Text

Proposed Tech Specs,Section 3/4.3.2 to Clarify Instrument Tables 3.3.2-1,3.3.2-2,3.3.2-3 & 4.3.2-1 & Section 3/4.6.3 to More Closely Resemble GE BWR/4 STS
	ML20147J010
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Site:	Brunswick
Issue date:	02/29/1988
From:	; CAROLINA POWER & LIGHT CO.
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ML20147H987	List: ML20147H982; ML20147J010;
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ENCLOSURE 2 BRUNSWICK STEAM ELECTRIC PIANT, UNITS 1 AND 2 NRC DOCKETS 50-325 & 50-324 OPERATING LICENSES DPR-71 & DPR 62 REQUEST FOR LICENSE AMENDMENT INSTRUCTIONS FOR INCORPORATION The proposed changes to the Technical Specifications (Appendix A to Operating Licenses DPR-71 and DPR 62) would be incorporated as follows:

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h j ' I . i ENCLOSURE-3 BRUNSWICK STEAM ELECTRIC PLANT, UNITS 1 AND 2 NRC DOCKETS 50-325 & 50-324 OPERATING LICENSES DPR-71 & DPR 62 REQUEST FOR LICENSE AMENDMENT UNIT 1 TECHNICAL SPECIFICATION PACES i l l i i l l l l l 1 i

e (BSEP-1-118) INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION Pt.CE 3/4.6 CONTAINMENT SYSTEMS (Continued) 3/4.6.2 DEPRESSURIZATION AND COOLINC SYSTEMS Suppression Pool........................................ 3/4 6-9 Suppression Pool Cooling................................ 3/4 6-11 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES.................... 3/4 6-12 3/4.6.4 VACUUM RELIEF Drywell - Suppression Chamber Vacuum Breakers........... 3/4 6-15 Suppression Pool - Reactor Building Vacuum Breakers..... 3/4 6-17 3/4.6.5 SECONDARY CONTAINMENT Secondary Containment Integrity......................... 3/4 6-18 Secondary Containment Automatic Isolation Dampers....... 3/4 6-19 3/4.6.6 CONTAINMENT ATHOSPHERE' CONTROL Standby Cas Treatment System............................ 3/4 6-21 Containment Atmosphere Dilution System.................. 3/4 6-24 0xygen Concentration.................................... 3/4 6-25 Cas Analyzer Systems................................*.... 3/4 6-26 3/4.7 PLANT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS Residual Heat Removal Service Water System.............. 3/4 7-1 Servic<a Water System.................................... 3/4 7-2 3/4.7.2 CONTROL ROOM EMERCENCY FILTRATION SYSTEM................ 3/4 7-3 i l 3/4.7.3 FLOOD PROTECTION........................ 3/4 7-6 l l l l l BRUNSWICK - UNIT 1 VII Amendment No.

(BSEP-1-118) INDEX BASES SECTION PACE 3/4.4 REACTOR COOLANT SYSTEM (Continued)' 3/4.4.4 CHEMISTRY......................................... B 3/4 4-2 3/4.4.5 SPECIFIC ACTIVITY................................. B 3/4 4-2 3/4.4.6 PRESSURE / TEMPERATURE LIMITS....................... B 3/4 4-3 3/4.4.7 MAIN STEAM LINE ISOLATION VALVES.................. B 3/4 4-7 3/4.4.8 STRUCTURAL INTECRITY.............................. B 3/4 4-7 3/4.5 EMERCENCY CORE COOLING SYSTEMS 3/4.5.1 HICH' PRESSURE COOLANT INJECTION SYSTEM............ B 3/4 5-1 3/4.5.2 AUTOKATIC DEPRESSURIZATION SYSTEM................. B 3/4 5-1 3/4.5.3 Led PRESSURE COOLING SYSTEMS...................... B 3/4.5-2 3/4.5.4 SUPPRESSION P00L.................................. B 3/4 5-4 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT............................... B 3/4 6-1 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS..........*.... B 3/4 6-3 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES.............. B 3/4 6-4 3/4.6.4 VACUUM RELIEF..................................... B 3/4 6-5 3/4.6.5 SECONDARY CONTAINMENT............................. B 3/4 6-5 3/4.6.6 CONTAINMENT ATMOSPHERE CONTR0L.................... B 3/4 6-6 3/4.7 PLANT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS............................. B 3/4 7-1 3/4.7.2 CONTROL ROOM EMERGENCY FILTRATION SYSTEM.......... B 3/4 7-1 I l l l BRUNSWICK - UNIT 1 XI Amendment No.

l 4 (BSEP-1-116) DEFINITIONS OPERATIONAL CONDITION An OPERATIONAL CONDITION shall be any one inclusive combination of mode switch position and average reactor coolant temperature as indicated in Table 1.2. PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the ' fundamental nuclear characteristics of the reactor core and related instrumentation and are 1) described in Section 13 of the FSAR, 2) authorized under the provisions of 10 CFR.50.59, or 3) otherwise approved by the Commission.. PRESSURE BOUNDARY LEAKACE PRESSURE BOUNDARY LEAKAGE shall be leakage through a non-isolatable fault in a reactor coolant system component body, pipe wall, or vessel wall. PRIMARY CONTAINHENT INTECRITY PRIMARY ColfrAINMENT INTECRITY shall exist whens All penetrations required to be closed during accident conditions a. are either: 1. Capable of being closed by an OPERABLE containment automatic isolation valve system, or 2. Closed by at least one manual valve, blind flange, or deactivated automatic valve secured in its closed position, except as provided in Specification 3.6.3. b. All equipment hatches are closed and sealed. c. Each containment air lock is OPERABLE pursuant to Specification 3.6.1.3. d. The containment leakage rates are within the limits of Specification 3.6.1.2. e. The sealing mechanism associated with each penetration (e.g., welds, bellows or 0-rings) is OPERABLE. PROCESS CONTROL PROCRAM (PCP) l The PROCESS CONTROL PROGRAM (PCP) shall contain the current f o rmul a, sampling, l analyses, tests and determinations to be made to ensure that the processing and packaging of solid radioactive wasts based on demonstrated processing of actual or simulated wet solid wastes will be accomplished in such a way as to assure compliance with 10 CFR Part 20,10 CFR Part 71, and Federal and State l regulations and other requirements governing the disposal of the radioactive waste. BRUNSWICK - UNIT 1 1-5 Amendment No.

(BSEP-1-116) TABLE 3.3.2-1 Eg ISOLATION ACTUATION INSTRUMENTATION Eg VALVE CROUPS MINIMUM NUMBER APPLICABLE M OPERATED BY OPERABLE CHANNELS OPERATIONAL' ACTION s TRIP FUNCTION AND INSTRUMENT NUMBER SIGNAL (a) PER TRIP SYSTEM (b)(c) CONDITION Ey 1. PRIMARY CONTAINMENT ISOLATION a. Reactor Vessel Water Level - 1. Low, Level 1 2, 6 - 2 1,2,3 20 (B21-LT-N017A-1,B-1,C-1,D-1) 8 2 1,2,3 27 (B21-LIN-N017A-1,B-1,C-1,D-1) 2. Low, Level 2 1 2 1,2,3 20 (B21-LT-NO24A-1,B-1; 3 2 1, 2, 3 24 B21-LT-N025A-1,B-1) g (B21... NO24A-1,B-1; l B21-LTM-N025A-1,B-1) Y [ b. Drywell Pressure - High 2, 6 2 1,2,3 20 l (C71-PT-N002A,B,C,D) (C71-PTM-N002A-1,B-1,C-1,D-1) c. Main Steam Line 1. Radiation - Iligh 1 2 1,2,3 21 (D12-RE-N006A,B,C.D) f (D12-RM-K603A,B,C,D) II) l 2. Pressure - Low I 2 1 22 (B21-PT-NO15A,B,C,D) g (B21-PTM-N015A-1,B-1,C-1,D-1) k II) 2/line 1 22 3. Flow - High I 2 (B21-PDT-N006A,B,C,D; f, B21-PDT-NOO7A,B,C,D; 2 B21-PDT-N008A,B,C,D; B21-PDT-N009A,B,C,D) o (B21-PDTM-N006A-1,B-1,C-1,D-1; B21-PDTM-N007A-1,B-1,C-1,D-1; B21-PDTM-N008A-1,B-1,C-1,D-1; B21-PDTM-N009A-1,B-1,C-1,D-1)

(BSEP-1-116) 5 TABLE 3.3.2-1 (Continued) E ~ y ISOLATION ACTUATION INSTRUMENTATION N PC VALVE CROUPS MINIMUM NUMBER APPLICABLE e OPERATED BY OPERABLE CHANNELS OPERATIONAL Q TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTION U PRIMARY CONTAINHENT ISOLATION (Continued) ~ d. Main Steam Line Tunnel Temperature - High 1(I) 2(d) 1, 2, 3 21 (821-TS-N010A,B,C,D; B21-TS-N0llA,B,C,D; B21-TS-N012A,B,C,D; B21-TS-N013A,B,C,D) II) 2 1, 2(*) 21 e. Condenser Vacuum - Low I fh (B21-PT-N056A,B,C,D) (B21-PTM-N056A-1,B-1,C-1,D-1) E-f. Turbine Building Area II) 4(d) 1, 2, 3 21 Temperature - High I (B21-TS-3225A,B,C,D; B21-TS-3226A,B,C,D; .B21-TS-3227A,B,C,D; B21-TS-3228A,B,C,D; B21-TS-3229A,B,C,D; B21-TS-3230A,B,C,D; B21-TS-3231A,B,C,D; B21-TS-3232A,B,C,D) g g. Reactor Building Exhaust g Radiation - High 6 1 1,2,3 20 g (D12-RE-N010A,B) (D12-RM-K609A,B) n O O

(BSEP-1-ll6) ll TABLE 3.3.2-1 (Continued) E! E ISOLATION ACTUATION INSTRUNENTATION N PC VALVE CROUPS MINIMUM NUMBER APPLICABLE 8 OPERATED E! OPERABLE CHANNELS OPERATIONAL gj TRIP FUNCTION AND INSTRUMENT NUMBER SIGNAL (a) PER TRIP SYSTEM (b)(c) CONDITION ACTION 2. SECONDARY CONTAINMENT ISOLATION a. Reactor Building Exhaust Radiation - High (k) 1 1, 2, 3, 5, 23 (D12-RE-N010A,B) and * (D12-RM-K609A,B) 6 1 1,2,3 20 b. Drywell Pressure - High (k) 2 1,2,3 23 (C71-PT-N002A,B,C,D) 2, 6 2 1,2,3 20 (C71-PTM-N002A-1,B-1,C-1,D-1) m 3E Reactor Vessel Water Level - c. y Low, Level 2 (k) 2 1, 2, 3 23 g (B21-LT-NO24A-1,B-1; 1 2 1,2,3 20 821-LT-NO25A-1,B-1) 3 2 1,2,3 24 (B21-LTM-NO24A-1,B-1; B21-LTM-NO2SA-1,B-1) 3. REACTOR WATER CLEANUP SYSTEM ISOLATION a. A Flow - High 3 1 1,2,3 24 (C31-FDS-N603-1A,lB) l b. Area Temperature - High 3 2 1,2,3 24 k (C31-TS-N600A,B'C,D,E,F) h c. Area Ventilation A Temperature - High 3 2 1,2,3 24 (C31-TDS-N602A,B,C,D,E,F) l If) d. SLCS Initiation 3 NA 1, 2, 3 24 c (C41A-SI) o

(BSEP-1-il6) E TABLE 3.3.2-1 (Continued) E E ISOLATION ACTUATION INSTRUMENTATION M* VALVE CROUPS MINIMUM NUMBER APPLICABLE OPERATED BY OPERABLE CHANNELS OPERATIONAL E TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER 11tIP SYSTEM (b)(c) CONDll' ION ACTION U REACTOR WATER CLEANUP SYSTEM ISOLATION (Continued) - e. Reactor Vessel Water Level - 1 2 1,2,3 20 Low, Level 2 3 2 1,2,3 24 (B21-LT-NO24A-1,B-1; B21-LT-NO25A-1,B-1) l (B21-LTM-NO24A-1,B-1; B21-LTM-NO25A-1,B-1) l ti f. A Flow - High - Time Delay Relay NA 1 1,2,3 24 (C31-R616C,D) l Tg 4. CORE STANDBY COOLING SYSTEMS ISOLATION High Pressure Coolant Injection System Isolation a. 1. HPCI Steam Line Flov - High 4 1 1,2,3 25 (E41-PDT-N004; E41-PDT-N005) (E41-PDTS-N004-2 ; E41-PDTS-N005-2) 2. HPCI Steam Line Flow - High g Time Delay Relay , NA 1 1,2,3 25 l (E41-TDR-K33; a h. E41-TDR-K43) k 3. HPCI Steam Suoply Pressure - Low 4 2 1,2,3 25 I5) (E41-PSL-N001A,B,C,D) 7 1 1,2,3 25 ? 4

(BSEP-1-ll6) E TABLE 3.3.2-1 (Continued) E I E ISOLATION ACTUATION INSTRUMENTATION M VALVE CROUPS MINIMUM NUMBER APPLICABLE OPERATED BY OPERABLE CHANNELS OPERATIOt!AL E TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTION G CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) ~ l 4. HPCI Steam Line Tunnel Temperature - High 4 2 1 2, 3 25 3 (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; t' E41-TS-3354; y E41-TS-3488; E41-TS-3489) I8) 1/ bus 1, 2, 3 26 l U 5. Bus Power Monitor NA (E41-K55; l E41-K56) 6. HPCI Turbine Exhaust Diaphragm Pressure - High 4 2 1,2,3 25 (E41-PSH-NO12A,B,C,D) 7. HPCI Steam Line Ambient Temperaturc - High 4 1 1,2,3 25 (E5.-fS-N603C,D) f 8. HPCI Steam Line Area g a Temperature - High 4 1 1,2,3 25 g (E51-TDS-N604C,D)

sa 9.

HPCI Equipment Area y Temperature - High 4 1 1,2,3 25 (E41-TS-N602A,B) 7 5) 1 1,2,3 25 I 10. Drywell Pressure - High (Ell-PT-N0 llc,D) I (Ell-PTS-N0 llc-2,D-2)

(BSEP-1-il6) E TABLE 3.3.2-1 (continued) Ey I_ SOLATION ACTUATION INSTRUMENTATION M M VALVE CROUPS MINIMUM NUMBER APPLICABLE s OPERATED BY OPERABLE CHANNELS OPERATIONAL g TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTION U b. Reactor Core Isolation Cooling System Isolation 1. RCIC Steam Line Flow - High 5 ,1 1,2,3 25 (E51-PDT-NOl7; E51-PDT-NOl8) (E51-PDTS-N017-2; E51-PDTS-N018-2) 2. RCIC Steam Line Flow - High Time Delay Relay NA 1 1,2,3 25 ,p (E51-TDR-K32; E51-TDR-K12) 1 3. RCIC Steam Supply Pressure - Low 5 2 1,2,3 25 (E51-PS-N019A,B,C,D) 9UI 1 1,2,3 25 4. RCIC Steam Line Tunnel Temperature - liigh 5 2 1,2,3 25 (E51-TS-3319; E51-TS-3320; E51-TS-3321; E51-TS-3322; E51-TS-3323; E51-TS-3355; k E51-TS-3487) h IE) 1/ bus 1, 2, 3 26 5. Bus Power Monitor NA (E51-K42; E51-K43) l 6. RCIC Turbine Exhaust Diaphragm Pressure - Iligh 5 2 1, 2, 3 25 (E51-PS-N012A,B,C,D)

(BSEP-1-ll6) E TABLE 3.3.2-1 (Continued) E E ISOLATION ACTUATION INSTRUMEEATION N* VALVE CROUPS MINIMUM NUMBER AtPLICABLE OPERATED BY OPERABLE CHANNELS OrERATIONAL E TRIP FUNCTION AND INSTRUMENT NUMBER SIGNAL (a) PER TRIP SYSTEM (b)(c) CONDITION ACTION U CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) r 7. RCIC Steam Line Ambient Temperature - High 5 1 1,2,3 25 (E51-IS-N603A,B) 8. RCIC Steam Line Area A Temperature - High 5 1 1,2,3 25 (E51-TDS-N604A,B) R 9. FCIC Equipment Room Ambient Temperature - High 5 1 1,2,3 25 (E51-TS-N602A,B) 10. RCIC Equipment Room A Temperature - High 5 1 1,2,3 25 (E51-TDS-N601A,B) 11. RCIC Steam Line Tunnel Temperature - High NA 1 1,2,3 25 Time Delay Relay (E51-KC-M602A,B) 9 i} l 1, 2, 3 25 I 12. Drywell Pressure - High (Ell-PT-N0llA,B) g (Ell-PTS-N0llA-2,B-2) E 5. SHUTDOWN COOLING SYSTEM ISOLATION S a. Reactor Vessel Water Level - 2, 6 2 1,2,3 20 g Low, Level 1 8 2 1,2,3 27 (B?l-LT-N017A-1,B-1,C-1,D-1) (321-LTM-N017A-1,B-1,C-1,D-1) b. Reactor Steam Dome Pressure - High 8(h) g 1, 2, 3 27 (B32-PS-N018A-1,3)

(BSEP-1-ll6) TABLE 3.3.2-1 (Continued) ISOLATION ACTUATION INSTRUMENTATION ACTIONS ACTION 20 - Be in at least HOT SHUTDOWN within 6 hours and in COLD SHUTDOWN within the following 30 hours. ACTION 21 - Be in at least STARTUP with the main steam line isolation valves closed within 2 hours or be in at least HOT SHUTDOWN within 6 hcurs and in COLD SHUTDOWN within the next 30 hours. ACTION 22 - Be in at least STARTUP within 2 hours. ACTION 23 - Establish SECONDARY CONTAINMENT INTECRITY with the standby gas treatment system operating within one hour. ACTION 24 - Isolate.the reactor water cleanup system. ACTION 25 - Close the affected system isolation valves and declare the affected system inoperable. ACTION 26 - Verify power availability to the bus at least once per 12 hours. ACTION 27 - Deactivate the shutdown cooling supply and reactor vessel head spray isolation valves in the closed position until the reactor steam dome pressure is within the specified limits. NOTES When handling irradiatec fuel in the secondary containment. (a) Refer to plant procedure for valves in each valve group. (b) A channel may be placed in an inoperable status for up to 2 hours for required surveillance without placing the trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter. (c) With only one channel per trip system, an inoperable channel need not be placed in the tripped condition where this would cause the Trip Function to occur. In these cases, the inoperable channel shall be restored to OPERABLE status within 2 hours or the ACTION required by Table 3.3.2-1 for that Trip Function shall be taken. (d) A channel is OPERABLE if 2 of 4 instruments in that channel are OPERABLE. (e) With reactor steam pressure > 500 psig. BRUNSWICK - UNIT 1 3/4 3-18 Amendment No.

