypass leakage must be restricted to the leakage rate required by LCO 3.6.1.3. The secondary containment boundary required to be OPERABLE is dependent on the operating status of both units, as well as the configuration of walls, doors, hatches, SCIVs, and available flow paths to the SGT System.

W. . ---- M-0 - -- ffiffifto --

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.1 - 11,- - - -I,--- I --;,. - - -o Mi, go, i - I...

SUSQUEHANNA - UNIT 1 T S I B 3.6-85 Revision 2

PPL Rev. 3 Secondary Containment B 3.6.4.1

- ~ A ~---- - ---- -. 1_ - - -- - - I- - "

Dj1\0r_ tW111llnUWU)

I APPLICABILITY In MODES 1, 2, and 3, a LOCA could lead to a fission product release to primary containment that leaks to secondary containment. Therefore, secondary containment OPERABILITY is required during the same operating conditions that require primary containment OPERABILITY.

In MODES 4 and 5, the probability and consequences of the LOCA are reduced due to the pressure and temperature limitations in these MODES.

Therefore, maintaining secondary containment OPERABLE is not required in MODE 4 or 5 to ensure a control volume, except for other situations for which significant releases of radioactive material can be postulated, such as during operations with a potential for draining the reactor vessel (OPDRVs), during CORE ALTERATIONS, or during movement of irradiated fuel assemblies in the secondary containment.

--- 1_1 ACTIONS A.1 If secondary containment is inoperable, it must be restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Completion Time provides a period of time to correct the problem that is commensurate with the importance of maintaining secondary containment during MODES 1, 2, and 3. This time period also ensures that the probability of an accident (requiring secondary containment OPERABILITY) occurring du ring periods where secondary containment is inoperable is minimal. -

(continued)

- _ ;it's: ; i SUSQUEHANNA - UNIT I TS /B 3.686 Revision 2

PPL Rev. 3 Secondary Containment B 3.6.4.1 BASES ACTIONS B.1 and B.2 (continued)

If secondary containment cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

C.1, C.2, and C.3 Movement of irradiated fuel assemblies in the secondary containment, CORE ALTERATIONS, and OPDRVs can be postulated to cause fission product release to the secondary containment. In such cases, the secondary containment is the only barrier to release of fission products to the environment. CORE ALTERATIONS and movement of irradiated fuel assemblies must be immediately suspended if the secondary containment is inoperable.

Suspension of these activities shall not preclude completing an action that involves moving a component to a safe position. Also, action must be immediately initiated to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release.

Actions must continue until OPDRVs are suspended.

Required Action C.1 has been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 4 or 5, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations. Therefore, in either case, inability to suspend movement of irradiated fuel assemblies would not be a sufficient reason to require a reactor shutdown.

SURVEILLANCE SR 3.6.4.1.1 REQUIREMENTS This SR ensures that the secondary containment boundary is sufficiently leak tight to preclude exfiltration.

_continued)

SUSQUEHANNA - UNIT 1 TS / B 3.6-87 Revision I

PPL Rev. 3 Secondary Containment B'3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.1 (continued)

REQUIREMENTS The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this SR was developed based on operating experience related to secondary containment vacuum variations during the applicable MODES and the low probability of a DBA occurring between surveillances.

Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal secondary containment vacuum condition.

SR 3.6.4.1.2 and SR 3.6.4.1.3 Verifying that secondary containment equipment hatches, removable walls and one access door in each access opening required to be closed are closed ensures that the infiltration of outside air of such a magnitude as to prevent maintaining the desired negative pressure does not occur.

Verifying that all such openings are closed also provides adequate assurance that exfiltration from the secondary containment will not occur.

- this applicatin thermsea'l'ed"has no connotation of leak tightness'. '

An access opening typically contains one-inner and one outer door.

Maintaining secondary containment OPERABILITY requires verifying one door in each access opening to secondary containment zones is closed.

In some cases (e.g., railroad bay), secondary containment access openings are shared such that a secondary containment barrier may have multiple inner or multiple outer doors. The intent is to maintain the secondary containment barrier intact, which is achieved by maintaining the inner or outer portion of the barrier closed at all times. However, all secondary containment access doors are normally kept closed, except when the access opening is being used for entry and exit or when maintenance is being performed on an access opening.

When the railroad bay door (No. 101) is closed; all Zone I and IlIl hatches, removable walls, dampers, and one door in each access opening connected to the railroad access bay are closed; or, only Zone I removable walls and/or doors are open to the railroad access shaft; or, only Zone IlIl hatches and/or dampers are open to the railroad access shaft. When the railroad bay door (No. 101) is open; all Zone I and IlIl hatches, removable walls, dampers, and one door in each access opening connected to the railroad access bay are closed. The truck bay hatch is closed and the truck bay door (No. 102) is closed unless Zone II is isolated from Zones I and Ill.

7 continued) 1 1 1 SUSQUEHANNA - UNIT 1 TS / B 3.6-88 Revision 2

U PPL Rev. 3 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.2andSR 3.6.4.1.3 (continued)

REQUIREMENTS When an access opening between required secondary containment zones l is being used for exit and entry, then at least one door (where two doors are provided) must remain closed. The access openings between secondary containment zones which are not provided with two doors are administratively controlled to maintain secondary containment integrity during exit and entry. This Surveillance is modified by a Note that allows access openings with a single door (i.e., no airlock) within the secondary containment boundary (i.e., between required secondary containment zones) to be opened for entry and exit. Opening of an access door for entry and exit allows sufficient administrative control by individual personnel making the entries and exits to assure the secondary containment function is not degraded. When one of the zones is not a zone required for secondary containment-OPERABILITY, the Note allowance would not apply.

The 31 day Frequency for these SRs has been shown to be adequate,

_ ' A -- -based on operating experience, and is considered adequate in view of the other indications of door and hatch status that are available to the operator.

> -(continued)

I I - - - - I- I . - - -. _ ,, . _

SUSQUEHANNA - UNIT 1 TS I B 3.6-88a Revision 2

PPL Rev. 3 Secondary Containment B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 REQUIREMENTS (conti rinued) The SGT System exhausts the secondary containment atmosphere to the environment through appropriate treatment equipment. To ensure that all fission products are treated, SR 3.6.4.1.4 verifies that the SGT System will rapidly establish and maintain a pressure in the secondary containment that is less than the pressure external to the secondary containment boundary. This is confirmed by demonstrating that one SGT subsystem will draw down the secondary containment to > 0.25 inches of vacuum water gauge in less than or equal to the maximum time allowed. This cannot be accomplished if the secondary containment boundary is not intact. SR 3.6.4.1.5 demonstrates that one SGT subsystem can maintain 2 0.25 inches of vacuum water gauge for at least 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months at less than or equal to the maximum flow rate permitted for the secondary containment configuration that is operable. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months test period allows secondary containment to be in thermal equilibrium at steady state conditions. As noted, both SR 3.6.4.1.4 and SR 3.6.4.1.5 acceptance limits are dependent upon the secondary containment configuration when testing is being performed. The acceptance criteria for the SRs based on IF I-- -

secondary containment configuration is defined as follows:

SECONDARY MAXIMUM DRAWDOWN TIME(SEC) MAXIMUM FLOW RATE (CFM)

CONTAINMENT (SR 3.6.4.1.4 (SR 3.6.4.1.5 TEST CONFIGURATION ACCEPTANCE CRITERIA) ACCEPTANCE CRITERIA)

Zones I, 11and III.

125 Seconds

4000 CFM (Zones 1,11, and III) (From Zones I, II, and III)

Zones land III. S117 Seconds

2885 CFM (Zones I and III) (From Zones I and III)

(continued)

-_ _.__1 I . .. .. . . . . .. . . I-SUSQUEHANNA - UNIT 1 TS I B 3.6-89 Revision 3

PPL Rev. 3 Secondary Containment B 3.6.4.1

'q6A- WW_*

BASES SURVEILLANCE SR 3.6.4.1.4 and-SR 3.6.4.1.5 (continued)

REQUIREMENTS Only one of the above listed configurations needs to be tested to confirm secondary containment OPERABILITY.

A Note also modifies the Frequency for each SR. This Note identifies that each SR must be performed in the most limiting Secondary Containment Configuration every 60 months. The 60 month Frequency is acceptable because operating experience has shown that these components usually pass the Surveillance and all active components are tested more frequently. Therefore, these tests are used to ensure secondary containment boundary integrity.

Since these SRs are secondary containment tests, they need not be performed with each SGT subsystem. The SGT subsystems are tested on a STAGGERED TEST BASIS, however, to ensure that in addition to the requirements of LCO 3.6.4.3, either SGT subsystem will perform SR 3.6.4.1.4 and SR 3.6.4.1.5. Operating experience has shown these components usually pass the Surveillance when performed at the

_ k

'24'montfi6Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

REFERENCES 1. FSAR, Section 6.2.3.

2. FSAR, Section 15.6.

3. FSAR, Section 15.7.4.

4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).

~^

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-4 SUSQUEHANNA - UNIT 1 TS / B 3.6-90 Revision 1

PPL Rev. 3 AC Sources - Operating B 3.8.1 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.1 AC Sources - Operating BASES BACKGROUND The unit Class I E AC Electrical Power Distribution System AC sources consist of two offsite power sources (preferred power sources, normal and alternate), and the onsite standby power sources (diesel generators (DGs) A, B, C and D). A fifth diesel generator, DG E, can be used as a substitute for any one of the four DGs A, B, C or D. As required by 10 CFR 50, Appendix A, GDC 17 (Ref. 1), the design of the AC electrical power system provides independence and redundancy to ensure an available source of power to the Engineered Safety Feature (ESF) systems.

The Class I E AC distribution system is divided into redundant load groups, so loss of any one group does not prevent the minimum safety functions from being performed. Each load group has connections to two preferred offsite power supplies and a single DG.

The two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System are e twoinepen er sources. A 230 kV line from the Susquehanna TI0 230 kV switching station feeds start-up transformer No. 10; and, a 230 kV tap from the 500-230 kV tie line feeds the startup transformer No. 20.

The two independent offsite power sources are supplied to and are shared by both units. These two electrically and physically separated circuits provide AC power, through startup transformers (ST) No. 10 and ST No. 20, to the four 4.16 kV Engineered Safeguards System (ESS) buses (A, B, C and 0) for both Unit 1 and Unit 2. A detailed description of the offsite power network and circuits to the onsite Class 1E ESS buses is found in the FSAR, Section 8.2 (Ref. 2).

An offsite circuit consists of all breakers, transformers, switches, automatic tap changers, interrupting devices, cabling, and controls required to transmit power from the offsite transmission network to the onsite Class 1E ESS bus or buses.

