Text

Amend 100 to License NPF-49,removing Expired one-time Extensions of Surveillance & Obsolete Definition & Adding 11 Line Item Improvements IAW GL 93-05
	ML20077N165
Person / Time
Site:	Millstone
Issue date:	01/03/1995
From:	Mckee P; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML17253A007	List: ML17253A006; ML20077N165;
References
	GL-93-05, GL-93-5, NUDOCS 9501170090
	Download: ML20077N165 (68)
	v • d • e

_____ _ _ _ _ _

k2 EIGOg

g UNITED STATES y

2 S

NUCLEAR REGULATORY COMMISSION E

f WASHINGTON, D.C. 20666 0001 5

NORTHEAST NUCLEAR ENERGY COMPANY. ET AL.

DOCKET NO. 50-423 MILLSTONE NUCLEAR POWER STATION. UNIT NO. 3 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 100 License No. NPF-49 1.

The Nuclear Regulatory Comission (the Comission) has found that:

A.

The application for amendment by Northeast Nuclear Energy Company, et al. (the licensee), dated June 2,1994, as supplemented August 25, 1994, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission's rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Comission; C.

There is reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations; D.

The issuance of this amendment will not be inimical to the comon defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Comission's regulations and all applicable requirements have been satisfied.

R A

3

.. 2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-49 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No.100

, and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

This license amendment is efmtive as of the date of its issuance, to be implemented within 30 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION l

Phillip F.

Kee, Director Project Directsrate I-4 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

January 3, 1995

ATTACHMENT TO LICENSE AMENDMENT NO. 100 FACILITY OPERATING LICENSE NO. NPF-49 DOCKET NO. 50-423 Replace the following pages of the Appendix A Technical Specifications with the enclosed pages.

The revised pages are identified by amendment number and contain vertical lines indicating the areas of change.

Remove Insert 11 11 ix ix x

x

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xV xV 1-7 1-7 3/4 2-20 3/4 2-20 3/4 2-23 3/4 2-23 3/4 3-1 3/4 3-1 3/4 3-10 3/4 3-10 3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-14 3/4 3-14 3/4 3-16 3/4 3-16 3/4 3-36 3/4 3-36 3/4 3-37 3/4 3-37 3/4 3-38 3/4 3-38 3/4 3-39 3/4 3-39 3/4 3-40 3/4 3-40 3/4 3-41 3/4 3-41 3/4 3-45 3/4 3-45 3/4 3-49

'3/4 3-49 3/4 3-53 3/4 3-53 3/4 3-58 3/4 3-58 3/4 3-62 3/4 3-62 3/4 3-63 3/4 3-63 3/4 3-68 3/4 3-68 3/4 4-11 3/4 4-11 3/4 4-16 3/4 4-16 3/4 4-21 3/4 4-21 3/4 4-23 3/4 4-23 3/4 4-39 3/4 4-39 3/4 4-43 3/4 4-43 3/4 5-1 3/4 5-1 3/4 5-2 3/4 5-2 3/4 5-4 3/4 5-4 3/4 6-3 3/4 6-3 3/4 6-12 3/4 6-12 3/4 6-13 3/4 6-13 3/4 6-16 thru 3/4 6-42 3/4 6-16 thru 3/4 6-23 m

(continued)

Remove Insert 3/4 7-4 3/4 7-4 3/4 7-5 3/4 7-5 3/4 7-23 3/4 7 3/4 7-26a thru 3/4 7-47 3/4 7-27 thru 3/4 7-35 3/4 8-5 3/4 8-5 3/4 8-7 3/4 8-7 3/4 8-12 3/4 8-12 B 3/4 5-2 B 3/4 5-2 8 3/4 7-7 8 3/4 7-7 B 3/4 7-8 i

4

1 MK DEFINITIONS SECTION M

1 1.32 SLAVE RELAY TEST.............................................

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

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

1-6 1.35 THERMAL P0WER................................................

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

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

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

1-6 1.39 VENTING.....................................,................

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

1-7 1.41 SPENT FUEL POOL STORAGE PATTERNS.............................

1-7 1.42 CORE OPERATING LINITS REPORT (C0LR)..........................

1-7 1.43 ALLOWED POWER LEVEL--APL"...................................

1-7 1.44 ALLOWED POWER LEVEL--APL"...................................

1-7 i

TABLE 1.1 FREQUENCY NOTAT!0N......................................

1-8 TABLE 1.2 OPERATIONAL M0 DES.......................................

1-9 4

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NILLSTONE - UNIT 3 11 Amendment No. M. M. M. 7X. M.100 0229 i

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i LIMITING COM ITIONS FOR OPERATION AS SURVEILLANCE REQUIREMENTS 1

i SECTION P.8E Air Temperature 3/4 6-9 Containment Structural Integrity...........

3/4 6-10 i

Containment Ventilation System............

3/4 6-11 j

3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS 4

l Containment Quench Spray System 3/4 6-12

)

. Recirculation Spray System............... 3/4 6-13 1

Spray Additive System 3/4 6-14 i

3/4.6.3 CONTAINNENT ISOLATION VALVES.............

3/4 6-15 j

3/4.6.4 COMBUSTIBLE GAS CONTROL Hydrogen Monitors 3/4 6-16 j

Electric Hydrogen Recombiners 3/4 6-17

{

3/4.6.5 SUBATMOSPHERIC PRESSURE CONTROL SYSTEM I

Steam Jet Air Ejector 3/4 6-18 3/4.6.6 SECONDARY CONTAINNENT

[

Supplementary Leak Collection and Release System...

3/4 6-19

]

Secondary Containment Boundary............

3/4 6-22 i

Secondary Containment Boundary Structural Integrity.................

3/4 6-23 3/4.7 PLANT SYSTEMS 3/4.7.1 TURBINE CYCLE i

i Safety Valves 3/4 7-1 4

}

TABLE 3.7-1 MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH SETPOINT WITH INOPERABLE STEAM LINE SAFETY VALVES i

DURING FOUR LOOP OPERATION 3/4 7-2 l

TABLE 3.7-2 MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH j

SETPOINT WITH INOPERABLE STEAM LINE SAFETY VALVES DURING THREE LOOP OPERATION 2

3/4 7-2

.I 1

i MILLSTONE - UNIT 3 1x Amendment No. pp, 77, 77, pp.100 i

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1 IMEX I

4 LIMITING ColSITIONS FOR OPERATION AM SURVEILLME RE0UIREMENTS

)

i l-SECTION P. AGE i

TABLE 3.7-3 STEAM LINE SAFETY VALVES PER LOOP 3/4 7-3 j

Auxiliary Feedwater System 3/4 7-4

}

Domineralized Water Storage Tank 3/4 7-6 i

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Specific Activity 3/4 7-7 l

TABLE 4.7-1 SECONDARY COOLANT SYSTEM SPECIFIC ACTIVITY SAMPLE j

AND ANALYSIS PROGRAM 3/4 7-8 l

Main Steam Line Isolation Valves 3/4 7-9 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION 3/4 7-10

{

3/4.7.3 REACTOR PLANT COMPONENT COOLING WATER SYSTEM 3/4 7-11 3/4.7.4 SERVICE WATER SYSTEM 3/4 7-12 j

3/4.7.5 ULTIMATE HEAT SINK 3/4 7-13 j

3/4.7.6 FLOOD PROTECTION 3/4 7-14 l

3/4.7.7 CONTROL ROOM EMERGENCY VENTILATION SYSTEM 3/4 7-15 j

3/4.7.8 CONTROL ROOM ENVELOPE PRESSURIZATION SYSTEM 3/4 7-18 l

3/4.7.9 AUXILIARY BUILDING FILTER SYSTEM 3/4 7-20 j

3/4.7.10 SNUBBERS 1

...................... 3/4 7-22 l

TABLE 4.7-2 SNUBBER VISUAL INSPECTION INTERVAL 3/4 7-27 FIGURE 4.7-1 SAMPLE PLAN 2) FOR SNU8BER FUNCTIONAL TEST 3/4 7-29

)

3/4.7.11 SEALED SOURCE CONTAMINATION 3/4 7-30

{

3/4.7.12 DELETED 4

i Table 3.7-4 DELETED 1

j Table 3.7-5 DELETED i

3/4.7.13 DELETED f

3/4.7.14 AREA TEMPERATURE MONITORING 3/4 7-32

}

TABLE 3.7-6 AREA TEMPERATURE MONITORING 3/4 7-33 i

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. MILLSTONE - UNIT 3 x

Amendment No. E, M,100 m

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BASES l

l SECTION PAGE 3/4.7.11 SEALED SOURCE CONTAMINATION B 3/4 7-6 3/4.7.12 DELETED 3/4.7.13 DELETED 3/4.7.14 AREA TEMPERATURE MONITORING............... B 3/4 7-7 l

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 P05'ER DISTRIBUTION B 3/4 8-1 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTIVE DEVICES......... B 3/4 8-3 3/4.9 REFUELING 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 B3/49-1 3/4.9.4 CONTAIMENT BUILDING PEHETRATIONS............ 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 I

3/4.9.7 CRANE TRAVEL - SPENT FUEL STORAGE AREAS......... B 3/4 9-2 3/4.9.8 RESIDUAL HEAT RFMOVAL AND COOLANT CIRCULATION...... B 3/4 9-2 3/4.9.9 CONTAIMENT PURGE AND EXHAUST ISOLATION SYSTEM B 3/4 9-2 3/4.9.10 and 3/4.9.11 WATER LEVEL - REACTOR VESSEL AND j

STORAGE POOL

...................... B 3/4 9-3 l

3/4.9.12 FUEL BUILDING EXHAUST FILTER SYSTEM...........