(BSEP-1-ll6) TABLE 3.3.2-1 (Continued) ISOLATION ACTUATION INSTRUMENTATION NOTES (f) Closes only RWCU outlet isolation valve. (g) Alarm only. (h) Does not isolate El'1-F015A,B. (i) Does not isolate B32-F019 or B32-F020. (j) Valve isolation depends upon low steam supply pressure coincident with high drywell pressure. (k) Secondary containment isolation dampers as listed in plant proceduce [ l l BRUNSWICK - UNIT 1 3/4 3-19 Amendment No.

(BSEP-1-116) e E! M TABLE 3.3.2-2 P a ISOLATION ACTUATION INSTRUMENTATION SETPOINTS $y ALLOWABLE TRIP FUNCTION AND INSTRUMENT NUMBER TRIP SETPOIuT r VALUE 1. PRIMARY CONTAINMENT ISOLATION a. Reactor Vessel Water Level - 3 + 162.5 inches ") 3 + 162.5 inches *) l I I 1. Low, Level 1 (B21-LTM-NOl7A-1,B-1,C-1,D-1) 3 + 112 inches (a) + 112 inches (a) 2. Low, Level 2 (B21-LTM-NO24A-1,B-1; B21-LTM-NO25A-1,B-1) l b. L'rywell Pressure - High $ 2 psig $ 2 psig (C71-PTM-N002A-1,B-1,C-1,D-1) id c. Main Steam Line l. Radiation - High $ 3 x full power background 13.5 x full power y* (D12-RM-K603A,B,C,D) background w c> 2. Pressure - Low 3 825 psig 3 825 psig -(B21-PTM-NO15A-1,B-1,C-1,D-1) 3. Flow - High $ 140% of rated flow $ 140% of rated flow (B21-PDTM-NOO6A-1,B-1,C-1,D-1; B21-PDTM-NOO7A-1,B-1,C-1,D-1; B21-PDTM-NOO8A-1,B-1,C-1,D-1; B21-PDTM-NOO9A-1,B-1,C-1,D-1) e B 9n

(BSEP-1-ll6) E TABLE 3.3.2-2 (Continued) U E ISOLATION ACTUATION INSTRUMENTATION SETPOINTS n ALLOWABLE TRIP FUNCTION AND INSTRUMENT NUMBER ' TRIP SETPOINT VALUE U PRIMARY CONTAllMENT ISOLATION (Continued) r d. Main Steam Line Tunnel Temperature - High $ 200*F $ 200*F (B21-TS-N010A,B,C,D; B21-TS-N011A,B,C,D; B21-TS N012A,B,C,D; B21-TS-N013A,B,C,D) e. Condenser Vacuum - Low 3 7 inches Hg vacuum 3 7 inches Hg vacuum (B21-PTM-N056A-1,8-1,C-1,D-1) f. Turbine Building Area Temperature - High $ 200*F $ 200*F (B21-TS-3225A,B,C,D; B21-TS-3226A,B,C,D; if B21-TS-3227A,B,C,D; B21-TS-3228A,B,C,D; Y B21-TS-3229A,B,C,D;. 03 821-TS-3230A,B,C,D; B21-TS-3231A,B,C,D; B21-TS-3232A,B,C,D) g. Reactor Building Exhaust Radiation - High $ 11 mr/hr $ 11 mr/hr (D12-RM-K609A,B) 2. SECONDARY OCJTAINMENT ISOLATION { Reactor Building Exhaust Radiation - High -< 11 mr/hr ~< 11 mr/hr l a. (D12-RM-K609A,B) l b. Drywell Pressure - High $ 2 psig $ 2 psig g (C71-PTM-N002A-1,B-1,C-1,D-1) 3 + 112 inches (*) 3 + 112 inches (*} c. Reactor Vessel Water Level - Low, Level 2 (B21-LTM-N024A-1,B-1; o 3 B21-L'IM-NO25A-1,B-1) 4

(BSEP-1-ll6) TABLE 3.3.2-2 (Continued) ISOLATION ACTUATION INS 11tlMENTATION SETPOINTS E E ALLOWABLE y TRIP FUNCTION AND INSTPUMENT NUMBER TRIP SETPOINT VALUE lrc 8 3. REACTOR WATER CLEANUP SYSTEM ISOLATION E a. A Flow - High 1.53 gal / min 1 53 gal / min y (C31-FDS-N603-1A,lB) l b. Area Temperature - High -< 150*F ~< 150*F (C31-TS-N600A,B,C,D,E,F) c. Ares Ventilation A Temperature - High $ 50*F $ 50*F (C31-TDS-N602A,B,C,D,E,F) d. SLCS Initiation NA Ne (C41A-SI) u A e. Reactor Vessel Water Level - 3 + 112 inches ") 3 + 112 inches ") I I y Low, Level 2 3 (B21-LTM-NO24A-1,B-1; B21-LTM-NO25A-1,B-1) f. A Flow - High - Time Delay Relay $ 45 seconds 5 45 seconds (C31-R616C,D) 4. QRE STANDBY COOLING SYSTEMS ISOLATION a. High Pressure Coolant Injection System Isolation 1. HPCI Steam Line Flow - High 5 300% of rated flow $ 300% of rated flow (E41-PDTS-N004-2; k E41-PDTS-N005-2) h 2. HPCI Steam Line Flow - High Time Delay Relay 3 $ t $ 7 seconds 3 $ t $ 12 seconds (E41-TDR-K33; ,E E41-TDR-K43) 3. HPCI Steam Supply Pressure - Low 3 100 psig 3 100 psig (E41-PSL-NOOIA,B,C,D)

(BSEP-1-ll6) TABLE 3.3.2-2 (Continued) g E ISOLATION ACTUATION INSTRIMENTATION SETPOINTS y U M ALLOWABLE TRIP FUNCTION AND INSTRUMENT NUMBER TRIP SETPOINT VALUE E y CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) 4. HPCI Steam Line Tunnel Temperature - High < 200*F < 200*F (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; E41-TS-3354; E41-TS-3488; t* E41-TS-3489) v. 5. Bus Power Monitor NA NA u, 4 (E41-K55; E41-K56) 6. HPCI Turbine Exhaust Diaphragm Pressure - High $ 10 psig < 10 psig (E41-PSH-NO12A,B,C,D) 7. HPCI Steam Line Ambient Temperature - High < 200*F $ 200*F (E51-TS-N603C,D) l 8. HPCI Steam Line Area A Temperature - High < 50*F < 50*F l (E51-TDS-N604C,D) g 9.- HPCI Equipment Area Temperature - Vigh < 175*F $ 175'F l (E41-TS-N602A,B) o. g 10. Drywell Pressure - High < 2 psig < 2 psig (E11-PTS-N0 llc-2,D-2) D x ,o b. Reactor Core Isolation Cooling System Isolation 1. RCIC Steam Line Flow - High < 300% of rated flow < 300% of rated flow (E51-PDTS-N017-2; E51-PDTS-NOl8-2)

o (BSEP-1-116) TABLE 3.3.2-2 (Continued) E! ISOLATION ACTUATION INSTRIMENTATION SETPOINTS g I ALLOWABIE TRIP FUNCTION AND INSTRUMENT MIMBER TRIP SETPOINT VALUE E! j c l ll 2. RCIC Steam Line Flow - High Time Delay Relay 3 $ t $ 7 seconds 3 $ t $ 12 seconds l r. (E51-TDR-K32; E51-TDR-K12) 3. RCIC Steam Supply Pressure - Low > 50 psig > $0 peig (E51-PS-N019A,B,C,D) 4. RCIC Steam Line Tunnel Temperature - High $ 175"F $ 175*F o (E51-TS-3319; E51-TS-3320; E51-TS-3321; If 'E51-TS-3322; i I E51-TS-3323; Y E51-TS-3355; "o E51-TS-34&7) 5. Bus Power Monitor MA MA (E51-K42; l E51-K43) 6. RCIC Turbine Exhaust Diaphragm Pressure - High $ 10 psig $ 10 peig i (E51-PS-N012A,B,C,D) 7. RCIC Steam Line Ambient Temperature - High < 200*F $ 200*F (E51-TS-N603A,B) i g 8. RCIC Steam Line Area A Temperature - High $ 50*F $ 50*F

g (E51-TDS-N604A,B) l

,( 9. RCIC Equipment Room Ambient g Temperature - High < 175*F $ 175*F (E51-TS-N602A,B) 2 9 1

- s.? e

z. m g

i' ^ f>d h. L s% 6 8 GM fi ~ : s l (BSEP-1-ll6) TABLE 3.3.. -2 ' continued) g ISOLATION ACTUATION INSTRCHENTATION SETPOINTS E ALLOWABLE y T f,P SETPOINT VALUE j E , TRIP FUNCTION AND INSTRUMENT NUMBEE n .. -.ANDBY COOLING SYSTEMS ISOLATION (Continued' 8 '; r

m...

J Q 10. RCic Equipment Room A Tempurature - High 5 50*F $ 50*F '?T'-TDS-N601A,8) l . *,I.ine Tunnel Temperature - High Relay $ 30 minutes $ 30 minutes 's - sy 11.1 =. %602A,B) ..r.11 Pressure - High $ 2 psig $ 2 psig

11-PTS-N 0l l A-2, B-2 )

t,' ~.. .4 STEM ISOLATION 5. SHO '? a. c. t Vessel Water Level - > + 162.5 inches *) > > 162.5 inches *) I I 0 Low, Level 1 l (B21-L'IM-N017A-1,B-1,C-1,D a) l b. Reactor Steam Dome Pressure - High .$ 140 psig $ 140 psig I (B32-PS-NOl8A-1,B) l (a) Vessel water levels refer to RFFERENCE LEVEL ZERO. \\ l 5 aaB Z .O L u..x

(BSEP-1-116) TABLE 3.'3.2-3 ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME l TRIP F, UNCTION AND INSTRUMENT NUMBER RESPONSE TIME (Seconds)(a)(d) l. PRIMARY CONTAINMENT ISOLATION a. Reactor Vessel Water Level - 1. Low, Level 1 <13 ~ (B21-LT-N017A-1,B-1,C-1,D-1) (B21-LTM-NOl7A-1,B-1,C-1,D-1) 2. Low, Level 2 <1.0(c) (821-LT-NO24A,1,B-ll {43(h) 821-LT-NO25A-1,B-1) (B21-LTM-N024A-1,B-11 l B21-LTM-N025A-1,B-1) b. D.ywell Pressure - High <13 (C71-PT-N002A,B,C,D) (C71-PTM-N002A-1,5-1,C-1,D-1) <l.0((h ) c) c. Main Steam Line 1. Radiation - High(b) < 13 ~ (D12-RM-K603A,B,C,D) 2. Pressure - Low <13 ~ (B21-PT-N015A,B,C,D) (B21-PTM-N015A-1,B-1,C-1,D-1) 3. Flow - High <0.y(c) (B21-PDT-NOO6A,B,C,DI 313(h) B21-PDT-N007A,B,C,D; B21-PDT-N008A,B,C,DI B21-PDT-N009A,B,C,D) (B21-PDTM-NOO6A-1,B-1,C-1,0-ll B21-PDTM-NOO7A-1,B-1,C-1,D-ll B21-PDTM-N008A-1,B-1,C-1,D-ll B21-PDTM-N009A-1,B-1,C-1,D-1) d. Main Steam Line Tunnel Temperature - High <13 (B21-TS-r010A,B,C,DI B21-TS-N0llA,B,C,D) B21-TS-N011A,B,C,DI B 21-TS-N0134,, B, C, D) e. Condenser Vacuum - Low (13 ~ (B21-PT-N056A,B,C,D) (B21-PTM-N056A-1,B-1,C-1,D-1) l BRUNSWICK - UNIT 1 3/4 3-26 Amendment No.

TABLE 3.3.2-3 (Crntinu-d) (BSEP-1-116) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME RESPONSE TIME (Seconds)(a)(d) k TRIP FUNCTION AND INSTRUMENT NUMBER PRIMARY CONTAINME:IT ISOLATION (Continued) f. Turbine Building Arce Temperature - High NA (B21-TS-3225A,3,C,DI 821-TS-3226A,B,C,D) B21-TS-3227A,B,C,DI B21-TS-3228A.B,C,D) l B21-TS-3229A,B,C,D) i B21-TS-3230A,B,C,DI B21-TS-3231A,B,C,DI B21-TS-3232A,B,C,D) Reactor Building Exhaust Radiation - High(b) NA g. (D12-RE-N010A,B) (D12-RM-K609A,B) 2. SECONDARY CONTAINMENT ISOLATION Reactor hilding Exhaust Radiation - Hign(b) $13 a. (D12-RE-N010A,B) (D12-EM-K609A,B) b. Drywell Pressure - High. $13 (C71-PT-N002A,B,C,D) ,C71-PTM-N002A-1,B-1,C-1,D-1) ( C} c. Reactor Vessel Water Lavel - Low, Level 2 $1 ) (821-LT-N024A-1,B-ll $13 821-LT-N025A-1,B-1) (B21-LTM-N024A-1,B-ll l B21-LTM-N025A-1,B-1)' 3. REACTOR WATER CLEANUP SYSTEM ISOLATION a. A Flow - High $45(g) (C31-FDS-N603-1A,1B) b. Area Temperature - High $13 (G31-TS-h600A,B,C,D,E,F) c. Are.1 Ventilation a Temperature - High $13 (C31-TDS-N602A,B,C,D,E,F) d. SLCS Initiation NA (C41A-S1) 3 1.0(c) e. Reactor Vessel Water Lev'el - Low, Level 2 (B21-LT-NO24A-1,B-ll <13(h) B21-LT-NO25A-1,B-1) (B21-LTM-NO2?A-1,B-ll l B21-LIN-N025 A-1,8-1) f. A Flow - High - Time Delay Relay NA (C31-R616C,D) BRUNSWICK - UNIT 1 3/4 3-27 Amendment No.

(BSEP-1-116) TABLE 3.3.2-3 (continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION AND INSTRUMENT NUMBER RESPONSE TIME (Seconds)(a)(d) 4. CORE STANDBY C00LINC SYSTEMS ISOLATION a. High Pressure Coolant Injection System Iso 1Gion 1. HPCI Steam Line Flow - High <13(*) ~ (E41-PDT-N004) E41-PDT-W005) (E41-PDTS-N004-21 E41-PDTS-N005-2) 2. HPCI Steam Line Flow - High l Time Delay Relay NA I (E41-TDR-K331 E41-TDR-K43) 3. HPCI Steam Supply Pressure - Low 113 (E41-PSL-N001A,B,C,D) 4. HPCI Steam Line Tunnel Temperature - High $13 (E41-TS-33141 E41-TS-3315 E41-TS-3316 E41-TS-33171 E41-TS-33181 E41-TS-33541 E41-TS-34881 E41-TS-3489) 5. Bus Power Monitor NA (E41-K55 l E41-K56) 6. HPCI Turbine Exhaust Diaphragm Pressure - High NA (E41-PSH-N012A,B,C,D) 7. HPCI Steam Line Ambient Temperature - High NA (E51-TS-N603C,D) 8. HPCI Steam Line Area a Temperature - High NA (E51-TDS-t!604C,D) 9. HPCI Equipment Area Temperature - High NA (E41-TS-602A,5)

10. Drywell Pressure - High NA (E11-PT-N011C,D)

(E11-PTS-N011C-2,D-2) BRUNSWICK - UNIT 1 3/4 3-28 Amendment No.

(BSEP-1-ll6) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME , TRIP FUNCTION AND INSTRUMENT NUMBEE RESP 0t!SE TIhd (Seconds)(a)(d) b. Reactor Core Isolation Cooling System Isolation II)

1. RCIC Staan Line Flow - High

< 13 (E51-PDT-N0178 E51-PDT-W018) (E51-PDTS-N017-21 E51-PDTS-N018-2)

2. RCIC Steam Line Flow - High Time Delay P.elcy NA (E51-TDR-K328 E51-TDR-K12)

3. RCIC Steam Supply Pressure - Lov NA (E51-PS-N019A,B,C,D)

4. RCIC Steam Line Tunnel Temperature - High NA (E51-TS-33191 E51-TS-33208 E51-TS-3321; E51-TS-33221 E51-TS-33231 E51-TS-33551 E51-TS-3487)

5. Bus Power Monitor NA (E51-K42; E51-K43) 4

6. RCIC Turbine Exhaust Diapheta Pressure - High NA (E51-PS-N012A,B,C,D)

7. RCIC Steam Line Ambient Temperature - High NA (E51-TS-N603A,B)

8. RCIC Steam Line Area A Temperature - High NA (E51-TDS-N604A,B)

9. RCIC Equipment Room Ambient Temperature - High NA l

l (E51-TS-N602A,B) l l

10. RCIC Equipment Room A Tempsrature - High NA (E51-TDS-N601A,5)

11. RCIC Steam Line Tunnel Temperature - High NA Time Delay Relay (E51-KC-M602A,5) l

12. Drywell Pressure - High NA (Ell-PT-N0llA,B)

( (Ell-PTS-N011A-2,B-2) l l l BRUNSWICK - UNIT 1 3/4 3-29 Amendment No. 4

(BSEP-1-116) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME RESPONSETIME(Seconds)(a)(d)l TRIP FUNCTION AND INSTRUMENT NUMBER 5. SHUTDOWN COOLING SYSTEM ISOLATION a. Reactor Vessel Water Level - Low, Level 1 NA ( (B21-LT-N017A-1,R-1,C-1,D-1) i l (B21-LTM-N017A-1.8-1,C-1,D-1) b. Reactor Steam Dome Pressure - High NA (B32-ES-N018A-1,B) 9 i BRUNSWICK - UNIT 1 3/4 3-29a Amendment No.

(BSEP-1-116) TABLE 3.3.2-3 (Continued) i l ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME NOTES (a) The isolation system instrumentation response time shall be measured and recorded as a part of the ISOLATION SYSTEM RESPONSE TIME. Isolation system instrumentation response time specified includes any delay for diesel generator starting assumed in the accident analysis. (b) Radiation monitors are exempt from response time testing. Response time shall be measured from detector output or the input of the first electronic component in the channel. (c) ' Isolation actuation instrumentation response time for MSIVs only. No dissel genarator delays assumed. (d) Isolation system instrumentation response time specified for the Trip Function actuating each valve group / damper shall be added to isolation time shown in plant procedure for valves in each valve group and secondary containment isolation damper to obtain ISOLATION SYSTEM RESPONSE TIME for each valve / damper. (e) Includes time delay added by the time delay relay (E41-TDR-K33 and E41-TDR-K43). (f) Includes time delay added by the time delay relay (E51-TDR-K32 and E51-TDR-K12). (g) Includes time delay added by the time delay relays (C31-R616C,D). (h) Isolation system instrumentation response time for associated valves except MSIVs'. BRUNSWICK - UNIT 1 3/4 3-29b Amendment No.