(continued)

SUSQUEHANNA~~~~~ S/381NT

- eiso SUSQUEHANNA - UNIT 1 TS / B 3.8-1 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES BACKGROUND ST No. 10 and ST No. 20 each provide the normal source of power to (continued) two of the four 4.16 kV ESS buses in each Unit and the alternate source of power to the remaining two 4.16 kV ESS buses in each Unit.

If any 4.16 kV ESS bus loses power, an automatic transfer from the normal to the alternate occurs after the normal supply breaker trips.

When off-site power is available to the 4.16 kV ESS Buses following a LOCA signal, the required ESS loads will be sequenced onto the 4.16 kV ESS Buses in order to compensate for voltage drops in the onsite power system when starting large ESS motors.

The onsite standby power source for 4.16 kV ESS buses A, B, C and D consists of five DGs. DGs A, B, C and D are dedicated to ESS buses A, B, C and D, respectively. DG E can be used as a substitute for any one of the four DGs (A, B, C or D) to supply the associated ESS bus. Each DG provides standby power to two 4.16 kV ESS buses-one associated with Unit 1 and one associated with Unit 2.

The four "required" DGs are those aligned to a 4.16 kV ESS bus to provide onsite standby power for both Unit 1 and Unit 2.

A DG, when aligned to an ESS bus, starts automatically on a loss of

- ( ) siEgt nal-(i.e., low reactor water le`velsignal or high drywell pressure signal) or on an ESS bus degraded voltage or undervoltage signal. After the DG has started, if automatically ties to its respective bus after offsite-power is tripped as a consequence of ESS bus undervoltage or degraded voltage, independent of or coincident with a LOCA signal. The DGs also start and operate in the standby mode without tying to the ESS bus on a LOCA signal alone.

Following the trip of offsite power, non-permanent loads are stripped from the 4.16 kV ESS Buses. When a DG is-tied to the ESS Bus, loads are then sequentially connected to their respective ESS Bus by individual load timers. The individual load timers control the starting permissive signal to motor breakers to prevent overloading the associated DG.

In the event of loss of normal and alternate offsite power supplies, the 4.16 kV ESS buses will shed all loads except the 480 V load centers and the standby diesel generators will connect to the ESS busses. When a DG is tied to its respective ESS bus, loads are then sequentially connected to

-. - - -contnued)

. . . . . . . . . . . 9. . . .

SUSQUEHANNA - UNIT 1 TS/ B3.8-2 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES BACKGROUND the ESS bus by individual load timers which control the permissive and (continued) starting signals to motor breakers to prevent overloading the DG.

In the event of a loss of normal and alternate offsite power supplies, the ESS electrical loads are automatically connected to the DGs in sufficient time to provide for safe reactor shutdown and to mitigate the consequences of a Design Basis Accident (DBA) such as a LOCA.

Certain required plant loads are returned to service in a predetermined sequence in order to prevent overloading of the DGs in the process.

Within 286 seconds after the initiating signal is received, all automatic and permanently connected loads needed to recover the unit or maintain it in a safe 'condition are returned to service. Ratings for the DGs satisfy the requirements of Regulatory Guide 1.9 (Ref. 3).

DGs A, B, C and D have the following ratings:

a. 4000 kW-continuous,

b. 4700 kW-2000 hours, DG E has the following ratings:

a. 5000 kW-continuous,

_kW-2000 hours.

APPLICABLE The initial conditions of DBA and transient analyses in-the FSAR, SAFETY ANALYSES Chapter 6 (Ref. 4) and Chapter 15 (Ref. 5), assume ESF systems are OPERABLE. The AC electrical power sources are designed to provide sufficient capacity, capability, redundancy, and reliability to ensure the availability of necessary power to ESF systems so that the fuel, Reactor Coolant System (RCS), and containment design limits are not exceeded. These limits are discussed in more detail in the Bases for Section 3.2, Power Distribution Limits; Section 3.4, Reactor Coolant System (RCS); and Section 3.6, Containment Systems.

The OPERABILITY of the AC electrical power sources is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the unit and supporting safe shutdown of the other unit. This includes maintaining the onsite or offsite AC sources (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.8-3 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES APPLICABLE OPERABLE during accident conditions in the event of an assumed SAFETY ANALYSES loss of all offsite power or all onsite AC power; and a worst case single failure.

(continued)

AC sources satisfy Criterion 3 of the NRC Policy Statement (Ref. 6).

LCO Two qualified circuits between the offsite transmission network and the onsite Class 1E Distribution System and four separate and independent DGs (A, B, C and D) ensure availability of the required power to shut down the reactor and maintain it in a safe shutdown condition after an anticipated operational occurrence (AOO) or a postulated DBA. DG E can be used as a substitute for any one of the four DGs A, B, C or D.

Qualified offsite circuits are those that are described in the FSAR, and are part of the licensing basis for the unit. In addition, the required automatic load timers for each ESF bus shall be OPERABLE.

The Safety Analysis for Unit 2 assumes the OPERABILITY of some equipment that receives power from Unit 1 AC Sources. Therefore, Unit 2 Technical Specifications establish requirements for the OPERABILITY of the DG(s) and qualifiedfite cs neede'd to

- :=support thie Unit 1 onsite Class I E AC electrical power distribution subsystem(s) required by LCO 3.8.7, Distributionr Systems-Operating.

Each offsite circuit must be capable of maintaining rated frequency and voltage, and accepting required loads during an accident, while connected to the ESS buses. One OPERABLE offsite circuit consists of an energized ST. No. 10 transformer and the respective circuit path including energized ESS transformers 101 and 111 and feeder breakers capable of supplying three of the four 4.16 kV ESS Buses. The other OPERABLE offsite circuit consists of an energized-ST. No. 20 transformer, and the respective circuit path including energized ESS transformers 201 and 211 and feeder breakers capable of supplying three of the four 4.16 kV ESS Buses. Both offsite circuits are OPERABLE provided each meets the criteria described above and provided that no 4.16 kV ESS Bus has less than one OPERABLE offsite circuit

- .. * .(continued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-4 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES

11 _.. _ , _ . : ,,I,> ,,,_ , .

LCO capable of supplying the required loads. If no OPERABLE offsite (continued) circuit is capable of supplying any of the 4.16 kV ESS Buses, provided that the offsite circuits otherwise meet the above requirements, one offsite source shall be declared inoperable.

Four of the five DGs are required to be Operable to satisfy the initial assumptions of the accident analyses. Each required DG must be capable of starting, accelerating to rated speed and voltage, and connecting to its respective ESS bus on detection of bus undervoltage after the normal and alternate supply breakers open. This sequence must be accomplished within 10 seconds. Each DG must also be capable of accepting required loads within the assumed loading sequence intervals, and must continue to operate until offsite power can be restored to the ESS buses. These capabilities are required to be met from a variety of initial conditions, such as DG in standby with the engine hot and DG in normal standby conditions. Normal standby conditions for a DG mean that the diesel engine oil is being continuously circulated and engine coolant is circulated as necessary to maintain temperature consistent with manufacturer recommendations. Additional DG capabilities must be demonstrated to meet required Surveillances, e.g., capability of the DG to revert to . x standby status on an ECSsignal while operating in parallel test

_- A^ , 7 - mode.

Although not normally aligned as a required DG, DG E is normally maintained OPERABLE (i.e., Surveillance Testing completed) so that it can be used as a substitute for any one of the four DGs A, B, C or D.

Proper sequencing of loads, including tripping of nonessential loads, is a required function for DG OPERABILITY.

The AC sources must be separate and independent (to the extent possible) of other AC sources. For the DGs, the separation and independence are complete. For the offsite AC sources, the separation and independence are to the extent practical. A circuit may be connected to more than one ESS bus, with automatic transfer capability to the other circuit OPERABLE, and not violate separation criteria. A circuit that is not connected to an ESS bus is required to have OPERABLE automatic transfer interlock mechanisms to each ESS bus to support OPERABILITY of that offsite circuit.

.'- -'_ 7 - _;' ] - -- f -. _

__= = -'(continued)

SUSQUEHANNA - UNIT 1 -TS I B 3.8-5 Revision 4

PPL Rev. 3 AC Sources - Operating B 3.8.1

=-<BASES (continued)

APPLICABILITY The AC sources are required to be OPERABLE in MODES 1, 2, and 3 to ensure that:

a. Acceptable fuel design limits and reactor coolant pressure boundary limits are not exceeded as a result of AOOs or abnormal transients; and

b. Adequate core cooling is provided and containment OPERABILITY and other vital functions are maintained in the event of a postulated DBA.

The AC power requirements for MODES 4 and 5 are covered in LCO 3.8.2, "AC Sources-Shutdown."

ACTIONS A Note prohibits the application of LCO 3.O.4.b to an inoperable DG.

There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable DG and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components,hshould not beapplied in tlii crcumstance.

The ACTIONS are modified by a Note which allows entry into associated'Conditions and Required Actions to be delayed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months when an OPERABLE diesel generator is placed in an inoperable status for the alignment of diesel generator E to or from the Class 1E distribution system. Use of this allowance requires both offsite circuits to be OPERABLE. Entry into the appropriate Conditions and Required Actions shall be made immediately upon the determination that substitution of a required diesel generator will not or can not be completed.

A.I To ensure a highly reliable power source remains with one offsite circuit inoperable, it is necessary to verify the availability of the remaining required offsite circuit on a more frequent basis. Since the Required Action only specifies "perform," a failure of SR 3.8.1.1 acceptance criteria does not result in a Required Action not met.

However, if a second required circuit fails SR 3.8.1.1, the second offsite circuit is inoperable, and Condition C, for two offsite circuits inoperable, is entered.

(cniud SUSQUEHANNA - UNIT 1 TS I B 3.8-6 Revision 3

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES ACTIONS A.2 (continued)

Required Action A.2, which only applies if one 4.16 kV ESS bus cannot be powered from any offsite source, is intended to provide assurance that an event with a coincident single failure of the associated DG does not result in a complete loss of safety function of critical systems. These features (e.g., system, subsystem, division, component, or device) are designed to be powered from redundant safety related 4.16 kV ESS buses. Redundant required features failures consist of inoperable features associated with an emergency bus redundant to the emergency bus that has no offsite power. The Completion Time for Required Action A.2 is intended to allow time for the operator to evaluate and repair any discovered inoperabilities.

This Completion Time also allows an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action, the Completion Time only begins on discovery that both:

a. A 4.16 kV ESS bus has no offsite power supplying its loads; and

b. A redundant required feature on another 4.16 kV ESS bus is inoperable.

