Text

Proposed Rev to Ts,Gl 93-05 & Various Administrative Changes,Marked Up Pages,940630
	ML20071M868
Person / Time
Site:	Millstone
Issue date:	06/30/1994
From:	; NORTHEAST UTILITIES SERVICE CO.
To:	;
Shared Package
ML20071M837	List: ML20071M858; ML20071M868; ML20071M873;
References
	GL-93-05, GL-93-5, NUDOCS 9408040418
	Download: ML20071M868 (103)
	v • d • e

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I Docket No. 50-423 B14846 ,

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i Attachment 1 l Millstone Unit No. 3 Proposed Revision to Technica) Specifications ,

Generic Letter 93-05 and Various Administrative Changes ;

Marked-Up Pages ;

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June 1994 940BO40418 940001 Il ,

PDR ADOCK 05000423 P PDR P

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TABLE OF SECTIONS AND PAGE NUMBERS AFFECTED BY THIS SUBMITTAL TS Section Title of Section Page Reason for Number Number (s) Change N/A Index 11, ix, x, Administrative l and xv 1 1.45 The Charging Pump 1-7 Administrative l Operability 4.2.3.1.4 Power Distribution 3/4 2-20 Administrative Limits j 4.2.3.2.4 Power Distribution 3/4 2-23 Administrative l Limits l 1

4.3.1.2 Reactor Trip System 3/4 3-1 Administrative Instrumentation !

Table 4.3-1 Reactor Trip System 3/4 3-10 Administrative i Instrumentation through 12 I and 14 I 4.3.2.2 Instrumsntation 3/4 3-16 Administrative l Table 4.3-2 Engineered Safety 3/4 3-36 Administrative j Features Actuation through 41 1 J

System Instrumentation Table 4.3-3 Radiation 3/4 3-45 Administrative l Monitoring Instrument and CL 93-05 Table 4.3-4 Seismic Monitoring 3/4 3-49 Administrative Instrumentation 4.3.3.5.2 Remote Shutdown 3/4 3-53 Administrative Instrumentation Table 4.3-6 Remote Shutdown 3/4 3-58 Administrative Monitoring Instrumentation Table 4.3-7 Accident Monitoring 3/4 3-62 Administrative Instrumentation and 63 4.3.3.8.c Loose-Part 3/4 3-68 Administrative Detection System 4.4.3.2 Pressurizer 3/4 4-11 GL 93-05 4.4.5.3.a Steam Generators 3/4 4-16 Administrative i

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TABLE CONTINUED TS Section Title of Section Page Reason for Ntunber Number (s) Change Action Leakage Detection 3/4 4-21 Administrative ;

Statement b Systems of 3.4.6.1 and 4.4.6.1.b ,

4.4.6.2.2.b Operational Leakage 3/4 4-23 GL 93-05 >

4.4.9.3.1.b Overpressure 3/4 4-39 Administrative ,

Protection System 4.4.11.1 Reactor Coolant 3/4 4-43 GL 93-05 System Vents l 4.5.1.1.a Accumulators 3/4 5-1 GL 93-05 !

and b 4.5.1.2 Accumulators 3/4 5-2 GL 93-05 (Relocate to i Technical Requirements '

Manual) 4.5.2.c.2 Emergency Core 3/4 5-4 GL 93-05 Cooling Systems 4.5.2.d and {

Administrative 4.6.1.2.d Containment Systems 3/4 6-3 Administrative and e 4.6.2.1.d Containment Quench 3/4 6-12 GL 93-05 Spray System j 4.6.2.2.e Recirculation Spray 3/4 6-13 GL 93-05 System N/A 3/4 6-16 Administrative through 34 3.6.4.1 Hydrogen Monitors 3/4 6-35 Administrative and and 4.6.4.1 GL 93-05 3.6.4.2 Electric Hydrogen 3/4 6-36 Administrative Recombiners 4.6.4.2 a and and b GL 93-05 N/A 3/4 6-36a Administrative

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l TABLE CONTINUED TS Section Title of Section Page Reason for Number Number (s) Change 3/4.6.5 Subatmospheric 3/4 6-37 Administrative Pressure Control System 3/4.6.6 Secondary 3/4 6-38 Administrative Containment through 42 4.7.1.2.1.a Auxiliary Feedwater 3/4 7-4 GL 93-05 and b System and 5 4.7.10.e Snubbers 3/4 7-23 Administrative Table 4.7-2 Snubber Visual 3/4 7-26a Administrative Inspection and 26b Figure 4.7-1 Sample Plan 2) for 3/4 7-27 Administrative Snubber Functional Test 3/4.7.11 Sealed Source 3/4 7-28 Administrative Contamination and 29 N/A 3/4 7-30 Administrative through 43 3/4.7.14 Area Temperature 3/4 7-44 Administrative Monitoring Table 3.7-6 Area Temperature 3/4 7-45 Administrative Monitoring through 47 4.8.1.1.2.g. A. C. Sources 3/4 8-5 Administrative 1

4.8.1.1.2.g. A. C. Sources 3/4 8-7 Administrative 10 and 12 4.8.2.1.c D.C. Sources 3/4 8-12 Administrative through f B3/4.5.2 and ECCS Subsystems B3/4 5-2 GL 93-05 B3/4.5.3 B3/4.7.12 Deleted B3/4 7 *r Administrative B3 /4 .,7 .13 Deleted B3/4 7-8 Administrative B3/4.7.14 Area Temperature B3/4 7-8 Administrative Monitoring ;

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e lifDfl KFINITIONS PEI

$ECTION 1-6 1.32 SLAVE RELAY TEST.............................................

1-6 1.33 SOURCE CHECK.................................................

1-6 1.34 STAGGERED TEST BASIS.........................................

1-6 1.3 5 THERMAL P0WER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

1-6 1.36 TRIP ACTUATING DEVICE OPERATIONAL TEST. . . . . . . . . . . . . . . . . . . . . . .

1-6 1.37 UNIDENTIFIED LEAKAGE.........................................

1-6 1.38 UNRESTRICTED AREA............................................

1-7 1.39 VENTING......................................................

1-7 1.40 SPENT FUEL POOL STORAGE PATTERNS . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PATTERNS............................. 1-7 1.41 SPENT FUEL POOL STORAGE 1-7 l 1.42 CORE OPERATING LIMITS REPORT (C0LR) . . . . . . . . . . . . . . . . . . . . . . . . . .

1-7 LEVEL--APL"U...................................

1.43 ALLOWED POWER 1-7 1.44 ALLOWED POWER LEVEL--APLE................................... ,,

o .

. m. onnm. m. n,.-

mm -

. .....no - .................................. c, 1-8 TABLE 1.1 FREQUENCY N0TATION......................................

1-9 TABLE 1.2 OPERATIONAL M0 DES.......................................

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11 Amendment No. # , Jp, pp, 72, MILLSTONE - UNIT 3 )

un .

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

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,* ::l2"l"^

2 011 LIMITING CO W ITIONS FOR OPERATION AM SURVEILLANCE REQUIREMENTS lfi.I.10li fAE I

Air Temperature . . . . . . . . . . . . . . . . . . . 3/4 6-9 Containment Structural Integrity . . . . . . . . . . . 3/4 6-10 Containment Ventilation System . . . . . . . . . . . . 3/4 6-11 ;

3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS Containment Quench Spray System . . . . . . . . . . . 3/4 6-12 .

Recirculation Spray System . . . . . . . . . . . . . . 3/4 6-13 '

Spray Additive System . . . . . . . . . . . . . . . . 3/4 6-14 l 3/4.6.3 CONTAINMENT ISOLATION VALVES . . . . . . . . . . . . . 3/4 6-15 3/4.6.4 CONSUSTIBLE GAS CONTROL Hydrogen Monitors . . . . . . . . . . . . . . . . . . 3/4 6-K it, ;

Electric Hydrogen Recombiners . . . . . . . . . . . . 3/4 6-K l1 3/4.6.E SUBATMOSPHERIC PRESSURE CONTROL SYSTEM Steam Jet Air Ejector . . . . . . . . . . . . . . . . 3/4 6- 6 3/4.6.6 SECONDARY CONTAllMENT Supplementary Leak Collection and Release System . . . 3/4 6-K9 Secondary Containment Boundary . . . . . . . . . . . . 3/4 6-K.aa Secondary Containment Boundary Structural Integrity . . . . . . . . . . . . . . . . . 3/4 6- 93 3/4.7 PLANT SYSTEMS 3/4.7.1 TUR8INE CYCLE Safety Valves ....................... 3/4 7-1 i

TABLE 3.7-1 MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH SETPOINT WITH INOPERABLE STEAM LINE SAFETY VALVES DURING FOUR LOOP OPERATION ............... 3/4 7-2 TABLE 3.7-2 !

MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH SETPOINT WITH INOPERABLE STEAM LINE SAFETY VALVES :.3 !

DURING THREE LOOP OPERATION .............. 3/4 7-2 b, l

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n MILLSTONE - UNIT 3 ix AmendmentNo.#,63,87,//,

eies

,e, .,,.,.,,

INDEX 11[liTING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS 1

l EGIlEl fAGE Fj l

TABLE 3.7-3 STEAM LINE SAFETY VALVES PER L00P...................... 3/4 7-3 l Auxiliary Feedwater System............................... 3/4 7-4 :

Dominera11 red Water Storage Tank......................... 3/4 7-6 Specific Activity........................................ 3/4 7-7 TABLE 4.7-1 SECONDARY COOLANT SYSTEM SPECIFIC ACTIVITY SAMPLE AND ANALYSIS PR0GRAN..................................... 3/4 7-8 Main Steam Line Isol ation Va1 ves. . . . . . . . . . . . . . . . . . . . . . . . . 3/4 7-9 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION.......... 3/4 7-10 3/4.7.3 REACTOR PLANT COMP 0NENT C0OLING WATER SYSTEM............. 3/4 7-11 3/4.7.4 SERVICE WATER SYSTEM..................................... 3/4 7-12 3/4.7.5 ULTIMATE HEAT SINK....................................... 3/4 7-13 :

3/4.7.6 FLOOD PROTECTION......................................... 3/4 7-14 )

3/4.7.7 CONTROL R00M EMERGENCY VENTILATION SYSTEM................ 3/4 7-15 l 3/4.7.8 CONTROL ROOM ENVELOPE PRESSURIZATION SYSTEM.............. 3/4 7-18 i 3/4.7.9 AUXILIARY BUILDING FILTER SYSTEM......................... 3/4 7-20 i g4.7.IO $NU88ERS................................................. 3/4 7-22 !

FIGURE 4.7-1 SAMPLE PLAN 2) FOR SNUBBER FtmCTIONAL TEST........... 3/4 7- -

3/4.7.11 SEALED SOURCE CONTAMINATION.............................. 3/4 7- j 3/'.7.: : ;ELn:D L .

0 p) l T =:.: :.7-4 ;ELET. %

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3/4.7.dAREATEMPERATUREMONIT0 RING.............................. 3/4 7-44, i

TABLE -Sd6- AREA TEMPERATURE MONITORING . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/47-KD 3.w 4

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~Esut WF-2 $9dem Vr.m Ieru.m9 T nm% ,

3/4 ~&- D i

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MILLSTONE - UNIT 3 x cosa AmendmentNo.#,g l

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^2/24/^4 A ,

15lf1 SASES

SECTION f.A(if 3/4.7.11 SEALED SOURCE CONTANINATION .............. B 3/4 7-6 0/4.7.;; Lui ;; DA n s.i.. vu.u r.u !

3/4.7. [ AREA TEMPERATURE MONITORING . . . . . . . l. . . . . . . . B 3/4 7-8 'I 3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1,3/4.8.2,and3/4.8.3 A.C. SOURCES, D.C. SOURCES, AND ONSITE POWER DISTRIBUTION ............... B 3/4 8-1 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTIVE DEVICES . . . . . . . . . B 3/4 8-3 !

w .--_ ,

3/4.9 REFUELINC OPERATIONS 3/4.9.1 BORON CONCENTRATION . . . . . . . . . . . . . . . . . . . B 3/4 9-1 '

3/4.9.2 INSTRUMENTATION . . . . . . . . . . . . . . . . . . . . . B 3/4 9-1 3/4.9.3 DECAY TIME ....................... B 3/4 9-1 3/4.9.4 CONTAINMENT BUILDING PENETRATIONS . . . . . . . . . . . . B 3/4 9-1 3/4.9.5 COMUNICATIONS ..................... B 3/4 9-1 3/4.9.6 REFUELING MACHINE . . . . . . . . . . . . . . . . . . . . B 3/4 9-2 3/4.9.7 CRANE TRAVEL - SPENT FUEL STORAGE AREAS . . . . . . . . . B 3/4 9-2 3/4.9.8 RESIDUAL HEAT REMOVAL AND COOLANT CIRCUULT10M . . . . . . B 3/4 9-2 j 3/4.9.9 CONTAINMENT PURGE AND EXHAUST ISOLATION SYSTEM ..... B 3/4 9-2 3/4.9.10 and 3/4.9.11 MATER LEVEL - REACTOR VESSEL AND STORAGE POOL ...................... B 3/4 9-3 3/4.9.12 FUEL BUILDING EXHAUST FILTER SYSTEM . . . . . . . . . . . B 3/4 9-3 .