B 3/4 9-3 3/4.9.13 SPENT FUEL POOL - REACTIVITY B 3/4 9-3 3/4.9.14 SPENT FUEL POOL - STORAGE PATTERN............ B 3/4 9-3 l

3/4.10 SPECIAL TEST EXCEPTIONS 3/4.10.1 SHUTDOWN MARGIN..................... i 3/4 10-1 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

.MILLST0ME - WIT 3 xy Amendment No. pp 77.100

=

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 VENTING. Vent, used in system names, does not imply a VENTING process.

SPENT FUEL POOL STORAGE PATTERNS:

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 configurattom between Regic)n 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 II contains no cell blockers.

CORE OPERATING LIMITS REPORT (COLR) 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 ND 1.43 APL is the minimum allowable nuclear design power level for base load operation and is specified in the COLR.

0b 1.44 APL is the maximum allowable power level when transitioning into base load operation.

MILLSTONE - UNIT 3 1-7 Amendment No. #, M. M, 71, 100 an

-. = -. -

POWER DISTRIBUTION LINITS l

LIMITING COM ITION FOR OPERATION 4

i i

i 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 c

through incore flux mapping and RCS total flow rate that F," and RCS total flow rate are restored to within the above limits, or reduce 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 .

J c.

Identify and correct the cause of the out-of-limit condition prior to increasing THERMAL POWER above the reduced THERMAL POWER limit I

required by ACTION a.2. and/or b.,

above; subsequent POWER OPERATION l

may proceed provided that F," and indicated RCS total flow rate are demonstrated, through incore 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 50% of RATED THERMAL POWER, l

2.

A nominal 75% of RATED THERMAL POWER, and 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 1

RATED THERMAL POWER.

j SURVEILLANCE REQUIRENENTS 4.2.3.1.1 The provisions of Specification 4.0.4 are not applicable.

4.2.3.1.2 RCS total flow rate and F," shall be determined to be within the acceptable range:

j a.

Prior to operation above 75% of RATED THERMAL POWER after each fuel loading, and 1

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 of Fgtable 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 i

acce

, obtained per Specification 4.2.3.1.2, is assumed to exist.

1 4.2.3.1.4 The RCS total flow rate indicators shall be subjected to a CHANNEL CALIBRATION at least once per 18 months. The measurement instrumentation shall l

be calibrated within 7 days prior to the performance of the calorimetric flow measurement.

MILLSTONE - WIT 3 3/4 2-20 Amendment No. pp, 77,100 eam

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ION F ERATION ACTION (Continued) b.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of initially beina outside the above limits, d RCS verify through incore flux mapping and RCS total flow rate that F," an total flow rate are restored to within the above limits or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within, the next 2

hours, 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. angor b. Indicated RCS total flow rate areabove; sub may proceed provided that Fa" and demonstrated through incore flux mapping and RCS total flow rate comparison, lo be within the reiion of acceptable operation prior to exceeding the following THERMAL WER levels:

I 1.

A nominal 32% of RATED THERMAL POWER, and 2.

A nominal 50% of RATED THERMAL POWER.

SEVEILLANCE REQUIRENENTS 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 shall be determined to be within the acceptable range at least once per 3,"1 Effective Full Power Days.

4.2.3.2.3 The indicated RCS total flow rate shall be verified to be within the acceptable rangg 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 Fm, obtained per Specification 4.2.3.2.2, is assumed to exist.

4.2.3.2.4 The RCS total flow rate indicators shall be subjected to a CHANNEL CALIBRATION at least once per 18 months. The measurement instrumentation l

shall be calibrated within 7 days prior to the performance of the calorimetric flow measurement.

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 determinationofsteamhressure,feedwaterpressure,feedwatertemperature and feedwater venturi A in the calorimetric calculations shall be calibrafed.

4.2.3.2.6 If the feedwater venturis are not inspected at least once per 18 months uncertainly.an additional 0.1% will be added to the total RCS flow measurement NILLSTONE - WIT 3 3/42-23 Amendment No. J7. pp. 77 100 esa

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1 3/4.3 INSTRWENTATION i

3/4.3.1 REACTOR TRIP SYSTEN INSTRWENTATION LIMITING COMITION FOR OPERATION 3.3.1 As a minimum, the Reactor Trip System instrumentation channels and i

interlocks of Table 3.3-1 shall be OPERABLE.

APPLICABILITY: As shown in Table 3.3-1.

ACTION:

1 As shown in Table 3.3-1.

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SURVEILLANCE RESIIREMENTS h

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4.3.1.1 Each Reactor Trip System instrumentation channel and interlock and the automatic trip logic shall be demonstrated OPERABLE by the pe:formance of the Reactor Trip System Instrumentation Surveillance Requirements specified in Table 4.3-1.

a 4.3.1.2 The REACTOR TRIP SYSTEN RESPONSE TINE of each Reactor trip function j

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

l Neutron detectors and speed sensors are exempt from response time testing.

a 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 i

1 trains) per function such that all channels are tested at least once every N i

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

Reactor trip function as shown in the " Total No. of Channels" column of Table 3.3-1.

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MILLSTONE - UNIT 3 3/4 3-1 Amendment No. JJ. 77. 711@

j 0108 1

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1 TABLE 4.3-1 l,--

REACTOR TRIP 5Viitn INSTMBENTATION SERVEILI_"r wastNS l

TRIP ANALOG ACTUATING MODES FOR CHANNEL DEVICE WHICH g

CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REOUIRED

-A w

1.

Manual Reactor Trip

f. A.

N.A.

R(14)

N.A.

I 2, 3*, 4*,

5A 2.

Power Range Neutron Flux High setpoint S

M(C, 3, a.

D Q-N.A.

N.A.

1, 2 J

g},q, b.

Low Setpoint S

Rd S/U(1)

N.A.

1***,

2 3.

Power Range, Neutron Flux, M.A.

R(4)

Q N.A.

N.A.

1, 2 l

High Positive Rate

,1 4.

Power Ra Neutron Flux, N.A.

R(4)

Q N.A.

M.A.

1, 2 l

HighNegNNeRate w

o 5.

Intermediate Range S

R(4,5)

S/U(1)

N.A.

1***,

2 6.

Source Range, Neutron Flux S

R(4,5) 1),

M.A.

N.A.

g**,3,4, 7.

Overtemperature AT S

R

-Q N.A.

N.A.

1, 2 8.

Overpower AT S

R Q

N.A.

1, 2 g.

Pressurizer Pressure--Low S

R Q(18)

N.A.

1 e+

10. Pressurizer Pressure--High 5

R' Q(18)

N.A.

1, 2

.I

11. Pressurizer Water Level--High 5 R

Q N.A.

N.A.

1 M

12. Reactor Coolant Flow--Low S

R Q

N.A.

I M.

O l

-.------ a--.

..--.---.-a

TABLE 4.3-1 (Continued)

REACTOR TRIP SYSTEN INSTMBENTATION StRVEI a amer enms TRIP ANALOG ACTUATING MODES FOR CHANNEL DEVICE WICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE g

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REOUIRED

[

13. Steam Generator Water Level--

S R

Q(18)

N.A.

1, 2 Low-Low 14.

Low Shaft Speed - Reactor N.A.

R(13)

Q N.A.

N.A.

1 Coolant Pumps

15. Turbine Trip a.

Low Fluid Oil Pressure N.A.

R N.A.

S/U(1,10)****N.A.

I b.

Turbine Stop Valve N.A.

R N.A.

S/U(1,10)****N.A.

1 closure

,1 16.

Safety Injection Input from N.A.

N.A.

R N.A.

1, 2 t

ESF b

17. Reactor Trip System Interlocks a.

Intermediate Range Neutron Flux, P-6 N.A.

R(4)

R N.A.

N.A.

2**

l b.

Low Power Reactor Trips Block, Neutron P-7 N.A.

R(4)

R N.A.

M.A.

I Power Range c.

i Flux P-8 N.A.

R(4)

R N.A.

M.A.

1 4

d.

Power, Range Neutron Flux P-9 N.A.

R(4)

R N.A.

M.A.

1 e.

Power, Ranoe Neutron Flux P 10 N.A.

R(4)

R N.A.

N.A.

1, 2 f.

TurbineImpulseChamber Pressure, P-13 N.A.

-R R

N.A.

I

.+

=

8 o

4

TABLE 4.3-1 (Continued)

REACTOR TRIP SYSTEM Insi

_n ATION SIEtVEIILwe aranIREMS S

m TRIP ANALOG ACTUATING NODES FOR e

CHANNEL DEVICE WICH CHAMEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE-l FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED 2

18.

Reactor Trip Breaker N.A.

N.A.

N(7,11)

N.A.

2,3*,

g g

19.

Automatic Tri and N.A.

N.A.

N(7)

InterlockLog$c 1(I,2 3*,

20. Three Loop Operation N.A.

N.A.

R N.A.

1, 2 Bypass Circultry

21. Reactor Trip Bypass N.A.

N.A.

NCIS)

N.A.

I 2 4, $*3*,

Breakers Ri,16)

A

22. Shutdown Nargin Nonitor N.A.

N.A Q(19)

N.A.

3,4,5 Y

13 L

8

TABLE 4.3-1 (Continued)

TABLE NOTATIONS (Continued)

(10) Setpoint verification is not applicable.

(11) The TRIP ACTUATING DEVICE OPERATIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

(12)

(notused)

(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 Reactor Trip Function. The test shall also verify the OPERABILITY of the l

BypassBreakertripcircuit(s).