If, at any time during the existence of this Condition (one offsite circuit inoperable) a required feature subsequently becomes inoperable, this Completion'Time would begin-to be tracked. - -

Discovering no offsite power to one 4.16 kV ESS bus on the onsite Class 1E Power Distribution System coincident with one or more inoperable required support or supported features, or both, that are associated with any other emergency bus that has offsite power, results in starting the Completion Times for the Required Action. Twenty-four hours is acceptable because it minimizes risk while allowing time for restoration before the unit is subjected to transients associated with shutdown.

The remaining OPERABLE offsite circuits and DGs are adequate to supply electrical power to the onsite Class 1E Distribution System. Thus, on a component basis, single failure protection may have been lost for the required feature's function; however, function is not lost. The 24 s -. <v..

SUSQUEHANNA-UNIT 1 TS I B 3.8-7 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8. 1 BASES ACTIONS A.2 (continued) hour Completion Time takes into account the component OPERABILITY of the redundant counterpart to the inoperable required feature. Additionally, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

A.3 According to Regulatory Guide 1.93 (Ref. 7), operation may continue in Condition A for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . With one offsite circuit inoperable, the reliability of the offsite system is degraded, and the potential for a loss of offsite power is increased, with attendant potential for a challenge to the plant safety systems. In this condition, however, the remaining OPERABLE offsite circuit and DGs are adequate to supply electrical power to the onsite Class 1E Distribution System.

The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and

-Caability oft s , reasonabletime for repairs, and the low probability of a DBA occurring during this period.

The second Completion Time for Required Action A.2-establishes a limit on the maximum time allowed for any combination of required AC power sources to be inoperable during any single contiguous occurrence of failing to meet the LCO. If Condition A is entered while, for instance, a DG is inoperable, and that DG is subsequently returned OPERABLE, the LCO-may already have been not met for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This situation could lead to a total of 144 hours0.00167 days 0.04 hours 2.380952e-4 weeks 5.4792e-5 months , since initial failure to meet the LCO, to restore the offsite circuit. At this time, a DG could again become inoperable, the circuit restored OPERABLE, and an additional 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (for a total of 9 days) allowed prior to complete restoration of the LCO. The 6 day Completion Time provides a limit on the time allowed in a specified condition after discovery of failure to meet the LCO. This limit is considered reasonable for situations in which Conditions A and B are entered concurrently.

The "AND" connector between the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and 6 day Completion Times means that both (continued)

SUSQUEHANNA-UNIT 1 TS I B 3.8-8 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES ACTIONS _3 (continued)

Completion Times apply simultaneously, and the more restrictive Completion Time must be met.

As in Required Action A.2, the Completion Time allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." This exception results in establishing the "time zero" at the time the LCO was initially not met, instead of at the time that Condition A was entered.

B.1 To ensure a highly reliable power source remains with one required DG inoperable, it is necessary to verify the availability of the required offsite circuits on a more frequent basis. Since the Required Action only specifies "perform," a failure of SR 3.8.1.1 acceptance-criteria does not result in-a Required Action being not met. However, if a circuit fails to pass SR 3.8.1.1, it is inoperable. Upon offsite circuit inoperability, additional Conditions must then be entered.

Required Action B.2 is intended to provide assurance that a loss of offsite power, during the period that a DG is inoperable, does not result in a complete loss of safety function of critical systems. These features are designed with redundant safety related divisions (i.e.,

single division systems are not included). Redundant required features failures consist of inoperable features associated with a division redundant to the division that has aninoperable DG.

The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action the Completion

-- (continued)

SUSQUEHANNA - UNIT 1 TS I B 3.8-9 Revision 4

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES ACTIONS B.2 (continued)

Time only begins on discovery that both:

a. An inoperable DG exists; and

b. A required feature powered from another diesel generator (Division I or 2) is inoperable.

If, at any time during the existence of this Condition (one required DG inoperable), a required feature subsequently becomes inoperable, this Completion Time begins to be tracked.

Discovering one required DG inoperable coincident with one or more inoperable required support or supported features, or both, that are associated with the OPERABLE DGs results in starting the Completion Time for the Required Action. Four hours from the discovery of these events existing concurrently is acceptable because it minimizes risk while allowing time for restoration before subjecting the unit to transients associated with shutdown.

The remaining OPERABLE DGs and offsite circuits are adequate to supply electrical power to e o E Distrition System.

Thus, on a component basis, single failure protection for the required feature's function may have been lost, however, function has not been Ilost. The 4'hour Completion Time takes into account the component OPERABILITY of the redundant counterpart to the inoperable required feature. Additionally, the 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Completion Tirme takes into account the capacity and capability of the remaining AC sources, reasonable time for repairs, and low probability of a DBA occurring during this period.

B.3.1 and B.3.2 Required Action'18.3.1 provides an allowance to avoid unnecessary testing of OPERABLE DGs. If it can be determined that the cause of the inoperable DG does not exist on the OPERABLE DG, SR 3.8.1.7 does not have to be performed. If the cause of inoperability exists on other DG(s), they are declared inoperable upon discovery, and Condition E of LCO 3.8.1 is entered. Once the failure is repaired, and the common cause failure no longer exists, Required Action B.3.1 is satisfied. If the cause of the initial inoperable DG cannot be determined not to exist on the remaining DG(s), performance of SR 3.8.1.7 suffices to provide assurance of continued OPERABILITY of those DGs.

-- I..I (continued)

SUSQUEHANNA - UNIT I TS I B 3.8-1 0 Revision 3

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES ACTIONS B.3.1 and B.3.2 (continued)

However, the second Completion Time for Required Action B.3.2 allows a performance of SR 3.8.1.7 completed up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to entering Condition B to be accepted as demonstration that a DG is not inoperable due to a common cause failure.

In the event the inoperable DG is restored to OPERABLE status prior to completing either B.3.1 or B.3.2, the plant corrective action program will continue to evaluate the common cause possibility. This continued evaluation, however, is no longer under the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months constraint imposed while in Condition B.

According to Generic Letter 84-15 (Ref. 8), 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is a reasonable time to confirm that the OPERABLE DGs are not affected by the same problem as the inoperable DG.

B.4 According to Regulatory Guide 1.93 (Ref. 7), operation may continue in Condition B for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . In onditi a, the remaining OPERABLE D-s and offsite circuits are adequate -to supply electrical power to the onsite Class 1E Distribution System. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes info account the capacity and capability of the remaining AC sources, reasonable time for repairs, and low probability of a DBA occurring during this period.

The second Completion Time for Required Action B.4 establishes a limit on the maximum time allowed for any combination of required AC power sources to be inoperable during any single contiguous occurrence of failing to meet the LCO. If Condition B is entered while, for instance, an offsite circuit is inoperable and that circuit is subsequently restored OPERABLE, the LCO may already have been not met for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This situation could lead to a total of 144 hours0.00167 days 0.04 hours 2.380952e-4 weeks 5.4792e-5 months , since initial failure of the LCO, to restore the DG. At this time, an offsite circuit could again become inoperable, the DG restored OPERABLE, and an additional 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (for a total of 9 days) allowed prior to complete restoration of the LCO. The 6 day Completion Time provides a limit on the time allowed in a specified

- - _ continued)

SUSQUEHANNA - UNIT I . TS I B 3.8-1 1 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES -- -

ACTIONS B.4 (continued) condition after discovery of failure to meet the LCO. This limit is considered reasonable for situations in which Conditions A and B are entered concurrently. The "AND" connector between the 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and 6 day Completion Times means that both Completion Times apply simultaneously, and the more restrictive must be met.

As in Required Action B.2, the Completion Time allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." This exception results in establishing the "time zero" at the time that the LCO was initially not met, instead of the time that Condition B was entered.

C.1 Required Action C.1 addresses actions to be taken in the event of concurrent inoperability of two offsite circuits. The Completion Time for Required Action C.1 is intended to allow the operator time to evaluate and repair any discovered inoperabilities.

-Ac-or-ding -eg-ula-t~Gu-ide 1.93 (Ref. 7), operation may continue in Condition C for a period that should not exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . This level of degradation means that the offsite electrical power system does not have the capability to effect a-safe shutdown and to mitigate the effects of an accident; however, the onsite AC sources have not been degraded. This level of degradation generally corresponds to a total loss of the immediately accessible offsite power sources.

Because of the normally high availability of the offsite sources, this level of degradation may appear to be more severe than other combinations of two AC sources inoperable that involve one or more DGs inoperable. However, two factors tend to decrease the severity of this degradation level:

a. The configuration of the redundant AC electrical power system that remains available is not susceptible to a single bus or switching failure; and M- I -_ __ i_ - --- _

(continued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-12 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES -

ACTIONS C.1 (continued)

b. The time required to detect and restore an unavailable offsite power source is generally much less than that required to detect and restore an unavailable onsite AC source.

With both of the required offsite circuits inoperable, sufficient onsite AC sources are available to maintain the unit in a safe shutdown condition in the event of a DBA or transient. In fact, a simultaneous loss of offsite AC sources, a LOCA, and a worst case single failure were postulated as a part of the design basis in the safety analysis.

Thus, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time provides a period of time to effect restoration of one of the offsite circuits commensurate with the importance of maintaining an AC electrical power system capable of meeting its design criteria. According to Regulatory Guide 1.93 (Ref. 7), with the available offsite AC sources two less than required by the LCO, operation may continue for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . If two offsite sources are restored within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , unrestricted operation may continue. If only one offsite source is restored within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , power operation continues in accordance with Condition A.

~- t.~ I - -- c---

ran -

Pursuant to LCO 3.0.6, the Distribution System Actions would not be entered even if all AC sources to it were inoperable, resulting in de-energization. Therefore, the Required Actions of Condition D are modified by a Note to indicate that when Condition D is entered with no AC source to any ESS bus, Actions for LCO 3.8.7, "Distribution Systems-Operating," must be immediately entered. This allows Condition D to provide requirements for the lQss of the offsite circuit and one DG without regard to whether a division is de-energized. LCO 3.8.7 provides the appropriate restrictions for a de-energized bus.

According to Regulatory Guide 1.93 (Ref. 7), operation may continue in Condition D for a period that should not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . In Condition D, individual redundancy is lost in both the offsite electrical power system and the onsite AC electrical power system. Since power system redundancy is provided by two diverse sources of power, however, the

- - S - ~ -, _ "

SUSQUEHANNA - UNIT I >.-7S / B 3.8-13 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES ACTIONS D.1 and D.2 (continued) reliability of the power systems in this Condition may appear higher than that in Condition C (loss of both required offsite circuits). This difference in reliability is offset by the susceptibility of this power system configuration to a single bus or switching failure. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Completion Time takes into account the capacity and capability of the remaining AC sources, reasonable time for repairs, and the low probability of a DBA occurmng during this period.