3/4.9.13 SPENT FUEL P0OL - REACTIVITY .............. B 3/4 9-3 3/4.9.14 SPENT FUEL P00L - STORAGE PATTERN . . . . . . . . . . . . B 9-3 )

3/4.10 SPECIAL TEST EXCEPTIONS 3/4.10.1 SHUTDOWN MARGIN . . . . . . . . . . . . . . . . . . . . . B 3/4 10-1 C 3/4.10.2 GROUP HEIGHT, INSERTION, AND POWER DISTRIBUTION LIMITS . B 3/4 10-1 3/4.10.3 PHYSICS TESTS . . . . . . . . . . . . . . . . . . . . . . B 3/4 10-1 3/4.10.4 REACTOR COOLANT LOOPS . . . . . . . . . . . . . . . . . . B 3/4 10-1 3/4.10.5 POSITION INDICATION SYSTEM - SHUTDOWN . . . . . . . . . . B 3/4 10-1 4 % i l

.M.ILLSTONE - UNIT 3 xv AmendmentNo.##,/[,j

e e L n ic;l: r DEFINITIONS VENTING 1.39 VENTING shall be the controlled process of discharging air or gas from a confinement to maintain temperature, pressure, humidity, concentration, or other operating condition, in such a manner that replacement air or gas is not provided or required during VENTIhG. Vent, used in system names, does not imply a VENTING process.

SPENT FUEL POOL STORAGE PATTE E :

1.40 Region I spent fuel racks contain a cell blocking device in every 4th location for criticality control. This 4th location will be referred to as the blocked location. A STORAGE PATTERN refers to the blocked location and all adjacent and diagonal Region I cell locations surrounding the blocked location. Boundary configuration between Region I and Region II must have cell blockers positioned in the outermost row of the Region I perimeter, as shown in Figure 3.9-2.

1.41 Region 11 contains ac, cell blockers.

CORE OPERATING LIMITS REPORT ICOLR) 1.42 The CORE OPERATING LIMITS REPORT (COLR) is the unit-specific document that provides core operating limits for the current operating reload cycle.

These cycle-specific core operating limits shall be determined for each reload cycle in accordance with Specification 6.9.1.6. Unit Operation within these operating limits is addressed in individual specifications.

ALLOWED POWER LEVEL 1.43 APL ND is the mininum allowable nuclear design power level for base load operation and is specified in the COLR.

BL is the maximum allowable power level when transitioning into base 1.44 APL

' load operation. I l

M RGING PUMP OPERABILITY l l.45 For Cycle 4 op nly, if the outside tr-twiniferature is below 17'F,

{

OPERABILITY of the charging as including credit for a temporary heating source in o at least 32*F within the charging pump /reac n component cooling w areas of the auxiliary Motifications will be implemented, prior rtup for C ation, to remove reliance on a temporary heating source.

1-7 AmendmentNo.JJ,Sp,pp,h f M.IL.L.

. STONE - UNIT 3

POWER DISTRIBl1 TION LIMITS LIMITING CONDITION FOR OPERATION ACTION (Continued)

b. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of initially being outside the above limits, verify ,

through incore flux mapping and RCS total flow rate that FAH and RCS f l

total flow rate are restored to within the above limits, or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within t 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . ;

1

c. Identify and correct the cause of the out-of-limit condition prior to increasing THERMAL POWER above the reduced THERMAL POWER limit required by ACTION a.2. and/or b., above; subsequent POWER OPERATION may proceed provided that F3H N and indicated RCS total flow rate are demonstrated, through incore flux mapping and RCS total flow rate comparison, to be within the region cf acceptable operation prior to exceeding the following THERMAL POWEH 1evels: )

1. A nominal 50% of RATED THERMAL POWER, \

A nominal 75% of RATED THERMAL POWER, and j

2. l

3. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of attaining greater than or equal to 95% of RATED THERMAL POWER. l SURVEILLANCE RE0UIREMENTS 4.2.3.1.1 The provisions of Specification 4.0.4 are not applicable.

N 4.2.3.1.2 RCS total flow rate and F AH shall be detemined to be within the acceptable range:

a. Prior to operation above 75% of RATED THERMAL POWER after each fuel loading, and

b. At least once per 31 Effective Full Power Days.

4.2.3.1.3 The indicated RCS total flow rate shall be verified to be within the acceptable range at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months when the most recently obtained value of FAH obtained per Specification 4.2.3.1.2, is assumed to exist. ,

4.2.3.1.4 The RCS total flow rate indic rs shall be subjected to a CHANNEL CALIBRATION at least once per 18 months The measurement instrumentation shall be calibrated within 7 days prior to the perfomance of the calorimetric flow measurement.

A hept th:t tu utrveill.ance-requirement due no iii.er ihan June 13, 1930, = y -u

? - be d;f . ;d er,til the aext ref;:l%; 0"t:ge, b"t ae le th= ';epte;;bar 30, G.~

A l;;3, whisever is esilists 3/4 2-20 Amendment No. ES, MILLSTONE - UNIT 3 22.

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= 4

I ;_.I 0, :;;L l j

POWER DISTRIBUTION LIMITS 1 I

LIMITING CONDITION FOR OPERATION ACTION (Continued)

b. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of initially being outside the above limits, verify through incore flux mapping and RCS total flow rate that (g and RCS total flow rate are restored to within the above limits, or reduce j

THERMAL POWER to less than 5% of RATED THERMAL POWER within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

c. Identify and correct the cause of the out-of-limit condition prior to increasing THERMAL POWER above the reduced THE* MAL POWER limit required by ACTION a.2. and/or b., above; subsequent POWER OPERATION may proceed provided that FAH and indicated RCS total flow rate are demonstrated, through incere flux mapping and RCS total flow rate comparison, to be within the region of acceptable operation prior to exceeding the following THERMAL POWER levels: ,

1. A nominal 32% of RATED THERMAL POWER, and

2. A nominal 50% of RATED THERMAL POWER.

SURVEILLANCE REQUIREMENTS 4.2.3.2.1 The provisions of Specification 4.0.4 are not applicable.

4.2.3.2.2 RCS total flow rate and F AH shall be determined to be within the acceptable range at least once per 31 Effective Full Power Days.

4.2.3.2.3 The indicated RCS total flow rete shall be verified to be within theacceptableranggatleastonceper12hourswhenthemostrecently obtained value of FAH, obtained per Specification 4.2.3.2.2, is assu'ned to ,

exist.

4.2.3.2.4 The RCS total flow rate indicat rs shall be subjected to a CHANNEL f CALIBRATION at least once per 18 months. The measurement instrumentation shall be calibrated within 7 days prior to the perfonnance of the calorimetric ;W[

flow measurement. I' 4.2.3.2.5 The RCS total flow rate shall be determined by precision heat balance measurement at least once per 18 months. Within 7 days prior to performing the precision heat balance, the instrumentation used for determination of steam pressure, feedwater pressure, feedwater temperature, and feedwater venturi AP in the calorimetric calculations shall be calibrated.

4.2.3.2.6 If the feedwater venturis are not inspected at least once per 18 months, an additional 0.1% will be added to the total RCS flow neasurement %

uncertainty. n

<g">E ::pt that the vinM11ance req"ir: :nt 6: ne later th:r, Ar.;" 13,

v. Jeferred er.til th: r.;;t ref elifw vut.ge, hat - 1 =+=- +"

1003 ::y

,-"-5:r 30, F1003 r d.ich;;;r is ::rli:r.

ILL 3/4 2-23 AmendmentNo.77,JYj M.n. STONE - UNIT 3 7

g i

- N .) L-.; S, 002 I 3/4.3 INSTRUMENTATION i 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION i~

LIMITING CONDITION FOR OPERATION t

3.3.1 As a minimum, the Reactor Trip System instrumentation channels and interlocks of Table 3.3-1 shall be OPERABLE with RESPONSE TIMES as shown in Table 3.3-2. i APPLICABILITY: As shown in Table 3.3-1.

ACTION: ,.

As shown in Table 3.3-1. i

~

SURVEILLANCE RE0UIREMENTS 4.3.1.1 Each Reactor Trip System instrumentation channel and interlock and the automatic trip logic shall be demonstrated OPERABLE by the performance of the Reactor Trip System Instrumentation Surveillance Requirements specified in Table 4.3-1. n, -

i 4.3.1.2 The REACTOR TRIP SYSTEM RESPONSE TIME of each Reactor trip functio '

)

shall be demonstrated to be within its limit at least once per 18 months.

Each test shall include at least one train such that both trains are tested at least once per 36 months and one channel (to include input relays to both

( ..

j trains) per function such that all channels are tested at least once every N ,

times 18 months where N is the total number of redundant channels in a -

specific Reactor trip function as shown in the " Total No. of Channels

column l of Table 3.3-1. -

f I

l Cept that thi ini viilleMet 7:q"i" ;nt d'; 301 Ster th;;, Jg,,; };, ;;;;, ;;;;y A k d;fei.ed untti tM r.;;t-rek:1'n;; cete;e, bt n: 1:ter tha . Spt ,ur 30, hl?"3, "u -kgar u - ' i ~

s 0 MILLSTONE - UNIT 3 3/4 3-1 AmendmentNo.#,h, ,

one l

O 4

. f.

IABLE 4.3-1

l5 REACTOR TRIP $YSTEM INSTRUMDITATION SURVEILLANCE REQUIREMENTS 3

g ANALOG TRIP ACTUATING MODES FOR tm CHANNEL DEVICE WhlCN

' CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANEC E FUNCTIONAL UNIT CHECK Call 8 RATION TEST TEST LOGIC TEST IS REOUIRED

- 9

[ 1. Manual Reactor Trip N.A. N.A. M.A. R(14 2) N.A. 1, 2, 3*, 4*,

5* . :

i

2. Power Range, Neutron Flux !

a. High Setpoint 5 D(2,4), Q N.A. N.A. 1, 2 N(3,4),

Q(4,6) .f l

R(4, '2 4

b. Low Setpoint S R(4 2 S/U(1) N.A. M.A. 1***, 2 i$ 3. Power Range, Neutron Flux, High Positive Rate M.A. R( , 2 Q N.A. N.d. 1, 2 i,

w U 4. Power Range, Neutron Flux, N.A. R( , 2 Q N.A. M.A. 1, 2 High Megative Rate

^

5. Intermediate Range S R(4,5) S/U(1) N.A. N.A. 1***, 2

6. Source Range, Neutron Flux 5 R(4,5) S/U(1), M.A. M.A. 2**, 3, 4 Q(9) 5 1 7. Overtemperature AT S R Q N.A. N.A. 1, 2

8. Overpower AT S R Q N.A. N.A. 1, 2 f 9. Pressurtzer Pressure--Low 5 R (20) Q(18) N.A. N.A. 1 [;

$ ~ 10. Pressurih r Pressure--High S R (20) Q(18) N.A. N.A. 1, 2 ,

t

$ , 11. Pressurizer Water level--High S R (20) Q. . N.A. N.A. 1 *r e

12. Reactor Coolant Flow--Low S R Q N.A. N.A. 1

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A b 3,1933 '

TABLE 4.3-I (Continuedl y

- r-REACTOR TRIP SYSTEN INSTRUMENTATION SURVEILLANCE REQUIREMENTS U TRIP E

ANALOG ACTUATING MODES FOR CHANNEL DEVICE WHICH CHANE.;c. CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE E FUNCTI0tlAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED

-* S w 13. Steam Generator Water Level-- S Q(18) M.A. N.A. 1, 2 ,

Low-Low

14. Low Shaft Speed - Reactor M.A. R(13) Q N.A. N.A. I Coolant Pumps

15. Turbine Trip !

a. Low Fluid 011 Pressure N.A. R N.A. S/U(1, 10)**** N.A. I w b. Turbine Stop Valve N.A. R N.A. S/U(1, 10)**** N.A. 1

Closure w

a

~

16. Safety injection Input from N.A. N.A. M.A. R N.A. 1, 2 ESF

17. Reactor Trip System Interlocks

a. Intermediate Range Neutron Flux, P-6 O

N.A. R( 2 R M.A. M.A. 2** *

b. Low Power Reactor 2 Trips Block, P-7 N.A. R(4) R N.A. M.A. 1 5 c. Power Range Neutron E. Flux, P-8 N.A. R( g 2 ) R N.A. N.A. I 2 d. Power Range Neutron a Flux, P-9 N.A. R(4 2 R N.A. M.A. I x e. Power Range Neutron Flux, P-10 1, 2 sa f. Turbine impulse Chamber N.A.