(BSEP-1-Il6) en E 5e l n" TABI.E 4.3.2-1 Pc ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS Q CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN NHICH g TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED 1. PRIMARY CONTAINMEhT ISOLATION a. Reactor Vessel Water Level - 1. Iow, Level 1 NA ") NA R(b) 1, 2, 3 I (B21-LT-NOl7A-1,B-1,C-1,D-1) (B21-LW-NOl7A-1,8-1,C-1,D-1) D M M 1, 2, 3 2. Low, Level 2 (B21-LT-NO24A-1,B-1; NA *) NA R(b) 1, 2, 3 l I B21-LT-NO25A-1,8-1) t (B21-LTM-NO24A-1,B-1; B21-LTM-NO25A-1,B-1) D M M 1, 2, 3 l u E b. Drywell Pressure - High NA *) NA R(b) 1, 2, 3 I 8 (C71-PT-N002A,B,C,D) (C71-PTM-N002A-1,B-1,C-1,D-1) D M M 1, 2, 3 c. Main Steam Line 1. Radiation - High D W R(d) 1, 2, 3 (D12 RM-K603A,B C.D; D12-RE-N006A,B,C,D) 2. Pressure - Low ( 8121-PT-NO15 A, B, C, D) NA(a) NA R(b) g (821-PM-NO15A-1,B-1,C-1,D-1) e M M 1 3. Flow - High E (321-PDT-NOO6A,B,C,D; NA(a) NA R(b) y U B21-PDT-NOO7A,B,C,D; B21-PDT-NOO8A,B,C,D; O B21-PDT-NOO9A,B,C,D) re z (B21-PDTM-NOO6A-1,B-1,C-1,D-1; D M M 1 ? B 21-PDTW-NOO7 A-1, B-1, C-1, D-1 ; B21-PDTH-NOO8A-1,B-1,C-1,D-1; B21-PDTM-NOO9A-1,B-1,C-1,D-1)

(CSEP-1-Il6) j' TABLE 4.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENfS N M CHANNEL OPERATIONAL 8 CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH Q TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED l U ) PRIMARY CONTAIDE4ENT ISOLATION (Continued) d. Main Steam Line Tunnel Temperature - High

NA M

R 1, 2, 3 (B21-TS-LO10A,B,C,D; B21-TS-N0llA,B,C,D; B21-TS-N012A,B,C,D; B21-TS-N013A,B,C,D) e. Condenser Vacuum - Low NA *I NA R(b) 1, 2(f} I II (B21-PT-N056A,B,C,D) 1, 2(f) (B21-PTM-N056A-1,B-1.C-1,D-1) D M M h f. Turbine Building Area Temperature - High NA M R 1, 2, 3 n-(B21-TS-3225A,B,C,D; B21-TS-3226A,B,C,D; B21-TS-3227A,B,C,D; B21-TS-3228A,B,C,D; B21-TS-3229A,B,C,D; B21-TS-3230A,B,C,D; B21-TS-3231A,B,C,D; B21-TS-3232A,B,C,D) y g. Reactor Building Exhaust Radiation - High D M R 1, 2, 3 (D12-RE-N010A,B; D12-RM-K609A,B) .N 9 e,

TABLE 4.3.2-1 (Cortirued) (BSEP-1-116) ISOLATION ACTUATION INSTRLDIENTATION SLRVEILLANCE REQUIREMENTS E GANNEL OPERATIONAL E GANNEL FUNCTIONAL GANNEL CONDITIONS IN WHIG E TRIP FUNCTION AND INSTRUMENT MIMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED N 2. SECONDARY CONTAIWtENT ISOLATION E a. Reactor Building Exhaust 1,2,3,5, and '} I y Radiation - High D M 1 (D12-RE-N010A,8; D12-RM-K609A,B) b. Drywell Pressure - High (C71-PT-N002A,B,C,D) NA(s) NA R(b) 1, 2, 3 (C71-PTM-N002A-1,8-1,C-1,D-1) D M M 1, 2, 3 c. Reactor Vessel Water Level - Low, Level 2 (B21-LT-NO24A-1,B-1; NA(*} NA R(b) g 2 3 l t* B21-LT-NO25A-1,B-1) e ,+ (B21-LTM-NO24A-1,B-1; D M M 1, 2, 3 l u, /, B21-LTM-NO25A-1,8-1) eu 3. REACTOR NAT7.R CLEANUP SYSTEM ISOLATION s. A Flow - High D M R 1, 2, 3 l (C31-FDS-N603-1A,lB) b. Area Temperature - High NA M R 1, 2, 3 (C31-TS-N600'L,B,C,D,E,F) c. Area Ventilation a Temperature - High NA M R 1, 2, 3 (C31-TDS-N602A,B,C,D,E,F) i d. SLCS Initiation NA R NA. 1, 2, 3 l k (C41A-SI) a g e. Reactor Vessel L?ater Level - Low, Level 2 S NA *} NA R(b) 1, 2, 3 l I (B21-LT-NO24A-1,B-1; y B21-LT-N025A-1,B-1) (B21-LTM-N024A-1,B-1; D M M 1, 2, 3 l B21-LTM-NO25A-1,B-1) f. A Flow - High - Time Delay Relay NA M R 1, 2, 3 (C31-R616C,D) ~ ,w

(ESEP-1-116) en TABLE 4.3.2-1 (Continued) g h ISOLATION ACTUATION INSTRIMENTATION SURVEILIANCE REQUIREMENTS R GANNEL OPERATIONAL GANNEL FUNCTIONAL GANNEL CONDITIONS IN WHIG h TRIP FUNCTION AND INSTRUMENT MIMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED e 4. CORE STANDBY COOLING SYSTEMS ISOLATION a. High Pressure Coolant Injection System Isolation 1. HPCI Steam Line Flow - High ~ (E41-PDT-N004; NA(a) NA R(b) 1, 2, 3 E41-PDT-NOO5) (E41-PDTS-N004-2; D M M 1, 2, 3 E41-PDTS-N005-2) 2. HPCI Steam Line Flow - High Time Delay Relay NA R R 1, 2, 3 a 4 (E41-TDR-K33;

5l E41-TDR-K43) 3.

HPCI Steam Supply Pressure - Low NA M R 1, 2, 3 (E41-PSL-WOOIA,B,C,D) 4. HPCI Steam Lina ' mnel Temperature - ! gh NA M Q 1, 2, 3 (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; E41-TS-3354; E41-TS-3488; E41-TS-3489) g { 9 5. Bus Power Monitor NA R NA 1, 2, 3 (E41-K55; l E41-K56) e z 6. HPCI Turbine Exhaust ? Diaphragm Pressure - High NA M Q 1, 2, 3 (E41-PC-NO12A,B,C,D)

(sSEP-1-ll6) E TABLE 4.3.2-1 (Continued) E E ISOLATION ACTUATION INSTRLMENTATION SURVEILIANCE REQUIREMENTS N GANNEL OPERATIONAL GANNEL FUNCTIONAL GANNEL CONDITIONS IN WHIG E 11tIP FUNCTION AND INSTRUMENT NLMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED G CORE STANDBY 'C00LINC SYSTEMS ISOLATION (Continued) 7. HPCI Steam Line Ambient Temperature - High NA M R 1, 2, 3 (E51-TS-N603C,D) 8. HPCI Steam Line Area A Temperature - High NA M R 1, 2, 3 (E51-TDS-N604C,D) R 9. HPCI Equipment Area Temperature - l'agh NA M Q 1, 2, 3 l T (E41-TS-N602A,B) u g 10. Drywell Pressure - High (E11-PT-N0 llc,D) NA(a) NA R(b) 1 2, 3 (E11-PTS-N0 llc-2,D-2) D M M 1, 2, 3 b. Reactor Core Isolation Cooling System Isolation 1. RCIC Steam Line Flow - High NA *) NA R(b) 1, 2, 3 I (E51-PDT-NOl7; E51-PDT-NO18) (E51-PDTS-NO17-2; D M M 1, 2, 3 E51-PDTS-NOl8-2) [ 7. RCIC Steam Line Flow - High g Time Delay Relay NA R R 1, 2, 3 3 (E51-TDR-K32; E51-TDR-K12) Y 3. RCIC Steam Supply Pressure - Low NA M Q 1, 2, 3 (E51-PS-NOl9A,B,C,D) w. - - - - -. ~

(BSEP-1-116) E TABLE 4.3.2-1 (Continued) E E ISOLATION ACTUATION INSTRIMENTATION SURVEILLANCE REQUIREMENTS E GANNSL OPERATIONAL GANNEL FUNCTIONAL GANNEL CONDITIONS IN WWI G E TRIP FUNCTIOis AND INSTRUMENT NIMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) 4. RCIC Steam Line Tunnel Tcaperature - High NA M R 1, 2, 3 l (E51-TS-3319; E51-TS-3320; 1 E51-TS-3321; i E51-TS-3322; i E51-TS-3323; ti E51-TS-3355; E51-TS-3487) w 0 5. Bus Power Monitor NA - R NA 1, 2, 3 (E51-K42; E51-K43) 6. RCIC Turbine Exhaust Diaphragm Pressure - High NA , M R 1,2,3 (E51-PS-NO12A,B,C,D) 7. RCIC Steam Line Ambient Teeperature - High NA M R 1, 2, 3 (E51-TS-N603A,B) 8. RCIC Steam Line Area A Temperature - High

NA M

R 1,2,3 E (E51-TDS-N604A,B) a 9. RCIC Equipment Room Ambient Temperature - High NA M Q 1, 2, 3 y (E51-TS-N602A,B) 10. RCIC Equipment Room A Temperature - High NA M Q 1,2,3 (E51-TDS-N601A,B) 11. RCIC Steam Line Tunnel Temperature - High Time Delay Relay NA M R 1,'2, 3 (E51-KC-M602A,B)

(BSEP-1-116) TABLE 4.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRl2tENTATION SURVEILLANCE REQUIREMENTS E M GANNEL OPERATIONAL 8 GANNEL FUNCTIONAL GANNEL CONDITIONS IM UNIG TRIP FUNCTION AND INSTRUMENT NIMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED Y CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) y 12. Drywell Pressure - High (Ell-PT-N0llA,B) NA(*} NA R(b) g, y, 3 (E11-PTS-N0llA-2,B-2) D M M 1,2,3 5. SHUTDOWN COOLING SYSTEM ISOLATION a. Reactor Vessel Water Level - Low, Level 1 u NA *} NA R(b) 1, 2, 3 I A (821-LT-WO17A-1,B-1,C-1,D-1) y (821-LTM-N017A-1,B-1,C-1,D-1) D M M 1,2,3 ~ b. Reactor Steam Dome Pressure - High NAS/UIC} h ,MR 1, 2, 3 (B32-PS-NOl8A-1,B) E a 2 E .F

(BSEP-1-116) i TABLE 4.3.2-1 (Continued) ISOLATION AC't JATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS NOTES (a) The transmitter channel check is satisfied by the trip unit channel check. A separate transmitter check is not required. (b) Transmitters are exempted from the monthly channel calibration. (c) If not performed within the previous 31 days. (d) Testing shall verify that the mechanical vacuum pump trips and the mechanical vaevue pump line valve closes. (e) When handling irradiated fuel in the secondary containmen:. (f) When reactor steam perosure > 500 psig. 9 e BRUNSWICK - UNIT 1 3/4 3-29j Amendment No.

(BSEP-1-118) 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIM > g CONTAINMENT PRIMARY CONTAINMENT INTECRITY LIMITING CONDITION FOR OPERATION 3.6.1.1 PRIMARY CONTAINMENT INTEGRITY shall be maintained. APPLICABILITY: CONDITIONS 1, 2, and 3. ACTION: Without PRIMARY CONTAINMENT INTECRITY, restore PRIMARY CONTAINMENT INTECRITY within 2 hours or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. SURVEILLANCE REQUIRESENTS 4.6.1.1 PRIMARY CONTAINMENT INTECRITY shall be demonstratedt a. At least oneg per 31 days by verifying that all primary containment penetrations not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or deactivated automatic valves secured in position, except as provided in Specification 3.6.3. b. By verifying each primary containment air lock OPERABLE per Specification 3.6.1.3. By verifying the suppression pool OPERABLE per Specification 3.6.2.1. c.

Except valves, blind flanges, and deactivated automatic valves which are located inside the containment, the MSIV Pit, the RWCU Penetration Triangle Room, or the TIP Room, and are locked, sealed, or otherwise secured in the closed position. These penetrations shall be verified closed during each COLD SHUTDOWN except such verification need not be performed when the primary containment has not been de-inerted since the last verification or more often than once per 92 days.

Those valves located above the dryvell head requiring head shield block removal for verification will be verified i prior to each replacement of the shield blocks. BRUNSWICK - UNIT 1 3/4 6-1 /,mendment No.

(BSEP-1-110) CONTAINMENT SYSTEMS PRIMARY CONTAINMENT LEAXACE LIMITING CONDITION FOR OPERATION 3.6.1.2 Primary containment leakage rates shall be limited tot a. An overall integrated leakage rate of: 1. Less than or equal to L, 0.5 percent by weight of the containmentairper24$oursatP,,49psig,or 2. Less than or equal to L, 0.357 percent by weight of the containmentairper24fioursatareducedperssureofP, g 25 psig. b. A combined leakage rate of less than or equal to 0.60 L, for all penetrations and all valves, except for main steam isolation valves *, l subject to Type B and C tests when pressurized to P,, 49 psig. c.

Less than or equal to 11.5 sef per hour for any one main steam line isolation valve when tested at 25 psig.

APPLICABILITY: When PRIMARY CONTAINMENT INTEGRITY is required per Specification 3.6.1.1. ACTION With: a. The measured overall integrated primary containment leakage rate exceeding 0.75 L, or 0.75 L, as applicable, or g b. The measured combined leakage rate for all penetrations and all valves, except for main steam line isolation valves *, subject'to Type l B and C tests exceeding 0.60 L,, or { c. The measured leakage rate exceeding 11.5 sci per hour for any one main steam line isolation valve, restore: The overall integrated leakage rate (s) to less than or equal to a. 0.75 L, or 0.75 L, as applicable, and g b. The combined leakage rate for all penetrations and eli valves, except for main steam line isolation valves *, subject to Type B and C tests to less than or equal to 0.60 L,, and

Exemption to Appendix "J" of 10 CFR 50.

BRUNSWICK - UNIT 1 3/4 6-2 Amendment No.

4 (BSEP-1-113) CONTAINMENT SYSTEMS ) 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.3 The primary containment isolation valves and reactor instrumentation system isolation valves listed in plant procedure shall be OPERABLE with isolation times as specified in plant procedure APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: a. With one or more of the primary containment isolation valve (s) specified in plant procedure ,, inoperable, operation may l continue and the provision of Specification 3.0.4 are not applicable, provided that at least one isolation valve is maintained OPERABLE in each affecte,d penetration that is open and either 1. The inoperable valve (s) is restored to OPERABLE status within 8 hours, or 2. Each affected penetration line is isolated within 8 hours by use of at least one deactivated automatic valve secured in the isolation position, or 3. Each affected penetration line is isolated within 8 hours by use of at least one closed manual valve or blind flange. Otherwise, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. b. With one or more of the reactor instrumentation system isolation valves listed in plant procedure inoperable, opera' tion may l continue and the provisions of Specifications 3.0.3 and 3.0.4 are not applicable provided that within 8 hourst 1. The inoperable valve is returned to OPERABLE status, or 2. The instrument line is isolated and the associated instrument is declared inoperable. Otherwise, be in at least HOT SHUTDOVN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. BRUNSWICK - UNIT 1 3/4 6-12 Amendment No.

(BSEP-1-ll8) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.3.1 Each primary containment isolation valve specified in plant procedure shall be demonstrated OPERABLE prior to returning the l valve to service after maintenance, repair, or replacement work is performed on the valve or its associated actuator, control, or power circuit by performance of the cycling test and verification of isolation time. 4.6.3.2 Each isolation valve specified in plant procedure sha'll be l demonstrated OPERABLE at least once per 18 months by verifying that on a containment isolation test signal each isolation valve actuates to its isolation position. 4.6.3.3 The isolation time of each power-operated or automatic valve specified in plant procedure shall be determined to be within its l limit when tested pursuant to Specification 4.0.5. 4.6.3.4 Each reactor instrumentation system isolation valve specified in plant procedure shall be demonstrated OPERABLE at least once per l 18 months by cycling each valve through at 1 cast one complete cycle of full travel. L l BRUNSWICX - UNIT 1 3/4 6-13 Amendment No. [

l (BSEP-1-118) CONTAINMENT SYSTEMS 3/4.6.4 VACUUM RELIEF DRYWELL - SUPPRESSION CHAMBER VACUUM BREAKERS LIMITING CONDITION FOR OPERATION 3.6.4.1 All drywell-suppression chamber vacuum breakers shall be OPERABLE and in the closed positian with: a. The position indicator OPERABLE, and b. An opening set point of less than or equal to 0.5 psid. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: a. With no mere than 2 drywell-suppression chamber vacuum breakers inoperable for opening but known to be in the closed position, the provisions of Specification 3.0.4 are not applicable and operation may continue until the next COLD SHUTDOWN provided the surveillance requirements of Specification 4.6.4.1.a are performed on the OPERABLE vacuum breakers within 4 hocrs and at least once per 15 days thereafter, until the inoperable vacuum breakers are restored to OPERABLE status. b. With one drywell-suppression chamber vacuum breaker in the open position, as indicated by the position indicating system, the provisions of Specificaton 3.0.4 are not applicable and operation may continue provided the surveillance requirements of Specification 4.6.4.1.a are performed on the OPERABLE vacuum breakers, and the surveillance requirements of Specification 4.6.4.1.b are performed within 8 hours and at least once per 72 hours thereafter, until the inoperable vacuum breaker is restored to the closed position. c. With the position indicator of any drywell-suppression chamber vacuum breaker inoperable, the provisions of Specification 3.0.4 are no: applicable, and operation may continue provided the surveillance requirements of Specification 4.6.4.1.b are performed within 8 hours and at least once per 72 hours thereafter, until the inoperable i position indicator is returned to OPERABLE status. d. Otherwise, be in at least HOT SHUTDOWN within 12 hours and in COLD SHUTDOWN within the next 24 houro. l BRUNSWICK - UNIT 1 3/4 6-14 Amendment No.