E.I With two or more DGs inoperable and an assumed loss of offsite electrical power, insufficient standby AC sources are available to power the minimum required ESF functions. Since the offsite electrical power system is the only source of AC power for the majority of ESF equipment at this level of degradation, the risk associated with continued operation for a very short time could be less than that associated with an immediate controlled shutdown. (The immediate shutdown could cause grid instability, which could result in a total loss of AC power.) Since any inadvertent unit generator trip could also re'sult in a total loss of offs-ite AC power, however, the time allowed for

'-._-continued'operatfibn is severely restricted. The intent here is to avoid the risk associated with an immediatecontrolled shutdown and to minimize the risk associated with this level of degradation.

According to Regulatory Guide 1.93 (Ref. 7), with two or more DGs inoperable, operation may continue for a period that should not exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months F.1 and F.2 If the inoperable AC electrical power sources cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SUSQUEHANNA - UNIT I TS / B 3.8-14 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES ACTIONS G.1 (continued)

Condition G corresponds to a level of degradation in which all redundancy in the AC electrical power supplies has been lost. At this severely degraded level, any further losses in the AC electrical power system will cause a loss of function. Therefore, no additional time is justified for continued operation. The unit is required by LCO 3.0.3 to commence a controlled shutdown.

SURVEILLANCE The AC sources are designed to permit inspection and testing of all REQUIREMENTS important areas and features, especially those that have a standby function, in accordance with 10 CFR 50, GDC 18 (Ref. 9). Periodic component tests are supplemented by extensive functional tests during refueling outages (under simulated accident conditions). The SRs for demonstrating the OPERABILITY of the DGs are in accordance with the recommendations of Regulatory Guide 1.9 (Ref. 3), and Regulatory Guide 1.137 (Ref. 11), as addressed in the FSAR.

The Safety Analysis for Unit 2 assumes the OPERABILITY of some on equipment that receives power from Unit I AC Sources. Therefore, 1, I ,. . , =,45 - <

_

Surveillance requirements are established for the Unit 1 onsite Class I E AC electrical power distribution subsystem(s) required to support Unit 2 by LCO 3.8.7, Distribution Systems-Operating. The Unit 1 SRs required to support Unit 2 are identified in the Unit 2 Technical Specifications.

Where the SRs discussed herein specify voltage and frequency tolerances, the following summary is applicable. The minimum steady state output voltage of 3793 V is the value assumed in the degraded voltage analysis and is approximately 90% of the nominal 4160 V output voltage. This value allows for voltage drop to the terminals of 4000 V motors whose minimum operating voltage is specified as 90% or 3600 V. It also allows for voltage drops to motors and other equipment down through the 120 V level where minimum operating voltage is also usually specified as 90% of name plate rating. The specified maximum steady state output voltage of 4400 V is equal to the

== ~~_~= _ ~_ ~_ = ~ _ ~ =~. ~ _ . - =- . - = _ . _ _ .. .

-~~-= -(continued)

E

,0.~.__

SUSQUEHANNA - UNIT I TS /B 3.8-15 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE maximum operating voltage specified for 4000 V motors. It ensures REQUIREMENTS that for a lightly loaded distribution system, the voltage at the terminals (continued) of 4000 V motors is no more than the maximum rated operating voltages. The specified minimum and maximum frequencies of the DG are 58.8 Hz and 61.2 Hz, respectively. These values are equal to

+/- 2% of the 60 Hz nominal frequency and are derived from the recommendations found in Regulatory Guide 1.9 (Ref. 3). The lower frequency limit is necessary to support the LOCA analysis assumptions for low pressure ECCS pump flow rates. (Reference 12)

The Surveillance Table has been modified by a Note, to clarify the testing requirements associated with DG E. The Note is necessary to define the intent of the Surveillance Requirements associated with the integration of DG E. Specifically, the Note defines that a DG is only considered OPERABLE and required when it is aligned to the Class I E distribution system. For example, if DG A does not meet the requirements of a specific SR, but DG E is substituted for DG A and aligned to the Class 1E distribution system, DG E is required to be OPERABLE to satisfy the LCO requirement of 4 DGs and DG A is not required to be OPERABLE because it is not aligned to the Class I E distribution system. This is acceptable because only 4 DGs are asumd nth eet-anl7urthermore, the I we

-oeidentifies

, _ ; lse:ite>if:&_f:S z____xe the Surveillance Requirements, as modified by SR Notes, have been met and performed, DG E can be substituted for any other DG and declared OPERABLE after performance of two SRs which verify switch alignment. This is acceptable because the testing regimen defined in the Surveillance Requirement Table ensures DG E is fully capable of performing all DG requirements.

SR 3.8.1.1 This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power. The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to an Operable offsite power source and that appropriate independence of offsite circuits is maintained. The 7 day Frequency is adequate since breaker position is not likely to change without the operator being aware of it and because its status is displayed in the control room.

(continued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-16 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.2 REQUIREMENTS (continued) Not Used.

SR 3.8.1.3 This Surveillance verifies that the DGs are capable of synchronizing and accepting greater than or equal to the equivalent of the maximum expected accident loads. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.

Although no power factor requirements are established by this SR, the

-DG is normally operated at a power factor between 0.8 lagging and 1.0. The 0.8'value is the design rating of the machine, while 1.0 is an operational limitation to ensure circulating currents are minimized. The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

NoteT m-diie-s -t'iSurveillance to indicate that diesel engihe runs for

-this Surveillance may include gradual loading, as recommended by the Cooper Bessemer Service Bulletin 728, so that -mechanicalstress and wear on the diesel engine are minimized. '- -

Note 2 modifies this Surveillance by stating that momentary transients because of changing bus loads do not invalidate this test. Similarly, momentary power factor transients do not invalidate the test.

Note 3 indicates that this Surveillance should be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations.

Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.

Note 5 provides the allowance that DG E, when not aligned as substitute for DG A, B, C and D but being maintained available,

_ _- nft

_- con--nue SUSQUEHANNA - UNIT 1 TS / B 3.8-17 Revision 2

PPL Rev. 3 AC Sources - Operating B.3.8.1 BASES SURVEILLANCE SR 3.8.1.3 REQUIREMENTS (continued) may use the test facility to satisfy loading requirements in lieu of synchronization with an ESS bus.

Note 6 allows a single test (instead of two tests, one for each unit) to satisfy the requirements for both units, with the DG synchronized to the 4.16 kV ESS bus of Unit 1 for one periodic test and synchronized to the 4.16 kV ESS bus of Unit 2 during the next periodic test. This is acceptable because the purpose of the test is to demonstrate the ability of the DG to operate at its continuous rating (with the exception of DG E which is only required to be tested at the continuous rating of DGs A through D) and this attribute is tested at the required Frequency. Each unit's circuit breakers and breaker control circuitry, which are only being tested every second test (due to the staggering of the tests), historically have a very low failure rate. If a DG fails this Surveillance, the DG should be considered inoperable for both units, unless the cause of the failure can be directly related to only one unit.

In addition, if the test is scheduled to be performed on the other Unit, and the other Unit's TS allowance that provides an exception to performing the test is used (i.e., the Note to SR 3.8.2.1 for the other t _ an exc n to performing this test wothe Unit is in MODE 4 or 5, or moving irradiated fuel assemblies in the secondary containment), or it is not possible to perform the test due to equipment availabililty, then the test shall be performed synchronized to this Unit's 4.16 kV ESS bus. The 31 day Frequency for this Surveillance is consistent with Regulatory Guide 1.9 (Ref. 3).

SR 3.8.1.4 This SR verifies the level of fuel oil in the engine mounted day tank is at or above the level at which fuel oil is automatically added. The level is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of 55 minutes of DG A-D and 62 minutes of DG E operation at DG continuous rated load conditions.

The 31 day Frequency is adequate to ensure that a sufficient supply of fuel oil is available, since low level alarms are provided and operators would be aware of any large uses of fuel oil during this period.

-(continued)

SUSQUEHANNA - UNIT 1 T S / B 3.8-18 Revision 3

PPL Rev. 3 AC Sources - Operating B .3.8.1 BASES SURVEILLANCE SR 3.8.1.5 REQUIREMENTS (continued) Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Removal of water from the engine mounted day tanks once every 31 days eliminates the necessary environment for bacterial survival. This is the most effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and breakdown of the fuel oil by bacteria. Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequencies are established by Regulatory Guide 1.137 (Ref. 11). This SR is for preventive maintenance. The presence of water does not necessarily represent a failure of this SR provided that accumulated water is removed during performance of this Surveillance.

SR 3.8.1.6

_> aim -,r,.S4_4aFa :

This Surveillan&e demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from- its associated storage tank to its associated day tank. It is required to support continuous operation of standby power sources. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERABLE.

-~ ~

=~- -- ---- ~-~- - -- ~(c ntinued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-1 9 Revision 2

PPL Rev. 3 AC Sources - Operating B.3.8.1 BASES SURVEILLANCE SR 3.8.1.6 (continued)

REQUI REMENTS The Frequency for this SR is 31 days because the design of the fuel transfer system requires that the transfer pumps operate automatically.

Administrative controls ensure an adequate volume of fuel oil in the day tanks. This Frequency allows this aspect of DG Operability to be demonstrated during or following routine DG operation.

SR 3.8.1.7 This SR helps to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and maintain the unit in a safe shutdown condition.

To minimize the wear on moving parts that do not get lubricated when the engine is not running, this SR has been modified by Note 1 to indicate that all DG starts for these Surveillances may be preceded by an engine prelube period (which for DGs A through D includes operation of the lube oil system to ensure the DGs turbo charger is sufficiently prelubicated to prevent undo wear and tear).

. =For the purposes of this testing, the DGs are started from standby conditions. Standby conditions for a DG mean that the diesel engine oil is being continuously circulated and diesel engine coolant is being circulated as necessary to maintain temperature consistent with manufacturer recommendations. The DG starts from standby conditions and achieves the minimum required voltage and frequency within 10 seconds and maintains the required voltage and frequency when steady state conditions are reached. The 10 second start requirement supports the assumptions in the design basis LOCA analysis of FSAR, Section 6.3 (Ref. 12).

To minimize testing of the DGs, Note 2 allows a single test to satisfy the requirements for both units (instead of two tests, one for each unit).

This is acceptable because this test is intended to demonstrate attributes of the DG that are not associated with either Unit. If the DG fails this Surveillance, the DG should be considered inoperable for both (continued)

SUSQUEHANNA - UNIT I TS / B3.8-20 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1

-BASES REQUIREMENTS SR 3.8.17 (conitinhued)

SURVEILLANCE units, unless the cause of the failure can be directly related to one unit The time for the DG to reach steady state operation is periodically monitored and the trend evaluated to identify degradation.

The 31 day Frequency is consistent with Regulatory Guide 1.9 (Ref. 3). This Frequency provides adequate assurance of DG OPERABILITY.