R( J R N.A. M.A. -

? Pressure, P-13 N.A. R R N.A. M.A. 1 4.

9 e

- - - - - - -i--,- , -= ---w- - - - - - - -

9 : e 9, 1" n ,-

TABLE 4.3-1 (Continued) 33 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS *

P

$ TRIP g ANALOG ACTUATING NODES FOR m CHANNEL DEVICE WHICN

' CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCI g Bl!!CILQtl8LUt(II CHECK CALIBRATION IEST TEST LOGIC TEST IS REQUIRED Q 1, 2, 3*,

w 18. Reactor Trip Breaker N.A. N.A. M.A. N(7,11) N.A.

4*, 5*

19. Automatic Trip and M.A. N.A. N.A. N.A. M(7) 1, 2, 3*,

Interlock Logic ,

4*, 5*

23. Three loop Operation _ . M.A. M.A. H.A. 20) N.A. 1, 2 Bypass Circuitry Q w 21. Reactor Trip Bypass M.A. N.A. N.A. M(15) N.A. 2 3*,

) Breakers -

R(16) ,

22. Shutdown Margin Monitor N.A. N.A Q(19) N.A. N.A. 3, 4, 5 a

R a

F 1

9 '

< . Jr .

* ?=: e, 1992 TABLE 4.3-1 (Continued)

TABLE NOTATIONS (Continued)

-(10) Setpoint verification is not applicable.

(12) The TRIP ACTUAT]NG DEVICE OPERATIONAL TEST shall independently verify the ,'

OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

(12) (not used)

(13) Reactor Coolant Pump Shaft Speed Sensor may be excluded from CHANNEL CALIBRATION.

(14) The TRIP ACTUATING DEVICE OPERATIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip circuits for the Manual l Reactor Trip Function. The test shall also verify the OPERABILITY of the ,

BypassBreakertripcircuit(s). ;

(15) local manual shunt trip prior to placing breaker in service. l (16) Automatic undervoltage trip.

t (17) (not used). .:

i (18) The surveillance frequency and/or MODES specified for these channels in l Table 4.3-2 should be reviewed for applicability.

i (19) Quarterly ' surveillance shall include verification that the Shutdown .J - l Margin Monitor is set per the CORE OPERATING LIMITS REPORT (COLR). \ :

h!0),En.etth:tth: : r't:111:re -t';eir:n .t dse r.: 1:t:r th;r Ane 13,10^ ,

r .y ,. defe. e4 er.til th: ext 7: feeling est;g;, ,st ne leter thia i

M:pt;.O. 30,1;;;, ati;h:/:r i: ::r' f er-. -

j

?

I r

t

?

t i

1 MILLSTONE - UNIT 3 3/4 3-14 Amendment No. JZ1 S, ears 7p ,

U~ a , 2003-i S / .: ..

S, :003 TNSTRUMENTATION SURVEILLANCE REOUIREMENTS t 4.3.2.1 Each ESFAS instrumentation channel and interlock and the automatic actuation logic and relays shall be demonstrated OPERABLE by performance of

the ESFAS Instrumentation Surveillance Requirements specified in Table 4.3-2.

-9 4.3.2.2 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS funct on 1 shall be demonstrated to be within the limit at least once per 18 months.*

Each test shall include at least one train such that both trains are tested at g least once per 36 months and one channel (to include input relays to both trains) per function such that all channels are tested at least once per N tines 18 months where N is the total number of redur. dant channels in a specific ESFAS function as shown in the " Total No. of Channels" column of ,

Table 3.3-3.

6 e w =a* s s.e<...s._u = mem _ , % ls AM 6:f:rr:d enti!- the aertMht"tage, b"t no later th:r 5;pteiser%

J-1993, 1.id ;" r 1: earlie ,

G MILLSTONE - UNIT 3 3/4 3-16 AmendmentNo.f),h.

8121

,__2 n, in g .

TABLE 4.3-2

./*

ENGINEERED SAFETY FEATURES ACTUATION SYSTEK INSTRUNENTATION

~ e-SURVEILLANCE REQUIRENENTS M TRIP E

" ANALOG ACTUATING NODES

' CHANNEL DEVICE NASTER SLAVE FOR WHICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCT10 MAL. UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TCil IESI IS REQUIRED w 1. Safety Injection (Reactor Trip, Feedwater Isolation, Control Building Isolation (Nanual Initiation Only), Start Diesel Generators, and Service Water)

a. Nanual Initiation M.A. N.A. N.A. 4) N.A. N.A. N.A. 1, 2, 3, 4

b. Automatic Ac'.uation N.A. N.A. M.A. N.A. 1, 2, 3, 4 J

N(1) N(1) Q w Logic and Actuation 1 Relays w

a

c. Containment Pressure- S R Q N.A. M.A. N.A. N.A. 1, 2, 3 y High-1

{ i

d. Pressurizer Pressure- S 4 Q N.A. N.A. N.A. N.A. 1, 2, 3 Low L

e. Steam Line S Q N.A. M.A. N.A. N.A. 1, 2, 3 Pressure-Low y2.ContainmentSpray k a. Manual Initiation N.A. N.A. M.A. (4) N.A. N.A. N.A. I,2,3,4

. b. Automatic Actuation N.A. N.A. M.A. N.A. N(1) N(1) Q 1, 2, 3, 4 w logic and Actuation,

? Relays

c. Containment Pressure- S R Q N.A. N.A. N.A. N.A. 1, 2, 3, 4 g High-3

p ' ac 8, ' ,

TABLE 4.3-2 (Continued) ')

SE EMINEERED SAFETY FEATURES ACTUATION SYSTEN INSTRUMENTATION

{? SURVEILLANCE REQUIREMENTS N~ TRIP ANALOG ACTUATIM NODES CHANNEL DEVICE MASTER SLAVE FOR WHICH E CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE M FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST _ IS REQUIRED _

w -

3. Containment Isolation

a. Phase "A" Isolation

1) Manual Initiation M.A. N.A. N.A. N.A. N.A. N.A 1, 2, 3, 4

2) Automatic Actuation M.A. M.A. N.A. N.A. M(1) M(1) Q 1, 2, 3, 4 Logic and Actuation g Relays [

3) Safety injection See Item 1. above for all Safety Injection Surveillance Requirements.

b. Phase "B" Isolation N.A. N.A. N.A. N.A. N.A. N.A 1, 2, 3, 4

1) Manual Initiation 14 M.A. M.A. -

N.A. M(1) M(1) Q 1, 2, 3, 4

2) Automatic Actuation N.A.

Logic Actuation Relays g

8. 3) Containment S R Q N.A. M.A. N.A. N.A. 1, 2, 3, 4 2 Pressure-Nigh-3

z 4. Steam Line Isolation ,

~

! a. Manual Initiation

1) Individual N.A. N.A. N.A. R N.A. N.A. N.A. 1, 2, 3, 4 g

1, 2, 3, 4 h 2) System M.A. N.A. M.A. R N.A. N.A. N.A.

^ J a. : e, ' 99

TABLE 4.3-2 (Continued) .

SiE- ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUNENTATION

p SURVEILLANCE REQUIREMENTS M

E m

TRIP ANALOG ACTUATING MODES CHANNEL DEVICE MASTER SLAVE FOR WICH E CHANNEL CHAMEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE Q FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REOUIRED

4. Steam Line Isolation (Continued)

b. Automatic Actuation M.A. M.A. N.A. N.A. N(1) M(1) Q 1, 2, 3, 4 Logic and Actuation Relays

c. Containment Pressure- S R Q N.A. N.A. N.A. M.A. 1, 2, 3, 4 High-2 w

d. Steam Line Pressure-Low S

@ Q N.A. N.A. N.A. N.A. 1, 2, 3 V

e. Steam Line Pressure- S 4) Q N.A. N.A. N.A. N.A. 3 Negative Rate-High v

5. Turbine Trip and Feedwater Isolation 4

a. Automatic Actuation M.A. M.A. N.A. N.A. N(1) N(1) Q 1, 2 f Logic and Actuation i a Relays

b. Steam Generator Water S R Q N.A. N(1) N(1) Q 1, 2, 3 z level-High-High j,

c. Safety Injection N.A. M.A. N.A. R N.A. N.A. N.A. 1, 2'

? Actuation Logic

$ d. T,,, Low Coincident N.A. R Q N.A. N.A. M.A. N.A. 1, 2 with Reactor Trip.(P-4)

._ =

_ _ _ _ _ . _ _.._. _ . _ _ - ~ . . - - . . . - - , .- - --. -

Ja 'm^; --

TABLE 4.3-2 (Continued) , e 33 ENGINEERED SAFETY FEATURES ACTUATION 5VM tn INSTRUMENTATION

$URVEILLANCE JtEQUIREMENTS .

06 4

E TRIP

ACTUATING MODES ANALOG

CHANNEL DEVICE MASTER SLAVE FOR WHICH OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE E CHANNEL CHANNEL TEST LOGIC TEST TEST TEST. IS REOUIRED M FUNCTIONAL UNIT CHECK CALIBRATION TEST w

6. Auxiliary Feedwater N.A. R N.A. M.A. M.A. 1, 2, 3

a. Manual Initiation N.A. M.A.

M.A N.A. M.A. N(1) N{l) Q 1, 2, 3 .

b. Automatic Actuation M.A. '

and Actuation Relays N.A. N.A. N.A N.A 1, 2, 3

c. Steam Generator Water S Q g Level-Low-Low a

w d. Safety Injection See Item 1. above for all Safety Injection Surveillance Requirements.

a. Loss-of-Offsite Power See Item 8 below for all loss of Power Surveillance,

f. Containment Depres- See Item 2. above for all CDA Surveillance Requirements. ,

surization Actuation '

(CDA) i Control Building Isolation ,

g7.

I

a. Manual Actuation M.A. M.A. M.A.

[ M.A. N.A.

N.A.

All 1, 2, 3, 4

b. Manual Safety N.A. M.A. M.A. N.A.

?+

lejection Actuation (j

=

? M.A. N.A. N(I) N(1) Q 1, 2,' 3, 4 N c. Automatic Actuation N.A. M.A.

? Logic and Actuation

g Re sys N.A. M.A. N.A. N.A. 1, 2, 3 N Q

d. Containment Pressure-- S -

Nigh-I

. _ _ _ _ . ._________..-_._________.m_ _ _ -_m_m_.__-____.-____---r- -- -+_m-- e . W3-v --4 4-. < , - - +.-- _ w-+

9 : = 9, i :: -

TABLE 4.3-2 (Continued) c

$h EMINEERED SAFETY FEATMES ACTMTION SYSTEM INSTRUMENTATION "g SURVEILLANCE REQUIREMENTS k ANALOG TRIP ACTUATING MODES CHANNEL DEVICE. MSTER SLAVE FOR WICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIOML MIT CHECK CALIBRATION TEST TEST LOGIC TESI TEST TEST. IS REQUlBUL w

7. Control Building Isolation (Continued)

e. Control Building Inlet 5 R Q N.A. N.A. N.A. H.A. All Ventilatton RadIatton

8. Loss of Power

a. 4 kV Bus N.A. R N.A M(3) N.A. M.A. M.A. 1, 2, 3, 4

, Undervoltage (Lost

) of Voltage) w b. 4 kV Bus M.A. R N.A. N(3) M.A. N.A. N.A. 1, 2, 3, 4 g -Undervoltage (Grid Degraded Voltage)

9. Engineered Safety Features Actuation System Interlocks ) i g a. Pressurizer M.A. Q M.A. M.A. M.A. M.A. 1, 2, 3 Pressure, P-Il y

( b. Low-Low T,,9, P-12 N.A. R Q N.A. M.A. M.A. M.A. 1, 2, 3 d

5 c. Reactor Trip. P-4 N.A. N.A. N.A.

h N.A. N.A. N.A. 1, 2, 3

^

- 10. Emergency Generator N. A.- N.A. N.A. M.A. Q(1,2) N.A. M.A. 1, 2, 3, 4

, Load Sequencer ,

D.

'. Y. > 22: e, !???

TABLE 4.3-2 (Continued) i TABLE NOTATION !

i (1) Each train shall be tested at least every 62 days on a STAGGERED TEST BASIS. ;

(2) This surveillance may be performed continuously by the emergency I

generator load sequencer auto test system as long as the EGLS auto test system is demonstrated operable by the performance of an ACTUATION LOGIC TEST at least once per 92 days.

(3) On a monthly basis, a loss of voltage condition will be initiated at each undervoltage monitoring relay to verify individual relay operation.

Setpoint verification and actuation of the associated logic and alarm '

relays will be perfonned as part of the channel calibration required once per 18 months.