-(15) local manual shunt trip prior to placing breaker in service.

(16) Automatic undervoltage trip.

l (17)

(notused).

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

(19) Quarterly surveillance shall include verification that the Shutdown Margin Monitor is set per the CORE OPERATING LIMITS REPORT (COLR).

1 I

MILLSTONE - UNIT 3 3/4 3-14 Amendment No. JJ pp.100

=

77 77.

INSTRUNENTATION SURVEILLANCE REQUIREMENTS 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.

i 4.3.7,.2 The ENGINEERED SAFETY FEATURES RESPONSE TIME

of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months.

l 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 trains) per function such that all channels are tested at least once per N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the " Total No. of Channels" column of Table 3.3-3.

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The provisions of Specification 4.0.4 are not applicable for response time l

testing of steam line isolation for entry into MODE 4 and MODE 3 and turbine driven auxiliary feedwater pump for entry into MODE 3.

I MILLSTONE - UNIT 3 3/43-16 AmendmentNo.pp.77,pp,100

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omme l

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TABLE 4.3-2

[E ENGIIIrrarn SAFETY FEATNS ACTUATION SYSTEN INST __-~=TATION 5

SURVEILLANCE REOUIRENENTS M

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TRIP ANALOG ACTUATING MODES i

CHANNEL DEVICE MASTER SLAVE FOR WHICH E

CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEllVNCE 4 FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST JLil TEST JS_ REQUIRED w

1. Safety Injection (Reactor Trip, Feedwater Isolation Control Building Isolation Manual Initiation Only S art Diesel Generators,and)$erviceWater)

a. Manual Initiation-N.A.

N.A.

M.A.

R N.A.

N.A.

1, 2, 3, 4

b. Automatic Actuation M.A.

N.A.

N(1)

M(1)

Q 1, 2, 3, 4 w

togic and Actuation i

Relays Y

c. Containment Pressure-S R

Q N.A.

N.A.

M.A.

N.A.

1, 2, 3 M

High-1

d. Pressurizer Pressure-S R

Q N.A.

N.A.

1, 2, 3 Low

e. Steam Line S

R Q

N.A.

1, 2, 3 Pressure-Low

2. Containment Spray 3

a. Manual Initiation N.A.

N.A.

R N.A.

N.A.

1, 2, 3, 4 e+

l

b. Automatic Actuation N.A.

N.A.

N(1)

M(1)

Q 1, 2, 3, 4

.I L ic and Actuation Rgeays

c. Containent Pressure-S R

Q N.A.

N.A.

1, 2, 3, 4 y

Hiah-;

8 l

TABLE 4.3-2 (Continued) f ENRIntrarn SAFETY FEAnert ACTUATION SYSTEN ins e sATION SURVEILLANCE REGUIRDENTS l

TRIP ANALOG ACTUATING

. MODES CHANNEL DEVICE NASTER SLAVE FOR IN11CH E

CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY - SURVEILLANCE 4

FUNCTIONAL UNIT CHECK..

CALIBRATION TEST TEST LOGIC TEST II H IE H _ IS REQUIRED e.

3. Conta'insent Isolation l

a. Phase "A" Isolation

1) Manual Initiation N.A.

N.A.

R.

N.A.

N.A 1, 2, 3, 4 ]

2) Automatic Actuation N.A.

N.A.

N(1)

Q 1, 2, 3, 4 Logic and Actuation Relays

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

_l

[

b. Phase "B" Isolation u

1) Manual Initiation M.A.

N.A.

R N.A.

N.A.

M.A 1, 2, 3, 4 l

2) Automatic Actuation M.A.

N.A.

N(1)

Q 1, 2, 3, 4 Logic Actuation Relays

3) Containment S

R Q

N.A.

1, 2, 3, 4 Pressure-High-3

4. Steam Line Isolation y

a. Manual Initiation

1) Individual N.A.

N.A.

M.A.

R N.A.

N.A.

1, 2, 3, 4-j

2) System N.A.

N.A.

R N.A.

N.A.

1, 2, 3, 4 l M.

t 4

o i

i TABLE 4.3-2 (Continued) i gF.

ENGINEERED SAFETY FEATMES ACTUATION SYSTEN IllsTRINENTATI0ll SURVEILLAIICE REGUIREMENT4 l

g TRIP ANALOG ACTUATING NODES i

CHANNEL DEVICE NASTER SLAVE FOR WICH E

CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE A

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IISI IESI_ IS REQUIREQ w

4. Steam Line Isolation (Continued)

b. Automatic Actuation N.A.

N.A.

N(1)

Q 1, 2, 3, 4 d

Logic and Actuation Relays

c. Containment Pressure-S R

Q N.A.

N.A.

1, 2, 3, 4 3

High-2 ~

d. Steam Line S

R Q

N.A.

1, 2, 3 l-g Pressure-Low

)

i Y

e. Steam Line Pressure-S R

Q N.A.

M.A.

3 l

g Negative Rate-High

5. Turbine Trip and Feedwater Isolation

a. Automatic Actuation M.A.

N.A.

N.A.-

N(1)

Q 1, 2 Logic and Actuation Relays

b. Steam Generator Water S

R Q

N.A.

N(1)

Q-1, 2, 3 l

Level-High-High

c. Safety Injection N.A.

N.A.

R N.A.

.N.A.

N.A.

1, 2 l

f Actuation Logic

d. T,,, Low Coincident N.A.

R Q

N.A.

1, 2 with Reactor Trip (P-4)

M

~

8 4

TABLE 4.3-2 (Continued)

,' l

=iF ENGINEERED SAFETY FEATL915 ACTUATION 5Vuen INSTEL"NTATION t

5 SURVEILLAflCE REGUIREMENTS l

TRIP ANALOG ACTUATING MODES g

CHANNEL DEVICE NASTER SLAVE FOR WHICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE i

[

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IfJI IISL IS REQUIRED

6. Auxiliary Feedwater 1

a. Manual Initiation M.A.

N.A.

R N.A.

N.A.

1, 2, 3

b. Automatic Actuation M.A.

N.A N.A.

N.A.

N(1)

Q 1, 2, 3 and Actuation Relays

c. Steam Generator Water S

R Q

N.A.

1, 2, 3 l

Level-Low-Low

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

u g

e. 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) 7.

Control Building Isolation

a. Manual Actuation N.A.

N.A.

R N.A.

N.A.

~N.A.

All l

b. Manual Safety N.A.

N.A.

R N.A.

M.A.

N.A.

1,2,3,4l

Injection Actuation F

c. Automatic Actuation N.A.

N.A.

N(1)

Q 1, 2, 3, 4 Lgic and Actuation g

Relays

d. Containment Pressure--

S R

Q N.A.

N.A.

1, 2, 3 3

High-1

=

O

-w r

TABLE 4.3-2 (Continued) f ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRINENTATION

$URVEILLANCE REGUIREMENT$

i l

TRIP l

ANALOG ACTUATING MODES CHANNEL DEVICE NASTER SLAVE FOR IfHICH E

CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE 4 FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST J.ESI IESI_ IS REQUIREQ u

7. Control Building Isolation (Continued)

e. Control Buildig Inlet S

R Q

N.A.

All Ventilation Radiation

8. Loss of Power

a. 4 kV Bus N.A.

R N.A N(3)

N.A.

M.A.

1, 2, 3, 4 Undervoltage (Loss, of Voltage)

)

b. 4 kV Bus N.A.

R N.A.

N(3)

N.A.

M.A.

1, 2, 3, 4 Undervoltage (Grid Degraded Voltage)

.8

9. Engineered Safety Features Actuation 4

System Interlocks

a. Pressurizer N.A.

R Q

N.A.

1, 2, 3 l

Pressure, P-Il P-32 N.A.

R Q

N. A.'

N.A.

M.A.

N.A.

1, 2, 3

b. Low-LowT,h,,P-4

c. Reactor Tr N.A.

N.A.

R N.A.

N.A.

-N.A.

1, 2, 3 l

10. Emerg ncy Generator N.A.

N.A.

Q(1,2)

N.A.

.1, 2, 3, 4 g

Load Sequencer k

i

=

~

I t

i TABLE 4.3-2 (Continued) i i

TABLE NOTATION (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 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 alam relays will be performed as part of the channel calibration required once per 18 months.

4 NILLSTONE - WIT 3 3/43-41 Amendment No. JJ 7J. 77, 100 one I

TABLE 4.3-3 g:s

~

RADIATION NOMITORING INSTRMENTATION FOR PLANT 5

OPERATIONS 3GM EILLANCE REOUIRENENTS ANALOG e

CHANNEL N00ES FOR WHICH g

CHANNEL CHANNEL OPERATIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST IS REQUIRED

-4 1.

Containment a.

Containment Area Purge and Exhaust isolation S

R Q

5, 6 I

b.

RCS Leakage Detection I) Particulate Radio-S R

Q I, 2, 3, 4 activity y

,)

2) Gaseous Radioactivity S

R Q

I, 2, 3, 4 l

2.

Fuel Storage Pool Area Monitors a.

Radiation Level S

R Q

I TABLE NOTATIONS With fuel in the fuel storage pool area.

.+

M 8

3 i

TABLE 4.3-4 SEISMIC MONITORING INSTRUNENTATION SURVEILLANCE REQUIREMENTS i

1 j

ANALOG CHANNEL CHANNEL CHANNEL OPERATIONAL i

IhSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST 1.