(SSEP-1-118) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.4.1 Each drywell-suppression chamber vacuum breaker shall be demonstrated OPERA 8tEt a. At least once per 31 days and after any discharge of steam to the suppression chamber from any source, by exercising each vacuum breaker through one complete cycle and verifying that each vacuum breaker is closed as indicated by the position indicacion system. b. Whenever a vacuum breaker is in the open position, as indicated by the position indication system, by conducting a test that verifies that the differential pressure is maintained greater than 1/2 the initial delta P for one hour without N2 makeup. c. At least once per 18 months during shutdown by: 1. Verifying the opening setpoint, from the closed position, to be less than or equal to 0.5 psid, 2. Performance of a CHANNEL CALIBRATION that each position indicator. indicates the vacuum breaker to be open if the vacuum breaker does not satisfy the delta P test in 4.6.4.1.b. l BRUNSWICK - UNIT i 3/4 6-15 Amendment No.

(BSEP-1-ll8) CONTAINMENT SYSTEMS SUPPRESSION POOL - REACTOR BUILDINC VACUUM BREAKERS LIMITING CONDITION FOR OPERATION 3.6.4.2 All suppression pool-Reactor Building vacuum breakers shall be OPERABLE with I a. an opening setpoint of less than or equal to 0.5 psid L. an OPERABLE Nitrogen Backup System consisting of two independent subsystems (one subsystem for each vacuum breaker). APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: a. With one suppression pool-Reactor Building vacuum breaker inoperable for opening but known to be in the closed position, restore the inoperable vacuum breaker to OPERABLE status within 7 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. b. With one Nitrogen Backup System subsystem inoperable, verify the remaining subsystem is OPERABLE and restore the inoperable subsystem to OPERABLE status within 31 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours, c. With both Nitrogen Backup System subsystems inoperable, restore at least one inoperable subsystem to OPERABLE status within 7 days; otherwise, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN .j within the following 24 hours. SURVEILLANCE REQUIREMENTS 4.6.4.2.1 Each suppression pool-Reactor Building vacuum breaker shall be demonstrated OPERABLE: a. At least once per 92 days by: j i 1. Manually verifying that each vacuum breaker check valve is free to open, and I I 2. Cycling each vacuum breaker butterfly valve through at least one j complete cycle of full travel. I b. At least once per 18 months by: 1. Demonstrating that the force required to open each vacuum breaker check valve does not exceed 0.5 psid. l BRuNsWICx - UNIT 1 > 4 6-16 Amendment No.

(BSEP-A-l&B) SURVEILLANCE REQUIREMENTS (Continued) 2. Demonstrating that the vacuum breaker butterfly valve opens at -0.45 + 0.05 psid, drywell pressure going negative relative to Reactor Building pressure. 3. Visual inspections. 4.6.4.2.2 The Nitrogen-Backup System shall be demonstrated OPERABLEI a. At least once per-24 hours by verifying that each subsystem is pressurized to greater than or equal to 1130 psig. b. At least once per 18 months by verifying that each subsystem maintains system pressure with a leakage rate of less than or equal to.65 SCFM at 4'- starting pressure greater than or equal to 1130 psig. c. At least once per 18 months by performing a logic system functional test to ensure actuation of the nitrogen backup system. t i l i. i l I i i I BRUNSWICK - UNIT 1 3/4 6-17 Amendment No. f .-... I

( BliEP-1-l &8 ) CONTAINHENT SYSTEMS 3/4.6.5 SECONDARY CONTAINMENT SECONDARY CONTAINMENT INTECRITY LIMITINC CONDITION FOR OPERATION 3.6.5.1 SECONDARY CONTAINMENT INTEGRITY shall be maintained. APPLICABILITY: CONDITIONS 1, 2, 3, 5, and *. ACTION Without SECONDARY CONTAINMENT INTEGRITY, restore SECONDARY CONTAINMENT INTEGRITY within 8 hours, ort a. In CONDITION 1, 2, or 3, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. b. In CONDITION 5 or *, suspend irradiated fuel handling in.the secondary containment, CORE ALTERATIONS, and activities which could reduce the SHUTDOWN MARGIN. The provisions of Specification 3.0.3 are not applicable. SURVEILLANCE REQUIREMENTS 4.6.5.1 SECONDARY CONTAINMENT INTECRITY shall be demonstrated by verifyingt a. At least once per 92 days that each secondary containment isolation damper is OPERABLE or secured in the closed position per Specification 3.6.5.2. b. At least once per 18 months by operating a standby gas treatment system for 1 hour and maintaining > 1/4 inch of vacuum, water gauge, at a flow rate not exceeding 3000 CFM.

When irradiated fuel is being handled in the secondary containment.

l BRUNSWICK - UNIT 1 3/4 6-18 Amendment No.

(BSEP-1-118) CONTAINMENT SYS'TEMS I SECONDARY CONTAINMENT AUTOMATIC ISOLATION DAMPERS LIMITING CONDITION FOR OPERATION 3.6.5.2 The secondary containment automatic isolation dampers specified in plant procedure shall be OPERABLE. l ~ APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, 5, and *. l ACTION: With one or more of the secondary containment isolation dampers specif ied in plant procedure inoperable, operation may continue and the l provisions of Specification 3.0.4 are not applicable, provided that at least one isolation damper is maintained OPERABLE in each affected penetration that is open, andt The inoperable damper is restored to OPERABLE status within 8 hours, a. or b. The affected penetration is isolated by use of a closed damper within 8 hours, or c. SECONDARY CONTAINMENT INTEGRITY is demonstrated within 8 hours and the damper is restored to OPERABLE status within 7 days. Otherwise, in OPERATIONAL CONDITIONS 1, 2, or 3, be in at least HOT l SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. Otherwise, in OPERATIONAL CONDITION 5 or *, suspend irradiated fuel l handling in the secondary containment, CORE ALTERATIONS, or activities that could reduce the SHUTDOWN MARCIN. The provisions of Specification 3.0.3 are not applicable. I 4

When irradiated fuel is being handled in the secondary containment.

t i BRUNSWICK - UNIT 1 3/4 6-19 Amendment No. w

(BOCP-1-ll8) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.5.2 Each secondary containment automatic isolation damper specified in plant procedure shall be demonstrated OPERABLE l At least once per 92 days by cycling each automatic isolation damper a. testable during plant operation through at least one complete cycle of full travel. b. Prior to returning the damper to service after maintenance, repair, or replacement work is performed on the damper or its associated actuator, control, or power circuit by performance of the cycling test and verification of isolation time. c. At least once per 18 months during COLD SHUTDOWN or REFUELING byt 1. Cycling each automatic damper through at least one complete cycle of full travel and measuring the isolation time, and 2.* Verifying that on a secondary containment isolation test signal each automatic damper actuates to its isolation position. 1

For this verification scheduled to be completed by February 25, 1981, a onetime-only exemption is allowed to extend this verification until "before the completion of the Spring 1981 outage," scheduled to commence in March, 1981.

l BRUNSWICK - UNIT 1 3/4 6-20 Amendment No.

(BSEP-1-118) CONTAINMENT SYSTEMS 3/4.6.6 CONTAINMENT ATMOSPHERE CONTROL STANDBY CAS TREATMENT SYSTEM LIMITING CONDITION FOR OPERATION 3.6.6.1 Two independent standby gas treatment subsystems shall be OPERABLE. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, 5, and *. ACTION: a. With one standby gas treatment subsystem inoperable: 1. In OPERATIONAL CONDITION 1, 2, or 3, restore the inoperable subsystem to OPERABLE. status within 7 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. 2. In OPERATIONAL CONDITION 5 or *, restore the inoperable subsystem to OPERABLE status within 31 days or suspend irradiated fuel handling in the secondary containment, CORE ALTERATIONS, or operations that could reduce the SHVfDOWN MARCIN. The provisions of Specification 3.0.3 are not applicable. b. With both standby gas treatment subsystems inoperablei 1. In OPERATIONAL CONDITION 1, 2, or 3, be in at least HOT SHUTDOWN within 12 hours and in COLD SHUTDOWN within the next 24 hours. 2. In OPERATIONAL CONDITION 5 or *, suspend all irradiated fuel handling in the secondary containment, CORE ALTERATIONS, or operations that could reduce the SHUTDOWN MARCIN. The provisions of Specification 3.0.3 are no: s.pplicable. SURVEILLANCE REQUIREMENTS 4.6.6.1 Each standby gas treatment subsystem shall be demonstrated OPERABLE: a. At least once per 31 days by initiating, from the control room, flow through the HEPA filters and charcoal absorbers, and verifying that the subsystem operates for at least 10 hours with the heaters on automatic control.

When irradiated fuel is being handled in the secondary containment.

6 l BRUNSWICr ITNIT 1 3/4 6-21 Amendment No. t

(BSEP-A-ll8) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b. At least once per '.8 months or (1) after any structural maintenance on the HEPA filter or charcoal absorber housings, or (2) following painting, fire or chemical release in any ventilation zone, communicating with *.he system by: 1. Verifying that the cleanup system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.S.a., C.5.c, and C.S.d of Regulatory Guide 1.52, Revision 1, July 1976, and the system flow rate is 3000 cfm 3 10%. 2. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 1, July 1976, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 1, July 1976. 3. Verifying a system flow rate of 3000 cfm 1 10% during system operation when tested in accordance with ANSI N510-1975. c. After every 720 hours of charcoal absorber operation by verifying within 31 days after removal that a laboratory analysis of representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 1, July 1976, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 1, July 1976. d. At least once per 18 months by: 1. Verifying that the pressure drop across the combined HEPA filters and charcoal absorber banks is less than 8.5 inches Water cause while operating the filter train at a flow rate of 3000 cfm + 10%. 2.* Verifying that the filter train starts on each secondary containment isolation test signal. 3. Verifying that the heaters will dissipate at least 15.2 kw when tested in accordance with ANSI N510-1975.

For the performance of this surveillance scheduled to be completed by February 25, 1981, a onetime-only exemption is allowed to extend this surveillance until "before the completion of the Spring 1981 outage,"

scheduled to commence in March, 1982. l BRUNSWICK - UNIT 1 3/4 6-22 Amendment No.

(BSEP-1-118) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove > 99% of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 3000 cfm 10%. f. After each complete or partial replacement of a charcoal absorber bank by verifying that the charcoal absorbers remove > 99% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 3000 cfm 1 10%. 'l e l l l l I BRUNSWICK - UNIT 1 3/4 6-23 Amendment No.

l 1 (BSEP-1-118) CONTAINMENT SYSTEMS CONTAINMENT ATMOSPHERE DILUTION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.6.2 The containment atmosphere dilution (CAD) system shall be OPERABLE withs a. An OPERABLE flow path capable of supplying nitrogen to the drywell, and b. A minimum supply of 4350 gallons of liquid nitrogen. APPLICABILITY: CONDITION 1*. ACTION With the CAD system inoperable, restore the CAD system to OPERABLE status within 31 days or be in at least STARTUP within the next 8 hours. The l provisions of Specification 3.0.4 are not applicable. SURVEILLANCE REQUIREMENTS 4.6.6.2 The CAD system shall be demonstrated to be OPERABLEI a. At least once_per 31 days by verifying that: 1. The system contains a minimum of 4350 gallons of* Liquid nitrogen, and 2. Each valve (manual, power-operated, or automatic) in the flow path not locked, sealed, or otherwise secured in positica, is in its correct position. b. At least once per 18 months by: 1. Cycling each power operated (excluding automatic) valve in the flow path through at least one complete cycle of full travel, and 1 2. Verifying that each automatic valve in the flow path actuates to its correct position on a Group 2 and 6 isolation test signal. 4 I

When oxygen concentration is required to be < 41 per Specification 3.6.6.3.

J l BRUNSWICK - UNIT 1 3/4 6-24 Amendment No.

(BSEP-1-118) CONTAINMENT SYSTEMS OXYCEN CONCENTRATION LIMITINC CONDITION FOR OPERATION 3.6.6.3 The primary containment atmosphere oxygen concentration shall be less than 4% by volume during the period from: Within'24 hours after THERMAL POWER > 15% of RATED THERMAL POWER, to a. b. Within 24 hours prior to a scheduled reduction of THERMAL POWER to < 15% of RATED THERMAL POWER. APPLICABILITY: CONDITION 1. ACTION: With the oxygen concentration in ther primary containment exceeding the limit, be in at least STARTUP within 8 hours. SURVEILLANCE REQUIREMENTS 4.6.6.3 The oxygen concentration in the primary containment shall be verified to be within the limit within 24 hours af ter THERMAL POWER > 15% of RATED THERMAL POWER and at least once per 7 days thereafter. I f l I I L l l l I BRUNSWICK - UNIT 1 3/4 6-25 Amendment No.

(BSEP-1-113) CONTAINMENT SYSTEMS CAS ANALYZER SYSTEMS LIMITINC CONDITION FOR OPERATION 3.6.6.4 Two independent gas analyzer systems for the drywell and supptession chamber shall be OPERABLE with each system consisting of an oxygen analyzer and a hydrogen analyzer. APPLICABILITY: OPERATIONAL CONDITION 1. ACTION: With one oxygen and/or one hydrogen analyzer inoperable, restore at a. least two oxygen and two hydrogen analyzers to OPERABLE status within 31 days or be in at least STARTUP within the next 8 hours. The provisions of Specification 3.0.4 are not applicable. b. With no gas analyzer OPERABLE for oxygen and/or hydrogen, be in at least STARTUP within 8 hours. SURVEILLANCE REQUIREMENTS 4.6.6.4 Each gas analyzer system (CAC-AT-4409, Divison I and CAC-AT-4410, Division II) shall be demonstrated OPERABLE at least once per 92 days by performing a CHANNEL CALIBRATION using standard gas samples containing a nominal: Zero volume percent hydrogen, balance nitrogen. a. b. Seven to ten volume percent hydrogen, balance nitrogen. Twenty-five to thirty volume percent hydrogen, balance nitrogen. c. d. Zero volume percent oxygen, balance nitrogen. Seven to ten volume percent oxygen, balance nitrogen. e. f. Twenty to twenty-five volume percent oxygen, balance nitrogen. l BRUNSWICK - UNIT 1 3/4 6-26 Amendment No.

(BSEP-1-118) CONTAINMENT SYSTEMS BASES 3/4.6.3 PRIKARY CONTAINMENT ISOLATION VALVES (Continued) A list of automatic closing primary containment isolation valves and their associated closure times shall be available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50. The addition and deletion of primary containment isolation valves shall be made in accordance with Section 50.59 of 10 CFR Part 50. 3/4.6.4 VACUUM RELIEF Vacuum relief breakers are provided to equalize the pressure between the drywell and suppression pool and the suppression pool and reactor building. This system will maintain the structural integrity of the containment under conditions of large differential pressures. The vacuum breakers between the drywell and the suppression pool must not be inoperable in the open position since this would allow bypassing of the suppression pool in case of an accident. There are an adequate number of valves to provide some redundancy so that operation may continue with no more than 2 vacuum breakers inoperable and secured in the c.losed position. Each set of vacuum relief valves between the suppression chamber and reactor building provides 100% relief, which may by required in the unlikely event that negative pressures develop in the primary containment. The Nitrogen Backup System pro.vides backup motive power for these suppression pool-reactor building vacuum breakers on a loss of instrument air. The normal non-interruptible instrument air system for these vacuum breakers is designed as a Seismic Class I system supplied by air compressors powered from the emergency buses. The Nitrogen System serves as a backup to that air system and thus the loss of the Nitrogen System, or portions thereof, does not make the vacuum breakers inoperable. The design allows for the out of service times in Actions b and c. The Nitrogen Backup System is added to the Suppression Pool-Reactor Building Vacuum Breaker specification to satisfy NRC concerns relative to 10 CFR 50.44(c)(3) as addressed in the Brunswick Safety Evaluation Report dated October 30, 1986 concerning Generic Letter 84-09. Pressurization to 1130 psig assure's sufficient system capacity to provide 24 hours of operation with design valve actuation and system leakage. 3/4.6.5 SECONDARY CONTAINMENT Secondary containment is designed to minimize any ground level release of radioactive material which may result from an accident. The reactor building provides secondary containment during normal operation when the drywell is sealed and in service. When the reactor is shut down, or during refueling, the.dryvell may be open and the reactor building then becomes the primary containment. BRUNSWICK - UNIT 1 B 3/4 6-5 Amendment No.

(BSEP-1-118) CONTAINMENT SYSTEMS BASES (Continued) l '3/4.6.5 SECONDARY CONTAINMENT (Continued) Establishing and maintaining a vacuum in the building with the standby gas treatment system, once per 18 months, along with the surveillance of the I valves, is adequate to ensure that thern are no violations of the integrity of the secondary containment. .A list of secondary containment automatic isolation dampers shall be available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50. The addition and deletion of secondary containment automatic isolation dampers shall be made in accordance with Section 50.59 of 10 CFR Part 50. 3/4.6.6 CONTAINMENT ATMOSPHERE CONTROL The OPERABILITY of the containment iodine filter trains ensures that sufficient iodine removal capability will be available in the event of a LOCA. The reduction in containment iodine inventory reduces the resulting site boundary radiation doses associated with containment leakage. The operation of this system and resultant iodine removal capacity are consistent with the assumptions used in the LOCA analyses. l 4 3 i I I BRUNSWICK - UNIT 1 B 3/4 6-6 Amendment No.

l h i 1 ENCLOSURE 4 BRUNSWICK STEAN ELECTRI,C PIANT, UNITS 1 AND 2 2 NRC DOCKETS 50 325 & 50 324 OPERATING LICENSES DPR 71 & DPR-62 t REQUEST FOR LICENSE AMENDNENT UNIT 2 TECHNICAL SPECIFICATION PAGES I i j i f' e f I I I I I I 4 I P t t i i i dr

(BSEP-2-124) INDEX LIMITINC CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS h SECTION PACE 3.4.6 CONTAINMENT SYSTEMS (Continued) Primary Containment Structural Integrity.................. 3/4 6-6 I Primary Containment Internal Pressure..................... 3/4 6-7 Primary Containment Average Air Temperature............... 3/4 6-8 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS Suppression Poo1.......................................... 3/4 6-9 Suppression Pool Cooling.................................. 3/4 6-11 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES...................... 3/4 6-12 l 3/4.6.4 VACUUM RELIEF Drywell - Suppression Pool Vacuum Breakers................ 3/4 6-14 Suppression Pool - Reactor Building Vacuum Breakers....... 3/4 6-16 3/4.6.5 SECONDARY CONTAINMENT Secondary Containment Integrity........................... 3/4 6-18 Secondary Containment Automatic Isolation Dampers......... 3/4 6-19 3/4.6.6 CONTAINMENT ATMOSPHERE CON *ROL Standby Cas Treatment System.............................. 3/4 6-21 Containment Atmosphere Dilution System.................... 3/4 6-24 0xygen Concentration...................................... 3/4 6-25 l Cas Analyzer Systems...................................... 3/4 6-26 i 3/4.7 PLANT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS I Residual Heat Removal Service Water System................ 3/4 7-1 Service Water System...................................... 3/4 7-2 r BRUNSWICK - UNIT 2 VII Amendment No. l t - +-- "

(BSEP-2-124) INDEX BASES SECTION PAGE 3/4.4 REACTOR COOLANT SYSTEM (Continued) 3/4.4.4 CHEMISTRY.............................................B 3/4 4-2 3/4.4.5 SPECIFIC ACTIVITY.....................................B 3/4 4-2 3/4.4.6 PRESSURE /TEMPERATUME LIMITS...........................B 3/4 4-3 3/4.4.7 MAINSiEAMLINEISOLATIONVALVES......................B3/44-7 3/4.4.8 STRUCTURAL INTEGRITY..................................B 3/4 4-7 3/4.5 EMERGENCY CORE C00LINC SYSTEMS 3/4.5.1 HICH PRESSURE COOLANT INJECTION SYSTEM................B 3/4 5-1 3/4.5.2 AUTOMATIC DEPRESSURIZATION SYSTEM.....................B 3/4 5-1 3/4.5.3 LOW PRESSURE COOLING SYSTEMS..........................B 3/4 5-2 3/4.5.4 SUPPRESSION P00L......................................B 3/4 5-4 l 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT...................................B 3/4 6-1 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS..................B 3/4 6-3 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES..................B 3/4 6-4 3/4.6.4 VACUUM RELIEF.........................................B 3/4 6-5 3/4.6.5 SECONDARY C0NTAIAMENT.................................B 3/4 6-5 3/4.6.6 CONTAINMENT ATMOSPHERE C0NTROL........................B 3/4 6-6 3/4.7 PLAAT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS.................................B 3/4 7-1 3/4.7.2 CONTROL ROOM EMERCENCY FILTRATION SYSTEM..............B 3/4 7-1 BRUNSWICK - UNIT 2 XI Amendment No.