SR 3.8.1.8 Transfer of each 4.16 kV ESS bus power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of' the alternate circuit distribution network to power the shutdown loads. The 24 month Frequency of the Surveillance is based on engineering judgment taking into consideration the plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed on the 24 Moth Frequency. There~fore, _theFrequency was concluded to

~ be acceptable from a reliability standpoint.

This SR is modified by a Note- The.reason for the'-Note is that, during operation with the reactor critical, performance of the automatic transfer of the unit power supply could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, plant safety systems. The manual transfer of unit power supply should not result in any perturbation to the electrical distribution system, therefore, no mode restriction is specified.

This Surveillance tests the applicable logic associated with Unit 1. The comparable test specified in Unit 2 Technical Specifications tests the applicable logic associated with Unit 2. Consequently, a test must be performed within the specified Frequency for each unit. As the Surveillance represents separate tests, the Note specifying the restriction for not performing the test while the unit is in MODE I or 2 does not have applicability to Unit 2. The NOTE

- I - 7co tnu-ed)--

-I'- ._1_-________ _ - - .I SUSQUEHANNA -UNIT I S/B3821Rvso TS / B 3.8-21 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.8 (continued)

REQUIREMENTS only applies to Unit 1, thus the Unit 1 Surveillance shall not be performed with Unit 1 in MODE 1 or 2.

SR 3.8.1.9 Each DG is provided with an engine overspeed trip to prevent damage to the engine. Recovery from the transient caused by the loss of a large load could cause diesel engine overspeed, which, if excessive, might result in a trip of the engine. This Surveillance demonstrates the DG load response characteristics and capability to reject the largest single load without exceeding predetermined voltage and frequency and while maintaining a specified margin to the overspeed trip. The largest single load for each DG is a residual heat removal (RHR) pump (1425 kW). This Surveillance may be accomplished by:

a. Tripping the DG output breaker with the DG carrying greater than or equal to its associated single largest post-accident load while paralleled to offsite power, or while solely supplying the bus; or

b. pping s associaed single largest post-accident load with the

' DG solely supplying the bus.

As recommended by Regulatory Guide 1.9 (Ref. 3), the load rejection test is acceptable if the increase in diesel speed does not exceed 75%

of the difference between synchronous speed and the overspeed trip setpoint, or 15% above synchronous speed, whichever is lower. For DGs A, B, C, D and E, this represents 64.5 Hz, equivalent to 75% of the difference between nominal speed and the overspeed trip setpoint.

The time, voltage, and frequency tolerances specified in this SR are derived from Regulatory Guide 1.9 (Ref. 3) recommendations for response during load sequence intervals. The 4.5 seconds specified is equal to 60% of the 7.5 second load sequence interval between loading of the RHR and core spray pumps during an undervoltage on the bus concurrent with a LOCA. The 6 seconds specified is equal to 80% of that load sequence interval. The voltage and frequency specified are (continued)

SUSQUEHANNA- UNIT 1 TS / B 3.8-22 Revision 3

PPL Rev. 3 AC Sources - Operating 8 3.8.1

',BASES SURVEILLANCE SR 3.8.1.9 (continued)

REQUIREMENTS consistent with the design range of the equipment powered by the DG.

SR 3.8.1.9.a corresponds to the maximum frequency excursion, while SR 3.8.1.9.b and SR 3.8.1.9.c specify the steady state voltage and frequency values to which the system must recover following load rejection.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3) and is intended to be consistent with expected fuel cycle lengths.

To minimize testing of the DGs, a Note allows a single test to satisfy the requirements for both units (instead of two tests, one for each unit). This is acceptable because this test is intended to demonstrate attributes of the DG that are not associated with either Unit. If the DG fails this Surveillance, the DG should be considered inoperable for both units, unless the cause of the failure can be directly related to only one unit.

SR 3.8.1.10 f _This Surveillance demonstrates the DG capability to reject a full load without overspeed tripping or exceeding the predetermined voltage limits. The DG full load rejection may occur because 6f a system fault or inadvertent breaker tripping. This Surveillance ensures proper engine generator load response under the simulated test conditions.

This test simulates the loss of the total connected load that the DG experiences following a full load rejection and verifies that the DG does not trip upon loss of the load. These acceptance criteria provide DG damage protection. While the DG is not expected to experience this transient during an event, and continues to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.

-7 continued)

SUSQUEHANNA - UNIT 1 TS / B3.8-23 Revision 3

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 (continued)

REQUIREMENTS To minimize testing of the DGs, a Note allows a single test to satisfy the requirements for both units (instead of two tests, one for each unit).' This is acceptable because this test is intended to demonstrate attributes of the DG that are not associated with either Unit. If the DG fails this Surveillance, the DG should be considered inoperable for both units, unless the cause of the failure can be directly related to only one unit.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3) and is intended to be consistent with expected fuel cycle lengths.

SR 3.8.1.11 As required by Regulatory Guide 1.9 (Ref. 3), this Surveillance demonstrates the as designed operation of the standby power sources during loss of the offsite source. This test verifies all actions encountered from the loss of offsite power, including shedding of the nonessential loads and energization of the ESS buses and respective 4.16kV lads Tfrom the DG. It further demonstrates the capability of the DG to automatically achieve and maintain the required voltage and frequency within the specified time.

The DG auto-start time of 10 seconds is derived from requirements of the licensed accident analysis for responding to a design basis large break LOCA. The Surveillance should be continued for a minimum of 5 minutes in order to demonstrate that all starting transients have decayed and stability has been achieved.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3), takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

. 1

.I kVVI ILII lUV:UJ SUSQUEHANNA - UNIT 1 TS I B 3.8-24 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.11 (continued)

REQUIREMENTS This SR is modified by three Notes. The reason for Note I is to minimize wear and tear on the DGs during testing. Note 1 allows all DG starts to be preceded by an engine prelube period (which for DGs A through D includes operation of the lube oil system to ensure the DG's turbo charger is sufficiently prelubicated). For the purpose of this testing, the DGs shall be started from standby conditions that is, with the engine oil being continuously circulated and engine coolant being circulated as necessary to maintain temperature consistent with manufacturer recommendations.

This SR is also modified by Note 2. The Note specifies when this SR is required to be performed for the DGs and the 4.16 kV ESS Buses.

The Note is necessary because this SR involves an integrated test between the DGs and the 4.16 kV ESS Buses and the need for the testing regimen to include DG E being-tested (substituted for all DGs for both Units) with all 4.16 kV ESS Buses. To ensure the necessary testing is performed, the following rotational testing regimen has been established:

__________ UNIT IN OUTAGE - DIESEL E SUBSTITUTED FOR 2 DG E-nottested-1 Diesel Generator D 2 Diesel Generator A I DG E not tested 2 Diesel Generator B I Diesel Generator A 2 Diesel Generator C 1 Diesel Generator B 2 Diesel Generator D 1 Diesel Generator C The specified rotational testing regimen can be altered to facilitate unanticipated events which render the testing regimen impractical to implement, but any alternative (continued)

SUSQUEHANNA-UNIT 1 TS /B 3.8-25 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.11 (continued)

REQUIREMENTS testing regimen must provide an equivalent level of testing. This SR does not have to be performed with the normally aligned DG when the associated 4.16 kV ESS bus is tested using- DG E and DG E does not need to be tested when not substituted or aligned to the Class I E distribution system. The allowances specified in the Note are acceptable because the tested attributes of each of the five DGs and each unit's four 4.16 kV ESS buses are verified at the specified Frequency (i.e., each DG and each 4.16 kV ESS bus is tested every 24 months). Specifically, when DG E is tested with a Unit 1 4.16 kV ESS bus, the attributes of the normally aligned DG, although not tested with the Unit 1 4.16 kV ESS bus, are tested with the Unit 2 4.16 kV ESS bus within the 24 month Frequency. The testing allowances do result in some circuit pathways which do not need to change state (i.e., cabling) not being tested on a 24 month Frequency. This is acceptable because these components are not required to change state to perform their safety function and when substituted--normal operation of DG E will ensure continuity of most of the cabling not tested.

W, ___ -P The" rea6so6Hfor __t31~_s'that perfor-min--

g-t~he,&irv S6"Ulanhce would r~emove a required offsite -circuit from service, perturb the electrical distribution system, and challenge safety-systenis. This Surveillance tests the applicable logic associated with Unit 1. The comparable test specified in the Unit 2 Technical Specifications tests the applicable logic associated with Unit 2. Consequently, a test must be performed within the specified Frequency for each unit. As the Surveillance represents separate tests, the Note specifying the restriction for not performing the test while the unit is in MODE 1,2, or 3 does not have applicability to Unit 2. The Note only applies to Unit 1,thus the Unit I Surveillances shall not be performed with Unit I in MODES 1,2 or 3.

SR 3.8.1.12 This Surveillance demonstrates that the DG automatically starts and achieves the required voltage and frequency within the specified time (10 seconds) from the design basis actuation signal (LOCA signal) and operates for Ž5 minutes. The 5 minute period provides sufficient time to demonstrate

.(continued

- 7-----

SUSQUEHANNA - UNIT 1B.-6Rvso I TS / B 3.8-26 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1

= ~BASES SURVEILLANCE SR 3.8.1.12 (continued)

REQUIREMENTS stability. SR 3.8.1.12.d and SR 3.8.1.12.e ensure that permanently connected loads and emergency loads are energized from the offsite electrical power system on a LOCA signal without loss of offsite power.

The requirement to verify the connection and power supply of permanent and autoconnected loads is intended to satisfactorily show the relationship of these loads to the loading logic for loading onto offsite power. In certain circumstances, many of these loads cannot actually be connected or loaded without undue hardship or potential for undesired operation. For instance, ECCS injection valves are not desired to be stroked open, high pressure injection systems are not capable of being operated at full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of operation. In lieu of actual demonstration of the connection and loading of these loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable. This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified. SR 3.8.1.12.a through-SR 3.8.1.12.d are

- 'twth'e MDG running. b f K- -when the DG is not running.

The Frequency of 24 months takes into consideration-plant conditions required to perform the Surveillance and is intended to be consistent with the expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency. Therefore, the Frequency is acceptable from a reliability standpoint.

This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. Note I allows all DG starts to be preceded by an engine prelube period (which for DG A through D includes operation of the lube oil system to ensure the DG's turbo-charger is sufficiently prelubicated). For the purpose of this testing, the DGs must be started from standby conditions that is, with the engine oil being continuously circulated and engine coolant being circulated as necessary to maintain temperature consistent with manufacturer recommendations.

.. (continued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-27 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.13 REQUIREMENTS (continued) The reason for Note 2 is to allow DG E, when not aligned as substitute for DG A, B, C or D to use the test facility to satisfy loading requirements in lieu of aligning with the Class 1E distribution system.