Triaxial Time-History Accelerographs e

a. NBE20A M

R SA Containment Mat (-24'3')

i is. NBE208 M

R SA i

Containment Wall (40'6")

I

c. NBE21 M

R SA Emer. Generator Enclosure Located on Mat in Diesel Fuel Oil Vault (4'6")

d. NBE22 M-R SA i

Aux. Bldg. F-Line Wall Near The

]

Charging Pumps tooling Surge Tank (46'6) 2.

Triaxial Peak Accelerographs

a. P/A1 N.A.

R N.A.

j Containment Safety Injection j

Accum. Tank (-4'7")

i

b. P/A2 N.A.

R N.A.

j Safety Injection Accum. Disch, j

Line (-22'10")

c. P/A3 N.A.

R N.A.

l Aux. Bldg. Charging Pumps i

Cooling Surge Tank (46'6')

3a.

Triaxial Seismic Trigger Horizontal M

R SA (Control Room)

Vertical M

R SA (Control Room) 3b.

Triaxial Seismic Switch Horizontal M

R SA j

(Control Room) i Vertical M

R SA (Control Room) 4.

Triaxial Response-Spectrum Recorders

a. RSA-50 Spectrum Analyzer M

R SA (Control Roon)

b. Self-Contained Recorder N.A.

R N.A.

l Steam Generator Support (51'4")

4 d

i MILLSTONE - UNIT 3 3/43-49 Amendment No. 77 1 %

m 1

IH3IFWENTATION j

RDj91(,JjftjiDOWN INSTRUNENTATION LIMITINil C00E)ITION FOR OPERATION 3.3.3.5 The Remote Shutdown Instrumentation transfer switches, power, i

controls and monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE.

4 APPLICABILITY: MODES 1, 2, and 3.

1 ACTION:

i a.

With the number of OPERABLE remote shutdown monitoring channels less than the Minimum Channels OPERABLE as required by Table 3.3-9, j

restore the inoperable channel (s) to OPERABLE status within 7 days, l

or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b.

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

switch (s)/ circuit (s) 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 .

c.

Entry into an OPERATIONAL MODE is permitted while subject to these j

ACTION requirements.

1 l

SURVEILLANCE REQUIRENENT3 i

4.3.3.5.1 Each remote shutdown monitoring instrumentation channel shall be i

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 i

control circuit including the actuated components, shall be demonstrated j

OPERABLE at least once per 18 months.

I i

i i

j i

i N!LLSTONE - UNIT 3 3/4 3-53 Amendment No. J7, 77, 100 2

ous 1

TABLE 4.3-6 REMOTE SHimMMI MONITORINE INSTRUNENTATI0fl i

5

$URVEILLANCE RE0UIREMENTS CHANNEL CHANNEL e

INSTRUMENT CHECK CALIBRATION Eq 1.

Reactor Trip Breaker Indication M

N.A.

w 2.

Pressurizer Pressure M

R 3.

Pressurizer Level M

R l

4.

Steam Genernor Pressure M

R 5.

Steam Generator Water Level M

R 6.

Auxiliary Feedwater Flow Rate M

R-7.

Loop Hot Leg Temperature M

R 8.

Loop Cold Leg Temperature M

R I

R, 9.

Reactor Coolant System Pressure M

R e

(Wide Range) h

10. DWST Level M

R~

11.

RWST Level M

R

12. Containmant Pressure M

R 13.

Emergency Bus Voltmeters M

R

14. Source Range Count Rate M*

R 15.

Intermediate Range Amps M

R 16.

Boric Acid Tank Level M

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

i

=.

.n

TABLE 4.3-7 gm 8%

ACCIDENT MONITORING INSTIMIENTATION SURVEILLANGE REGUIRDENTS M

e CHANNEL CHANNEL m

INSTRUMENT CHECK CALIBRATION 1.

Containment Pressure

.E a.

Normal Range M

R b.

Extended Range M

R i

u 2.

Reactor Coolant Outlet Temperature - Ter (Wide Range)

M R

3.

Reactor Coolant Inlet Temperature - Tm (Wide Range)

M R

4.

Reactor Coolant Pressure - Wide Range M

R 5.

Pressurizer Water Level M

R

{

6.

Steam Line Pressure M

R 7.

Steam Generator Water level - Narrow Range M

R 8.

Steam Generator Water Level - Wide Range M

R 9.

Refueling Water Storage Tank Water Level M

R 10.

Demineralized Water Storage Tank Water Level M

R 11.

Auxiliary Feedwater Flow Rate M

R 12.

Reactor Coolant System Subcooling Margin Monitor M

R E,

13.

Containment Water Level (Wide Range)

M R

,5 14.

Core Exit Thermocouples M

R 15.

DELETED 4

o

________.___m...-..__._

TABLE 4.3-7 (Continued) h ACCIDDIT N0NITORING INSTRINEDITATION SURVEILLME RFGi_l]RDl GIT $

G

-4 E

m CHANNEL CHANNEL INSTRUMENT g

CHECK CALIBRATION 16.

Containment Area - High Range Radiation Monitor M

R*

l 17.

Reactor Vessel Water Level M

R**

18.

Containment Hydrogen Monitor M

R 19.

Neutron Flux M

R e

h

CHANNEL CALIBRATION may consist of an electronic calibration of the channel, not including the detector, for range decades above 10 R/h and a one point calibration check of the detector below 10 R/h with an

'i installed or portable gamma source.

- Electronic calibration from the ICC cabinets only.

l

.E 8

1

O INSTRUNENTATION LO0SE-PART DETECTION SYSTEN LIMITING COMITION FOR OPERATION 3.3.3.8 The Loose-Part Detection System shall be OPERABLE.

APPLICABILITY: NODES 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," are not applicable.

SURVEILUUICE 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.

l MILLSTONE - W IT 3 3/43-68 Amendment No. 77,77,100 asas

E ET0R C00LANT SYSTEN 3/4.4.3 PRESSURIZER LIMITING CO M ITION FOR OPERATION 3.4.3 The pressurizer shall be OPERABLE with a water volume of less than or equal to 92f, (1656 cubic faet), 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:

a.

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

i 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 H0T l

SHUTDOWN within the fo11owing.6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.4.3.1 The pressurizer water volume 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 .

4.4.3.2 The capacity of each of the above required groups of pressurizer heaters supplied by emergency power shall be verified by energizing the heaters and measuring circuit current at least once each refueling interval.

l i

i N

3/4 4-11 Amendment No. 100 jLST0FE-WIT 3

~

REACTOR C0OLANT SYSTEM STEAN GENERATORS SURVEILLANCE REQUIREMENTS (Continued)

~

4.4.5.3 Insnection Freauencies - The above required inservice inspections of steam generator tubes shall be performed at the following frequencies:

a.

Inservice inspections shall be performed at intervals of not less than

.12 nor more than 24 calendar months after the previous inspection.

If l

two consecutive inspections, not including the preservice inspection, result in all inspection results falling 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 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 4)

A main steam line or feedwater line t,reak.

l NILLSTONE - UNIT 3 3/44-16 Amendment No.

7 0348

REACTOR C0OLANT SYSTEN 3/4.4.6 REACTOR C00LANT SYSTEN LEAKAGE LEAKAGE DETECTION SYSTEMS LIMITING C0WITION 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 bm the Co7tainment Atmosphere Gaseous and Particulate Radioastivity Monitors IN0PERABLE, 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 ; 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 .

b.

With the Containment Drain Sump Level or Pumped Capacity Monitoring System INOPERABLE, operation may continue for up to 30 days provided either the Containment Atmosphere Gaseous or Particulate l

Radioactivity Monitoring System is OPERABLE; 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 followng 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 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 System-performance of CHANNEL CALIBRATION at least once per 18 months.

i MILLSTONE - WIT 3 3/44-21 Amendment No. 17,77,100 0240 l

REACTOR C0OLANT SYSTEN j

OPERATIONAL LEAKAGE l

SURVEILLANCE REQUIREMENTS i

4.4.6.2.1 Reactor Coolant System leakages shall be demonstrated to be within i

each of the above limits by:

l 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 ; 1

b.

Monitoring the containment drain sump inventory and discharge at 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 I

least once per 31 days with the modulating valve fully open. The i

provisions of Specification 4.0.4 are not applicable for entry into l

MODE 3 or 4; d.

Performance of a Reactor Coolant System water inventory balance at i

least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; and 1

]

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 .

i 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 18 months, b.

Prior to entering MODE 2 whenever the plant has been in COLD i

SHUTDOWN for 7 days or more and if leakage testing has not been l

j performed in the previous 9 months, c.

Prior to returning the valve to service following maintenance, 4

repair or replacement work on the valve, 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 IWV-3427(b).

l The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 1

{

or 4.

l

\\

i NILLSTONE - UNIT 3 3/44-23 Amendment No.100 i

,-q----

em w

l i

REACTOR COOLANT SYSTEN I

. i 0VERPRES$URE PROTECTION SYSTEN l

LINITING COMITION FOR OPERATION ACTION (Continued) i e.

In the event the PORVs, the RHR suction relief valves, or the RCS i

vent (s) are used to mitigate an RCS pressure transient, a Special Report shall be prepared and submitted to the Commission pursuant to i

Specification 6.9.2 within 30 days. The report shall describe the j

circumstances initiating the transient, the effect of the PORVs, the RHR suction relief valves, or RCS vent (s) on the transient, and any i

j corrective action necessary to prevent recurrence.

1 f.

Entry into an OPERATIONAL MODE is permitted while subject to these i

ACTION requirements.

SURVEILLANCE REQUIREMENTS i

4.4.9.3.1 Each PORV shall be demonstrated OPERABLE by:

k a.