,SL ( A) Ex:;,,i liiet th: :;rv;ill:Ste requir.;;.t do. ne leter th: 1 3: 13, 1000, a =ey 5 deferrad entil the r. ext refueling esteg;, Set ne 1:ter thst

'75:pt;;t:r 30,1993, "!:hever is ear'ier. '

t a

gSTONE-UNIT 3 3/43-41 AmendmenthJ./J,//)f,

. A '

.z -

TABLE 4.3-3 og .

g RADIATION MONITORING INSTRUMENTATION FOR PLANT R OPERATIONS SURVEILLANCE REQUIREMENTS c ANALOG 5

CHANNEL MODES FOR WHICH CHANNEL CHANNEL OPERATIONAL SURVEILLANCE EUKIIONALUM11 CHECK CALIBRATION TEST IS REQUIRED

1. Containment -

a. Contairment Area Purge and Exhr.ust Isolation S *

\Q 5, 6

b. RCS Leakage Detection R*

1) Particulate Radio-activity S R

%Q 1, 2, 3, 4

'd 2)GasecusRadioactivity S R

\Q 1, 2, 3, 4

2. Fuel Storage Pool Area Monitors

a. Radiation Level S R

\Q

TABLE NOTATIONS

With fuel in the fuel storage pool area.

g h f ** Ocept thit--the L. Kill =;; resci. ;n..t fr aa later the 2;n 13, !**3, :y M dafsir-j ::til th k 8

) ::t refce%g vui..v,1,4 :: later the ti,Rr 30, laa3, d!:hner4s e:r!!:r. .

)

. o

Da w

$2 EJ h

k.

. 3

.-

l h= a v>as-TABLE 4.3-4 SEISMICMONITORINGINSTRUMENTATIONSURVEILLANCEREOUIRI ANALOG CHANNEL q OPERATIONAL CHANNEL 4

CHANNEL CHECK CALIBRATION TEST INSTRUMENTS AND SENSOR LOCATIONS

1. Triaxial Time-History Accelerographs

a. NBE20A M RM SA Containment Mat (-24'3")

b. NBE20B M #DS SA >

-containment Wall (40'6") @ SA

c. hBE21 M Emer. Generator Enclosure Located on Mat in Diesel Fuel Oil '

Vault (4'6") M R@R SA l

d. NBE22 Aux. Bldg. F-Line Wall Near The Charging Pumps cooling Surge Tank (46'6")

2. Triaxial Peak Accelerographs

a. P/Al N.A. ROR N.A.

Containment Safety Injection Accum. Tank (-4'7") M N.A. N.A.

b. P/A2 Safety Injection Accum. Disch.

Line (-22'10")

c. P/A3 N.A. 6M N.A.

1 Aux. Bldg. Charging Pumps Cooling Surge Tank (46'6')

3a. Triaxial Seismic Trigger Horizontal M R@ SA (Control Room)

Vertical M 6[ SA D

(Control Room) 3b. Triaxial Seismic Switch R(/g SA Horizontal M (Control Room)

Vertical M R@ SA l (Control Room) 1 Triaxial Response-Spectrum Recorders 4.

a. RSA-50 Spectrum Analyzer. M R@ SA !

i (Control Room)

b. Self-contained Recorder N.A. R@ N.A.- i Steam Generator Support (51'4")

ef: e ' te e $1 r;i t ;; , Il.et[r $

?O;;td;r 30,1993, dithever 1: ::rlier.

MILLSTONE - UNIT 3 3/4 3-49 AmendmentNo./[,'

01344

,, y I i

~

f L...S.i=- ,

INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION 1,IMITING CONDITION FOR OPERATION t 3.3.3.5 The Remote Shutdown Instrumentation transfer switches, power, controls and monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE. f APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With the number of OPERABLE remote shutdown monitoring channels less ,

than the Minimum Channels OPERABLE as required by Table 3.3-9,

restore the inoperable channel (s) to OPERABLE status within 7 days, 1 or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . e l

b. With one or more Remote Shutdown Instrumentation transfer switches, power or control circuits inoperable, restore the inoperable :

switch (s)/ circuit (:) to OPERABLE status within 7 days, or be in HOT ,

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

l

c. Entry into an OPERATIONAL MODE is permitted while subject to these :

ACTION requirements. ;

SURVEILLANCE REQUIREMENTS 4 4.3.3.5.1 Each remote shutdown monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-6.

4.3.3.5.2 Each Remote Shutdown Instrumentation transfer switch, power and 4 l control circuit including the actuateicomponents, shall be demonstrated l

OPERABLE at least once per IB months.YJA. ,

l l

I 7S7N L;;uir$N[$

M.199?. INI5"dE42$NERN didnr i: ::rlf er. !!!d!.D MO$""Id ' " l O!* l I

3/4 3-53 AmendmentNo.F,h, MILLSTONE - 1) NIT 3 1

>2 Jun: S , 17;F

IABLE 4.3-6 ,

t 3

r-REMOTE SHUTDOWN MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS E

CHANNEL CHANNEL INSTRUMENI CHECK CALIBRATION E 1. Reactor Trip Breaker Indication M N.A.

[ 2. Pressurizer Pressure M R@

3. Pressurizer Level M' R@

4. Steam Generator Pressure M RM

5. Steam Generator Water Level M M

6. Auxillary Feedwater Flow Rate ,

M M

7. Loop Hot leg Temperature M R 0

8. Leop Cold Leg Tergerature b M R O

$ 9. Reactor Coolant System Pressure M R[

{

(Wide Range) U

10. DWST Level M R

11. RWST Level M R

12. Containment Pressure M R

13. Emergency Bus Voltmeters M' R g 14. Source Range, Count Rate M* R g 15. Intermediate Range Amps M R

! ! 16. Boric Acid Tank level M R

?.

z P

When below P-6 (Intermediate range neutron flux interlock setpoint).

y ?" Ex;;;;t th:t tS m;-!!!:::: r;;;i...a..i d;; :: let:r th:n A..e 13, 1553, may oe aeterreu uni.ii -

_5L the n;xt serveling uviage, uui. no later tS:n 5:;;t; i r 30, IM3, eid.ever i:; earticr.

4

l 4,

3 BBLE4.3-7

P

$ ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENS E

' CHANNEL CHANNEL INSTRUMENT

_ CHECK- CALIBRATION E

y 1. Containment Pressure w a. Normal Range M R

b. Extended Range M R

2. Reactor Coolant Outlet Temperature - THOT (Wide Range) M R

3.

Reactor Coolant inlet Temperature - TCOLD (Wide Range) M R 9

4. -Reactor Coolant Pressure - Wide Range M M w 5. Pressurizer Water level M (M w 6. Steam Line Pressure M RY E 7. Steam Generator Water level - Narrow Range M RY

8. Steam Generator Water level - Wide Range M RM

9. Refueling Water Storage Tank Water level M R >

10. Demineralized Water Storage Tank Water level M

11. Auxillary Feedwater Flow Rate R

f'

' [

s M R*8 b k 12. Reactor Coolant System Subcooling Margin Monitor M FM

,E 13. Containment Water level (Wide Range) M M b

$ 14. Core Exit Thermocouples M

% 15. dei.ETED u

1 w

. . _ _ . _ . . - --~ - . - . _ . . . . , . , - . . - - . . . - . . - - . . . . - -

a

, L 2 .

p IABLE 4.3-7 (Continued) m '

ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENTS.

CHANNEL INSTRUMENT CHANNEL Q _ CHECK [ALIBRATION -

4 Q .

w 16. Containment Area - H.lgh Range Radiation Monitor -

M R

~

17. Reactor Vessel Water level '

M R**

18. Containment Hydrogen Monitor M R

19. Neutron Flux M R N"

Y *range CHANNEL decades CALIBRATION above 10 R may consO:t of an electronic calibration of the channel, not including the d O or portable gama source /h and a one point calibration check of the detector below 10 R/h with an Installed

- Electronic calibration from the ICC cabinet,s only. -

^ " En epi ihai ine survettlance tequirements J.= uv leier June 13, 1993, m.j ,

yfueli;;; em; , het =e hier than Septem^ucr 3v,19 Wever is eariter,1,e Jere,, ed uniit-the ned.

5

= - e

' ?.'

8 I Y.

=

L

. to

.A E: e, 1992 INSTRUMENTATION LODSE-PART DETECTION SYSTEM

LIMITING CONDITION FOR OPERATION W

3.3.3.8 The Loose-Part Detection System shall be OPERABLE.

APPLICABILITY: MODES I and 2.

ACTION:

a. With one or more Loose-Part Detection System channels inoperable for more than 30 days, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status.

b. The provisions of Specifications 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS ;

4.3.3.8 Each channel of the Loose-Part Detection Systems shall be demonstrated OPERABLE by performance of:

a. A CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , ,

b. An ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, and c.' A CHANNEL CALIBRATION at least once per 18 months.@ i i

i e

o

^ = = t 15:e tu ..... m . _ i. _ ..t = = ute u ... m :3, : m ,

y =y a 4.T.. . .a uni.iMhe ==vt **faa'ir; eteiie, ht =e later t%

[ 27t:~'9r 30, 1993, d i d C"cr it 88Pli?r. I MILLSTONE - UNIT 3 3/43-68 AmendmentNo.57,ff.

esse

0 .

REACTOR COOLANT SYSTEM ESN *d1 E 3/4.4.3 PRESSUitIZER l

1 l LINITING CONDITION FOR OPERATION J l

3.4.3 The pressurizer shall be OPERABLE with a water volume of less than or equal to 92% (1656 cubic feet), and at least two groups of pressurizer heaters supplied by emergency power each having a capacity of at least 175 kW.

APPLICABILITY: MODES 1, 2, and 3.

. ACTION:

s. With only one group of pressurizer heaters supplied by emergency power OPERABLE, restore at least two groups to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHtJTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . j

b. With the pressurizer otherwise inoperable, be in at least HOT STANDBY with the Reactor Trip System breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS I

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

4.4.3.2 The capacity of each of the above required groups of pressurizer I heaters supplied by emergency pcwer shall be verified by energizing the heaters .

and measuring circuit current at least once w "M# ;

@ refue.AIn3 'n k e Al.

e MILtSTONE - UNIT 3 3/4 4-11 4 g i

l i

4 4 l E

. 02/24/94 1 l

REACTOR C0OLANT SYSTEN ITEAN GENERATORS E SURVEILLANCE REQUIREMENTS (Continued) 4.4.5.3 Insoection Frecuencies - The above required inservice inspections of steam generator tubes shall be performed at the following frequencies: ;

~

a. Inservice inspections shall be pehd at intervals of not less than l

12 nor more than 24 calendar monthsejafter the previous inspection. If two consecutive inspections, not including the preservice inspection, '

result in all inspection results fallinD into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months;

b. If the results of the inservice inspection of a steam generator conducted in accordance with Table 4.4-2 at 40-month intervals fall in Category C-3, the inspection frequency shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of ;

Specification 4.4.5.3a.; the interval may then be extended to a maximum of once per 40 months; and i i

c. Additional, unscheduled inservice inspections shall be performed on each steam generator in accordance with the first sample inspection specified in Table 4.4-2 during the shutdown subsequent to any of the following conditions:

1) Primary-to-secondary tubes leak (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of Specification 3.4.6.2, or

2) A seismic occurrence greater than the Operating Basis Earthquake, or

3) A loss-of-coolant accident requiring actuation of the ,

Engineered Safety Features, or !

1

4) A main steam line or feedwater line break. j MJ O c;pt that th: curveillen;: r:1*ted t the stees. genci.ter in:p :tica, 9 d;; Le-ister then Auguai. 21,- C 03,.;;; b: def;.ied entil th; next-

? : fueling-owtev e or nu lete th Se 6 due. 30, 1903, wii;ih;ver 1:-

- >-earlien ;

b 1

MILLSTONE - UNIT 3 3/4 4-16 Amendment No.fU.{N ms

_ 0, n;;

REACTOR COOLANT SYSTEM 3/4.4.6 REACTOR COOLANT SYSTEM LEAKAGE i LEAKAGE DETECTION SYSTEMS LIMITING CONDITION FOR OPERATION 3.4.6.1 The following Reactor Coolant System Leakage Detection Systems shall be OPERABLE:

a. Either the Containment Atmosphere Gaseous or Particulate Radioactivity Monitoring System, and

b. The Containment Drain Sump Level or Pumped Capacity Monitoring System APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

a. With both the Containment Atmosphere Gaseous and Particulate Radioactivity Monitors INOPERABLE, operation may continue for up to 30 days provided the Containment Drain Sump Level or Pumped Capacity Monitoring System is OPERABLE and gaseous grab samples of the containment atmosphere are obtained at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and analyzed for gross noble gas activity within the subsequent 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ; I otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in !

COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . I l

b. With the Containment Drain Sump Level or Pumped pacity Mon to g System INOPERABLE, operation may continue for upi to 30 days provi d either the Containment Atmosphere Gaseous or Par iculat4o Radioactivity Monitoring System is OPERABLE; othe ise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in C0 SHUTDOWN within the followng 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REOUIREMENTS 4.4.6.1 The Leakage Detection Systems shall be. demonstrated OPERABLE by:

a. Containment Atmosphere Gaseous and Particulate Radioactivity Monitoring Systems-performance of CHANNEL CHECK, CHANNEL CALIBRATION, and ANALOG CHANNEL OPERATIONAL TEST at the frequencies specified in Table 4.3-3, and

b. Containment Drain Sump Level and Pumped Capacity Monitoring Sys m-performance of CHANNEL CALIBRATION at least once per 18 months.* .

^^ Eu.e A that ine surveiiiance requiremeni duc ..e lete, ihan June 13, 1953,

.# mey 2 deferivd entil i.he next refueling eutege, but ne 1.te, ti. err {

M eptemb:r 30,1993, wt.icheid is earlicr. v -

.~? \'

MILLSTONE - UNIT 3 3/4 4-21 Amendment No. J/

0129 '

. 4 REACTOR COOLANT SYSTEM sjf g i g_

OPERATIONAL LEAKAGE

\.

SURVEILLANCE REQUIREMENTS 4.4.6.2.1 Reactor Coclant System leakages shall be demonstrated to be within each of the above limits by:

a. Monitoring the containment atmosphere (gaseous or particulate) radioactivity monitor at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ;

b. Monitoring the containment drain sump inventory and discharge at i

least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ;

c. Measurement of the CONTROLLED LEAKAGE to the reactor coolant pump seals when the Reactor Coolant System pressure is 2250 1 20 psia at least once per 31 days with the modulating valve fully open. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4; I

d. Performance of a Reactor Coolant System water inventory balance at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; and

e. Monitoring the Reactor Head Flange Leakoff System at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

' 4.4.6.2.2 Each Reactor Coolant System Pressure Isolation Valve specified in Table 3.4-1 shall be demonstrated OPERABLE by verifying leakage to be within its limit:

a. At least once per 1_R_ months, O 4%h 1)E 2 Whenever the plant has been in COLD

b. Prior to enterin i SHUTDOWN fo 72 hare or more and if leakage testing has not been performed in the previous 9 months, l

c. Prict to returning the valve to service following maintenance, repair or replacement work on the valve, l l

d. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve, and !

e. As outlined in the ASME Code,Section XI, paragraph IW-3427(b).

The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4.

L MILLSTONE - UNIT 3 3/4 4-23 Qu&M do.

< c e . .

' ) JULY 12, 1000

. REACTORC00thNTSYSTEM OVERPRESSURE PROTECTION SYSTEM LIMITING CONDITION FOR OPERATION AB ACTION (Continued)

.. e. In the event the PORVs, the RHR suction relief valves, or the RCS vent (s) are used to mitigate an RCS pressure transient, a Special ,

Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 30 days. The report shall describe the circumstances initiating the transient, the effect of the PORVs, the j RHR suction relief valves, or RCS vent (s) on the transient, and any corrective action necessary to prevent recurrenca.

L

f. Entry into an OPERATIONAL MODE is permitted while subject to these ACTION requirements.

SURVEILLANCE REQUIREMENTS 4.4.9.3.1 Each PORV shall be demonstrated OPERABLE by:

a. Performance of an ANALOG CHANNEL OPERATIONAL TEST on the PORV actuation channel, but excluding valve operation, within 31 days l prior to entering a condition in which the PORY is required OPERABLE l and at least once per 31 days thereafter when the PORV is required OPERABLE;

b. Performance of a CHANNEL CAL BRATION on the PORV actuation channel at least once per 18 months; nd

c. Verifying the PORV isolation valve is open at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months when the PORV is being used for overpressure protection.

4.4.9.3.2 Each RHR suction relief valve shall be demonstrated OPERABLE when the RHR suction relief valves are being used for cold overpressure protection as follows:

a. For RHR suction relief valve 3RHS*RV8708A, by verifying at least l once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that 3RHS*MV8701A and 3RHS*MV8701C are open; l

b. For RHR suction relief valve 3RHS*RV8708B, by verifying at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that 3RHS*HV8702B and 3RHS*MV8702C are open; and

.c . Testing pursuant to Specification 4.0.5. A(}

U E _. ,..$.3t f-b M_ . 1...I3..'L.

6u .sgveiiiance regou6.uo, neu ...u ..u3 rem. .(i(r.

'.g.i.h. .yu. 13, y ;3

. . . 6u.u .w ....,.. so, g N493, d.idiuver i 2 +arl i er.

s 3/4 4-39 AmendmentNo.Jy,k

{LLSTONE-UNIT 3

. ::l: Gin- ;

REACTOR COOLANT SYSTEM 3/4.4.11 REACTOR COOLANT SYSTEM VENTS LIMITING CONDITION FOR OPERATION M

3.4.11 At least one Reactor Coolant System vent path consisting of two i parallel trains with two valves inseries powered from amerpency busses shall be OPERABLE and the vent closed

at each of the following ocations: L

a. Reactor vessel head, and

b. Pressurizer steam space.

APPLICABILITY: MODES 1, 2, 3, and 4.

Ells: Mn

a. With one train of the reactor vessel head vent path inoperable, i i

STARTUP and/or POWER OPERATION may continue provided the inoperable train is maintained closed with power removed from the valve actuators of all valves in the inoperable train; restore the }

inoperable train to OPERABLE status within 30 days, or, be in HOT ,

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

b. With both trains of the reactor vessel head vent paths inoperable; maintain both trains closed with power removed from the valve actuators of all valves in the inoperable trains, and restore at least one of the trains to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following ,

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . ,

c. With any valve (s) of the pressurizer steam space vent path -(q '

I inoperable in MODES 1, 2, or 3, follow the ACTION requirements of Specification 3.4.4. l

d. With any valve (s) of the pressurizer steam space vent path -

inoperable in MODE 4. follow the ACTION requirements of /

Specification 3.4.9.3. (/ ,

SURVEILLANCE REQUIREMENTS 4.4.11.1 Each train of the reactor vessel head vent path isolation valve not )

required to be closed by ACTION a. or b., above, shall be demonstrated /

OPERABLE cycle of full travel at least once from th %per *dontrol room.* ty;; by operating the valve throu

% su m ,a, ,f no+ pedermA u b. hu

" 5

For an OPERABLE vent path using a power-operated relief valve (PORV) ask7j%,

the vent path, the PORV block valve is not requird to be closed.

i l

MILLSTONE - UNIT 3 8333 3/4 4-43 AmendmentNo.h

C' :x I 1, ! = 1 -

3/4.5 EMERGENCY CORE COOLING SYSTEMS 4 3/4.5.1 ACCUMULATORS LIMITING CONDITION FOR OPERATION 3.5.1 Each Reactcr Coolant System (RCS) accumulator shall be OPERABLE with: i

a. The isolation valve open and power removed, b.s A contained borated water volume of between 6618 and 7030 gallons,

c. A boron concentration of between 2600 and 2900 ppm, and

} j A nitrogen cover-pressure of between 636 and 694 psia.

d.

APPLICABILITY: MODES 1, 2, and 3*.

ACTION:

a. With one accumulator inoperable, except as a result of a closed isolation valve, restore the inoperable accumulator to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

[

b. With one accumulator inoperable due to the isolation valve being closed, either immediate1.y open the isolation valve or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REOUIREMENTS l 4.5.1 Each accumulator shall be demonstrated OPERABLE:

a. At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by- !

-hd i

1) Verifying A the contained borated water volume and nitrogen cover-pressure in the tanksmtc be within h e seve limits, and l

-Hvie

2) Verifying that each accumulator isolation valve is open,

b. At least once per 31 days and within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution j volume increase of greater than or equal to 1% of tank volume by verifying the boron concentration of the accumulator solution'g Tis surve' Man o i5 not rgwat h & vo(m hveue rn o k eu p to-a_ is % gas, r,

Pressurizer pressure above 1000 psig.

MILLSTONE - UNIT 3 3/4 5-1 Amendment No. JJ, JJ I

oor1 a ,EE)

A I

- * * '** 1.__n ::, : 000-Ew!ESEC Cot! C00'.!NG SYSTEws I

SURVil' .L ANCE REOUIREMEN15 (Continuee)

c. At least once per 33 days when the RCS pressure is above 1000 psig by verifying that power to the isolation valve operator is discon-nected by removal of the breater from the circuit. ,

... Each accumslater water level and pressure channel shall .

')

stratec 0Ft*x .

a. At least once per 31 dav erformance of an ANALOG CHANNEL OPERATIONAL TES ..

j At least once per IE months by the performance of a CH ..

CALIERAi!ON. . .

b DIC k Md AloC A44- 4u O Te.chn,"cq (

h i+ mon +s hnal ;

)

l I

l l

MILLSTONE - UN 73 3/4 5-2 Oc^& No.

a

' - 'e -

,a Err , 200 EMERGENCY GDRE COOLING SYSTEMS SURVEILLANCE REDUIREMENTS 9

4.5.2 Each ECCS subsystem shall be demonstrated OPERABLE:

Fl

a. At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the following valves I are in the indicated positions with power to the valve operators I removed: l l

Valve Number Valve Function Valve Position l 3SIH*MV8806 RWST Supply to SI Pumps OPEN 3SIH*MV8802A SI Pump A to Hot Leg Injection CLOSED 3SIH*MV8802B SI Pump B to Hot Leg Injection CLOSED 1 3SIH*MV8835 SI Cold Leg Master Isolation OPEN l 3SIH*MV8813 SI Pump Master Miniflow OPEN :

Isolation :

3SIL*MV8840 RHR to Hot Leg Injection CLOSED 3SIL*MV8809A RHR Pump A to Cold Leg OPEN Injection .

3SIL*MV8809B RHR Pump B to Cold Leg OPEN !

Injection !

b. At least once per 31 days by:

1) Verifying that the ECCS piping, except for the RSS pump, heat ;

exchanger and associated piping, is' full of water by venting the ECCS pump casings and accessible discharge piping high [

points, and ;

2) Verifying that each valve (manual, power-operated, or ;

automatic) in the flow path that is not locked, sealed, or .

otherwise secured in position, is in its correct position. j

c. By a visual inspection which verifies that no loose debris (rags, !

trash, clothing, etc.) is present in the containment which could be '

transported to the containment sump and cause restriction of the ;

pump suctions during LOCA conditions. This visual inspection shall !

be performed:

1) For all accessible areas of the containment prior to establish-M 5 ing CONTAINMENT INTEGRITY and

'M g g,wg ;

/n:theareasaffectedgwN,incontainment;^th;-=d.J-.J f

t :::::irn -t ::tr;i when CONTAINMENT INTEGRITY is i

established. '

d. At least once per 18by:month [k ud b;g h Ew 4 .

F) 1 i v >

1) Verifying automatic interlock action of the RHR System from the Reactor Coolant System by ensuring that with a simulated or ;

actual Reactor Coolant System pressure signal greater than or i equal to 390 psia the interlocks prevent the valves from being 1 opened. # '

V t

?t I;;;pt th;t th; r==i11==~ r;;, ;. . ..i. Juw7,e 1:ter th;; J a; 13, !"a!, '

A ny 5 d:f;rred :::til th; :: t ref.eli.,y vui.ve , Lui a; 1:t:r the .

? h at " :r 30, 1;;;, .4,1;he.e. is ;;rli;r.

MILLSTONE - UNIT 3 3/4 5-4 Amendment No. pp, //j ,

ellt l

?* * ' ' '

- S CilClX

~ .

\ .

. t CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

c. The accuracy of each Type A test shall be verified by a supplemental test which:

1) Confirms the accuracy of the test by verifying that the supple- ,

mental test results, L , minus the sum of the Type A and the superimposed leak, L,, is equal to or less than 0.25 L,;

2) Has a duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test; and

3) Requires that the rate at which gas is injected into the containment or bled from the containment during the supplemental test is between 0.75 L, and 1.25 L,.

. I

d. Type B and C tests shall be conducted with gas at P 53.27 psia -.qrs except for I I tests involv)ing:(38.57 psig , at intervals no greater than 24 months (

1) Air locks

e. The combine bypass leakage rate shall be determined to be less than or equal to 42 L by applicable Type B and C tests at least once i per 24 month

exfept for penetrations which are not individually testable; pene ations not individually testable shall be determined to have ho detectable leakage when tested with soap bubbles while the containment is pressurized to P,, 53.27 psia (38.57 psig), -

during each Type A test;

f. Air locks. shall be tested and demonstrated OPERABLE by the requirements of Specification 4.6.1.3;

g. Purge supply and exhaust isolation valves shall be demonstrated OPERABLE by the requirements of Specifications 4.6.3.2.c and 4.9.9.

h. The provisions of Specification 4.0.2 are not applicable. , j

/

i l

I N') T;= 24 month interval for lype o and Typ. C tests he; Le. ;i,cre;;;d tc

) 34 .d;5 f;r Cyc1: 4 0:1ys )

s.- .