When tested in this configuration, DG E satisfies the requirements of this test by completion of SR 3.8.1.12.a, b and c only. SR 3.8.1.12.d and 3.8.1.12.e may be performed by any DG aligned with the Class IE distribution system or by any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.

This Surveillance demonstrates that DG non-critical protective functions (e.g., high jacket water temperature) are bypassed on an ECCS initiation test signal. The non-critical trips are bypassed during DBAs and provide an alarm on an abnormal engine condition. This alarm provides the operator with sufficient time to react appropriately.

The DG availability to mitigate the DBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG.

The 24 month Frequency is based on engineering judgment, takes into M ideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

Operating experience has shown thafthese components usually pass the.SR when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

The SR is modified by two Notes. To minimize testing of the DGs, Note 1 to SR 3.8.1.13 allows a single test (instead of two tests, one for each unit) to satisfy the requirements for both units. This is acceptable because this test is intended to demonstrate attributes of the DG that are not associated with either Unit. If the DG fails this Surveillance, the DG should be considered inoperable for both units, unless the cause of the failure can be directly related to only one unit.

Note 2 provides the allowance that DG E, when not aligned as a substitute for DG A, B, C, and D but being maintained available, may use a simulated ECCS initiation signal.

continued)

SUSQUEHANNA - UNIT 1 TS / B3.8-28 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8. 1 BASES SURVEILLANCE SR 3.8.1.14 REQUIREMENTS (continued) Regulatory Guide 1.9 (Ref. 3), requires demonstration once per 24 months that the DGs can start and run continuously at full load capability for an interval of not less than 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s-22 hours of which is at a load equivalent to 90% to 100% of the continuous rating of the DG, and 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of which is at a load equivalent to 105% to 110% of the continuous duty rating of the DG. SSES has taken exception to this requirement and performs the two hour run at the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating for each DG. The requirement to perform the two hour overload test can be performed in any order provided it is performed during a single continuous time period.

The DG starts for this Surveillance can be performed either from standby or hot conditions. The provisions for prelube discussed in SR 3.8.1.7, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.

A load band is provided to avoid routine overloading of the DG.

Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3), takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths, This Surveillance has been modified by four Notes. Note 1 states that momentary transients due to changing bus loads do not invalidate this test.

To minimize testing of the DGs, Note 2 allows a single test (instead of two tests, one for each unit) to satisfy the requirements for both units.

This is acceptable because this test is intended to demonstrate attributes of the DG that are not associated with either Unit. If the DG fails this Surveillance, the DG should be considered inoperable for both units, unless the cause of the failure can be directly related to only one unit.

Note 3 stipulates that DG E, when not aligned as substitute for DG A, B, C or D but being maintained available, may use I I -- I (continued)

ED_ = .

. I - A'. . .: - =,- _ - - I-A SUSQUEHANNA - UNIT I TS / B3.829 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued)

REQUIREMENTS the test facility to satisfy the specified loading requirements in lieu of synchronization with an ESS bus.

SR 3.8.1.15 This Surveillance demonstrates that the diesel engine can restart from a hot condition, such as subsequent to shutdown from full load temperatures, and achieve the required voltage and frequency within 10 seconds. The 10 second time is derived from the requirements of the accident analysis to respond to a design basis large break LOCA.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3), takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

This SR is modified by three Notes. Note I ensures that the test is performed with the diesel sufficiently hot. The requirement that the diesel has operated for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months at full load conditions prior to performance of this Surveillance is based on manufacturer

--- ------- -- - -- recommendations for achieving hot conditions. The load band is provided to avoid routine overloading of the DG.- Routine overloads may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

Momentary transients due to changing bus loads do not invalidate this test.

Note 2 allows all DG starts to be preceded by an engine prelube period (which for DGs A through D includes operation of the lube oil system to ensure the DGs turbo charger is sufficiently prelubricated) to minimize wear and tear on the diesel during testing.

To minimize testing of the DGs, Note 3 allows a single test to satisfy the requirements for both units (instead of two tests, one for each unit). This is acceptable because this test is intended to demonstrate attributes of the DG that are not associated with either Unit. If the DG fails this Surveillance, the DG should be considered inoperable for both units, unless the cause of the failure can be directly related to only one unit.

continued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-30 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.16 REQUIREMENTS (continued) As required by Regulatory Guide 1.9 (Ref. 3), this Surveillance ensures that the manual synchronization and automatic load transfer from the DG to the offsite source can be made and that the DG can be returned to ready-to-load status when offsite power is restored. It also ensures that the auto-start logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs. The DG is considered to be in ready-to-load status when the DG is at rated speed and voltage, the DG controls are in isochronous and the output breaker is open.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3), takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

This SR is modified by a note to accommodate the testing regimen necessary for DG E. See SR 3.8.1.1 1 for the Bases of the Note.

SR 3.8.1.17

- A d- <Demonstration of the test mode override ensures that the DG

_-availability under accident conditions is not compromised as the result of testing. Interlocks to the LOCA seinsing circuits cause the DG to

- automatically reset to ready-to-load operation if an ECCS initiation signal is received during operation in the test mode. Ready-to-load operation is defined as the DG running at rated speed and voltage, the DG controls in isochronous and the DG output breaker open. These provisions for automatic switchover are required by IEEE-308 (Ref. 10), paragraph 6.2.6(2).

The requirement to automatically energize the emergency loads with offsite power is essentially identical to that of SR 3.8.1.12. The intent in the requirements associated with SR 3.8.1.17.b is to show that the emergency loading is not affected by the DG operation in test mode. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the emergency loads to perform these functions is acceptable. This test is performed by verifying that after the DG is tripped, the offsite source originally in parallel with the DG, remains connected to the (continugad)-

SUSQUEHANNA - UNIT I TS I B 3.8-31 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.17 (continued)

REQUIREMENTS affected 4.16 kV ESS Bus. SR 3.8.1.12 is performed separately to verify the proper offsite loading sequence.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3), takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

This SR is modified by a note to accommodate the testing regimen necessary for DG E. See SR 3.8.1.1 1 for the Bases of the Note.