Performance of an ANALOG CHANNEL OPERATIONAL TEST on the PORV i

actuation channel, but excluding valve operation, within 31 days prior to entering a condition in which the PORV is required OPERABLE 1

and at least once per 31 days thereafter when the PORV is required j

OPERABLE; b.

Performance of a CHANNEL CALIBRATION on the PORV actuation channel i

at least once per 18 months; and l

1 l

Verifying the PORV isolation valve is open at least once per c.

j 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.

]

J 4

4.4.9.3.2 Each RHR suction relief valve shall be demonstrated OPERABLE when i

the RHR suction relief valves are being used for cold overpressure protection as follows:

i a.

For RHR suction relief valve 3RHS*RV8708A, by verifying at least j

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; 1

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*MV8702B and 3RHS*MV8702C are open; and I

j c.

Testing pursuant to Specification 4.0.5.

i i

)

MILLSTONE - UNIT 3 3/4 4-39 Amendment No. N, M,100 8351 I

e e

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

,,v--

--r,

REACTOR COOLANT SYSTEN 3/4.4.11 REACTOR C0OLANT SYSTEN VENTS LIMITING C0WITION FOR OPERATION 3.4.11 At.least one Reactor Coolant System vent path consisting of two parallel trains with two valves inseries powered from emergency busses shall be OPERABLE and the vent closed

at each of the following locations:

a.

Reactor vessel head, and b.

Pressurizer steam space.

APPLICABILITY: N00ES 1, 2, 3, and 4.

ACTION:

a.

With one train of the reactor vessel head vent path inoperable, 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 inoperable in NODES 1, 2, or 3, follow the ACTION requirements of Specification 3.4.4.

d.

With any valve (s) of the pressurizer steam space vent path inoperable in N00E 4, follow the ACTION requirements of j

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 at least once per COLD SHUTDOWN, if not performed within the previous 92 days, by operating the valve through one complete cycle of full travel from the control room.

For an OPERABLE vent path using a power-operated relief valve (PORV) as the vent path, the PORV block valve is not required to be closed.

NILLSTONE - LBlIT 3 3/44-43 Amendment No. 5,100

.ma

. 3/4.5 DIEnn0CY CORE C00LIIIS SYSTEMS 3/4.5.1 ACCUNULATORS i

LIMITING C0WITION FOR OPERATION 3.5.1 Each Reactor Coolant System (RCS) accumulator shall be OPERABLE with:

a.

The isolation valve open and power removed, b.

A contained borated water volume of between 6618 and 7030 gallons, c.

A boron concentration of between 2600 and 2900 ppe, and d.

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

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 immediately 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 REQUIREMENTS 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:

1)

Verifying that the contained borated water volume and nitrogen cover-pressure in the tanks are within their limits, and 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 volume increase of greater than or equal to 1% of tank volume by verifying the boron concentration of the accumulator solution.

This surveillance is not required when the volume increase makeup source is the RWST.

I l

Pressurizer pressure above 1000 psig.

MILLSTONE - INIIT 3 3/4 6-1 Amendment No. JJ, pf, pp. 100 een

l.

s ENERGENCY C0RE COOLING SYSTEMS SURVEILLANCE RE511REMENTS (Continued) l t

At least once per 31 days when the RCS pressure is above 1000 psig c.

by verifying that power to the isolation valve operator is discon-1 i

nected by removal of the breaker from the circuit.

I i

4 i

4 1

4 4

1 i

I i

i 4

}

i MILLSTONE - IMIT 3 3/4 6-2 Amendment No. 100 om i

i

i'

EMERGENCY CORE C0OLING SYSTEMS l

SURVEILLANCE REQUIRENENTS i

l 4.5.2 Each ECCS subsystem 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 verifying that the following valves are in the indicated positions with power to the valve sperators j

removed:

}

Valve Nughgt Valve Function W h Pasition l

3SIH*MV8806 RWST Supply to SI Pumps OPEN j

3SIH*MV8802A SI Pump A to Hot Leg Injection CLOSED 3SIH*MV8802B SI. Pump B to Hot Leg Injection-CLOSED 3SIH*MV8835 SI Cold Leg Master Isolation OPEN 3SIH*MV8813 SI Pump Master Miniflow OPEN Isolation 3SIL*MV8840 RHR to Hot Leg Injection CLOSED j

3SIL*MV8809A RHR Pump A to Cold Leg OPEN i

Injection

[

3SIL*MV8809B RHR Pump B to Cold Leg OPEN Injection i

1 j

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 j

points, and 2)

Verifying that each valve (manual, power-operated, or j

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

otherwise secured in position, is in its correct position.

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

trash, clothing, etc.

is present in the containment which could be transported to the con)tainment sump and cause restriction of the i

pump suctions during LOCA conditions. This visual inspection shall J

be performed:

1)

For all accessible areas of the containment prior to establish-ing CONTAIMENT INTEGRITY, and i

2)

At least once daily of the areas affected (during each day)

I within containment by containment entry and during the final j

entry when CONTAI M ENT INTEGRITY is established.

j d.

At least once per 18 months by:

l 1

j 1)

Verifying automatic interlock action of the RHR System from the i

Reactor Coolant System by ensuring that with a simulated or actual Reactor Coolant System pressure signal greater than or 1

equal to 390 psia the interlocks prevent the valves from being j

opened.

1 i

j NILLSTONE - UNIT 3 3/4 5-4 Amendment No. pp. 77,100 i

ease i

4

3 t

1 j

CONTAllglENT SYSTPts l

SURVEILLANCE REQUIRENENTS (Continued)

~

J i

l l

c.

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

i 1

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 1

superimposed leak L., is equal to or less than 0.25 L ;

1-l 2)

Has a duration sufficient to establish accurately the change in i

leakage rate between the Type A test and the supplemental test; aM i

j 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 8 and C tests shall be conducted with gas at P., 53.27 psia j

(38.57 psig), 'at intervals no greater than 24 months except for l

tests involving:

4

{

1)

Air locks 4'

e.

The combined bypass leakage rate shall be determined to be less than or equal to 0.042 L, by applicable Type 8 and C tests at least once per 24 months except for penetration; which are not individually l

testable; penetrations not individua17y testable shall be determined j

to have no detectable leakage when iested with soap bubbles while j

the containment is pressurized to P., 33.27 psig (38.57 psig),

4 during each Type A test; i

l f.

Air locks shall be tested and demonstrated OPERABLE by the j

requirements of Specification 4.6.1.3; a

g.

Purge supply and exhaust isolation valves shall be demonstrated OPERABLE by the requirements of Specifications 4.6.3.2.c and 4.g.g.

i h.

The provisions of Specification 4.0.2 are not applicable.

i i

j-NILLSTONE - L511T 3 3/4 6-3 Amendment No. pp. 7J,100 esas

l C0KTAlf81ENT SYSTEMS 3/4.6.2 DEPRES$URIZATION AfD COOLING SYSTEMS l

CONTAlletENT GUENCH SPRAY SYSTEM i

LIMITING C0051 TION FOR OPERATION 3.6.2.1 Two independent Containment Quench Spray subsystems shall be OPERABLE.

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

ACTION:

With one Containment Quench Spray subsystem 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 and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.6.2.1 Each Containment Quench Spray subsystem shall be demonstrated OPERABLE:

a.

At least once per 31 days:

1)

Verifying that each valve (manual, power operated, or automatic) in the flow path is not locked, sealed, or otherwise secured in position, is in its correct position; and 2)

Verifying the temperature of the borated water in the refueling water storage tank is between 40*F and 50*F.

b.

By verifying, that on recirculation flow each pump develops a differential pressure of greater than or, equal to 114 psid when tested pursuant to Specification 4.0.5; At least once per 18 months during shutdown, by:

c.

1)

Verifying that each automatic valve in the flow path actuates to its correct position on a CDA test signal, and 2)

Verifying that each spray pump starts automatically on a CDA test signal.

d.

At least once per 10 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

NgLSTONE - LNt!T 3 3/4 6-12 AmendmentNo.J,pfl.00 l

(e CONTAllMENT SYSTEMS RECIRCULATION SPRAY SYSTEM i

LIMITING C0fGITION FOR OPERATION

{

3.6.2.2 Two independent Recirculation Spray Systems shall be OPERABLE.

J 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 REQUIREMENTS 4.6.2.2 Each Recirculation Spray System shall be demonstrated OPERABLE:

At least once per 31 days by verifying that each valve (manual, a.

power-operated, or automatic) in the flow path is not locked, sealed, or otherwise secured in position, is in its correct i

position; b.

By verifying, that on recirculation flow, each pump develops a differential pressure of greater than or equal to 130 psid when tested pursuant to Specification 4.0.5; At least once par 18 months by verifying that on a CDA test signal, c.

each r'ecirculation spray pump starts automatically after a 660 120 second delay; d.

At least once per 18 months during shutdown, by verifying that each automatic valve in the flow path actuates to its correct position on 1

a CDA test signal; and At least once per 10 years by performin; o air or smoke flow test j

e.

through each spray header and verif-each spray nozzle is j

unobstructed.

i NILLSTONE - IMIT 3 3/4 6-13 Amendment No. JP,100 ease

1 1

i i

CONTAlfflENT SYSTEMS l

i 3/4.8.4 ColBUSTIBLE GAS CONTROL i

)

j NYDR0 GEN NONITOR$

i.

j LIMITING C0WITION FOR OPERATION 3.6.4.1 Two independent containment hydrogen monitors shall be OPERABLE.

i APPLICABILITY: N0 DES 1, 2, and 3.

i

&CIlg:

1 a.