(BSEP-3-120) DEFINITIONS OFFSITE DOSE CALCULATION MANUAL (ODCM) The OFFSITE DOSE CALCULATIONAL MANUAL (ODCM) is a manual which contains the current methodology and parameters to be used to calculate off site doses resulting from the release of radioactive gaseous and liquid effluents; the methodology to calculate gaseous and liquid effluent monitoring instrumentation alare/ trip setpoints; and, the requirements of the environmental radiological monitoring program. OPERABLE - OPERA 8ILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified f unction (s). Implicit in this definition shall be the assumption that all necessary attendant instrumentation, controls, normal and emergency electric power sources, cooling or seal water, lubrication or other auxiliary equipment that are required for the system, cubsystem, train, component, or device to perform its function (s) are also capable of performing their related support function (s). OPERATIONAL C0KDITION An OFERATION4L CONDITION shall be any one inclusive combination of mode switch position and average reactor coolant temperature as indicated in Table 1.2. PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the t eactor core ar.d related instrumentation and are 1) described in Section 13 of the FSAR, 2) authorized under the provisions of 10 CFR 50.59, or 3) otherwise approved by the Commission. PRESSURE BOUNDARY LEAKACE PRESSURE BOUNDARY LEAKACE shall be leakage through a non-isolable fault in a reactor coolant system component body, pipe wall, or vessel wall. PRIMARY CONTAINMENT INTECRITY PRIMARY CONTAINHENT INTECRITY ahall exist whent All penetrations required to be closed during accident conditions a. are eithert 1. Capable of being closed by an OPERABLE containment automatic isolation valve system, or 2. Closed by at least one manual valve, blind flange, or deactivated automatic valve secured in its closed position, except as provided in Specification 3.6.3. BRUNSWICK - UNIT 2 1-5 Amendment No.

(BSEP-2-120) TABLE 3.3.2-1 ISOLATION ACTUATION INSTRUMENTATION E VALVE CROUPS MINIMUM NUMBER APPLICABLE E OPERATED BY OPERABLE CNAIBIELS OPERATIONAL E TRIP FUtiCTION AND INSTRUMENT NLDiBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTIOtt ~n 75 1. PRIMARY CONTAINMENT ISOLATION s a. Reactor Vessel Water Level - g 1. Low, Level 1 2, 6 2 1,2,3 20 (B21-LT-N017A-1,B-1,C-1,D-1) 8 2 1, 2, 3 27 (821-LTN-N017A-1,5-1,C-1,D-1) 9 e 2. Lsw, Level 3 1 '2 1, 2, 3 R20 l .i (B21-LT-N024A-1,B-1; B21-LT-N025A-1,B-1) (B21-LTS-N024A-1-2,B-1-2; B21-LTS-N025A-1-2,B-1-2) b. Drywell Pressure - Hi;n 2, 6 2 1,2,3 20 l t* (C72-PT-N002A,B,C,D) (C72-PTM-NOO2A-1,B-1,C-1,D-1)

saj, c.

Main Steam Line 1. Radiation - High 1 2 1, 2, 3 21 ( D12-RE-N006 A, B, C, D) (D12-RM-K603A,B,C,D) III l 2 1 22 2. Pressure - Low I (B21-PT-N015A,B,C,D) (B21-PTM-NO15A-1,B-1,C-1,D-1) III 2/line 1 22 l 3. Flow - High I (821-PDT-NOO6A,B,C,D; B21-PDT-NOO7A,B,C,D; g B21-PDT-NOO8A,B,C,D; g B21-PDT-N009A,B,C,D) k (B21-P DTM-NOO6 A-1, B-1,C-1, D-1; 3 B21-PDTM-NOO7A-1,B-1,C-1,D-1; B21-PDTM-WOO 8A-1,B-1,C-1,D-1; B21-PDTM-NOO9 A-1, B-1, C-1, D-1 ) o

(BSEP-2-120) g TABLE 3.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRUMENTATION N PG VALVE CBOUPS GINIMUM MUMBER APPLICABLE 8 OPERATED BY OPERABLE CHAIRIELS OPERATIONAL Q 1 RIP FUNCTION AND INSTRUMENT NUMBER SIGNAL (a) PER TRIP SYSTEM (b)(c) CONDITION ACTION N PRIMARY CONTAIDBtENT ISOLATION (Continued) u II) 4. Flow - High I 2 2, 3 21 (B21-PDTS-NOO6A-2; B21-PDTS-NOO78-2; B21-PDTS-NOO8C-2; B21-PDTS-NOO9 D-2 ) d. Main Steam Line Tunnel II) 2(d) 1, 2, 3 21 Temperature - High I 2: (B21-TS-N010A,B,C D; B21-TS-N011A,B,C,D; u, J. B21-TS-N012A,B,C,D; ^ B21-TS-N013A,B,C,D) II) 2 1, 2 * ) 21 I e. Condenser Vacuum - Low I (B21-P7-N056A,B,C,D) (521-PTM-N056A-1,B-1,C-1,D-1) f. Turbine Building Area III Id) 4 1, 2, 3 21 Temperature - High I (B21-TS-3225A,B,C,D; B21-TS-3226A,B,C,D; B21-TS-3227A,B,C,D; ji B21-TS-3228A,B,C,D; B21-TS-3229A,B,C,D; B21-TS-3230A,B,C,D; B21-TS-3231A,B,C,D; B21-TS-3232A,B,C,D) g. Reactor Building Exhaust 6 1 1,2,3 20 Radiation - High (D12-RE-N010A,B) (012-RM-K609A,B) .__-.-.r, y 4 m,,,.

(BSEP-2-120) TABLE 3.3.2-1 (Continued) E %} ISOLATION ACTUATION INSTRUMENTATION N M VALVE GROUPS MINIMUM MUMBER APPLICABLE 8 OPERATED BY OPERABLE CHAINIELS OPERATIONAL TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTION U 2. SECONDARY CONTAINMENT ISOLATION y a. Reactor Building Exhaust , 1 1, 2, 3, 5, 23 Radiation - High (k) (D12-RE-N01CA,B) and * (D12-RM-K609A,B) 6 1 1,2,3 20 b. Drywell Pressure - High (k) 2 1,2,3 23 (C72-PT-N002A,B,C,D) 2, b 2 1,2,3 20 (C72-PTM-NOO2A-1,B-1,C-1,D-1) fh c. Reactor Vessel Water Level - Low, Level 2 (k) 2 1,2,3 23 u,j, ( 821-LT-NO24 A-1, B-1 ; 3 2 1, 2, 3 24 B21-LT-N025A-1,B-1) (B21-LTM-NO24A-1-1,B-1-1; B21-LTM-NO25A-1-1 B-1-1) 3. REAC1DR WATER CLEANUP SYSTEM ISOLATION a. A Flow - High 3 1 1,2,3 24 (C31-FDS-N603-1 A, lB ) b. Area Temperature - High 3 2 1, 2, 3 24 f (C31-TS-N600A,B,C,D,E,F) S-Area Ventilation A Temperature - High 3 2 1, 2. 3 24 c. 5 (C31-TDS-N602A,B,C,D,E,F) l If) NA 1, 2, 1 24 d. SLCS Initiation 3 [ (C41A-SI)

(BSEP-2-120) TABLE 3.3.2-1 (Continued) gl ISOLATION ACTUATION INSTRUMENTATION Ey VALVE CROUPS MINIMUN NUMBER APPLICABLE g OPERATED BY OPERABLE CHANNELS OPERATIONAL M TRIP FUNCTION AND INSTRUMENT NIMBER SICMAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTION s REACTOR WATER CLEANUP SYSTEM ISOIATION (Continued) N e. Reactor Vessel Water Level - r, Low, Level 2 3 2 1, 2, 3 24 (821-LT-NO24A-1,B-1; l B21-LT-NO25A-1,B-1) ( B21-LTM-N024 A-1-1, B-1-1 ; B21-LTM-NO25A-1-1,B-1-1) l f. A Flow - High - Time Delay Relay NA 1 1,2,3 24 (C31-R616C,D) R 4. CORE STANDBY COOLINC SYSTEMS ISOLATION Y High Pressure Coolant Injection System Isolation Z a. 1. HPCI Steam Line Flow - High 4 1 1, 2, 3 25 (E41-PDT-NOO4; E41-PDT-NOO5) (E41-PDTS-NOO4-2; E41-PDTS-NOO5-2) 2. HPCI Steam Line Flow - High Time Delay Relay NA 1 1, 2, 3 25 (E41-TDR-K33; g E41-TDR-K43) 2 1, 2, 3 25 j[ 3. HPCI Steam Supply Pressure - Low g (E41-PSL-NOOlA,B,C,D) 7 1 1, 2, 3 25 E .E

(BSEP-2-120) TABLE 3.3.2-1 (Continued) Eg ISOLATION ACTUATION INSTRUMERFTATION M P5 VALVE CROUPS MINIMUM NUMBER APPLICABLE 8 OPERATED BY OPERABLE CHAINIELS OPERATIONAL E TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITIOtf ACTIOtf U CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) u 4. HPCI Steam Line Tunnel Temperature - High 4 2 1,2,3 25 (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; ti E41-TS-3354; E41-TS-3488; Y E41-TS-3489) 5. Bus Power Monitor NA(E} 1/ bus 1, 2, 3 26 N l (E41-K55; E41-K56) 6. HPCI Turbine Enhaust Diaphragm Pressure - High 4 2 1,2,3 25 (E41-PSH-NO12A,B,C,D) 7. HPCI Steam Line Ambient Temperature - High 4 1 1, 2, 3 25 (E51-TS-N603C,D) k 8. HPC1 Steam Line Ares E. A Temperature - High 4 1 1,2,3 25 g 2 (E51-TDS-N604C,D) l n 9. HPCI Equipment Area Temperature - High 4 1 1,2,3 25 (E41-TS-N602A,B) 10. Drywell Pressure - High (E11-PT-N011C,D) 7(3) 1 1,2,3 25 (E11-PTS-N011C-2,D-2) l

(BSEP-2-123) ,;i 5 TA3LE 3.3.2-1 (Continued) E E ISOLATION ACTUATION INSTRUMENTATION M* VALVE CROUPS MINIMUM MUMBER APPLICABLE OPERATED BY OPERABLE CHAMELS OPERATIONAL TRIP FUNCTION AND INSTRUMENT NUMBER SICMAL(a) PER TRIP 3YSTEM(b)(c) CONDITION ACTION U b. Reactor Core Isolation Cooling System Isolation u 1. RCIC Steam Line Flow - High 5 1 1, 2, 3 25 (E51-PDT-NOl7; E51-PDT-NOl8) (E51-PDTS-N017-2; E51-PDTS-N018-2) 2. RCIC Steam Line Flow - High Time Delay Relay NA 1 1,2,3 25 w 2: (E51-TDR-K32; E51-TDR-K12) 5 3. RCIC Steam Supply Pressure - Low 2 1,2,3 25 3) 1 1,2,3 25 (E51-PS-N019A,B,C,D) 9 4. RCIC Steam Line Tunnel Temperature - High 5 2 1,2,3 25 (E51-TS-3319; E51-TS-3320; E51-TS-3321; E51-TS-3322; E51-TS-3323; E51-TS-3355; k F51-TS-3487) IE) 1/ bus 1, 2, 3 26 l 5. Bus Power Monitor MA (E51-K42; 3" E51-K43) 6. RCIC Turbine Exhaust Diaphragm Pres ~ S - High 5 2 1, 2, 3 25 (E' J-N012A,B,C,D) i .,rywy--- -y, vi r-- w- ,y w w- ,r ey r-~ n-- 4-m.

.r-r-r

(BSEP-2-120) g TABLE 3.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRUMENTATION

s M

VALVE CROUPS MINIMUM NUMBER APPLICABLE 8 OPERATED BY OPERABLE CHARRIELS OPERATIONAL TRIP FUNCTION AND INSTRUMENT NUMBER SICNAL(a) PER TRIP SYSTEM (b)(c) CONDITION ACTION U CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) u 7. RCIC Steam Line Ambient Temperature - High 5 1 1, 2, 3 25 (E51-TS-N603A,B) 8. RCIC Steam Line Area A Temperature - High 5 1 1,2,3 25 (E51-TDS-N604A,5) t* 9. RCIC Equipment Room Ambient Temperature - High 5 1 1,2,3 25 8' j' (E51-TS-N602A,B) 10. RCIC Equipment Room A Temperature - High 5 1 1,2,3 25 (E51-TDS-N601 A,B) 11. RCIC Steam Line Tunnel NA 1 1,2,3 25 Temperature - High Time Delay Relay (E51-KC-M602A,B) I5) 12. Dryvell Pressure - High 9 1 1,2,3 25 (Ell-PT-N0llA,B) g (E11-PTS-N011A-2,B-2) Eg 5. SHUTDOWN COOLING SYSTEM ISOLATION a. Reactor Vessel Water Level - 2, 6 2 1, 2, 3 20 g Low, Level 1 8 2 1,2,3 27 (821-LT-N017A-1,B-1,C-1,D-1) (B21-LTM-NOl7A-1,B-1.C-1,D-1) b. Reactor Steam Dome Pressure - High 8(h) g g, y, 3 27 (B32-PS-N018A-1,B)

(BSEP-3-130) TABLE 3.3.2-1 (continued) ISOLATION ACTUATION INSTRUMENTATION ACTIONS ACTION 20 - Be in at least HOT SHUTDOWN within 6 hours and in COLD SHUTDOWN within the following 30 hours. ACTION 21 - Be in at least STARTUP with the main steam line isolation valves closed within 2 hours or be in at least HOT SHUTDOWN within 6 hours and in COLD SHUTDOWN within the next 30 hours. ACTION 22 - Be in at least STARTUP within 2 hours. ACTION 23 - Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within one hour. ACTION 24 - Isolate the reactor water cleanup system. ACTION 25 - Close the affected system isolation valves and declare the affected system inoperable. ACTION 26 - Verify power availability to the bus at least once per 12 hours. ACTION 27 - Deactivate the shutdown cooling supply and reactor vessel head spray isolation valves in the closed position until the reactor steam done pressure is within the specified limits. NOTES When handling irradiated fuel in the secondary containment. (a) Refer to plant procedure for valves in each valve l group. (b) A channel may b.e placed in an inoperable status for up to 2 hours for required surveillance without placing the trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter. (c) With only one channel per trip system, an inoperable channel need not be placed in the tripped condition where this would cause the i Trip Function to occur. In these cases, the inoperable channel shall be restored to OPERABLE status within 2 hours or the ACTION required by Table 3.3.2-1 for that Trip Function shall be taken. i 5 A channel is 01ERABLE if 2 of 4 instruments in that channel are (d) OPERABLE. (e) With reactor steam pressure > $00 psig. BRUNSWICK - UNIT 2 3/4 3-18 Amendment No.