SR 3.8.1.18 Under accident conditions, loads are sequentially connected to the bus by individual load timers Which control the permissive and starting signals to motor breakers to prevent overloading of the AC Sources due to high motor starting currents. The load sequence time interval tolerance ensures that sufficient time exists for the AC Source to restore frequency an-d volt-age prio-r to applying the next load and that

~~~a f e t fey analysis -assumptionsmrgarding q ipet r timre delays a-r-no i ted-Reference provi es asummaryo auomti loading of ESS buses. A list of the req-uired timees and the associated setpoints are included in the Bases as Table B 3.8;.1-, Unit I and Unit 2 Load Timers. Failure of a timer identified as an offsite power timer may result in both offsite sources being inoperable. Failure of any other timer may result in the associated DG being inoperable. A timer is considered failed for this SR if it will not ensure that the associated load will energize within the Allowable Value Lo Table B 3.8.1-1. These conditions will require entry into applicable Conditions of this specification. With a load timer inoperable, the load can be rendered inoperable to restore OPERABILITY to the associated AC sources. In this condition, the Condition and Required Actions of the associated specification shall be entered for the equipment rendered inoperable.

The 24 month Frequency is consistent with the recommendation of Regulatory Guide 1.9 (Ref. 3), takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

SUSQUEHANNA - UNIT I TS /B 3.8-32 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.18 (continued)

REQUIREMENTS This SR is modified by a Note that specifies that load timers associated with equipment that has automatic initiation capability disabled are not required to be Operable. This is acceptable because if the load does not start automatically, the adverse effects of an improper loading sequence are eliminated. Furthermore, load timers are associated with individual timers such that a single timer only affects a single load.

SR 3.8.1.19 In the event of a DBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to ESF systems so that the fuel, RCS, and containment design limits are not exceeded.

This Surveillance demonstrates DG operation, as discussed in the Bases for SR 3.8.1.11, during a loss of offsite power actuation test signal in conjunction with an ECCS initiation signal. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions Is acceptable. This testing may Include any seres of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified. To simulate the n6n-LOCA unit 4.16 kV ESS Bus loads on the DG, bounding loads are energized on the tested 4.16 kV ESS Bus after all auto connected energizing loads are energized.

The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance and is intended to be consistent with an expected fuel cycle length. This SR is modified by three Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. Note 1 allows all DG starts to be preceded by an engine prelube period (which for DGs A through D includes operation of the lube oil system to ensure the DG's turbo charger is sufficiently prelubricated.) For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine oil being continuously circulated and engine coolant being circulated as necessary to maintain temperature consistent with manufacturer recommendations.

- . -- - .- -. .. ti ued)

SUSQUEHANNA - UNIT 1 TS / B 3.8-33 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES.

SURVEILLANCE SR 3.8.1.19 (continued)

REQUIREMENTS Note 2 is necessary to accommodate the testing regimen associated with DG E. See SR 3.8.1.11 forthe Bases of the Note.

The reason for Note 3 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems. This Surveillance tests the applicable logic associated with Unit 1. The comparable test specified in the Unit 2 Technical Specifications tests the applicable logic associated with Unit 2. Consequently, a test must be performed within the specified Frequency for each unit. As the Surveillance represents separate tests, the Note specifying the restriction for not performing the test while the unit is in MODE 1, 2 or 3 does not have applicability to Unit 2. The Note only applies to Unit 1, thus the Unit 1 Surveillances shall not be performed with Unit 1 in MODE 1, 2 or 3.

SR 3.8.1.20 This Surveillance demonstrates that the DG starting independence has not been compromised. Also, this Surveillance demonstrates that

- engine can aheve p hin the specified time when the DGs are started simultaneously. The 10 year Frequency is consistent with the recommendations bf Regulatory Guide 1.9 (Ref. 3).

This SR is modified by two Notes. The reason for Note I is to minimize wear on the DG during testing. The Note allows all DG starts to be preceded by an engine prelube period (which for DGs A through D includes operation of the lube oil system to ensure the DG's turbo charger is sufficiently prelubricated). For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine oil continuously circulated and engine coolant being circulated as necessary to maintain temperature consistent with manufacturer recommendations.

Note 2 is necessary to identify that this test does not have to be performed with DG E substituted for any DG. The allowance is acceptable based on the design of the DG E transfer switches.

The transfer of control, protection, indication, O(continuedM)

SUSQUEHANNA - UNIT 1 TS / B3.8-34 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.20 (continued)

REQUIREMENTS and alarms is by switches at two separate locations. These switches provide a double break between IDG Eand the redundant system within the transfer switch panel. The transfer of power is through circuit breakers at two separate locations for each redundant system. There are four normally empty switch gear positions at IDG E facility, associated with each of the four existing DGs. Only one circuit breaker is available at this location to be inserted into one of the four positions.

At each of the existing DGs, there are two switchgear positions with only one circuit breaker available. This design provides two open circuits between redundant power sources. Therefore, based on the described design, it can be concluded that DG redundancy and independence is maintained regardless of whether IDG E is substituted for any other DG.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.

2. FSAR, Section 8.2.

3. Regulatory Guide 1.9.

~ 4. FSAR, Chapter 6.-

5. FSAR, Chapter 15.

6. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).

7. Regulatory Guide 1.93.

8. Generic Letter 84-15.

9. 10OCFR 50,Appendix A, GDC 18.

10. IEEE Standard 308.

11. Regulatory Guide 1.137.

12. FSAR, Section 6.3.

13. ASME Boiler and Pressure Vessel Code, Section Xi.

- -- ---- ---- --- con tin ued)

SUSQUEHANNA -UNITI TSB1-5Rvso TS / B 3.8-35 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1 AM** TUTAB 3.8.1-- _2 (page - =..

_-_ 1 of UNIT I AND UNIT 2 LOAD TIMERS NOMINAL DEVICE SETTING ALLOWABLE VALUE TAG NO. SYSTEM LOADING TIMER LOCATION (seconds) (seconds) 62A-20102 RHR Pump 1A 1A201 3 2 2.7 and* 3.6 62A-20202 RHR Pump 1B 1A202 3 2.7 and S3.6 62A-20302 RHR Pump 1C 1A203 3 2.7 and

3.6 62A-20402 RHR Pump 1D 1A204 3 2.7 and S3.6 62A-20102 RHR Pump 2A 2A201 3 2 2.7 and S3.6 62A-20202 RHR Pump 2B 2A202 S 3 22.7 and S3.6 62A-20302 RHR Pump 2C 2A203 3 2 2.7 and S 3.6 .-. . . I --- E 1I, 62A-20402 I.

RHR Pump 2D 2A204 3 2 2.7 and < 3.6 ft~v

- 4 4 4 E11 A-K2B9R RH.R Piimn 1 C'.- (fnfita Power Timer) 1C161R 7.0 >--. 6.5 and < 7.5

-.... - .-.--.. _ _ _ _ _ _ _ _ _ 4 E11 A-KI20A RHR Pump 1C (Offsite Power Timer) 1C617 7.0 2 6.5 and s 7.5 El

.A-K 2013 RHR Pump ID (Offste Power Timer) 10618 7.0 Ž6.5 and5 *7.5 E11 A-K202A RHR Pump 1D (Offsite. Power Timer) 1C617 7.0 Ž6.5 and s7.5 ElI A-K1 20A RHR Pump 20 (Offsite Power Timer) 2C617 7.0 Ž6.5 and s 7.5 E11 A-K202A RHR Pump 2C (Offsite Power Timer) 2C618 7.0 Ž6.5 and s7.5 E11 A-KI20B RHR Pump 2C (Offsite Power Timer) 2C618 7.0 Ž6.5 and s7.5 E11 A-K202A RHR Pump 2D (Offsite Power Timer) 2C617 7.0 Ž6.5 and s7.5 E21A-K116A CS Pump IA 1C626 10.5 2Ž9.4 and* 11.6 E21A-K116B CS Pump 1B 1C627 10.5 2Ž9.4 and *11.6 E21 A-K125A CS Pump 1C 1C626 10.5 2Ž9.4 and*S 11.6 E21A-K125B CS Pump I D 1C627 10.5 2Ž9.4 and* 11.6 MP' E21 A-K116A CS Pump 2A 2C626 10.5 2 9.4 and*s 11.6 E21A-K116B CS Pump 2B 2C627 10.5 - 29.4 and* 11.6 E21 A-K1 25A CS Pump 2C 2C626 10.5 29.4 and S 11.6 E21A-K125B CS Pump 2D 2C627 105 2 9.4 and S 11.6 E21 A-K1 6A CS Pump IA (Offsite Power Timer) 1C626 15 > 14.0 and S 16.0 E21 A-K16B CS Pump 1B (Offsite Power Timer) I C627 15 2 14.0 and S 16.0 E21 A-K25A CS Pump I C (Offsite Power Timer) 1C626 15 2 14.0 and S 16.0 E21 A-K25B CS Pump 1D (Offsite Power Timer) 1C627 15 2 14.0 and S 16.0 E21 A-K1 6A CS Pump 2A (Offsite Power Timer) 2C626 15 2 14.0 and S 16.0 E21 A-K1168 CS Pump 28 (Offsite Power Timer) 2C627 15 2 14.0 and S 16.0 E21 A-K25A CS Pump 2C (Offsite Power Timer) 2C626 15 2 14.0 and S 16.0 E21 A-K25B CS Pump 2D (Offsite Power Timer) 2C627 15 2Ž14.0 and s 16.0 62AX2-20108 Emergency Service Water 1A201 40 2 36 and S 44 62AX2-20208 Emergency Service Water 1A202 40 2Ž36 and S 44 62AX2-20303 Emergency Service Water 1A203 44 >39.6 and S 48.4 62AX2-20403 Emergency Service Water 1A204 48 2 43.2 and

52.8 62X3-20404 Control Structure Chilled Water System OC877B 60 2 54 62X3-20304 Control Structure Chilled Water System OC877A 60 2Ž54 62X-20104 Emergency Switchgear Rm Cooler A & OC877A 60 254

__________RHR SW Pump H&V Fan A ______

62-X-20204 Emergency Switchgear Rm Cooler B & 00877B 60 Ž54 62X-20204 __ RHR SW Pump H&V Fan B OC87B 602 S 62X-5653A DG Room Exhaust Fan E3 OB565 60 254 62X-5652A DG Room Exhausts Fan E4 OB565 60 2 54 262X-20204 Emergency Switchgear Rm Cooler B OC877B 120 254 262X-20104 Emergency Switchgear Rm Cooler-A OC877A 120 2 54 (continued)

SUSQUEHANNA-UNIT I TS I B 3.8-36 Revision 2

PPL Rev. 3 AC Sources - Operating B 3.8.1

.- - - = -- - . - -, - _ =_ =. , = .-- ; , ,.- - ,

TABLE B 3.8.1-1 (page 2 of 2)

UNIT 1AND UNIT 2 LOAD TIMERS

- --.1..----- - ----- 1---l-NOMINAL DEVICE ALLOWABLE VALUE TAG NO. SYSTEM LOADING TIMER LOCATION (seconds) (seconds) 62X-546 DG Rm Exh Fan D OB546 120 2 54 62X-536 DG Rm Exh Fan C OB536 120 2 54 62X-526 DG Rm Exh Fan B OB526 120 2 54 62X-516 DG Rm Exh Fan A OB516 120 Ž54 CRX-5652A DG Room Supply Fans El and E2 OB565 120 2 54 62X2-2041 0 Control Structure Chilled Water System OC876B 180 2 54 62X1 -20304 Control Structure Chilled Water System OC877A 180 2 54 62X2-2031 0 Control Structure Chilled Water System OC876A 180 2 54 62X1 -20404 Control Structure Chilled Water System OC877B 180 2 54 62X2-20304 Control Structure Chilled Water System OC877A 210 Ž54 62X2-20404 Control Structure Chilled Water System OC877B 210 Ž54 62X-KI BB Emergency Switchgear Rm Cooling2C2BŽ52CB250B 260 62X-K1 1BB Compressor B 54

,- I -_, , -, ,.

62X-K1IAB Emergency Switchgear Rm Cooling 2CB250A - 260 2 54 Compressor A . :

SUSQUEHANNA - UNIT I ITS / B 3.8-37 Revision 2

PPL Rev. 1 Distribution Systems-Operating B 3.8.7 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.7 Distribution Systems-Operating BASES BACKGROUND The onsite Class 1E AC and DC electrical power distribution system is divided into redundant and independent AC and DC electrical power distribution subsystems and a DG E electrical power distribution subsystem.

The primary AC distribution system consists of four 4.16 kV Engineered Safeguards System (ESS) buses each having a primary and alternate offsite source of power as well as an onsite diesel generator (DG) source that supports one 4.16 kV ESS bus in each unit. Each 4.16 kV ESS bus is normally supplied by either Startup Transformer (ST) No. 10 or ST No. 20. ST No. 10 and ST No. 20 each provide the normal source of power to two of the four 4.16 kV ESS buses in each Unit and the alternate source of power to the remaining two 4.16 kV ESS buses in each Unit. If any 4.16 kV ESS bus loses power, an automatic transfer from the normal to the alternate occurs after the normal supply breaker trips. If both offsite sources are uMMnavilb, the onsite emergency D~Gs sup~ply power to the 4.16 kV god . <... sl: ESS buses.

There are two 250 VDC electrical power distribution subsystems, four 125 VDC electrical power distribution subsystems, and one 125 VDC DG E electrical power distribution subsystem, all of which support the necessary power for ESF functions.

In addition, some components required by Uoit 2 receive power through Unit 1 electrical power distribution subsystems, the Unit I AC and DC electrical power distribution subsystems needed to support the required equipment are addressed in Unit 2 LCO 3.8.7.

Required distribution subsystems are listed in LCO 3.8.7, Table 3.8.7-1.

APPLICABLE The initial conditions of Design Basis Accident (DBA) and SAFETY ANALYSES transient analyses in the FSAR, Chapter 6 (Ref. 1) and Chapter 15 (Ref. 2), assume ESF systems are OPERABLE. The AC and DC electrical power distribution systems are designed

-- continued)

SUSQUEHANNA- UNIT 1 B. 3.8-78 Revision 0

PPL Rev. I Distribution Systems-Operating B 3.8.7 BASES APPLICABLE to provide sufficient capacity, capability, redundancy, and reliability to SAFETY ANALYSES ensure the availability of necessary power to ESF systems so that the (continued) fuel, Reactor Coolant System, and containment design limits are not exceeded. These limits are discussed in more detail in the Bases for Section 3.2, Power Distribution Limits; Section 3.4, Reactor Coolant System (RCS); and Section 3.6 Containment Systems.

The OPERABILITY of the AC and DC electrical power distribution subsystems is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the unit. This includes maintaining distribution systems OPERABLE during accident conditions in the event of:

a. An assumed loss of all offsite power or all onsite AC electrical power; and