MILLSTONE - UNIT 3 3/4 6-3 Amendment No. JJ, sies

1 s - >,*

Ahn: C, 2 000 -

l l

CONTAINMENT SYSTEMS j 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS !

CONTAINMENT 00ENCH SPRAY SYSTEM l l

LIMITING CONDITION FOR OPERATION l 3.6.2.1 Two independent Containment Quench Spray subsystems shall be OPERABLE. l i

APPLICABILITY: MODES 1, 2, 3, and 4. l ACTION: l With one Containment Quench Spray subsystem inoperable, restore the inoperable j system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within '

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

SURVEILLANCE REOUIREMENTS l

4.6.2.1 Each Containment Quench Spray subsystem shall be demonstrated OPERABLE:

a. At least once per 31 days:

1

1) Verifying that each valve (manual, power-operated, or l automatic) in the flow I,ath that is not locked, sealed, or otherwise secured in position, is in its correct position; and hi I l

2) Verifying the temperature of the borated water in the refueling !

water storage tank is between 40*F and 50*F. I

b. By verifying, that on recirculation fl ow, each pump develops a j differential pressure of greater than or equal to 114 psid when '

tested pursuant to Specification 4.0.5;

c. At least once per 18 months du*ing shutdown, by:

1) Verifying that each automatic valve in the flow path actuates to its correct position on a CDA test signal, and

2) Verifying tha spray pump starts automatically on a CDA test sign .

10 ,

d. At least once r4 years y performing an air or smoke flow test through each s ray hea and verifying each spray nozzle is unobstructed.

MILLSTONE - UNIT 3 3/4 6-12 Amendment No. [

l e

n.

.J uus: ko .)

~

,- CONTAINMENT SYSTEMS RECIRCULATION SPRAY SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.2 Two independent Recirculation Spray Systeas shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With one Recirculation Spray System inoperable, restore the inoperable system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the inoperable Recirculation Spray System to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE RE0VIREMENTS 4.6.2.2 Each Rccirculation Spray System shall be demonstrated OPERABLE:

a. At least once per 31 days by verifying that each valve (manual, l power-operated, or automatic) in the flow pathis that is not locked, in its correct sealed, or otherwise secured in position, position;

b. By verifying, that on recirculation fl ow, each pump develops a differential pressure of greater than or equal to 130 psid when tested pursuant to Specification 4.0.5;

c. At least once per 18 months by verifying that on a CDA test signal, each recirculation spray pump starts automatically after a 660 20 second delay;

d. At least once per 18 months during shutdown, by verifying that each automatic valve i ow path actuates to its correct position on a CDA test sign ; and to

e. At least once pe 1 years y performing an air or smoke flow test througn each sp bead and verifying each spray nozzle is unobstructed.

4 I

l l

~ \

(~ Amencment No.

MILLSTONE - UNIT 3 3/4 6-13

l Deccaber 19. 1988 I

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MILLSTONE - UNIT 3 3/4 6-17 Amendment No. 28 l

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1 MILLSTONE - UNIT 3 3/4 6-19 Amendment No. 28

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HILL ONE - UNIT 3 3/4 6-29 Amendment No. 2B 4

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i H, LSTONE - UNIT 3 3/4 6-30 Amendment No. 28

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W HI, STONE - UNIT 3 3/4 6-34 Amendment No. 28

+ - 3 om.- er

, 73

)

CONTAINMENT SYSTEMS 3/4.6.4 COMBUSTIBLE GAS CONTROL HYDROGEN MONITORS LIMITING CONDITION FOR OPERATION )

l 3.6.4.1 Two independent containment hydrogen monitors shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTION: . i

a. With one hydrogen monitor inoperable, restore the inoperable sonitor l to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHIRDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . l

b. With both hydrogen monitors inoperable, restore at least one monitor to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least NOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

c. Entry into an OPERATIONAL MME is permitted while subject to these ACTION requirements.

SURVE1LLANCE RE0VIREMENTS 91 4.6.4.1 Each hydrogen monitor shall be demonstrated OPERABLE by the performance of a CHANNEL CHECK a least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an ANALOG CHANNEL OPERATIONAL TEST at least once perKdays, and at least once p a2 hp = 3 a-PETAGGE""' '"' "'"' by performing a CHANNEL CAllBRATION using sample gas containing:

toch cc.kh'n3 1

a. One volume percent hydrogen, bala~nce nitrogen, and gg j

b. Four volume percent hydrogen, balance nitrogen. l l

e O

O MILLSTONE - UNIT 3 3/46-K AmendmentNo.O,[

4 =

g.

% wu u , 1001 CONTAINMENT SYSTEMS ELECTRIC HYDROGEN RECOMBINERS ,

LIMITING CONDITION FOR OPERATION f 3.6.4.2 Two independent Hydrogen Recombiner Systems shall be OPERABLE.

APPLICABILITY: MODES I and 2.

ACTION:

With one Hydrogen Recombiner System inoperable, restore.the inoperable system to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE RE0VIREMENTS 4.6.4.2 Each Hydrogen Recombiner System shall be demonstrated OPERABLES at Ieen om. c.aca uh ny m+w i h:

a.t 3 ^t lent once per 6 month by derifying during a Hydrogen Recombiner System functional test that the minimum reaction chamber gas temperature increases to greater than or equal to 700*F within 90 minutes and is maintained for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and that the purge blower operates for 15 minutes.

"b. iu. le.st enc; per 18 :: nth: by4 bR Performing a CHANNEL CALIBRATION of all recombiner l instrumentation and control circuits,

)

C.'t) Verifying through a visual examination that there is no evidence of abnormal conditions within the recombiner enclosure (i.e., loose wiring or structural connections, deposits of foreign materials, etc.),

dq) Verifying the integrity of all heater electrical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than 10,000 ohms, and d) Verifying during a recombiner system fune.tirnal s test using containment atmospheric air at an acceptable flow rate as S) I determined in Section 4.6.4.2.b.5 that the gas temperature J i increases to greater than or equal to 1100*F within 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months { l and is maintained for at least 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . l i

f '5,) Verifying during a recombiner system functional test using l containment atmospheric air that the blower would be capable '

of delivering at least 41.52 scfm at contafnment conditions of 12.47 psia and 130*F.

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17 MILLSTONE - UNIT 3 3/4 6D4 AmendmentNo.U,f/

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HILLSTONE - UNIT 3 3/4 6-36a co4s AmendmentNo.g,g[p

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CONTAINMENT SYSTEMS 3/4. 6. 5 SUBATHOSPHERIC PRESSURf CONTROL SYSTEM STEAM JET AIR EJECTOR

,LIMITINdCONDITIONFOROPERATION

.3.6.5.1 The inside and outside isolation valves in the staan jet air ejector suction line shall be closed.

APPLICABILITY: MODES 1, 2, 3, and 4 l

ACTION.

With the inside or outside isolation valves in the steam jet air ejector suction line not closed, restore the valve to the closed position within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

4

$URVEILLANCE REQUIREMENTS 4.6.5.1.1 The steam jet air ejector suction line outside isolation valve sha11' be determined to be in the closed position by a visual inspection prior to increasing the Reactor Coolant System temperature above 200'F and at le'st a once per 31 days thereafter. ,

4.6.5.1.2 The staan jet air ejector suction Ifne inside isolation valve shall be determined to be locked in the closed position by a visual inspection prior '

to increasing the Reactor Coolant System temperature above 200*F.

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MILLSTONE - UNIT 3

3/46-K b enc (m m f W .

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tellTAlletDfT $YSTDt3 l 3/4 1 s sgtoleARY ColfTAllStENT Fi EllPPLDIDfTARY LEAK $0LLECTION Als RELEASE SYSTEM I

LBEITIIIS C00e! TION FOR OPERATION 3.6.6.1 Two independent Supplementary Leak Collection and Release Systems :

shall be OPERABLE with each system comprised of:

a. one OPERABLE filter and fan, and i

b. one OPERABLE Auxiliary Building Filter System as defined in Specification 3.7.9.

V APPLICABILITY: MODES I, 2, 3, and 4.

ACTION:

With one Su>plementary Leak Collection and Release Systesi inoperable, restore the inopera>1e system to OPERABLE status within 7 days or be in at least P0T l

. STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . i

)

SERVEILLANCE REQUIRENENTS l

4.6.6.1 Each Supplementary Leak Collection and Release System shall be demon-strated OPERABLE:

a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal edsorbers and verifying a system flow rate of 7600 cfm to 9800 cfm and that the system operates for at least 10 continuous hours with the heaters operating. .

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 communi- i cating with the system by:

s

1) Verifying that the system satisfies the in-place penetration and bypass leaka<pe testing acceptance criteria of less than

, 0.05% and uses tie test procedure guidance in Regulatory Posi- l tions C.5.a. C.5.c. and C.5.d of Regulatory Guide 1.52, Revi- !

sinn 2, March 1978,* and the system flow rate is 7600 cfm to 1 9600 cfe; i 19 I,IILL3 TONE - int!T 3 3/4 6-K AmendmentNo.J,57.k

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ggNTADRIENT SYSTDis q SLRVEILLANCE ltEQUIRDIENTS (Continued) l 2) within 31 days after removal, that a laboratory -

Verifying,f analysis o a representative carbon san >1e obtained in accord- l ance with Regulatory Position C.6.b of tegulatory Guide 1.52, i Revision 2, March 1978,* meets the laboratory testing criteria ,

of Regulatory Position C.6.a of Regulatory Guide 1.52. Revi-sion Z, March 1978,* for a methyl iodide penetration of less

' than 0.175%; and

3) Verifying a system flow rate of 7600 cfm to 9800 cfm during system operation when tested in accordance with ANSI N510-1980.

c; After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation, by verifying, within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory i Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978,*

meets the laboratory testing criteria of Regulatory Position C.6.a i of Regulatory Guide 1.52 Revision 2, March 1978,* for a methyl

. iodide penetration of less than 0.175%: .

d. At least once per 18 months by: ;

3) Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6.25 inches ,;

Water tauge while operating the system at a flow rate of .

7600 cfm to 9800 cfe, *

2) Verif ing that the system starts em a Safety Injection test ,

signa ,

~3) Verifying that each system produces a negative pressure of !

} ,

Ireater utiding than or elevation at 24'6" equal to within 0.4 inch 120Water secondsGau0e after ainstart the Auxiliarl signal, and

4) Verifying that the heaters dissipate 50 15 kW when tested in -

! accordance with ANSI N510-1990.

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ANSI N510-1980 shall be used in place of ANSI N510-1975 referenced in Regulatory Guide 1.52, Revision 2, March 1978.

3/46-p2.0 AmendmentNo.g,77,k RI,LLSTONE - ISt!T 3 l

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A-+2/ 09/ 9P CONTADDfENT SYSTDl3 SERVEILLANCE REQUIRDIDITS (Continued) y

e. After each complete or partial replacement of a HEPA filter bank, by verifying that the cleanup system satisfies the in-place penetration

- and bypass leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a DOP test aerosol while operating the system at a flow rate of 7600 cfm to 9800 cfs; and

f. After each complete or partial replacement of a charcoal adsorber bank, by verifying that the cleanup system satisfies the in-place penetration and bypass leakage testing acceptance criteria of less ,

than 0.05% in accordance with ANSI N510-1980 for a halogenated hydrocarbon refrigerant test gas while operating the system at a flow rate of 7600 cfm to 9800 cfs.

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N LLSTONE - IMIT 3 3/46-% AmendmentNo.J,77,f/)

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CONTAlltfENT SYSTEMS q SEC00BARY CONTA110tEFr B0UNDARY LIMITING C00SITION FOR OFERATION D

3.6.6.2 SECONDARY CONTAINMENT BOUNDARY shall be maintained. O APPLICABILITY: MODES I, 2, 3, and 4.

EllDK: - -QS Without SECONDARY CONTAINMENT BOUNDARY, restore SECONDARY CONTAINMENT BOUNDARY within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILUDICE REQUIREMENT 4.6.6.2 SECONDARY CONTAINMENT BOUNDARY shall be demonstrated at least once per 31 days by verifying that each door in each access opening is closed except when the )

access opening is being used for normal transit entry and exit.

tP gl,LL5 TONE - LSIIT 3 3/46-M AmendmentNo.ff

.. w- J 12/0C/33 CONTAllBIENT SYSTEMS tranman_y twTAll8 TENT B0tNIDARY STRUCTINtAL INTEGRITY V

F LIMITING C0fGITION FOR OPERATION 3.6.6.3 The structural integrity of the SECONDARY CONTAINMENT BOUNDARY shall be J maintained at a level consistent with the acceptance criteria in Specification 4.6.6.3. U I

APPLICABILITY: ' MODES 1, 2, 3, and 4.