I (BSEP-2-120) l TABLE 3.'.2-1 (Continued)' a t IS01.ATION ACTUATION INSTRUMENTATION r NOTES (f) Closes only RWCU outlet isolation valve. (g) Alarm only. [ (h) Does not isolate E11-F015A,B. { (i) .Does not isolate B32-F019 or 532-F020. I (j) Valve isolation depends upon low steam supply pressure coincident I with high drywell pressure. I (k) Secondary containment isolation dampers as listed in plant procedure j l I i-1 f r I l f I i i i i i i l i t i 1 I i BRUNSWICK - UNIT 2 3/4 3-19 Amendment No. l

~ (CSEP-2-123) Q TABLE 3.3.2-2 3 E ISOLATION ACTUATION INSTRIMENTATION SETPOINTS "n ALLOWABLE TRIP FUNCTION AND INSTRUMENT NUMBER TRIP SETPOINT VALUE Ey 1. PRIMARY CONTAINMENT ISOLATION Reactor Vessel Water Level - a. 3 + 162.5 inches *) 3 + 162.5 inches *) I I 1. Low, Level 1 (B21-LTM-NOl7A-1,B-1,C-1,D-1) 3 + 2.5 inches *) 3 + 2.5 inches *) I I 2. Iow, Level 3 i (B21-LTS-N024A-1-2,L-1-2; l i 821-LTS-N025A-1-2,B-1-2) b. Drywell Pressure - High - $.2'psig $ 2 psig (C72-PTM-NOO2A-1,B-1,C-1,D-1) w N Main Steam Line c. 1. Radiation - High $ 3 x full power background $ 3.5 x full power g (D12-RM-K603A,B,C,D) ~ background 2. Pressure - Low 3'825 psig 3 825 psig I (821-P1M-NO15A-1,B-1,C-1,D-1) l 3. Flow - High $ 140% of rated flow $ 140% of rated flow (B21-PDTM-N006A-1,8-1,C-1,D-1; B21-PDTM-N007A-1,B-1,C-1,D-1; B21-PDTM-NOO8A-1,B-1,C-1,D-1; B21-PDTM-N009A-1,B-1,C-1,D-1) l 4 Flow - High $ 40% of rated flow $ 40% of rated flow I g (821-PDTS-N006A-2; B21-PDTS-N0078-2; y 821-PDTS-POO8C-2; B21-PDTS-N009D-2) e .O -___._-.__._m__

(CSEP-2-123) 5 e 13 7* TABLE 3.3.2-2 (Continued)

n 8

ISOLATION ACTUATION INSTRLMENTATION SETPOINTS E ALLOWAEIE y TRIP FUNCTION AND INSTRUMENT NUMBER TRIP SETPOINT VALUE PRIMARY CONTAllMENT ISOLATION (Continued) d. Main Steam Line Tunnel Temperature - High 1 200*F $ 200*F (B21-TS-N010A,B,C,D; B21-TS-N011A,B,C,D: ^ 521-75 N012A,B,C,D; B21-TS-N013A,B,C,D) e. Condenser Vacuum - Low 3 7 inches Hg vacuum 3 7 inches Ng vacuum (B21-PTM-NOS6A-1,B-1,C-1,D-1) ti (521-TS-3225A,B,C,D; 1 200*F $ 200*F f. Turbine Building Area Temperature - High B21-TS-3226A,B,C,D; Y B21-TS-322 7 A, B, C,'D; 'd 521-TS-3228A,B,C,D; B21-TS-3229A,B,C,D; B21-TS-3230A,B,C,D; B21-TS-32311.,3,C,D; B21-TS-3232A,8,C,D) g. Reactor Building Eahaust Radiation - High 1 11 mr/hr 1 11 mr/hr (D12-RM-K609A 8) 2. SECONDARY CONTAINMENT ISOLATION Reactor Building Exhaust Radiation - High $ 11 mr/hr $ 11 mr/hr a. g (D12-RM-K609A,B) E b. Drywell Pressure - High 1 2 psig i 2 psig g (C72-PTM-NOO2A-1,B-1.C-1,D-1) 3 + 112 inches *) 3 + 112 inches *) I I N Reactor Vessel Water Level - Low, Level 2 c. g: (821-LTM-NO24A-1-1,B-1-15 B21-LTM-NO25A-1-1,B-1-1)

(CSEP-2-122) E i e l E l g TABLE 3.3.2-2 (Continued)

n l

8 ISOLATION ACTUATION INSTRLDIENTATION SETPOINTS Ey ALIANABLE 1 RIP F128CTION AND INSTRUMENT NUMBER TRIP SETPOINT VALUE y 3. REACTOR MATER CLEANUP SYSTEM ISOIATION A Flow - High < 53 sal / min < 53 sal / min l a. (C31-FDS-N603-1A,15) 4 i b. Area Temperature - High < 150*F < 150*F (C31-TS-5600A,B,C,D,E,F) ~ c. Ares Ventilation j A Temperature - High < 50*F $ 50*F (C31-TDS-N602A,B,C,D,E,I') i i j d. SLCS Initiation NA NA i (C41A-51) i e' Reactor Vessel Water Level - u e. I Id 3 + lli inches *I 3 + 112 inches j Low, Level 2 l (321-LDI-NO24 A-1-1,8-1-1 ; B 21-LTM-NO2 5 A-1-1,B-1-1 ) f. A Flow - Higi. - Time Delay Relay < 45 seconds < 45 seconds 1 (831-R616C,D) i 4. CORE STANDBY C00LINC SYSTEMS ISOLATION a. High Pressure Coolant Injection System Isolation 1. HPCI Steam Line Flow - High < 300% of rated flow < 300% of rated flow a (E41-PDTS-NOO4-2; E41-PDTS-WOO 5-2) g 2. HPCI Steam Line Flow - High ti Time Delay Relay 3<t< ~ S (E41-TDR-K33; ~ ~ 7 seconds 3<t<~ 12 seconds E41-TDR-K43) 4 z 3. HPCI Steam Supply Pressure - Low 3 100 psig 3 100 psig l ( E41-PSL-N001 A, B.C D) i

. ~ -. (BSEP-2-120) TABLE 3.3.2-2 (Continued) Ey ISOIATION ACTUATION INSTRIStENTATION SETPOINTS M* ALIANASLE TRIP FUNCTION AND INSTRUMENT NIMBER TRIP SETPOINT VALUE Ey CORE STAND 8Y COOLING SYSTEMS ISOIATION (Continued) u 4. HPCI Steam Line Tunnel Temperature - High -< 200*F < 200*F ~ (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; E41-TS-3354; E41-TS-3488; E41-TS-3489) s. l 5. Bus Power Monitor Hs NA v4 (E41-K55; E41-K56) 6. HPCI Turbine Eshaust Diaphragm Pressure - High $ 10 psig $ 10 peig (E41-PSH-N012A,B,C,D) 7. HPCI Steam Line Ambient Temperature - High $ 200*F < 200*F (E51-TS-N603C,D) 8. HPCI Steam Line Area a Temperature - High < 50*F $ 50*F (E51-TDS-N604C,D) { 9. HPCI Equipment Area Temperature - High $ 175*F $ 175*F (E41-TS-5602A,5) 3 o. 10. Drywell Pressure - High 3 2 psig $ 2 psig ,3, (E11-PTS-N011C-2,D-2) z* b. Reactor Core Isolation Cooling System Isolation i 1. RCIC Steam Line Flow - High < 300Z of rated flow $ 300Z of rated flow i ( E51-PDTS-N017-2; E51-PDTS-NO18-2) i i

(BSEP-2-120) E TAB E 3.3.2-2 (continuedi E E ISOLATION ACTUATION IMSTRLSIENTATION SETFOINTS N M ALIANARIE 8 TRIP FUNCTION AND INSTRUMENT NEMBER TRIP SE1 POINT VALUE E Q CORE STANDBY COOLING SYSTEMS ISO 1ATION (Continued) sa 2. RCIC Steam Line Flow - High Time Delay Relay 3 $ t i 7 s'econds 3 $ t i 12 seconds (E51-TDR-K32; F51-TDR-K12) 3. RCIC Steam Supply Pressure - Iow 1 50 psig 3 50 pois (E51-PS-N019A.R.C.D) 4. RCIC Steam Line Tunnel Temperature - Nigh 1 175*F $ 175*F t (E51-TS-3319; E51-TS-3320; Y E51-TS-3321; y E51-TS-3322; E51-TS-3323; E51-TS-3355; E51-TS-3487) 5. Bus Power Monitor NA NA (E51-K42; E51-K43) 6. RCIC Turbine Exhaust Diaphragm Pressure - High 1 10',54-1 10 peig (E51-PS-N012A,R,C,D) f g (E51-TS-N603A,5) ~< 20,.'" ~< 200*F 7. RCIC Steam Line Ambient Temperature - Migh 3 8. RCIC Steam. Line Area A Temperature - High $ 50*F 1 50*F (E51-TDS-N604A,5) 9. RCIC Equipment Room Ambient Temperature - High 1 175*F $ 175*F l (E51-TS-N602A,R) a .)

'l (BSEP-2-120) g TABLE 3.3.2-2 (Continued) Ey ISOLATION ACTUATION INSTRUMENTATION SETPOINTS R M ALLOWABLE TRIP FUNCTION AND INSTRUMENT NUMBER TRIP SETPOINT VALUE Ey CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) p 10. RCIC Equipment Room A Temperature - High ~< $0*F < 50*F (E51-TDS-N601A,B) ~ 11. RCIC Steam Line Tunnel Temperature - High ~< 30 minutes ~< 30 min ~utes Time Delay Relay (E51-KC-H602A,B) 12. Drywell Pressure - High < 2 psig < 2 psig t3 ( El l-PTS-N0 ll A-2, B-2 ) c-y 5. SHUTD013i COOLING SYSTEM ISOLATION a. Reactor Vessel Water Level - Low, Level 1 ~> + 162.5 inches ") ~> + 162.5 inches ") I I (B21-LTM-h017A-1,B-1,C-1,D-1) b. Reactor Steam Dome Pressure - High < 140 psig < 140 psig (B32-PS-NOl8A-1,B) (a) Vessel water levels refer to REFERENCE LEVEL ZERO. Eo. E .E t

(BSEP-2-120) ) TABLE 3.3.2-3 ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION AND INSTRUMENT NUMBER RESPONSE TIME (Seconds)(a)(d) 1. PRIMARY CONTAINMENT ISOLATION a. Reactor Vessel Water Level - 1. Low, Level 1 ~<i3 (B21-LT-N017A-1,B-1,C-1,D-1) (B21-LTM-N017A-1,B-1,C-1,D-1) 2. Low, Level 3 < 1.0(c) (B21-LT-N024A-1,B-1; E 13th) ~ B21-LT-N025A-1,B-1) (B21-LTS-N024A-1-2,B-1-2; B21-LTS-N025A-1-2,B-1-2) b. Drywell Pressure - High <13 ~ (C72-PT-N 02A,B,C,D) (C72-PTM-N002A-1,B-1,C-1,D-1) c. Main Steam Line <l.0(C) 1. Radiation - High(b) 7 13(h) (D12-RM-K603A,B,C,D) ~ 2. Pressure - Low ~<13 (B21-PT-N015A,B,C,D) (B21-PTM-N015A-1,B-1,C-1,D-1) 3. Flow - High <0.5(c) 313(h) (B21-PDT-N006A,B,C,D) B21-PDT-NOO7A,B,C,D; B21-PDT-N008A,B,C,D; B21-PDT-N009A,B,C,D) (B21-PDTM-N006A-1,B-1,C-1,D-1; B21-PDTM-N007A-1,B-1,C-1,D-1; B21-PDTM-N008A-1,B-1,C-1,D-1; B21-PDTM-N009A-1,B-1,C-1,D-1) 4. Flow - High <0.5(c) (B21-PDTS-N006A-2; 313(h) B21-PDTS-N0078-2; l B21-PDTS-N008C-2; l B21-PDTS-N009D-2) d. Main Steam Line Tunnel Temperature - High <13 (B21-TS-N010A,B,C,D; B21-TS-N011A,B,C,D; B21-TS-N012A,B,C,D; B21-TS-N013A,B,C,D) e. Condenser Vacuum - Low <13 ~ (B21-PT-N056A,B,C,D) l (B21-PTM-N056A-1,B-1,C-1,D-1) BRUNSWICK - UNIT 2 3/4 3-26 Amendment No.

k (BSEP-2-120) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION AND INSTRUMENT NUMBER RESPONSE TIME (Seconds)(a)(d PRIMARY CONTAINMENT ISOLATION (Continued) f. Turbine Building Area Temperature - High NA (B21-TS-3225A,B,C,Di B21-TS-3226A,B,C,Di B21-TS-3227A,B,C,Di. B21-TS-3228A,B,C,D; B21-TS-3229A,B,C,D; B21-TS-3230A,B,C,Di B21-TS-3231A,B,C,Di B21-TS-3232A,B,C,D) Reactor Building Exhaust Radiation - High(D) NA g. (D12-RE-N010A,B) (D12-RM-K609A,B) 2. SECONDARY CONTAINMENT ISOLATION Reactor Building Exhaust Radiation - High(b) $3; a. (D12-RE-N0010A,B) (D12-RM-K609A,B) b. Drywell Pressure - High 313 (C72-PT-N002A,B,C,D) (C72-PTM-NOO2A-1,B-1,C-1,D-1) f c. Reactor Vessel Water Level - Low, Level 2 ~< 13 (B21-LT-N024A-1,B-1; B21-LT-N025A-1,B-1) (B21-LTM-N024A-1-1,B-1-1; B21-LTM-N025A-1-1,B-1-1) 3. -R_EACTOR WATER CLEANUP SYSTEM ISOLATION a. A Flow - High 145(8) f (C31-FDS-N603-1A,lB) b. Area Temperature - High $13 (G31-TS-N600A,B,C,D,E,F) c. Area Ventilation A Temperature - High $13 (C31-TDS-N602A,B,C,D,E,F) d. SLCS Initiation NA (C41A-S1) e. Reactor Vessel Water Level - Low, Level 2 $ 13 1 (B21-LT-N024A-1,B-1; B21-LT-N025A-1,B-1) (B21-LTM-N024A-1-1,B-1-li B21-LTM-N025A-1-1,B-1-1) f. A Flow - High - Time Delay Relay NA l (C31-R616C,D) i BRUNSWICK - UNIT 2 3/4 3-27 Amendment No. 1

(BSEP-2-130) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION AND INSTRUMENT NUMBER RESPONSE TIME (Seconds)(a)(d) 4. CORE STANDBY C00LINC SYSTEMS ISOLATION High Pressure Coolant Injection System Isolation a. 1. HPCI Steam Line Flow - High <13(*) ~ (E41-PDT-N004) E41-PDT-N005) (E41-PDTS-NOO4-21 E41-PDTS-NOO5-2) 2. HPCI Steam Line Flow - High Time Delay Relay NA (E41-TDR-K33; E41-TDR-K43) 3. HPCI Steam Supply Pressure - Low <13 (E41-PSL-N001A,B,C,D) 4. HPCI Steam Line Tunnel Temperature - High <13 (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; E41-TS-3354; E41-TS-3488; E41-TS-3489) 5. Bus Power Monitor NA (E41-K55; l E41-K56) 6. HPCI Turbine Exhaust Diaphragm Pressure - High NA (E41-PSH-N012A,B,C,D) 7. HPCI Steam Line Ambient Temperature - High NA (E51-TS-N603C,D) l HPCI Steam Line Area a Temperature - High NA l 8. l (E51-TDS-N604C,D) { i 9. HPCI Equipment Area Temperature - High NA (E41-TS-602A,B)

10. Drywell Pressure - High NA (E11-PT-N011C,D)

(E11-PTS-N011C-2,D-2) I l \\ BRUNSWICK - UNIT 2 3/4 3-28 Amendment No. I 1

(BSEP-2-130) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION AND INSTRUML'NT NUMBER RESPONSE TIME (Seconds)(a)(d) g b. Reactor Core Isolation Cooling System Isolation 13(f)

1. RCIC Steam Line Flow - High

~ (E51-PDT-N017; E51-PDT-N018) (E51-PDTS-N017-2; E51-PDTS-N018-2)

2. RCIC Steam Line Flow - High Time Delay Relay NA (E51-TDR-K32; E51-TDR-K12)

3. RCIC Stdam Supply Pressure - Low NA (E51-PS-N019A,B,C,D)

4. RCIC Steam Line Tunnel Temperature - High NA (E51-TS-3319; E51-TS-3320; E51-TS-3321; E51-TS-3322; E51-TS-3323; E51-TS-3355; E51-TS-3487)

5. Bus Power Monitor NA (E51-K42; l

E51-K43)

6. RCIC Turbine Exhaust Diaphram Pressure - High NA (E51-PS-N012A,B,C,D)

7. RCIC Steam Line Ambient Temperature - High NA (E51-TS-N603A,B)

8. RCIC Steam Line Area a Temperature - High NA (E51-TDS-N604A,B)

9. RCIC Equipment Room Ambient Temperature - High NA (E51-TS-N602A,B)

10. RCIC Equipment Room a Temperature - High NA (E51-TDS-N601A,B)

11. RCIC Steam Line Tunnel Temperature - High NA Time Delay Relay (E51-KC-M602A,B) 12..Drywell Pressure - High NA (Ell-PT-N0llA,B)

(E11-PTS-N011A-2,B-2) BRUNSWICK - UNIT 2 3/4 3-29 Amendment No.

1 \\ (BSEP-2-120) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION AND INSTRUMENT NUMBER RESPONSE TIME (Seconds)(a)(d) 5. SHUTDOWN COOLING SYSTEM ISOLATION a. Reactor Vessel Water Level - Low, Level 1 NA-(821-LT-N017A-1,B-1,C-1,D-1) (B21-LTM-NOl7A-1,B-1,C-1,D-1) b. Reactor Steam Dome Pressure - High NA (B32-PS-N018A-1,B) l l i i BRUNSWICK - UNIT 2 3/4 3-29a Amendment No.

(BSEP-2-120) TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME NOTES (a) The isolation system instrumentation response time shall be measured and recorded as a part of the ISOLATION SYSTEM RESPONSE TIME. Isolation system instrumentation response time specified includes any delay for diesel generator starting assumed in the accident analysis. (b) Radiation monitors are exempt from response time testing. Response time shall be measured from detector output or the input of the first electronic component in the channel. (c) Isolation actuation instrumentation response time for MSIVs only. No diesel generator delays assumed. (d) Isolation system instrumentation response time specified for the Trip Function actuating each valve group / damper shall be added to isolation time shown in plant procedure for valves in each valve group and secondary containment isolation damper to obtain ISOLATION SYSTEM RESPONSE TIME for each valve / damper. (e) Includes time delay added by the time delay relay (E41-TDR-K33 and E41-TDR-K43). (f) Includes time delay added by the time delay relay (E51-TDR-K32 and E51-TDR-K12). (g) Includes time delay added by the time delay relay (C31-R616C,D). (h) Isolation system instrumentation response time for associated valves except MSIVs. BRUNSWICK - UNIT 2 3/4 3-29b Amendment No.