With one hydrogen monitor inoperable, restore the inoperable monitor I-to OPERABLE status within 30 days or be in at least HOT STANDBY within 3

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

hours.

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 '

i within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the j

following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

i c.

Entry into an OPERATIONAL N00E is permitted while subject to these l

ACTION requirements.

j SURVEILLANCE REQUIREMENTS i

)

4.6.4.1 Each hydrogen monitor shall be demonstrated OPERABLE by the performance of a CHANNEL CHECK at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an ANALOG CHANNEL OPERATIONAL TEST i

at least once per 92 days, and at least once each refueling interval by l

j performing a CHANNEL CALIBRATION using sample gas containing:

1 f'

One volume percent hydrogen, balance nitrogen, and a.

b.

Four volume percent hydrogen, balance nitrogen.

)

I e

i i

4 i

NILLSTONE - WIT 3 3/46-16 Amendment No. E, U, 3go 0357 i

4

i I

j CONTAlfetENT SYSTEMS

}

ELECTRIC HYDR 0 GEN REC 0MBINERS LIMITING ColWITION FOR OPERATION I

i l

3.6.4.2 Two independent Hydrogen Recombiner Systems shall be OPERABLE.

{

APPLICABILITY: MODES I and 2.

i 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 j

next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 j

SURVEILLANCE REQUIREMENTS 4.6.4.2 Each Hydrogen Recombiner System shall be demonstrated OPERABLE at least once each refueling interval by:

a.

Verifying during a Hydrogen Recombiner System functional test that the l

l minimum reaction chamber gas temperature increases to greater than or equal to 700*F within 90 minutes and is maintained for at least 2 j

hours and that the purge blower operates for 15 minutes.

b.

Performing a CHANNEL CALIBRATION of all recombinor instrumentation and c

control circuits, c.

Verifying through a visual examination that there is no evidence of abnormal conditions within the recombiner enclosure (i.e.,

loosc j

wiring or structural connections, depositt cf foreign materials, etc.),

d.

Verifying the integrity of all heater electrical circuits by j

performing a resistance to ground test following the above required j

functional test. The resistance to ground for any heater phase shall j

be greater than 10,000 ohns, and 4

l e.

Verifying during a recombiner system functional test using containment atmospheric air at an acceptable flow rate as determined in Section J

4.6.4.2.f that the gas temperature 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 and is maintained for at least 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

f.

Verifying during a recombiner system functional test using containment l

j atmospheric air that the blower would be capable of delivering at least 41.52 scfm at containment conditions of 12.47 psia and 130*F.

a l

1 MILLSTONE - UNIT 3 3/4 6-17 Amendment No. R. M,100 s

0257 9

d

CONTAllglENT SYSTEMS 3/4.6.5

$UBATN0 SPHERIC PRESSURE CONTROL SYSTElf STEAN JET AIR EJECTOR LIMITING C05ITION FOR OPERATION 3.6.5.1 The inside and outside isolation valves in the steam jet air ejector suction line shall be closed.

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

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 I hour 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 REQUIREMENTS 4.6.5.1.1 The steam jet air ejector suction line outside isolation valve shall 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 least once per 31 days thereafter.

4.6.5.1.2 The staan jet air ejector suction line inside isolation valve shall be detemined to be locked in the closed position by a visual inspection prior to increasing the Reactor Coolant System temperature above 200*F.

1 l

l MILLSTONE - WIT 3 3/4 6-18 Amendment No.100 l

0257

l l

CONTAllglENT SYSTEMS i

i 3/4.6.6 SEC01BARY CONTAllOIENT SUPPLEMENTARY LEAK COLLECTION Als RELEASE SYSTEN LIMITIIIB ColWITION FOR OPERATION l

3.6.6.1 Two independent Supplementary Leak Collection and-Release Systems shall be OPERABLE with each system comprised of:

4 a.

one OPERABLE filter and fan, and i

b.

one OPERABLE Auxiliary Building Filter System as defined in l

Specification 3.7.9.

APPLICABILITY: N0 DES 1, 2, 3, and 4.

ACIIM:

l With one Supplementary Leak Collection and Release System inoperable, restore j

the inoperable system to OPERABLE status within 7 days or be in at least HOT j

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 REQUIREMENTS i

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

t i

At least once per 31 days on a STAGGERED TEST BASIS by initiating, a.

?

from the control room, flow through the HEPA filters and charcoal adsorbers and verifying a system flow rate of 7600 cfm to 9800 cfm and that t h system operates for at least 10 continuous hours with the heaters operating.

4 l

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-j cating with the system by:

l 1)

Verifying that the system satisfies the in-place penetration 1

and bypass leakage testing acceptance criteria of less than 1

0.057, and uses the test procedure guidance in Regulatory Posi-j tions C.5.a. C.S.c, and C.5.d of Regulatory Guide 1.52, Revi-1 sion 2, March 1978,* and the system flow rate is 7600 cfm to j

9800 cfa; l

i NILLSTONE - int!T 3 3/4 6-19 Amendment flo. 3, p, 77, i

100 l

l

-~_

1 l

e.

1 CONTAllglENT SYSTEMS

. SURVEILLANCE REQUIREMENTS (Continued) i i

2)

Verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accord-j ance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2 March 1978,* meets the laboratory testing criteria 4

1 of Regulatory Position C.6.a of Regulatory Guide 1.52, Revi-i sion 2, March 1978,* for a methyl iodide penetration of less j

than 0.175%; and i

i 3)

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

After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation, by verifying, c.

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 j

of Regulatory Guide 1.52, Revision 2, March 1978,* for a methyl iodide penetration of less than 0.175%:

?

j d.

At least once per 18 months by:

i 1)

Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6.25 inches Water Gauge while operating the system at a flow rate of 7600 cfm to 9800 cfs, l

2)

Verifying that the system starts on a Safety Injection test i

signal,

)

3)

Verifying that each system produces a negative pressure of l

greater.than or equal ts 0.4. inch Water Gauge in the Auxiliary j

Building at 24'6" elevation within 120 seconds after a start j

signal, and j

4)

Verifying that the heaters dissipate 5015 kW when i.asted in j

accordance with ANSI N510-1980.

2 i

1 i

i i

l

ANSI H510-1980 shall be used in place of ANSI N510-1975 referenced in i

Regulatory Guide 1.52, Revision 2, March 1978.

i 4

NILLSTONE - WIT 3 3/4 6-20 AmenhentNo.f(f0

' N' j

0357 1

_,__m

j n

j CONTAIMIENT SYSTEMS

$URVEILLANCE REQUIREMENTS (Continued) l

)

e.

After each complete or partial replacement of a HEPA filter bank, by i

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 cfm; and

}

f.

After each complete or partial replacement of a charcoal adsorber i

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 cfE to 9800 cfs.

j i

4 1

l l

1 i

i i

j i

h i.

NILLSTONE - LMIT 3 3/4 6-21 Amendment No. J U, 77, W87 100 m

CONTAll0 LENT SYSTEMS SEC0fGARY CONTAIf91ENT B00feARY LINITING C0fGITION FOR OPERATION 3.6.6.2 SECONDARY CONTAINNENT BOUNDARY shall be maintained.

APPLICABILITY: NODES I, 2, 3, and 4.

ACTION:

Without SECONDARY CONTAIMENT B0UNDARY, restore SECONDARY CONTAIMENT 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 .

SURVEILLANCE REQUIRENENT 4.6.6.2 SECONDARY CONTAINNENT 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.

NILLSTONE - UNIT 3 3/4 6-22 Amendment No. 77 100

CONAIMENT SYSTEMS SEC00BARY CONTAllglENT B0WBARY STRUCTURAL INTEGRITY LIMITING ColWITION FOR OPERATION 3.6.6.3 The structural integrity of the SECONDARY CONTAIMENT BOUNDARY shall be maintained at a level consistent with the acceptance criteria in Specification 4.6.6.3.

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

EIl0ll:

With the structural integrity of the SECONDARY CONTAINNENT 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 SHUTDOM 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 CONTAIMENT B0UNDARY shall be determined during the shutdown for each Type A containment leakage' rate test (reference Specification 4.6.1.2) by a visual inspection of the exposed accessible interior and exterior surfaces of the SECONDARY CONTAI MENT BOUNDARY and verifying no apparent changes in appearance of the concrete surfaces or other abnormal degradation. Any abnormal degradation of the SECONDARY CONTAIMENT BOUNDARY detected during the above required inspections shall be reported to the Cennission in a Special Report pursuant to Specification 6.9.2 within 15 days.

4 i

NILLSTONE - MIT 3 3/46-13 Amendment No. 77 100 i

PLANT SYSTEMS AUXILISY FEEDWATER SYSTEM I

LIMITING COM ITION FOR OPERATION l

l 3

3.7.1.2 At least three independent steam generator auxiliary feedwater j

pumps and associated flow paths shall be OPERABLE with:

I Two motor-driven auxiliary feedwater pumps, each capable of being a.

l powered from separate emergency busses, and b.

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

.I 1

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

}

a.

With one auxiliary feedwater pump inoperable, restore the required 4

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

1 l

b.

With two auxiliary feedwater pumps inoperable, be in at least H0T 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 .

j c.

With three auxiliary feedwater pumps inoperable, immediately 4

initiate corrective action to restore at least one auxiliary i

feedwater pump to OPERABLE status as soon as possible. Entry into an OPERATIONAL N0DE pursuant to Specification 3.0.4 is not permitted with three auxiliary feedwater pumps inoperable.

]e SURVEILLANCE REQUIREMENTS I

l 1

4.7.1.2.1 Each auxiliary feedwater pump shall be demonstrated OPERABLE:

I a.