EIIM: ,

With the structural integrity of the SECONDARY CONTAINMENT BOUNDARY not conforming to the above requirements, restore the structural integrity to within the limits within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in' COLD SHLTTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . :

SURVEILLANCE REQUIREMENT 4.6.6.3 The structural integrity of the SECONDARY CONTAINME i determined during the shutdown for each Type A containment leakage rate test (reference 1 Specification 4 6.I.2) by a visual inspection of the exposed accessible interior and exterior surfaces of the SECONDARY CONTAINMENT B0UNDARY and verifying no apparent l changes in appearance of the concrete surfaces or other abnormal degradation. Any g abnormal degradation of the SECONDARY CONTAINMENT BOUNDARY detected during the above ,

required inspections shall be reported to the Comission in a Special Report pursuant ;

to Specification 6.g.2 within 15 days.

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23 gl,LLSTONE-ISIIT3 3/46-M AmendmentNo.//

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S tm;;;;: 25 m00 PLANT SYSTEMS .-)F AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater pumps and associated flow paths shall be OPERABLE with:

a. Two motor-driven auxiliary feedwater pumps, each capable of being powered from separate emergency busses, and

b. One steam turbine-driven auxiliary feedwater pump capable of being powered from an OPERABLE steam supply system.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With one auxiliary feedwater pump inoperable, restore the required auxiliary feedwater pumps to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY "8 thin the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hwrs.

b. With two auxiliary feedwater pumps inoperable, be in at least HOT (

(

STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c. With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary i feedwater pump to OPERABLE status as soon as possible. Entry into :

an OPERATIONAL MODE pursuant to Specification 3.0.4 is not permitted l with three auxiliary feedwater pumps inoperable. ]

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SURVEILLANCE RE0VIREMENTS 4.7.1.2.1 Each auxiliar.y feedwater pump shall be demonstrated OPERABLE:

(3tg At least once per'92.S(daysonaSTAGGEREDTESTBASISby:

1) Verifying that on recirculation flow each motor-driven pump develops a differential pressure of greater than or equal to 1460 psid when tested pursuant to Specification 4.0.5; 1

2) Verifying that on recirculation flow the steam turbine-driven ,

pump develops a differential pressure of greater than or equal to 1640 psid when the secondary steam supply pressure is l greater than 800 psig. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3;

< 's.

MILLSTONE - UNIT 3 3/4 7-4 AMENDMENTNO.//, $

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a

s jl_ l 'a 's "o"1"' snor PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) q, M i cast- Cm cc_ pe< 'dl c%s by*

1 94)

Verifying that each non-autcoatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in its correct position; and

24) Verifying that each auxiliary feedwater control and isolation valve in the flow path is in the fully open position when above 10% RATED THERMAL POWER.

At least once per 18 months during shutdown by verifying that each ,

C 1(. auxiliary feedwater pump starts as designed automatically upon receipt of an Auxiliary Feedwater Actuation test signal.

4.7.1.2.2 An auxiliary feedwater flow path to each steam generator shall be demonstrated OPERABLE following each COLD SHUTDOWN of greater than 30 days prior to entering MODE 2 by verifying flow to each steam generator.

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MILLSTONE - UNIT 3 3/4 7-5 bmdmed Mo, I

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' PLANT SYSTEMS )'

, SURVEILLANCE REQUIREMENTS (Continued) l l

type that may be generically susceptible; and (2) the affected snubber is functionally tested in the as-found All condition and snubbers found i l

determined OPERABLE per Specification 4.7.10.f. con for determining the next inspection counted as unacceptable to justify continued operation with an unaccep If ;

continued operation cannot be justified, the snubber shall be l declared inoperable and the ACTION requirements shall be met.

l

d. Transient Event Insoection '

An inspection shall be performed of all snubbers attached to sections of systems that have experienced unexpected, potentiallyi damaging transients as determined from a review of operational da .

and a visual inspection of the systems within 6 months following l In addition to satisfying the visual inspection r such an event.

acceptance criteria, freedom-of-motion of mechanical snubbers s be verified using at leastorone of the following:

(2) evaluation of in-place snubber induced snubber movement; piston setting; or (3) stroking the mechanical snubber through its full range of travel, f

e. Functional Tests 1 '

D, During the first refueling shutdown and at least oj '

each type shall be tested using one of the following sample plans. :

1he sample plan for each type shall be selected prior The to the NRCtest period and cannot be changed during the test period. ;

~

Regional Administrator shall be notified in w !

sample plan used in the prior test period shall be implemented:

At least 10% of the total of each type of snubber shall be Fo-

1) functionally tested either in-place or in a bench test. :

each snubber of a type that does not meet the functional tes l acceptance criteria of Specification 4.7.10f., an additional 5 i of that type of snubber shall be functionally tested until e l more failures are found or until all snubbers of that type has ;

been functionally tested; or i l0Ier IbOC wissuiry $$, UN

[XC0pt that ihe sui vu $llshss e squ's s u.-. sit d 0 ::1?:; ::ts;e. 5'M -e liter then

> aey 50 ife. red ;;til th: r. ext reft:

7 September % , I;;3, Jiiche ur i: ::r'fer.

Amendment #

HILLSTONE - UNIT 3 3/47-23 0109 b

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Acn " - ?, 'co' TABLE 4.7-2 l

SNUBBER VISUAL INSPECTION INTERVAL NUMBER OF UNACCEPTABLE SNUBBERS g

Column B Column C Population Column A or Category Extend Interval Repeat Interval Reduce Interval (Nn'es 3 and 6) (Notes 4 and 6) (Notes 5 and 61 (Notes 1 and 21 l

1 0 0 1 0 0 2 80 0 1 4 100 0 3 8 150 2 5 13 i 200 300 5 12 25 .

400 8 18 36 500 12 24 48 750 20 . 40 78 1000 or greater 29 56 109 I

Note 1: The next visual inspection interval for a snubber population or category size shall be determined based upon the previous inspection interval and the number of unacceptable snubbers found during that interval. Snubbers may be categorized, based upon their !

accessibility during power operation, as accessible or inaccessible.

These categories may be examined separately or jointly. However, the licensee must make and document that decision before any inspection and shall use that decision as the basis upon which to determine the next inspection interval for that category.

Note 2: Interpolation between population or category sizes and the number of unacceptable snubbers is permissible. Use next lower integer for the value of the limit for Columns A, B, or C if that integer included a fractional value of unacceptable snubbers as determined by interpolation.

Note 3: If the number of unacceptable snubbers is equal to or less than the number in Column A, the next inspection interval may be twice the previous interval but no greater than 48 months.

Note 4: If the number of unacceptable snubbers is equal to or less than the number in Column B but greater than the number in Column A, the next inspection interval shall be the same as the previous interval.

Note 5: If the number of unacceptable snubbers is equal to or greater than the number in Column C, the next inspection interval shall be two-thirds of the previous interval . However, if the number of unacceptable snubbers is less than the number in Column C but greater than the number in Column B, the next interval shall be reduced proportionally by interpolation, that is, the previous interval shall be reduced by a factor that is one-third of the ratio of the difference between the number of unacceptable snubbers found during the previous interval and the number in Column B to the difference in the numbers in Columns B and C.

MILLSTONE - UNIT 3 3/4 7 % '2jt knendment No.

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TABLE 4.7-2 SNUBBER VISUAL INSPECTION INTERVAL

'''9#

[j Note 6: The provisions of Specification 4.0.2 are applicable for all Il inspection intervals up to and including 48 months.

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CONTINUE {

- TESTING -

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0 10 20 30 40 50 60 70 80 90 100 N

FJGURE 4.7 2 5 AMPLE PLAN 2) FOR SNUBBER FUNCT]DNAL TEST 29 MILLSTONE - pH}T 3 3/47.M AmendmentNo.((

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3%c t a. O , 1^ m PLANT SYSTEMS I 3/4.7.11 SEALED SOURCE CONTAMINATION LIMITING CONDITION FOR OPERATION 3.7.11 Each sealed source containing radioactive material either in excess of 100 microcuries of beta and/or gamma emitting material or 5 microcuries of alpha emitting material shall be free of greater than or equal to !

0.005 microcurie of removable contamination.

APPLICABILITY: At all times.

ACTION:

a. With a sealed source having removable contamination in excess of the above limits, immediately withdraw the sealed source from use and either:

1. Decontaminate and repair the sealed source, or

2. Dispose of the sealed source in accordance with Commission Regulations.

b. The provisions of Specification 3.0.3 are not applicable. d SURVEILLANCE RE0VIREMENTS 4.7.11.1 Test Requirements - Each sealed source shall be tested for leakage '

and/or contamination by:

a. The licensee, or

b. Other persons specifically authorized by the Commission or an ,

Agreement State.

The test method shall have a dettetion sensitivity of at least 0.005 microcurie per test sample.

4.7.11.2 Test Frequencies - Each category of sealed sources (excluding startup sources and fission detectors previously subjected to core flux) shall be tested at the frequency described below.

a. Sources in use - At least once per 6 months for all sealed sources containing radioactive materials:

1) With a half-life greater than 30 days (excluding Hydrogen 3),

and

2) In any form other than gas.

3S MILLSTONE - UNIT 3 3/47-X AMENDMENTNO.//

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.. ...,...;.., .. , k ,*r.;.cr;".21.,17M'., . . ,...

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

b. Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous 6 months. Sealed sources and fission detectors transferred without a certificate indicating the last test

- date shall be tested prior to being placed into use; and

c. Startup sources and fission detectors Each sealed startup source and fission detector shall be tested within 31 days prior to being subjected to core flux or installed in the core and following repair or maintenance to the source. .

4.7.11.3 Reports - A report shall be prepared and submitted to the Comission on an annual basis if sealed source or fission detector leakage tests reveal the presence of greater than or equal to 0.005 microcurie of removable contamination.

I 31 pagg go. \

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Oa::: 25 ,1000 L. .

PLANT SYSTEMS tr_

3/4.7.N AREA TEMPERATURE MONITORING LIMITING CONDITION FOR OPERATION lt 9 3.7.h The temperature limit of each area shown in Table 3.7-/ shall not be exceeded.

APPLICABILITY: Whenever the equipment in an affected area is required to be OPERABLE.

ACTION:

With one or more areas exceeding the temperature limit (s) shown in Table 3.7- :

a. By less than 208F and for less than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , record the cumulative time and the amount by which the temperature in the affected area (s) exceeded the limit (s),

b. By less than 20eF and for more than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , prepare and submit to the Commission within 30 days, pursuant to Specification 6.9.2, a Special Report that prov'Ss a record of the cumulative time and the amount by which the teeperature in the affected area (s) exceeded the limit (s) and an analysis to demonstrate the continued OPERABILITY of the affected equipment. The provisions of Specification 3.0.3 are not applicable. !

4

c. With one of more areas exceeding the temperature limit (s) shown in Table 3.7-E by more than 20eF, prepare and submit a Special Report as required by ACTION b. above and within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either restore the area (s) to within the temperature limit (s) or declare the equip-ment in the affected area (s) inoperable.

SURVEILLANCE REOUIREMENTS IL 4 4.7.M The temperature in each of the areas shown in Table 3.7 'E shall be determined to be within its limit at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

32 MILLSTONE - UNIT 3 AMENDMENT NO.

3/47-K

e . ,,

S__ ann.,nry u ions ,

i i i TABLE 3.7-4 i

AREA TEMPERATURE MONITORING l AREA TEMPERATURE LIMIT ('F)

1. AUXILIARY BUILDING ,

i AB-02, VCT and Boric Acid Transfer Pump Ared El 43'6" 1 120 l AB-03, Charging Pump Area, El 24'6" 1 110 AB-04, General Area, El 66'6" 1 120 I

AB-06, General Area, El 43'6" 1 120 AB-07, General Area, El 4'6" 1 120 AB-08, General Area (East), El 4'6" i 120 AB-09. General Area (South), El 4*6" 1 120 i

AB-10, General Area, El 4'6" i 120 AB-11, General Area, El 43'6" 1 120 f AB-13, General Area (North), El 4'6" 1 120 AB-16, Supplemental Leak Collection Filter .

i Area, El 66'6" i 120 AB-19, MCC/ Rod Drive Area, El 24'6" 1 120 AB-21, MCC Air Conditioning Room, El 66'6" 5 120 AB-22, Rod Drive Area, El 43'6" 1 120 3

AB-25, Charging Pump Area, El 24'6" 1 110 AB-26, RPCCW Pump Area, El 24'6" 1 110 AB-29, General Area (Southeast), El 24'6" 1 120 AB-33, Boric Acid Tank Area, El 43'6" 1 120 AB-35, Boric Acid Tank Area, El 43'6" 1 120 AB-39, Fuel Building and Auxiliary Building )

Filter Area, El 66'6" 1 120 i

i MILLSTONE - UNIT 3 3/47-D gg 4 !

l

~ 'n .