TABLE 4.3.2-1 (BSEP-2-120) ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH h TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED r 1. PRIMARY CONTAINMENT ISOLATION a. Reactor Vessel Water Level - 1. Low, Level 1 y (B21-LT-NOl7A-1,B-1,C-1,D-1) NA(a) NA R(b) 1, 2, 3 (B21-LTM-NOl7A-1,B-1,C-1,D-1) D M M 1, 2, 3 u 2. Low, Level 3 l (B21-LT-N024A-1,B-1; NA(a) NA R(b) 1, 2, 3 B21-LT-N025A-1,B-1) (B21-LTS-N024A-1-2,B-1-2; D M M 1, 2, 3 B21-LTS-N025A-1-2,B-1-2) b. Drywell Pressure - High (C72-PT-N002A,B,C,D) NA(a) NA R(b) 1 2, 3 w2 (C72-PTM-NOO2A-1,B-1,C-1,D-1) D M M 1, 2, 3 c. Main Steam Line h 1. Radiation - High D W. R(d) 1, 2, 3 (D12-RM-K603A,B,C,D; a D12-RE-N006A,B,C,D) 2. Pressure - Low (B21-PT-NO15A,B,C,D) NA(a) NA R(b) 1 (B21-PTM-NO15A-1,B-1,C-1,D-1) D M M 1 3. Flow - High (B21-PDT-NOO6A,B,C,D; NA(*) NA R(b) i B21-PDT-NOO7A,B,C,D; B21-PDT-NOO8A,B,C,D; B21-PDT-NOO9A,B,C,D) h (B21-PDTM-NOO6A-1,B-1,C-1,D-1; D M M 1 y B21-PDTM-NOO7A-1,B-1,C-1,D-1; B21-PDTM-NOO8A-1,B-1,C-1,D-1; B21-PDTM-NOO9A-1,B-1,C-1,D-1) e

(BSEP-2-120) g TABLE 4.3.2-1 (Continued) E! y ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E M CHANNEL OPERATIONAL e CilANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH gj TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED G PRIMARY CONTAINMENT ISOLATION (Continued) 4. Flow - liigh D M M 2, 3 (B21-PDTS-NOO6A-2; B21-PDTS-NOO7B-2; B21-PDTS-NOO8C-2; B21-PDTS-NOO9 D-2 ) d. Main Steam Line Tunnel Temperature - liigh NA M R 1, 2, 3 m 3: (B21-TS-N010A,B,C,D; B21-TS-N011A,B,C,D; m 4 B21-TS-N012A,B,C,D; y B21-TS-N013A,B,C,D) e. Condenser Vacuum - Low (B21-PT-N056A,B,C,D) NA(a) NA R(b) 1 2(f) 1, 2(f} (B21-PTM-N056A-1,B-1,C-1,D-1) D M M f. Turbine Building Area Temperature - liigh NA M R 1, 2, 3 (B21-TS-3225A,B,C,D; B21-TS-3226A,B,C,D; B21-TS-3227A,B,C,D; B21-TS-3228A,C,C,D; B21-TS-3229A,B,C,D; B21-TS-3230A,B,C,D; B21-TS-3231A,B,C,D; B21-TS-3232A,B,C,D) z g. Reactor Building Exhaust Radiation - liigh D M R 1, 2, 3. (D12-RE-N010A,B; D12-RM-K609A,B)

(BSEP-2-120) TABLE 4.3.2-1 (Continued) g ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E un CHANNEL OPERATIONAL E5 CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH E TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED I g 2. SECONDARY CONTAINHENT ISOLATION a. Reactor Building Exhaust 1,2,3,5, and (*) Radiation - High D M R (D12-RE-N010A,B; D12-RM-K609A,B) b. Drywell Pressure - High (C72-PT-N002A,B,C,D) NA(a) NA R(b) g, 2, 3 (C72-PTM-NOO2A-1,B-1,C-1,D-1) D M M 1,2,3 c. Reacto'r Vessel Water Level - y, Low, Level 2 ) ) (B21-LT-NO24A-1,B-1; NA NA R 1, 2, 3 y B21-LT-NO25A-1,B-1) h (B21-LTM-NO24A-1-1,B-1-1; D M, M 1, 2, 3 l B21-LTM-NO25A-1-1,B-1-1) 3. REACTOR WATER CLEANUP SYSTEM ISOLATION a. A Flow - High D M R 1, 2, 3 l (C31-FDS-N603-1A,lB) b. Area Temperature - High NA M R 1, 2, 3 (C31-TS-N600A,B,C,D,E,F) c. Area Ventilation A Temperature - liigh JiA M R 1, 2, 3 l g (C31-TDS-N602A,B,C,D,E,F) w h d. SLCS Initiation NA R NA 1, 2, 3 (C41A-SI) e. Reactor Vessel Water Level - E Low, Level 2 (B21-LT-NO24A-1,B-1; NA(a) NA R(b) 1, 2, 3 B21-LT-NO25A-1,B-1) (B21-LTM-NO24A-1-1,B-1-1; D M M 1,2,3 B21-LTM-NO25A-1-1,B-1-1) f. A Flow - High - Time Delay Relay NA M R 1, 2, 3 (C31-R616C,D)

(BSEP-2-120) E TABLE 4.3.2-1 (Continued) -3 E ISOLATION ACTUATION INSTRLMENTATION SURVEILLANCE REQUIREMENTS b CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED G w 4. CORE STANDBY COOLINC SYSTEMS ISOLATION High Pressure Coolant Injection System Isolation a. 1. HPCI Steam Line Flow - High f ID) NA *) NA R 1, 2, 3 (E41-PDT-NOO4; E41-PDT-MOO 5) (E41-PDTS-NOO4-2; D M M' 1, 2, 3 E41-PDTS-NOOS-2) U 2. HPCI Steam Line Flow - High Time Delay Relay NA R R 1, 2, 3 Y (E41-TDR-K33; E41-TDR-K43) m 3. HPCI Steam Supply Pressure - Low NA M R 1, 2, 3 (E41-PSL-NOOlA,B,C,D) 4. HPCI Steam Line Tunnel Temperature - High NA M Q 1,2,3 (E41-TS-3314; E41-TS-3315; E41-TS-3316; E41-TS-3317; E41-TS-3318; g E41-TS-3354; g E41-TS-3488; g g E41-TS-3489) g 5. Bus Power Monitor NA R NA 1, 2, 3 (E41-K55; 2 ,o E41-K56) 6. HPCI Turbine Exhaust Diaphragm Pressure - High NA M Q 1, 2, 3 (E41-PSH-NO12A,B,C,D)

(BSEP-2-120) ll TABLE 4.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E X CHANNEL OPERATIONAL 8 CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED G CORE STANDBY COOLINC SYSTEMS ISOLATION (Continued) y 7. HPCI Steam Line Ambient Temperature - High NA M R 1, 2, 3 (E51-TS-N603C,D) 8. HPCI Steam Line Area a Temperature - High NA M R 1, 2, 3 (E51-TDS-N604C,D) t* 9. HPCI Equipment Area Temperature - High NA M Q 1, 2, 3 8' y (E41-TS-N602A,B) w jf 10. Drywell Pressure - High (Ell-PT-N0 llc,D) NA(*) NA R(b) 1, 2, 3 (E11-PTS-N0 llc-2,D-2) D M M 1, 2, ~3 b. Reactor Core Isolation Cooling System Isolation 1. RCIC Steam Line Flow - High NA(a) NA R(b) 1, 2, 3 (E51-PDT-NOl7; E51-PDT-NOl8) (E51-PDTM-NOl7-2; D M M 1, 2, 3 g E51-PDTM-NO18-2) k 2. RCIC Steam Line Flow - High g Time Delay Relay NA R R 1, 2, 3 3 (E51-TDR-K32 ; E51-TDR-K12) zo 3. RCIC Steam Supply Pressure - Low NA M Q 1, 2, 3 (E51-PS-NOl9A,B,C,D)

(SSEP-2-120) g TABLE 4.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRtMENTATION SURVEILLANCE REQUIREMENTS E M CHANNEL OPERATIONAL 8 CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED U CORE STANDBY COOLING SYSTEMS ISOLATION (Continued) u 4. RCIC Steam Line Tunnel Temperature - High NA M R 1, 2, 3 (E51-TS-3319; E51-TS-3320; E51-TS-3321; E51-TS-3322; E51-TS-3323; R E51-TS-3355; E51-TS-3487) 5. Bus Power Monitor NA R NA 1, 2, 3 y (E51-K42 l E51-K43) 6. RCIC Turbine Exhaust Diaphragm Pressure - High NA M R 1, 2, 3 (E51-PS-NO12A,B,C,D) 7. RCIC Steam Line Ambient Temperature - High NA M. R 1, 2, 3 (E51-TS-N603A,B) 8. RCIC Steam Line Area A Temperature - High MA M R 1, 2, 3. l 1 (E51-TDS-N604A,B) 9 g 9. RCIC Equipment Room Ambient Temperature - High NA M Q 1, 2, 3 (E51-TS-N602A,B) 10. RCIC Equipment Room A Temperature - High NA H Q 1, 2, 3 (E51-TDS-N601A,B) 11. RCIC Staam Line Temperature - High Time Delay Relay NA M R 1, 2, 3 (E51-KC-M602A,B)

(BSEP-2-120) E TABLE 4.3.2-1 (Continued) Ey ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E M CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH E TRIP FUNCTION AND INSTRUMENT NUMBER CHECK TEST CALIBRATION SURVEILLANCE REQUIRED G CORE STANDBY C00LINC SYSTEMS ISOLATION (Continued) u 12. Drywell Pressure - High NA *) NA R(b) 1, 2, 3 I (Ell-PT-N0llA,B) (Ell-PTS-N0llA-2,B-2) D M M 1, 2, 3 5. SHUTDOWN COOLING SYSTEM ISOLATION s. Reactor Vessel Water Level - t' Low, Level 1 (B21-LT-N017A-1,B-1,C-1,D-1) NA(a) NA R(b) 1, 2 3 8' i' ( B21-LTM-NOl7 A-1, B-1, C-1, D-1 ) D M M 1, 2, 3 hk b. Reactor Steam Dome Pressure - High NA S/U(c),M R 1, 2, 3 (B32-PS-NOl8A-1,B) y a t

(BSEP-2-120)' TABLE 4.3.2-1 (Continued) ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS NOTES (a) The transitter channel check is satisfied by the trip unit channel check. A separate transmitter check is not required. (b) Transmitters are exempted from the monthly channel calibration. (c) If not performed within the previous 31 days. (d) Testing shall verify that the mechanical vacuum pump trips and the mechanical vacuum pump line valve closes. (e) When handling irradiated fuel in the secondary containmer.:. (f) When reactor steam pressure > 500 psig. e BRUNSWICK - UNIT 2 3/4 3-29j Amendment No.

(BSEP-2-124) 3/4.6 CONTAINMENT SYSTEMS 3 / 4. "6.1 PRIMARY CONTAINMENT PRIMARY CONTAINMENT INTECRITY LIMITING CONDITION FOR OPERATION 3. 6. 'l.1 PRIMARY CONTAINMENT INTEGRITY shall be maintained. APPLICABILITY: CONDITIONS 1, 2, and 3. ACTION: Without PRIMARY CONTAINMENT INTECRITY, restore PRIMARY CONTAINMENT INTECRITY within 2 hours or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. SURVEILLANCE REQUIREMENTS 4.6.1.1 PRIMARY CONTAINMENT INTECRITY shall be demonstrated: a. At least oneg per 31 days by verifying that all, primary containment penetrations not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or deactivated automatic valves secured in position, except as provided in Specification 3.6.3. b. By verifying each primary contaicment air lock OPERABLE per Specification 3.6.1.3. By verifying the suppression pool OPERABLE per Specification 3.6.2.1. c.

Except valves, blind flanges, and deactivated automatic valves which are located inside the containment, the MSIV Pit, the RWCU Penetration Triangle Room, or the TIP Room, and are locked, sealed, or otherwise secured in the closed position. These penetrations shall be verified closed during each COLD SHUTDOWN except such verification need not be performed when the primary containment has not been de-inerted since the last verification or more often than on e per 92 days. Those valves located above the drywell head requiring head Cdeld block removal for verification will be verified prior to each replacement of the shield blocks.

BRVNSWICK - UNIT 2 3/4 6-1 Amendment No.

(BSEP-2-124) INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PACE 3.4.6 CONTAINMENT SYSTEMS (Continued) Primary Containment Structural Integrity.................. 3/4 6-6 Primary Containment Internal Pressure..................... 3/4 6-7 Primary Containment Average Air Temperature............... 3/4 6-8 3/4.6.2 DEPRESSURIZATION AND COOLINC SiSTEMS Suppression Pool.......................................... 3/4 6-9 Suppre s s ion' Pool Cooling.................................. 3 /4 6-11 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES...................... 3 /4 6-12 3/4.6.4' VACUUM RELIEF Drywell - Suppression Pool Vacuum Breakers................ 3/4 6-14 Suppress {on Pool - Reactor Building Vacuum Breakers....... 3/4 6-16 3/4.6.5 SECONDARY CONTAINMENT Secondary Containment Integrity........................... 3/4 6-18 Secondary Containment Automatic Isciation Dampers......... 3/4 6-19 3/4.6.6 CONTAINMENT ATMOSPHERE CONTROL Standby Gas Trestrent System.............. ............... 3/4 6-21 Containment Atmosphere Dilution System.................... 3/4 6-24 0xygen Concentration...................................... 3/4 6-25 Gas Analyzer Systems...................................... 3/4 6-26 3/4.7 PLANT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS Residual Heat Removal Service Water System................ 3/4 7-1 Service Water System...................................... 3/4 7-2 BRUNSWICK - UNIT 2 VII Amendment No.

l (BSEP-2-134) i l l l INDEX BASES SECTION PAGE 3/4.4 REACTOR COOLANT SYSTEM (Continued) 3/4.4.4 CHEMISTRY.............................................B 3/4 4-2 3/4.4.5 SPECIFIC ACTIVITY.....................................B 3/4 4-2 3/4.4.6 PRESSURE / TEMPERATURE LIMITS...........................B 3/4 4-3 3/4.4.7 MAIN STEAM LINE ISOLATION VALVES......................B 3/4 4-7 3/4.4.8 STRUCTURAL INTEGRITY..................................B 3/4 4-7 3/4.5 EMERCENCY CORE COOLING SYSTEMS 3/4.5.1 HICH PRESSURE COOLANT INJECTION SYSTEM................B 3/4 5-1 3/4.5.2 AUTOMATIC DEPRESSURIZATION SYSTEM.....................B 3/4 5-1 3/4.5.3 LOW PRESSURE COOLING SYSTEMS....................:.....B 3/4 5-2 3/4.5.4 SUPPRESSION P00L......................................B 3/4 5-4 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT...................................B 3/4 6-1 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS..................B 3/4 6-3 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES..................B 3/4 6-4 3/4.6.4 VACUUM RELIEF.........................................B 3/4 6-5 3/4.6.5 SECONDARY C0NTAINNENT.................................B 3/4 6-5 3/4.6.6 CONTAINMENT ATMOSPHERE CONTR0L........................B 3/4 6-6 3/4.7 PLANT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS.................................B 3/4 7-1 3/4.7 2 CONTROL ROOM EMERCENCY FILTRATION SYSTEM..............B 3/4 7-1 BRUNSWICK - UNIT 2 XI Amendment No.

(BSEP-2-124) CONTAINNENT SYSTEMS PRIMARY CONTAINMENT LEAKACE LIMITING CONDITION FOR OPERATION 3.6.1.2 Primary containment leakage rates shall be limited to: a. An overall integrated leakage rate of: 1. Less than or equal to L, 0.5 percent by weight of the containmentairper24$oursat P,, 49 psig, or 2. Less than or equal to L, 0.357 percent by weight of the g containment air per 24 hours at a reduced pressure of P, g 25 psig. for all A combined leakage rate of less than or equal to 0.60 L, isolation l b. penetrations and all valves, except for main steam line valves *, subject to Type B and C tests when pressurized to P,, 49 psig.

Less than or equal to 11.5 scf per hour for any one main steam line c.

isolation valve when tested at 25 psig. APPLICABILITY: When PRIKARY CONTAINMENT INTEGRITY is required per Specification 3.6.1.1. ACTION: With: a. The measured overall integrated primary containment leakage rate exceeding 0.75 L, or 0.75 L, as applicable, or e b. The measured combined leakage rate for all penetrations and all valves, except for main steam line isolation valves *, subject to Type l B and C tests exceeding 0.60 L,, or The measured leakage rate exceeding 11.5 scf per hour for any one c. main steam line isolation valve, restore: a. The overall integrated leakage rate (s) to less than or equal to 0.75 L, or 0.75 L, as applicable, and t b. The combined leakage rate for all penetrations and all valves, except for main steam line isolation valves *, subject to Type B and C tests to less than or equal to 0.60 L,, and

Exemption to Appendix "J" of 10 CFR 50.

BRUNSWICK - UNIT 2 3/4 6-2 Amendment No.

i (BSEP-2-124) CONTAINNENT SYSTEMS 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES LIMITINC CONDITION FOR OPERATION 3.6.3 The primary containment isolation valves and reactor instrumentation system isolation valves listed in plant procedure shall be OPERABLE with isolation times as specified in plant procedure APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: a. With one or more of the primary containment isolation valve (s) specified in plant procedure inoperable, operation may l continue and the provisions of Specification 3.0.4 are not applicable provided that at least one isolation valve is maintained OPERABLE in each affectsd penetration that is open and either: 1. The inoperable valve (s) is restored to OPERABLE status within 8 hours, or 2. Each affected penetration line is isolated within 8 hours by use of at least one deactivated automatic valve secured in the isolation position, or 3. Each affected penetration line is isolated within 8 hours by use of at least one closed manual valve or blind fla,nge. Otherwise, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. b. With one or more of the reactor instrumentation system isolation valves listed in plant procedure inoperable, operation may l continue and the provisions of Specifications 3.0.3 and 3.0.4 are not applicable provided that within 8 hours; 1. The inoperable valve is returned to OPERABLE status, or 2. The instrument line is isolated and the associated instrument is declared inoperable. Otherwise, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. BRUNSWICK - UNIT 2 3/4 6-12 Amendment No.

(BSEP-2-124) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.3.1 Each primary containment isolation valve specified in plant procedure shall be demonstrated OPERABLZ prior to returning the l valve to service after maintenance, repair, or replacement work is performed on the valve or its associated actuator, control, or power circuit by performance of the cycling test and verification of isolation time. 4.6.3.2 Each isolation valve specified in plant procedure shall be l demonstrated OPERABLE at least once per 18 months by verifying that on a containment isolation test signal each isolation valve actuates to its isolation position. 4.6.3.3 The isolation time of each power-operated or automatic valve specified in plant procedure shall be determined to be within its l limit when tested pursuant to Specification 4.0.5. 4.6.3.4 Each reactor instrumentation system isolation valve specified in plant procedure shall be demonstrated OPERABLE at least once pe l 18 months by cycling each valve through at least one complete cycle of full . travel. BRUNSWICK - UNIT 2 3/4 6-13 Amendment No. I

(BSEP-2-124) CONTAINMENT SYSTEMS 3/4.6.4 VACUUM RELIEF DRYWELL - SUPPR'ESSION CHAMBER VACUUM BREAKERS LIMITING CONDITION FOR OPERATION 3.6.4.1 All drywell-suppression chamber vacuum breakers shall be OPERABLE and in the closed position with: a. The position indicator OPERABLE, and b. An opening setpoint of less than or equal to 0.5 psid. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: a. With no more than 2 drywell-suppression chamber vacuum breakers inoperable for opening but known to be in the closed position, the provisions of Specification 3.0.4 are not applicable and operation may continue until the next COLD SHUTDOWN provided the surveillance requirements of Specification 4.6.4.1.a are performed on the OPERABLE vacuum breakers within 4 hours and at least once per 15 days thereafter until the inoperable vacuum breakers are restored to OPERABLE status, b. With one drywell-suppression chamber vacuum breaker in the open position, as indicated by the position indicating system, the provisions of Specification 3.0.4 are not applicable and operation may continue provided the surveillance requirements of Specification 4.6.4.1.a are performed on the OPERABLE vacuum brer.kers and the surveillance requirements of Specification 4.6.4.1.b are performed within 8 hours and at least once per 72 hours thereafter until the inoperable vacuum breaker is restored to the closed position. With the position indicator of any dryv?ll-suppression chamber vacuum c. breaker inoperable, the provisions of Specification 3.0.4 are not applicable and operation may continue, provided the surveillance requirements of Specification 4.6.4.1.b are performed within 8 hours and at least once per 72 hours thereafter until the inoperable position indicator is returned to OPERABLE status. d. Otherwise, be in at least HOT SHUTDOWN within 12 hours and in COLD SHUTDOWN within the nuxt 24 hours. l BRUNSWICK - UNIT 2 3/4 6-14 Amendment No.