b. A worst case single failure.

The AC and DC electrical power distribution system satisfies Criterion 3 of the NRC Policy Statement (Ref. 4).

LCO The required electrical power distribution subsystems listed in Table 3.8.7-1 ensure the availability of AC and DC electrical power for the systems required to shut down the reactor and maintain it in a safe condition after an anticipated operational occurrence (AOO) or a postulated DBA. The AC and DC electrical power distribution subsystems are required to be OPERABLE.

Maintaining the AC and DC electrical power distribution subsystems OPERABLE ensures that the redundancy incorporated into the design of ESF is not defeated. Therefore, a single failure within any system

--or within the electrical power distribution subsystems will not prevent safe shutdown of the reactor. -

AC electrical power distribution subsystems require the associated buses and electrical circuits to be energized to their proper voltages.

DC electrical power distribution subsystems require the associated buses to be energized to their proper voltage from either the associated battery or-charger. The AC and DC electrical power distribution b- - ~ -

(continued)

SUSQUEHANNA - UNIT 1 B. 3.8-79 Revision 0

PPL Rev. 1 Distribution Systems-Operating B 3.8.7 w=-- ,BASES LCO subsystem is only considered Inoperable when the subsystem is not (continued) energized to its proper voltage.

APPLICABILITY The electrical power distribution subsystems are required to be OPERABLE in MODES 1, 2, and 3 to ensure that:

a. Acceptable fuel design limits and reactor coolant pressure boundary limits are not exceeded as a result of AQOs or abnormal transients; and

b. Adequate core cooling is provided, and containment OPERABILITY and other vital functions are maintained in the event of a postulated DBA.

Electrical power distribution subsystem requirements for MODES 4 and 5 are covered in the Bases for LCO 3.8.8, "Distribution Systems-Shutdown."

- _ACTIONS A.1 With one or more required AC busesload centers, rnotor control centers, or distribution panels inoperable but not resulting in a loss of safety function, the remaining AC electrical power distribution subsystems are capable of supporting the minimum safety functions necessary to shut down the reactor and maintain it in a safe shutdown condition, assuming no single failure. The overall reliability is reduced, however, because a single failure in the remaining power distribution subsystems could result in the minimum required ESF functions not being supported. Therefore, the required AC buses, load centers, motor control centers, and distribution panels must be restored to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

The Condition A worst scenario is one division without AC power (i.e., no offsite power to the division and the associated DG inoperable). In this Condition, the unit is more vulnerable to a complete loss of AC power. It is, therefore, imperative that the unit operators' attention be focused on minimizing the potential for loss of power to the remaining division by stabilizing the unit, and on restoring power to the affected division. The 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months time limit

_ - (continued)

-; a-. L L=_- _ =--

SUSQUEHANNA- UNIT 1 B. 3.8-80 Revision 0

PPL Rev. 1 Distribution Systems-Operating B 3.8.7

. BASES ACTIONS A.1 (continued) before requiring a unit shutdown in this Condition is acceptable because

a. There is a potential for decreased safety if the attention of unit operators is diverted from the evaluations and actions necessary to restore power to the affected division to the actions associated with taking the unit to shutdown within this time limit.

b. The potential for an event in conjunction with a single failure of a redundant component in the division with AC power. (The redundant component is verified OPERABLE in accordance with Specification 5.5.11, "Safety Function Determination Program (SFDP).")

The second Completion Time for Required Action A.1 establishes a limit on the maximum time allowed for any combination of required distribution subsystems to be inoperable during any single continuous occurrence of failing to meet LCO 3.8.7. If Condition A is entered while, for instance, a DC bus is inoperable and subsequently returned OPERABLE, this LCO may already have been not met for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . This situation could lead to a total duration of 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months , since initial failure of the LCO, to restore the AC distribution system. At this time a DC circuit could again become inoperable, and AC distribution could be restored OPERABLE.

ThIls could continue indefinitely e This Completion Time allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." This results in establishing the "time zero" at the time this LCO was initially not met, instead of at the time Condition A was entered. The 16 hour1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months Completion Time is an acceptable limitation on this potential to fail to meet the LCO indefinitely.

The completion time exception is not applicable to Condition D or E because Conditions D and E are only applicable to DG E DC electrical power subsystem.

Condition A is modified by a Note that states that Condition A is not applicable to the DG E DC electrical power subsystem. Condition D or E is applicable to an inoperable DG E DC electrical power subsystem.

Required Action A.1 is modified by a Note that requires the applicable Conditions and Required Actions of LCO 3.8.4 "DC Sources - Operating,"

to be entered for DC subsystems made inoperable by inoperable AC electrical power distribution subsystems. This is an exception to LCO 3.0.6 and ensures the proper actions are taken for inoperable DC sources. Inoperability of a distribution subsystem can result in loss of charging power to batteries and eventual loss of DC power. This Note ensures that the appropriate attention is given to restoring charging power to batteries, if necessary, after loss of distribution systems.

_(continued)

SUSQUEHANNA - UNIT I TS I 8 3.8-81 Revision 1

PPL Rev. 1 Distribution Systems-Operating B 3.8.7 BASES ACTIONS B.1 (continued)

With one or more Unit 1 DC buses inoperable, the remaining DC electrical power distribution subsystems may be capable of supporting the minimum safety functions necessary to shut down the reactor and maintain it in a safe shutdown condition, assuming no single failure.

The overall reliability is reduced, however, because a single failure in one of the remaining DC electrical power distribution subsystems could result in the minimum required ESF functions not being supported.

Therefore, the required DC buses must be restored to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months by powering the bus from the associated battery or charger.

Condition B represents one subsystem or multiple DC buses without adequate DC power, potentially with both the battery significantly degraded and the associated charger non-functioning. In this situation the plant is significantly more vulnerable to a loss of minimally required DC power. It is, therefore, imperative that the operators attention focus on stabilizing the plant, minimizing the potential for loss of power to the remaining divisions, and restoring power to the affected division.

This 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limit is more conservative than Completion Times allowed for the majority of components that would be without power. Taking

-exception to LCO 3.0.2 for components Without adequate DC power, which would have Required Action Completion Times shorter than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , is acceptable because of:

a. The potential for decreased safety when requiring a change in plant conditions (i.e., requiring a shutdown) while not allowing stable operations to continue; -

b. The potential for decreased safety when requiring entry into numerous applicable Conditions and Required Actions for components without DC power, while not providing sufficient time for the operators to perform the necessary evaluations and actions for restoring power to the affected division;

c. The potential for an event in conjunction with a single failure of a redundant component.

r(cnlinuea)

SUSQUEHANNA - UNIT 1 B. 3.8-82 Revision 0

PPL Rev. 1 Distribution Systems-Operating B 3.8.7

-BASES ACTIONS B.1 (continued)

The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Completion Time for DC buses is consistent with Regulatory Guide 1.93 (Ref. 3).

The second Completion Time for Required Action B.1 establishes a limit on the maximum time allowed for any combination of required distribution subsystems to be inoperable during any single continuous occurrence of failing to meet the LCO. If Condition C is entered while, for instance, an AC bus is inoperable and subsequently restored OPERABLE, the LCO may already have been not met for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . This situation could lead to a total duration of 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months , since initial failure of the LCO, to restore the DC distribution system. At this time, an AC division could again become inoperable, and DC distribution could be restored OPERABLE. This could continue indefinitely.

Condition B is modified by a Note that states that Condition B is not applicable to the DG E DC electrical power subsystem. Condition D or E is applicable to an inoperable DG E DC electrical power subsystem.

This Completion Time allows for an exception to the normal "time zero" btheallowed outage time-"clock." This allowance results in establishing the "time zero" at the time the LCO was initially not met, instead of at the time Condition C was entered. The 16 hour1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months Completion Time is an acceptable limitation on this potential of failing to meet the LCO indefinitely. The Completion Time exception is not applicable to Condition D or E because Condition D and E are only applicable to DG E DC electrical power subsystem.

C.1 and C.2 If the inoperable distribution subsystem cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

=.=.0 . . . .

-(continued)

_ -. ,......... .wl..A g SUSQUEHANNA - UNIT 1 B. 3.8-83 Revision 0

PPL Rev. 1 Distribution Systems-Operating B 3.8.7

_4 t -BASES ACTIONS D.1 (continued)

If Diesel Generator E is not aligned to the Class 1E distribution system, the only supported safety function is for the ESW system. Therefore, under this condition, if Diesel Generator E DC power-distribution subsystem is not OPERABLE, to ensure the OPERABILITY of the ESW system, actions are taken to either restore the power distribution subsystem to OPERABLE status or shutdown Diesel Generator E and close the associated ESW valves. The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limit is consistent with the allowed time for other inoperable DC power distribution subsystems and provides sufficient time to evaluate the condition and take the corrective actions.

E.1 If the Diesel Generator E is aligned to the class 1E distribution system, the loss of Diesel Generator E DC power distribution subsystem will result in the loss of a on-site class 1E power source. Therefore, under this condition, if Diesel Generator E DC power distribution subsystem is not OPERABLE actions are taken to either restore the power distribution subsystem to OPERABLE status or'declare Diesel

-Genie'ratorr I'nopoera~bleaidtk Action fC .1~. 'h'e -2fiour ' ' ~'

limit is consistent with the allowed time for other DC -sourcesand provides sufficient time to evaluate the condition and take the necessary corrective actions.

F.1 Condition F corresponds to a level of degradation in the electrical distribution system that causes a required safety function to be lost.

When more than one AC or DC electrical power distribution subsystem is lost, and this results in the loss of a required function, the plant is in a condition outside the accident analysis. Therefore, no additional time is justified for continued operation. LCO 3.0.3 must be entered immediately to commence a controlled shutdown. Entry into Condition F is not required if the loss of safety function is the result of entry into Condition A in combination with the loss of safety functions governed by LCOs other than LCO 3.8.7. In this case, enter LCO 3.8.7, Condition A, and the Condition for loss of function in the LCO that governs the safety function that is lost.

(continued)

SUSQUEHANNA - UNIT 1 B. 3.8-84 Revision 0

PPL Rev. I Distribution Systems-Operating B 3.8.7

_---: ~BA-SES (continued}

SURVEILLANCE SR 3.8.7.1 REQUIREMENTS This Surveillance verifies that the AC and DC, electrical power distribution systems are functioning properly, with the correct circuit breaker alignment. The correct breaker alignment ensures the appropriate independence of the electrical buses are maintained, and the appropriate voltage or indicated power is available to each required bus. This includes a verification that Unit 1 and common 125 VDC loads are aligned to a Unit 1 DC power distribution subsystem. The verification of voltage availability on the buses ensures that the required voltage is readily available for motive as well as control functions for critical system loads connected to these buses. The 7 day Frequency takes into account the redundant capability of the AC and DC electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.

REFERENCES 1. FSAR, Chapter 6.

_ Z.. FSAR, Chapter 15.

. --- .L . = -* 3-.. R _e g la o --.. G.ui _e. . r 1 9_

- 3. kegulatory Guide 1.93, December 1974.-

_ :7 . I

- 4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).

z - I I I - -

SUSQUEHANNA - UNIT 1 B. 3.8-85 Revision 0

ML052910067

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