At least once per 31 days by:

1)

Verifying that each non-automatic valve in the flow path that i

j is not locked, sealed, or otherwise secured in position is in i

Its correct position; and 2)

Verifying that each auxiliary feedwater control and isolation l

valve in the flow path is in the fully open position when j

above 10% RATED THERMAL POWER.

i j

MILLSTONE - UNIT 3 3/4 7-4 AMEE MENT N0. R.100 i

1

i b

=

\\

l PLANT SYSTEMS 1

j-SURVEILLANCE REQUIREMENTS (Continued) i i

l b.

At least once per 92 days on a STAGGERED TEST BASIS by:

l 1)

Verifying that each non-automatic valve in the flow path that l

is not locked, sealed, or otherwise secured in position is in its correct position; and l

2)

Verifying that each auxiliary feedwater control and isolation l

j valve in the flow path is in the fully open position when above 10% RATED THERNAL POWER.

3 l

1 c.

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

l auxiliary feedwater pump starts as designed automatically upon i

receipt of an Auxiliary Feedwater Actuation test signal.

For the steam turbine-driven auxiliary feedwater pump, the provisions of j

Specification 4.0.4 are not applicable for entry into NODE 3.

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

l 1i i

i 4

b

]

N!LLSTONE - UNIT 3 3/4 7-5 Amendment No. JJ.100 0264

e i

PLANT SYSTEMS j

SURVEILLANCE REQUIREMENTS (Continued) type that may be generically susceptible; and (2) the affected snubber is functionally tested in the as-found condition and determined OPERABLE per Specification 4.7.10.f. All snubbers found connected to an inoperable common hydraulic fluid reservoir shall be counted as unacceptable for determining the next inspection i

interval. A review and evaluation shall be performed and documented to justify continued operation with an unacceptable snubber.

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

l d.

Transient Event Inspection l

An inspection shall be performed of all snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a review of operational data and a visual inspection of the systems within 6 months following such an event.

In addition to satisfying the visual inspection 2

acceptance criteria, freedom-of-motion of mechanical snubbers shall j

be verified using at least one of the following:

(1) manually 1

induced snubber movement; or (2) evaluation of in-place snubber i

piston setting; or (3) stroking the mechanical snubber through its full range of travel.

e.

functional Tests l

During the first refueling shutdown and at least once per 18 months l

thereafter during shutdown, a representative sample of snubbers of each type shall be tested using one of the following sample plans.

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

The NRC i'

Regional Administrator shall be notified in writing of the sample plan selected for each snubber type prior to the test period or the sample plan used in the prior test period shall be implemented:

1)

At lent IGE of th:: total of each type of snubber shall be functionally tested either in-place or in a bench test.

For i

each snubber of a type that does not meet the functional test acceptance criteria of Specification 4.7.10f., an additional 5%

l of that type of snubber shall be functionally tested until no j;

more failures are found or until all snubbers of that type have been functionally tested; or I

MILLSTONE - UNIT 3 3/4 7-23 Amendment JJ, 77,100 i

em 1

4

1 i

r TABLE 4.7-2 i

SNUBBER VISUAL INSPECTION INTERVAL a-l NUMBER OF UNACCEPTABLE SNUB 8ERS Population Column A Column B Column C or Category Extend Interval Repeat Interval Reduce Interval (Notes 1 and 2)

(Notes 3 and 6)

(Notes 4 and 6)

(Notes 5 and 6) 1 0

0 1

M 0

0 2

{

100 0

1 4

i 150 0

3 8

1 200 2

5 13 i

300 5

12 25 400 8

18 36-500 12 24 48 750 20 40 78.

1000 or greater 29 56 10g i

Note 1:

The next visual inspection interval for a snubber population or j

category size shall be determined based upon the previous inspection interval and the number of unacceptable snubbers found during that a

j interval.

Snubbers may be categorized, based upon their l

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 1

inspection and shall use that decision as the basis upon which to detemine the next inspection interval for that category.

l Note 2:

Interpolation between population or category sizes and the number of f

unacceptable snubbers is armissible.

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 detemined 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 i

previous interval but no greater than 48 months.

a j

Note 4:

If the number of unacceptable snubbers is equal to or less than the t

number in Column B but greater than the number in Column A, the next inspection interval shall be the same as the previous interval.

L I

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 i

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 t

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 j

difference in the numbers in Columns B and C.

00 l

NILLSTONE - W IT 3 3/47-17 Amendment No. E,1 om

]'

TABLE 4.7-2 SNUBBER VISUAL INSPECTION INTERVAL Note 6:

The provisions of Specification 4.0.2 are applicable for all inspection intervals up to and including 48 months.

I i

i NILLSTONE - LNtIT 3 3/4 7-28 hdment No. g,100 mi i

1 i

i ii i

10 b

s l

8 i

i i

i 7

)

1 i

6 i

4 C

6 1

)

CONTINUE

[

l1 3

TESTING l

i i

2 1

i i

ACCEPT 1

r

}

0 10 20 30 40 60 60 70 to 90 100 1

N i

i FIGURE 4.7-1 i

SAMPLE PLAN 2) FOR SNUBBER FUNCTIONAL TEST J

I

)

i MILLSTONE - UNIT 3 3/4 7-29 Amendment No, y,100 i

em i

i

3 l

]

PLANT SYSTEMS 1

j 3/4.7.11 SEALED SN M E CONTANINATION 1

1 LIMITING ColeITION FOR OPERATION 3.7.11 Each sealed source containing radioactive material either in excess of j

100 microcuries of beta and/or gama emitting material or 5 microcuries of alpha emitting material shall be free of greater than or equal to 1

0.005 microcurie of removable contamination.

APPLICABILITY: At all times.

I j

Ellati:

j a.

With a sealed source having removable contamination in excess of the j

above limits, immediately withdraw the sealed source from use and either:

i 1.

Decontaminate and repair the sealed source, or j

2.

Dispose of the sealed source in accordance with Commission j

Regulations.

l b.

The provisions of Specification 3.0.3 are not applicable.

b SURVEILLANCE REQUIREMENTS l

4.7.11.1 Test Requirements - Each sealed source shall be tested for leakage and/or contamination by:

i j

a.

The licensee, or 1

i b.

Other persons specifically authorized by the Connission or an j

Agreement State.

1 i

The test method shall have a detection sensitivity of at least 0.005 j

microcurie per test sample.

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

3 a.

Sources in use - At least once per 6 months for all sealed sources l

containing radioactive materials:

4 1

1)

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

j and 3

2)

In any form other than gas.

4 l

. MILLSTONE - LNIIT 3 3/47-30 Amendment No. J7,100 l

s an i

1

~

PLANT SYSTENS 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 Comeission on an annual basis if sealed source or fission detector leakage tests reveal 1

the presence of greater than or equal to 0.005 microcurie of removable contamination.

MILLSTONE - W IT 3 3/4 7-31 Amenteent NoJ00

=$

i 4

PLANT SYSTEMS 3/4.7.14 AREA TEMPERATURE MONITORING

]

l LINITING ColWITION FOR OPERATION 3.7.14 The temperature limit of each area shown in Table 3.7-6 shall not be

exceeded, j

APPLICABILITY:

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

i ACTION:

With one or more areas exceeding the temperature limit (s) shown in Table 3.7-6:

a.

By less than 20*F 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 20'F 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 provides a record of the cumulative time and the amount by which the temperature in the affected area (s) exceeded l

the limit (s) and an analysis to demonstrate the continued OPERABILITY of the affected equipment.

The provisions of l

Specification 3.0.3 are not applicable.

c.

With one or more areas exceeding the temperature limit (s) shown in Table 3.7-6 by more than 20*F, 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 l

the area (s) to within the temperature limit (s) or declare the equip-ment in the affected area (s) inoperable.

SURVEILLANCE REQUIRENENTS i

l 4.7.14 The temperature in each of the areas shown in Table 3.7-6 shall be i

determined to be within its limits:

a.

At least once per seven days when the alarm is OPERABLE, and; b.

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months when the alarm is inoperable.

l i

l l

l NILLSTONE - UNIT 3 3/47-32 Amendment No. J7, 75 400 l

0281

l j

f TABLE 3.7-6 l

AREA TEMPERATURE MONITORING i

i

}

gg TEMPERATURE LIMIT (*F) l 1.

AUXILIARY BUILDING AB-02, VCT and Boric Acid Transfer Pump Area, El 43'6" s 120 l

l AB-03, Charging Pump Area, El 24'6" i 110 AB-04, General Area, El 66'6" s 120 l

AB-06, General Area, El 43'6" s 120

{

AB-07, General Area, El 4'6" s 120 l

AB-08, General Area (East), El 4'6" s 120 l

AB-09, General Area (South), El 4'6" s 120 i

j AB-10, General Area, El 4'6" s 120 a

1 AB-11, General Area, El 43'6" s 120 t

AB-13, General Area (North), El 4'6" s 120 I

AB-16, Supplemental Leak Collection Filter j

Area, El 66'6" 1 120 AB-19, MCC/ Rod Drive Area, El 24'6" s 120 AB-21, MCC Air Conditioning Room, El 66'6" s 120 L

AB-22, Rod Drive Area, El 43'6" 1 120

?

j AB-25, Charging Pump Area, El 24'6" s 110 l

AB-26, RPCCW Pump Area, El 24'6" s 110 i

AB-29, General Area (Southeast), El 24'6" s 120

~

AB-33, Boric Acid Tank Area, El 43'6" s 120 i

AB-35, Boric Acid Tank Area, El 43'6" s 120 i

i AB-39, Fuel Building and Auxiliary Building Filter Area, El 66'6" 5 120 i

i i

NILLSTONE - LBIIT 3 3/47-33 Amendment No.100 9tM

TABLE 3.7-6 (Continued)

AREA TEMPERATURE MONITORING g

TEMPERATURE LIMIT f'F) 2.