F e:teer ?, 5 05 -

4- .

Table 3.7 / (Continued)

AREA TEMPERATURE MONITORING l

p_BEA TEMPERATURE LIMIT (OF)

2. CONTROL BUILDING CB-01, Switchgear and Battery Rooms, El 4'6" $104 CB-02, Cable Spreading Room, El 24'6" 5110 CB-03, Control and Computer Rooms, El 47'6" 5 . 95 CB-04, Chiller Room, El 64'6" Il04 CB-05, Mechanical Equipment Room, El 64-6" f.104 is

3. CONTAINMENT '

CS-01, Inside Crane Wall, El all except CS-03 and CS-04 .$120 CS-02, Outside Crane Wall, El all .$120 CS-03, Pressurizer Cubicle, El all 5130 -

CS-04, Inside Crane wall, El 51'4" except CS-03 and steam 6-.120 generator enclosures

4. INTAKE STRUCTURE CW-01, Entire Building $__110

5. DIESEL GENERATOR BUILDING l DG-01 Entire Building 1.120

6. ESF BUILDING' ES-01, HVAC and MCC Area, El 36'6" 4 110 ES-02, SIH Pump Area, El 21'6" 4 110 ES-03, Pipe Tunnel Area, El 4'6" 4 110 ,

i ES-04, RHS Cubicles, El all 4 110 ES-05, RSS Cubicles, El all 4 110 ES-06, Motor Driven Auxiliary Feedwater Pump ,

Area, El 24'-6" d:.110 ES-07. Turbine Driven Auxiliary Feedwater Pump 4 110 Area, El 24'6" MILLSTONE - UNIT 3 3/4 7- Amendment No.

. . .e TABLE 3.7- (Continued) o

- 4 % 2 1 togg AREA TEMPERATURE MONITORING l

AREA TEMPERATURE LIMIT ('F)

7. FUEL BUILDING FB-02, Fuel Pool Pump Cubicles, El 24'6" 1 110 FB-03, General Area, El 52'4" 1 104

8. FUEL OIL VliULT FV-01, Diesel Fuel Oil Vault i 95

9. HYOROGEN RECOMBINER BUILDING HR-01, Recombiner Skid Area, El 24'6" 1 125 HR-02, Controls Area, El 24'6" 1 110 HR-03, Sampling Area, El 24'6" 1 110 HR-04, HVAC Area, El 37'6" 1 110

10. MAIN STEAM VALVE BUILDING MS-01, Entire building 5 120 -

11. T_URBINE BUILDING TB-01, Entire Building i 115

12. TUNNEL TN-02, Pipe Tunnel-Auxiliary, Fuel and ESF Building i 112

13. YARD YD-01, Yard i 115 1

36 MILLSTONE - UNil J ~ 7' h m en d N d N O. ,

., 3 f M 2/22/92_

ELECTRICAL POWER SYSTEMS" ggEVEILLANCE REQUIREMENTS (Continued) b) A kinematic viscosity at 40*C of greater than or equal to 1.9 centistokes, but less than or equal to 4.1 centistokes (alternatively, Saybolt viscosity, SUS at 100'F of greater than or equal to 32.6, but not less than or equal to 40.1), if gravity was not determined by comparison with the supplier's certification; c) A flash point equal to or greater than 125'F; and d) A clear and bright appearance with proper color when tested in accordance with ASTM-D4176-82.

2) By verifying within 30 days of obtaining the sample that the other properties specified in Table 1 of ASTM-D975-81 are met when tested in accordance with ASTM-D975-81 except that the analysis for sulfur may be performed in accordance with ASTM-D1552-79, ASTM-D2622-82 or ASTM-D4294-83.

f. At least once every 31 days by obtaining a sam >1e of fuel oil in accordance with ASTM-D2276-78, and verifying tiat total particulate contamination is less than 10 mg/ liter when checked in accordance with ASTM-D2276-78, Method A; ,

g. At least once per 18 months, during shutdown, by:

1) Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufasturer's recommendations for this class of standby serviceO* -A ,

2) Verifying the generator capability to reject a load of greater than or equal to 595 kW while maintaining voltage at 4160 1 420 volts and frequency at 60 i 3 Hz; ;

3) Verifying the generator capability to reject a load of 4986 kW without tripping. The generator voltage shall not exceed 4784 volts during and following the load rejection;

4) Simulating a loss-of-offsite power by itself, and:

a) Verifying deenergization of the emergency busses and load shedding from the emergency busses, and b) Verifying the diesel starts on the auto-start signal, energizes the emergency busses with permanently connected loads within 11 seconds, energizes the auto-connected shutdown loads through the load sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown loads. After energitation, the l

steady-state. voltage and frequency of the emergency busses shall be maintained at 4160 1 420 volts and 6010.8 Hz ,

during this test.

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/

MILLSTONE - UNIT 3 3/4 8-5 AmendmentNo.p,Jp,JJ,/[

ess7

!. . .. aune ^, U3 ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) i

8) Verifying that the auto-connected loads to each diesel genera-tor do not exceed the 2000-hour rating of 5335 kW;

9) Verifying the diesel generator's capability to:

a) Synchronize with the offsite power source while the generator is loaded with its emergency loads upon a simulated restoration of offsite power,

, b) Transfer its loads to the offsite power source, and c) Be restored to its standby status.

10) Verifyin at with the diesel generator operating in a test mode, connected to its bus, a simulated Safety injection signal overrides the test mode by: (1) returning the diesel generator to standby operation, and (2) automatically energizing the emergency loads with offsite power;

11) Verifying that the fuel transfer pump transfers fuel fron: each fuel storage tank to the day tank of each diesel via the installed cross-connection lines;

12) Verifyin at the automatic load' sequence timer is OPERABLE with the interval'between each load block within i 105 of its design interval; and -

j

13) Verifying that the following diesel generator lockout features prevent diesel generator starting: l a) Engine overspeed, b) Lube oil pressure low (2 of 3 logic),

c) Generator differential, and ;

d) Emergency stop. ,

h. At least once per 10 years or after any modifications which could affect diesel generator interdependence by starting both diesel generators simultaneously, during shutdown, and verifying that both .

diesel generators accelerate to at least 508 rps in less than or equal to 11 seconds; and

1. At least once per 10 years by:

1) Draining each fuel oil storage tank, removing the accumulated sediment and cleaning the tank using a sodium hypochlorite solution, and

A A rmat that +ha n==!!h::: r;;;'rn-+ da= r 1;te, G .. 2 .: !!,1^03,

>-may M ef:cred ;r.til th: ert r;f.;;lir.i, ;;t;;;;, but e ht:- tM-(- . ,__e <__ .a .... 2,_<_... 4.

. . .u _ . .

.m ll- )

.' 'v* o . _ _ e inn, ELEcTRfcAL POWER SYSTEMS / ""' "'~

SURVEILLANCE REQUIREMENTS (Continued)

b. At least once per 92 days and within 7 days after a battery discharge with battery terminal voltage below 110 volts, or battery E overcharge with battery terminal voltage above 150 volts, by verify- I ing that:

1) The parameters in Table 4.8-2a meet the Category B limits,

2) There is no visible corrosion at either teminals or connec-tors, or the connection resistance of these items is less than '

150 x 10~5 chm, and

3) The average electrolyte temperature of six connected cells is ;

above 60*F.

c. At least once per 18 mont by verifying that:

1) The cells, cell plates, and battery racks show no visual :

indication of physical damage or abnormal deterioration,

, l The cell-to-cell and teminal connections are clean, tight, and

~

2)

- coated with anticerresten material,

3) The resistance of each cell-to-cell and teminal connection is !

less than or equal to 150 x 10~8 ohn, and

4) Each battery charger will supply at least the amperage indi- '

cated in Table 4.8-2b at 125 volts for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . I

d. At least once per 18 monthduring shutdown, by verifying that the :

battery capacity is adequate to supply and maintain in OPERABLE 1 status all of the actual or simulated emergency loads for the design i duty cycle when the battery is subjected to a battery service test; I

e. At least once per 60 mont during shutdown, by verifying that the l battery capacity is at least 80% of the manufacturer's rating when j subjected to a performance distharge test. Once per 60-month '

interval this perfomance discharge test may be perfomed in lieu of the battery service test required by Specification 4.8.2.3d.; and At least once per 18 mon during shutdown, by giving performance f.

discharge tests of battery capacity to any battery that shows signs ~

)

of degradation or has reached 85% of the service life expected for the application. Degradation is indicated when the battery capacity drops more than 10% of rated capacity from its average on previous perfomance tests, or is below 90% of the manufacturer's rating. y 94 he st th;t th; rrve!!!re r:;ir: 1..t 4.. nu isier i' n.n J... 13, i;A My M ef;rred er.til ins ned ef.eiir.g eet;;; L.t i.e leter ther. { ;

J Oed eu 30,ivu,wnnn.... i; ::rlier.

\} I MILLSTONE - UNIT 3 3/4 8-12 ess4 AmendmentNo.$f,/h, l

)

e . ,

EMERGENCY CORE COOLING SYSTEMS v'AIE O I COO ~

l BASES -

ECCS SUBSYSTEMS (Continued) j The limitation for a maximum of one centrifugal charging pump and one ;

safety injection pump to be OPERABLE and the Surveillance Requirement to verify all charging pumps and safety injection pumps except the required OPERABLE charging pump to be inoperable below 350*F provides assurance that a mass addition pressure transient can be relieved by the operation of a = ingle PORV.

.ne Surveillance Requirements provided to ensure OPERABILITY of each component ensures that at a minimum, the assumptions used in the safety analyses are met and that subsystem OPERABILITY is maintained. Surveillance Requirements for throttle valve position stops and flow balance testing provide assurance that proper ECCS flows will be maintained in the event of a LOCA.

Maintenance of proper flow resistance and pressure drop in the piping system to each injection point is necessary to: (1) prevent total pump flow from exceeding runout conditions when the system is in its minimum resistance configuration, (2) provide the proper flow spilt between injection poir.ts in accordance with the assumptions used in the ECCS-LOCA analyses, and (3) provide an acceptable level of total ECCS flow to all injection points equal to or above that assumed in the ECCS-LOCA analyses.

marr- A 3/4.5.4 REFUELING WATER STORAGE TANK ,

The OPERABILITY of the refueling water storage tank (RWST) as part of the ECCS ensures that a sufficient supply of borated water is available for injec-tion by the ECCS in the event of a LOCA. The limits on RWST minimum volume and boron concentration ensure that: (1) sufficient water is available within containment to permit recirculation cooling flow to the core, and (2) the reactor will remain subcritical in the cold condition following mixing of the RWST and the RCS water volumes with all control rods inserted except for the most reactive control assembly. These assumptions are consistent with the LOCA analyses.

The contained water volume limit includes an allowance for water not usable because of tank discharge line location or other physical characteristics.

The limits on contained water volume and boron concentration of the RWST also ensure a pH value of between 7.0 and 7.5 for the solution recirculated within containment after a LOCA. This pH band minimizes the effect of chloride and caustic stress corrosion on mechanical systems and components.

The maximum / minimum solution temperatures for the RWST in H0 DES 1, 2, 3 and 4 are based on analysis assumptions.

i l

MILLSTONE - UNIT 3 B 3/4 5-2 bulcodment M.

l

o. *m

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M -W. N W J.w m <. J . Au . becw e. d e. M A 4 d w g . c4 M mu%~i t-so om __+ .% u w. vs a wsAwc -%. ww mb u g awwu.<.a g

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.. p A 10 /25/03--

t PLANT SYSTEMS BASES 3/4.7.11 SEALED SOURCE CONTAMINATION (Continued) plutonium. This limitation will ensure that leakage from Byproduct, Source, ,

and Special Nuclear Material sources will not exceed allowable intake values.

Sealed sources are classified into three groups according to their use, with Surveillance Requirements comensurate with the probability of damage to a source in that group. Those sources which are frequently handled are required to be tested more often than those which are not. Sealed sources which are continuously enclosed within a shielded mechanism (i.e., sealed sources within radiation monitoring or boron measuring devices) are considered to be stored and need not be tested unless they are removed from the shielded mechanism.

I 3/4.7.12 Oeleted MILLSTONE - UNIT 3 B 3/4 7-7 AmendmentNo.EE,h)

, ! 1^ /2 5/ =

PLANT SYSTEMS y

BASES M- ?!A 7 11 Slet:d Iz 3/4.7.M AREA TEMPERATURE MONITORING The area temperature limitations ensure that safety-related equipment will not be subjected to temperatures in excess of their environmental qualification temperatures. Exposure to excessive temperatures may degrade equipment and can cause a loss of its OPERABILITY. The temperature limits include an allowance for instrument error of 12.2*F.

hhhSTONE - WIT 3 B 3/4 7-8 Amendment No. JE,

ML20071M868

Text

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