(BSEP-2-124) 4 CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.4.1 Each drywell-suppression chamber vacuum breaker shall be demonstrated OPERABLE: a. At least once per 31 days and after any discharge of steam to the suppression chamber from any source, by exercising each vacuum breaker through one complete cycle and verifying that each vacuum breaker is closed as indicated by the position indication system. b. Whenever a vacuum breaker is in the open position, as indicated by the position indication system, by conducting a test that verifies that the differential pressure is maintained greater than 1/2 the initial delta P for one hour without N2 makeup. c. At least once per 18 months during shutdown by: 1. Verifying the opening setpoint, from the closed position, to be less than or equal to 0.5 psid, 2. Performance of a CHANNEL CALIBRATION that each position indicator indicates the vacuum breaker to be open if the vacuum breaker does not satisfy the delta.P test in 4.6.4.1.b. I l i i I l l BRUNSWICK - UNIT 2 3/4 6-15 Amendment No.

(BSEP-2-124) CONTAINMENT SYSTEMS SUPPRESSION POOL - REACTOR BUILDING VACUUM BREAKERS LIMITING CONDITION FOR OPERATION 3.6.4.2 All suppression pool-Reactor Building vacuum breakers shall be OPERABLE with: a. an opening setpoint of less than or equal to 0.5 psid b. an OPERABLE Nitrogen Backup System consisting of two ir. dependent subsystems (one subsystem for each vacuum breaker). APPLICABILITY; OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: a. With one suppress ~ ion pool-Reactor Building vacuum breaker inoperable for opening but known to be in the closed position, restore the inoperable vacuum breaker to OPERABLE status within 7 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. b. With one Nitrogen Backup System subsystem inoperable, verify the remaining subsystem is-OPERABLE and restore the inoperable subsystem to OPERABLE status within 31 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. c. With both Nitrogen Backup System subsystems inoperable, restore at least one inoperable subsystem to OPERA *LE status within 7 days; otherwise, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. SURVEILLANCE REQUIREMENTS 4.6.4.2.1 Each suppression pool-Reactor Building vacuum breaker shall be demonstrated OPERABLE: a. At least once per 92 days by: 1. Manually verifying that each vacuum breaker check valve is free to open, and 2. Cycling each vacuum breaker butterfly valve through at least one complete cycle of full travel. b. At least once per 18 months by: 1. Demonstrating that the force required to open each vacuum breaker check valve does not exceed 0.5 psid. BRUNSWICK - UNIT 2 3/4 6-16 Amendment No.

1: (OSEP-2-124) SURVEILLANCE REQUIREMENTS (Continued) 2. Demonstrating that the vacuum breaker butterfly valve opens at -0.45 1 0.05 psid, drywell pressure going negative relative to Reactor Building pressure. 3. Visual inspections. 4.6.4.2.2 The Nitrogen Backup System shall be demonstrated OPERABLE: a. At least once per 24 hours by verifying that each subsystem is pressurized to greater than or equal to 1130 psig. b. At least once per 18 months by ~ierifying that each subsystem maintains system pressure with a leakage rate of less than or equal to.65 SCEM at a starting pressure greater than or equal to 1130 psig, c. At least once per 18 months by performing a logic system functional test to ensure actuation of the nitrogen backup system. r e l BRUNSWICK - UNIT 2 3/4 6-17 Amendment No.

(BSEP-3-124) CONTAINMENT SYSTEMS 3/4.6.5 SCCONDARY CONTAINMENT SECONDARY CONTAINNENT INTEGRITY LIMITINC CONDITION FOR OPERATION 3.6.5.1 SECONDARY CONTAINMENT INTEGRITY shall be maintained. APPLICABILITY: CONDITIONS 1, 2, 3, 3, and *. ACTION: Without SECONDARY CONTAINMENT INTEGRITY, restore SECONDARY CONTAINMENT INTEGRITY within 8 hours, or: a. In CONDITION 1, 2, OR 3, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hcurs. b. In CONDITION 5 or *, suspend irradiated fuel handling in the secondary containment, CORE ALTERATIONS, and activities which could reduce the SHUTDOWN MARCIN. The provisions of Specification 3.0.3 are not applicable. SURVEILLANCE REQUIREMENTS 4.6.5.1 SECONDARY CONTAINNENT INTEGRITY shall be demonstrated,,by verifying: a. At least once per 92 days that each secondary containment isolation damper is OPERABLE or secured in the closed position per Specification 3.6.5.2. b. At least once per 18 months by operating a standby gas treatment system for 1 hour and maintaining > 1/4 inch of vacuum, water gauge, at a flow rate not exceeding 3000 CFM.

When irradiated fuel is being handled.in the secondary containment.

BRUNSWICK - UNIT 2 3/4 6-18 Amendment No. l \\

(BSEP-2-124) CONTAINMENT SYSTEMS SECONDARY CONTAINMENT AUTOMATIC ISOLATION DAMPERS LIMITING CONDITION FOR OPERATION 3.6.5.2 The secondary containment automatic isolation dampers specified in plant procedure shell be OPERABLE. l APPLICA5ILIT_Y: OPERATIONAL CONDITIONS 1, 2, 3, 5, and *. l ACTION: With one or more of the secondary containment isolation dampers specified in 5.lant procedure inoperable, operation may continue and the l provisions of Specification 3.0.4 are not applicable, provided that at least one isolation damper is maintained OPERABLE in each affected penetration that is open, and: a. The inoperable damper is restored to OPERABLE status within 8 hours, or b. The affected penetration is isolated by use of a closed damper within 8 hours, or c. SECONDARY CONTAINMENT INTEGRITY is demonstrated within 8 hours and the damper is restored to OPERABLE status within 7 days. Otherwise, in OPERATIONAL CONDITION 1, 2, or 3, be in at least HOT l SHUWOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. Otherwise, in OPERATIONAL CONDITION 5 or *, suspend irradiated fuel l handling in the secondary containment, CORE ALTERATIONS, or activities that could reduce the SHUTDOWN MARCIN. The provisions of Specification 3.0.3 are not applicable.

When irradiated fuel is being handled in the secondary containment.

BRUNSWICK - UFIT 2 3/4 6-19 Amendment No.

4 (BSEP-2-124) P CONTAINMENT SYSTEMS SURVEILLANCE kEQUIREMENTS 4.6.5.2 Each secondary containment automatic isolation damper specified in plant procedure shall be demonstrated OPERABLE: l At least once per 92 days by cycling each automatic isolation damper a. testable during plant operation through at least one complete cycle of full travel. b. Prior to returning the damper to service after maintenance, repair, or replacement work is performed on the damper or its associateu actuator, control, or power circuit by performance of the cycling r test and verification of isolation cime. c. At least once per 18 months during COLD SHUTDOWN or REFUELING by: 1. Cycling each automatic damper through at least one complete cycic of full travel and measuring the isolation time, and 2. Verifying that on a secondary containment isolation test signal each automatic damper actuates to its isolation position. BRUNSWICK - UNIT 2 3/4 6-20 Amendment No.

(BSEP-2-124) CONTAINMENT SYSTEMS 3/4.6.6 CONTAINMENT ATMOSPHERE CONTROL STANDBY CAS TREATMENT SYSTEM LIMITING CONDITION FOR OPERATION 3.6.6.1 Two independent standby gas treatment subsystems shall be OPERABLE. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, 5, and *. ACTION: a. With one standby gas treatment subsystem inoperable: 1. In OPERATIONAL CONDITION 1, 2, or 3, restore the inoperabta sybsystem to OPERABLE status within 7 days oe be in.at least LOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the fcilowing 24 hours. 2. In OPERATIONAL CONDITION 5 or *, restore the inoper4 Ele subsystem to y OPERABLE status within 31 days or sustend irradiated ' fuel handling; \\ in the secondary containmet,t, CORE ALTERATIONS, or oparations :n2t 'l could reduce the SHUTDOWN MARGIN. The provisions of Specifir,atich T~ \\ 3.0.3 are not applicable. -s y s a b. With both standby gas trep.tment subsysteNsinoperable{ ' ~ I s 1. In OPEMIIONM, CONDITION 1, 2, o-e 3, he in at byst HOT SHUTDOWN within 12 hours and in COL 3 SHUTDOWN withste the 't. ext. 24 hours. s ( ,t 2. In OPERATIONN. COND1' TION 5,or *, suspend all irradia. <d fuel handling in the acendary dontainment, C0dC ALTERA*l[ONS, or. g opera'; ions that codd redace t: a 'lHUTDOWN MARG 7N.\\ lThe prelis[ inns of gg Specification 3.0.3 are not applicable. \\ t 4 + s SURVEILLANCE REQUIREMEg S_ ) ) '\\ -- s 4.6.6.1 Each standby gas treatment subsystem shall' hr demonstrated '0PERABLS:, t 3 g6 At least once per 7L days by initiating, f h through the HEPA filters an charcoal ad<,j rom the control room, fl w d.' orber. And verifying th;at) the subsystem operat'es for at least 10 hours with the heaters on. automatic control. \\t s, t

When irradiated Eel is being hac tled i.n the secondary cantainment.

g s L.;,~ t \\ , \\ h \\ \\ \\ ,'t x t BRUNSWICK - UNIT 2 3/4 6-21 .m edrunkNo. xl

(3SEP-2-124) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire, or chemical release in any ventilation zone communicating with the system byt 1. Verifying that the cleanup system satisfies the in-place tasting acceptance criteria and uses the test procedures of Regulatory Positions C.5.a, C.S.c, and C.S.d of Regulatory Guide 1.52, Revision 1, July 1976, and the system flow rate is 3000 cfm 1 10%. 2. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide'1.52, Revision 1, July 1976, meets the laboratory testing criteria of Regulatory Position C.6.a of Regula-tory Guide 1.52, Revision 1, July 1976. 3. Verifying a system flow rate of 3000 cfm 1 10% during system operation when tested in accordance with ANSI N510-1975. After every 720 hours of charcoal adsorber operation by verifying within c. 31 days after removal that a laboratory analysis of representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 1, July 1976, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, A Revision 1,.Jaly 1976. d. At least once per 18 months byt 1. Verifying that the pressure drop across the combined HEPA filters ,,l, and charcoal adsorber banks is less than 8.5 inches Water Cauge 1 while operating the filter train at a flow rate of 3000 cfm + 10%. 2. Verifying that the filter train starts on each secondary containment isolation test signal. 4 3. Verifying that the heaters will dissipate at least 15.2 kw when tested in accordance with ANSI N510-1975. s +\\ A'

c l > <s 1

l ( BRUNSWICK - UNIT 2 3/4 6-22 Amendment No. 3

(BSEP-2-124) CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) e. After each complete or partial replecement of a HEPA filter bank by verifying that thu HEPA filter banks remove 3 99% of tha DOS when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 3000 cfm 3 10%. f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove 1 99% of a halogenated hydrocarbon refrigerant test gas when they are tested in-place in accordance with ANSI N510-1975 while operating the system at a flow rate of 3000 cfm 1 10%. t l 1 1 1 I l BRUNSWICK - UNIT 2 3/4 6-23 Amendment No.

(BSEP-2-134) CONTAINMENT SYSTEMS CONTAINMENT ATMOSPHERE DILUTION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.6.2 The containment atmosphere dilution (CAD) system shall be OPERABLE with a. An OPERABLE flow path capable of supplying nitrogen to the drywell, and b. A minimum supply of 4350 gallons of liquid nitrogen. APPLICABILITY: CONDITION 1*. ACTION With the CAD system inoperable, restore the CAD system to OPERABLE status within 31 days or be in at least STARTUP within the next 8 hours. The provisions of Specification 3.0.4 are not applicable. SURVEILLANCE REQUIREMENTS 4.6.6.2 The CAD system shall be demonstrated to be OPERABLE a. At least once per 31 days by verifying thatt 1. The system contains a minimum of 4350 gallons of* liquid nitrogen, and 2. Each valve (manual, power-operated, or automatic) in the flow path not locked, sealed, or otherwise secured in position, is in its correct position. b. At least once per 18 months byt 1. Cycling each power-operated (excluding automatic) valve in the flow path through at least one complete cycle of full travel, and 2. Verifying that each automatic valve in the flow path actuates to its correct position on a Group 2 and 6 isolation test signal.

When oxygen concentration is required to be < 4% per Specification 3.6.6.3.

l BRUNSWICK - UNIT 2 3/4 6-24 Amendment No.

(BSEP-3-134) CONTAINMENT SYSTEMS OXYCEN CONCENTRATION LIMITING CONDITION FOR OPERATION 3.6.6.3* The primary containment atmosphere oxygen concentration shall be less than 4% by volume during the period front a. Within 24 hours af ter THERMAL POWER > 15% of RATED THERMAL POWER, to b. Within 24 hours prior to a scheduled reduction of THERMAL POWER to < 15% of RATED THERMAL POWER. APPLICABILITY: CONDITION 1. ACTION: With the oxygen concentration in the primary containment exceeding the limit, be in at least START-UP within 8 hours. SURVEILLANCE REQUIREMENTS 4.6.6.3 The oxygen concentration in the primary containment shall be verified to be within the limit within 24 hours after THERMAL POWER > 15% of RATF.D THERMAL POWER and at least once per 7 days thereafter.

For the period commencing at 0630 on June 29, 1981, a temporary exemption is allowed to operate BSEP-2 in Condition 1 with containment oxygen concentration exceeding 4% by volume for 72 hours.

BRUNSWICK - UNIT 2 3/4 6-25 Amendment No.

I (BSEP-3-134) CONTAINNENT SYSTEMS 1 CAS ANALYZER SYSTEMS l LIMITING CONDITION FOR OPERATION 4 3.6.6.4 Two independent gas analyzer systems for the drywell and suppression chamber shall be OPERABLE with each system consisting of an oxygen analyzer and a hydrogen analyzer. APPLICABILITY: CONDITION 1. ACTION: a. With one oxygen and/or one hydrogen analyzer inoperable, restore at least two oxygen and two hydrogen analyzers to OPERABLE status within 31 days or be in at least STARTUP within the next 8 hours. The provisions of Specification 3.0.4 are not applicable. i b. With no gas analyzer OPERABLE for oxygen and/or hydrogen, be in at least STARTUP within 8 hours. SURVEILLANCE REQUIREMENTS 4.6.6.4 Each gas analyzer system (CAC-AT-4409, Division I and CAC-AT-4410, ] Division II) shall be demonstrated OPERABLE at least once per 92 days by performing a CHANNEL CALIBRATION using standard gas samples containing a I nominalt a. Zero volume percent hydrogen, balance nitrogen. 1 i j b. Seven to ten volume percent hydrogen, balance nitrogen. c. Twenty-five to thirty volume percent hydrogen, balance nitrogen. d. Zero volume percent oxygen, balance nitrogen. I e. Seveti to ten percent oxygen, balance nitrogen, f. Twenty to twenty-five percent oxygen, bairnce nitrogen. 4 1 l l E i 4 l BRUNSWICK - UNIT 2 3/4 6-26 Amendment No.

(BSEP-2-184) CONTAINMENT SYSTEMS BASES 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES (Continued) A list of automatic clos'ing primary containment isolation valves and their associated closure times shall be available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50. The addition and deletion of primary containment isolation valves shall be made in accordance with Section 50.59 of 10 CFR Part 50. 3/4.6.4 VACUUM RELIEF Vacuum relief breakers are provided to equalize the pressure between the drywell and suppression pool and the suppression pool and reactor building. This system will maintain the structural integrity of the containment under conditions of large differential pressures. The vacuum breakers between the drywell and the suppression pool must not be inoperable in the open position since this would allow bypassing of the suppression pool in case of an accident. There are an adequate number of valves to provide some redundancy so that operation may continue with no more than 2 vacuum breakers inoperable and secured in the closed position. Each set of vacuum relief valves between the suppression chamber and reactor building provides 100% relief, which may be required in the unlikely event that negative pressures develop in the primary containment. The Nitrogen Backup System provides backup motive power for these suppression pool-reactor building vacuum breakers on a loss of instrument air. The normal non-interruptible instrument air system for these vacuum breakers is designed as a Seismic Class I system supplied by air compreesors powered from the emergency buses. The Nitrogen System serves as a backup to the air system and thus the loss of the Nitrogen System, or portions thereof, does not make the vacuum breakers inoperable. This design allows for the out of service times in Actions b and c. The Nitrogen Backup System is added to the Suppression Pool-Reactor Building Vacuum Breaker specification to satisfy NRC concerns relative to 10 CFR 50.44(c)(3) as addressed in the Brunswick Safety Evaluation Report dated October 30, 1986 concerning Generic Letter 84-09. Pressurization to 1130 psig assures sufficient system capacity to provide 24 hours of operation with design valve actuation and system leakage. 3/4.6.5 SECONDARY CONTAIKMENT Secondary containment is designed to minimize any ground level release of radioactive material which may result from an accident. The reactor building provides ser.ondary containment during normal operation when the drywell is sealed and in service. When the reactor is shut down or during refueling the drywell may be open and the reactor building then becomes the primary containment. BRUNSWICK - UNIT 1 B 3/4 6-5 hsendment No.

(BSEP-2-124) CONTAINMENT SYSTEMS BASES (Continued) 3/4.6.5 SECONDARY CONTAINNENT (Continued) l Establishing and maintaining a vacuum in the building with the standby gas treatment system, once per 18 months, along with the surveillance of the valves, is adequate to ensure that there are no violations of the integrity of the secondary containment. A list of secondary containment automatic isolation dampers shall be available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50. The addition and deletion of secondary containment automatic isolation dampers shall be made in accordance with Section 50.59 of 10 CFR Part 50. 3/4.6.6 CON'TAINMENT ATMOSPHERE CONTROL The OPERABILITY of the containment iodine filter trains ensures that ~ sufficient iodine removal capability will be available in the event of a LOCA. The reduction of containment iodine inventory reduces the resulting site boundary radiation doses associated with containment leakage. The operation of this system and resultant iodine removal capacity are consistent with the assumptions used in the LOCA analyses. The OPERABILITY of the equipment and systems required for the detection and control of hydrogen gas ensures that this equipment will be available to maintain the hydrogen concentration within containment below its flammable limit during post-LOCA conditions. The containment inerting system is capable of controlling the expected hydrogen generation associated with 1) zirconium- . vater reactions, 2) radiolytic decomposition of water, and 3) corrosion of metals within containment. The hydrogen control system is consistent with the recommendations of Regulatory Guide 1.7, "Control of Combustible Gas l Concentrations in Containment Following a LOCA." i 1 i l BRUNSWICK - UNIT 2 B 3/4 6-6 Amendment No. r - _}}

ML20147J010

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