CONTROL BUILDING CB-01, Switchgear and Battery Rooms, El 4'6" s 104 CB-02, C;;,le Spreading Room, El 24'6" 1 110 CB-03, Control and Computer Rooms, El 47'6" s 95 CB-04, Chiller Room, El 64'6" 1 104 CB-05, Mechanical Equipment Room, El 64-6" 1 104 3.

CONTAINMENT CS-01, Inside Crane Wall, El all except CS-03 and CS-04 1 120 CS-02, Outside Crane Wall, El all 5 120 CS-03, Pressurizer Cubicle, El all 1 130 CS-04, Inside Crane wall,_El 51'4" except CS-03 and steam 5 120 generator enclosures 4.

INTAKE STRUCTURE CW-01, Entire Building i 110 5.

DIESEL GENERATOR BUILDING DG-01, Entire Building i 120 6.

ESF BUILDING ES-01, HVAC and MCC Area, El 36'6" s 110 ES-02, SlH Pump Area, El 21'6" s 110 ES-03, Pipe Tunnel Area, El 4'6" i 110 ES-04, RHS Cubicles, El all 1 110 ES-05, RSS Cubicles, El all i 110 ES-06, Motor Driven Auxiliary Feedwater Pump Area, El 24'-G" s 110 ES-07, Turbine D:*iven Auxiliary Feedwater Pump i 110 Area, El 24'6" NILLSTONE - L5IIT 3 3/47-34 Amendment No. 77.100 tatt

TABLE 3.7-6 (Continued) i AREA TEMPERATURE MONITORING gg TEMPERATURE LIMIT (*F) 7.

FUEL BUILDING 3

FB-02, Fuel Pool Pump Cubicles El 24'6" s 110 i

FB-03, General Area, El 52'4" s 104

\\

8.

FUEL OIL VAULT FV-01, Diesel Fuel Oil Vault s 95 9.

HYDROGEN RECOMBINER BUILDING I

HR-01, Recombiner Skid Area, El 24'6" s 125 j

HR-02, Controls Area, El 24'6" s 110 i

HR-03, Sampling Area, El 24'6" 1 110 i

j HR-04, HVAC Area, El 37'6" s 110 I

10.

MAIN STEAM VALVE BUILDING l

l MS-01, Areas Above El 58'0' s 140 MS-02, Areas Below El. 58'0' s 140 l

1 l

11.

TURBINE BUILDING l

TB-01, Entire Building i 115 i

12. TUNNEL 4

i TN-02, Pipe Tunnel-Auxiliary, Fuel and ESF Building S 112 j

13. 188Q j

YD-01, Yard s 115 i

MILLSTONE - LMIT 3 3/4 7-35 Amendment No. N,100 ones i

i l

ELECTRICAL POWER SYSTDi$

I SURVE!LLANCE REQUIRENENTS (Continued) b)

A kinematic viscosity at 40*C of greater than or equal to 1.9 contistokes, 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 l

the supplier's certification; c)

A flash point equal to or greater than 125'F; and i

i d)

A clear and bright appearance with proper color when i

tested in accordance with ASTM-D4176-82.

]

2)

By verifying within 30 days of obtaining the sample that the j

other properties specified in Table 1 of ASTH-D975-81 are met when tested in accordance with ASTM-D975-81 except that the 4

analysis for sulfur may be perfonned in accordance with ASTM-j D1552-79, ASTM-D2622-82 or ASTM-D4294-83.

8 i

f.

At least once every 31 days by obtaining a sample of fuel oil in j

accordance with ASTM-D2276-78, and verifying t sat total particul' ate i

contamination is less than 10 mg/ liter when checked in accordance with ASTM-D2276-78, Method A;

}

1; g.

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

l 1)

Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service; l

l 2)

Verifying the generator capability to reject a load of greater than or equal to 595 kW while maintaining voltage at 4160 1 420 l

volts and frequency at 60 i 3 Hz; 3)

Verifying the generator capability to reject a load of 4986 kW f-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 j

shedding from the emergency busses, and I

b)

Verifying the diesel starts on the auto-start signal, energizes the emergency busses with permanently connected i

loads within 11 seconds, energizes the auto-connected i

shutdown loads through the load sequencer and operates for i

greater than or equal to 5 minutes while its generator is i

loaded with the shutdown loads. After energization, the steady-state voltage and frequency of the emergency busses j

shall be maintained at 4160 1 420 volts and 60 1 0.8 Hz 3

during this test.

)

i 1'

NILLSTONE - UNIT 3 3/4 8-5 Amendment No. J, 5. M. U,100 t

essa i' '

ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 8)

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

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)

Verifying that with the diesel generator operating in a test l

side, connected to its bus, a simulated Safety In,jection 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 from each fuel storage tank to the day tank of each diesel via the installed cross-connection line:;

12)

Verifying that the automatic load sequence timer is OPERABLE l

with the interval between each load block within i 105 of its design interval; and 13)

Verifying that the following diesel generator lockout features prevent diesel generator starting:

a)

Engine overspeed, b)

Lube oil pressure low (2 of 3 logic),

c)

Generator differential, and.

j l

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 diese1' generators accelerate to at least 508 rps in less than or 1

equal to 11 seconds; and j

1.

At least once per 10 years by:

i 1)

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

\\

NILL 5 TONE - LAIIT 3 3/48-7 Amendment No. pp, 77, 100

i l

ELECTRICAL POWER.SYSTDis SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per 92 days and within 7 days after a battery i

discharge with battery terminal voltage below 110 volts, or battery overcharge with battery terminal voltage above 150 volts, by verify-

}

ing that:

1 i

1)

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

2)

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

150 x 10* ohm, and a

i 3)

The average electrolyte temperature of six connected cells is-l above 60*F.

c.

At least once per 18 months by verifying that:

l 4

I 1).

The cells, cell plates, and battery racks show no visual j

indication of physical damage or abnormal deterioration, a

j 2)

The cell-to-cell and teminal connectione are clean, tight, and coated with anticorrosion material, i

3)

The resistance of each call-to-cell and teminal connection is I

less than or equal to 150 x 10* ohn, and l

j-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 months, during shutdown, by verifying that the l

battery capacity is adequate to supply and maintain in OPERABLE 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

i e.

At least once per 60 months, during shutdown, by verifying that the 1

1 battery capacity is at least 80% of the manufacturer's rating when

{

subjected to a performance discharge test. Once per 60-month 4

interval this perfomance discharge test may be perfomed in lieu of

}

the battery service test required by Specification 4.8.2.ld.; and f.

At least once per 18 months, during shutdown, by giving performance i

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 IDE of rated capacity from its average on previous performance tests, or is below 905 of the manufacturer's rating.

/

1 4

ii i

NILL 5 TONE - UNIT 3 3/4 8-12 Amendment No. #, U.100 l

l i

I i

l ENERGENCY CORE COOLING SYSTEMS l

BASES i

l ECCSSUBSYSTEMS(Continued) i i

The limitation'for a maximum of one centrifugal charging pump and one i

safety injection pump to be OPERABLE and the surveillance Requirement to i

verify all charging pumps and safety injection pumps except the required

{

0PERABLE charging pump to be inoperable below 350*F provides assurance

(

that a mass addition pressure transient can be relieved by the operation of a single p0RV.

The surveillance Requirements provided to ensure OPERABILITY of each 4

component ensures that at a minimum, the assumptions used in the safety analyses are met and that subsystem 0PERABILITY 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 i

system to each injection point is necessary to:

(1) prevent total pump flow i

from exceeding runout conditions when the system is in its minimum resistance l

configuration (2) provide the proper flow split between injection points j

in accordance w1th the assumptions used in the ECCS-LOCA analyses, and (3) provide an acceptable level of total ECCS flow to all injection points i

equal to or above that assumed in the ECCS-LOCA analyses.

f Surveillance Requirement 4.5.2.C.2 requires that the visual inspection of the containment be performed at least once daily if the containment has i

been entered that day and when the final containment entry is made. This will reduce the number of unnecessary inspections and also reduce personnel exposure.

3/4.5.4 REFUELING WATER STORAGE TAfK 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 l

containment to permit recirculation c)ooling flow to the core, and (2) the j

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 witn the l

LOCA analyses.

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

]

characteristics.

i 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.

4 l

The maximum / minimum solution temperatures for the RWST in N0 DES 1, 2, 3 3

and 4 are based on analysis assumptions.

3, f

NILLSTONE - UNIT 3 B 3/4 5-2 Amendment No.100 am

~

1 PLANT SYSTEMS j

BASES i

I

)

l 3/4.7.11 SEALED SOURCE CONTAMINATION (Continued) j 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 commensurate with the probability of damage to a i

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 I

radiation monitoring or baron measuring devices) are considered to be stored l

and need not be tested unless they are removed from the shielded mechanism.

4 3/4.7.14 AREA TEMPERATURE MONITORING 1'

The area temperature limitations ensure that safety-related equipment will' not be subjected to temperatures in excess of their environmental qualification j

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 2.2*F.

)

I i

I l

I i

i

)

i i

4 1

i 1

4 MILLSTONE - LMIT 3 8 3/4 7-7 Amendment No. M. M.

l 100 I

ML20077N165

Text

Attachment:

=

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