Text

Forwards Addl Comments on Proof & Review Tech Specs Provided in NRC .Changes Result of Internal Validation Program,Review of Existing Analyses,Data Generated During Preoperational Testing & Review of FSAR
	ML20197J487
Person / Time
Site:	Seabrook
Issue date:	05/17/1986
From:	George Thomas; PUBLIC SERVICE CO. OF NEW HAMPSHIRE
To:	Noonan V; Office of Nuclear Reactor Regulation
References
	SBN-1055, NUDOCS 8605200051
	Download: ML20197J487 (60)
	v • d • e

_

' e)( George S. Thomas

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vice PreMent-Nuc; eor PrMxtien May 17, 1986 Put2c Service of New Hampshire SBN-1055 New Hampshire Yankee Division T.F. B7.1.2 United States Nuclear Regulatory Commission Washington, DC 20555 Attention: Mr. Vincent S. Noonan, Project Director PWR Project Directorate No. 5

References:

(a) Construction Permits CPPR-135 and CPPR-136, Docket Nos.

50-443 and 50-444.

(b) USNRC Letter dated March 13, 1986, "Seabrook Technical Specifications," V. S. Noonan to R. J. Harrison (c) PSNH Letter (SBN-1012) dated April 22, 1986, "Seabrook Proof and Review Technical Specifications," G. S. Thomas to V. S. Noonan

Subject:

Additional Comments to Seabrook Station Technical Specifications

Dear Sir:

Enclosed please find additional comments on the Seabrook Station Proof and Review Technical Specifications provided by the staff in Reference (b).

Justifications for each of these changes are provided with the comments.

Please be advised that these additional comments da not request any additional improvements over and above our initial request. These changes are generated as a result of our internal validation program, review of existing analyses, data generated during preop testing, and a review of the FSAR with respect to the Technical Specifications.

Should you have any comments regarding these changes, please contact Mr. Warren J. Hall at (603) 474-9574, extension 4046.

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8605200051 860517 PDR ADOCK 05000443

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~S m Thomas CST /cjb Enclosures cc: ASLB Service List tP P.O. Box 300 Seabrook.NH 03874 Telephone (603)474-9521 l\i

Enclosure to SBN-1055 JUSTIFICATIONS

1. Definition 1.29 - This change is made to make the definition consistent

with the subject Technical Specifications.

2. Specifications 3.1.2.5 and 3.1.2.6 - The volume in the boric acid tank was discovered in our technical specification validation program to be nonconservative when using two boric acid tanks to satisfy the technical specification requirement. The revised values are conservative for use of ona or two tanks.

3. Specifications 3.1.2.6 and 3.5.4 - A reanalysis of the Containment Response to a LOCA was performed with the analysis assumption of 98* for RWST temperature. Marked pages of the FSAR are being submitted with SBN-1054, dated May 17, 1986.

4. Specification 3.1.2.7 - This change is made as a result of the NRC Region I audit inspection. The previously worded specification was incorrect.

These changes rectify the error to assure proper implementation of the 4 specification.

5. Specification 3.2.5 - Typographical error on our previous submittal. The 594.3*F is the analysis value.

6. Table 3.3-1, Action 5 - A revision of the action statement has been proposed to prevent unmonitored dilution of the RCS when no source range nuclear instruments are operable.

7. Table 3.3-4, Item 8.b - The values have been revised as a result of changing the RWST temperature limits and the resulting density changes.

8. Table 3.3 The table has been revised based on a review of the actual response times used in the safety analysis, and has been verified by both the NSSS vendor and AE. Also, it has been revised to resolve Item 18 in SBN-1054, dated May 17, 1986.

9. Table 3.3-6, Item 2.b - typographical error in previous submittal.

Item 3 - the radiation monitor is on the steam line and hence we feel it is more appropriate to use that terminology.

10. Table 3.3-9, Items I and 2 - Only one channel is required to.be operable because there are other parameters which are available from which power can be determined.

11. Table 3.3-9, Items, 3, 4 and 5 - The remote shutdown study assumed both channels of this instrumentation was available hence both must be operable.

12. Table 3.3-9, Items 6 and 7 - Typographical error in previous submittal and on first page of attachment.

13. Specification 4.3.3.6 - A revision to the proposed surveillance for AMI is made to satisfy the staff's concern with regard to identifying the concentration of the calibration gases for the hydrogen analyzers.

14. Table 3.3 Deleted Item 13 and renumbered. Also, added the condensate storage tank level indication. The table now includes all category I variables. Refer to Item 9 in SBN-1054, dated May 17, 1986.

15. Specification 3.3.3.7 - Change made to be consistent with previously submitted comments editorial.

16. Table 4.3-5, Item 2a - Frequency of testing changed to be consistent with the associated radiation monitor.

17. Table 3.3-13, Item 3a - Made change to be consistent with applicability for sampler flow rate indication.

18. Specification 3.5.1.1 - The accumulator volumes have been revised as a result of cur validation effort.

19. Specification 4.5.1.1.2 - Typographical error. The number of the surveillance has been corrected.

20. Specifications 3.6.1.2.a, 3.6.1.3.b, 4.6.1.1.c, 4.6.1.2.a, 4.6.1.2.d, and 4.6.1.3.a - As a result of the reanalysis done on the containment response to a LOCA, Pa has been raised to 49.6 psig. This is still below the design pressure of 52 psid. The reanalysis was required due to'the change in the RWST maximum temperature.

21. Table 3.6 This change made because this penetration encloses the containment H2 purge lines. Although the lines process containment atmosphere directly to the containment enclosure emergency filter units, a small amount of piping passes through the H2 analyzer cubicle. This cubicle is not part of the secondary containment filtered area.

22. Specification 3.6.1.3 - The change to the footnote resolves a concern raised by the staff reviewer.

23. Specification 3.6.1.4 - The footnote has been changed to address a concern raised by the staff reviewer.

24. Specification 4.6.2.1 - As part of our validation program we determined that the pressure for the CBS pump dif ferential pressure could actually be much lower than was originally calculated. We have verified the proposed differential pressure still ensures that the analysis value for flow is satisfied.

25. Specification 3.6.2.2 - As part of our validation program we determined that the Spray Additive Tank Volumes needed to be revised. This was

, determined by independent review of the design documents.

. 26. Table 3.6 Valve stroke times for the C0P and CAP containment ventilation isolation valves were revised to be consistent with the safety analysis requirement. This was discovered as part of our validation program.

27. Specification 4.6.4.2 - The sheath temperature of the hydrogen recombiner is dependent on the power setting hence we have specified an appropriate setting. We are supplying appropriate values to demonstrate operability consistent with information supplied by the vendor. This item was discovered in our validation effort.

28. Specification 3.7.1.2 - This specification and the surveillances have been changed to accommodate the use of the Startup Feedpump as a backup to the Emgerency Feedwater System. This specification was discussed with the Region I Technical Specification auditors recently on site. This proposed specification was found to be acceptable and in accordance with

) their review of the FSAR and the SER. The values given in this specification are a result of recent modifications to the EFW system {

following HFT. The numbers have been verified by evaluation of the data i taken during HFT and will ensure adequate flow to meet requirements of the safety analysis.

29. Specification 3.7.1.3 - As part of our validation effort we determined that the value of CST volume should be revised.

30. , Specification 4.7.3 and 4.7.4 - This change made as a result of the NRC Region I inspection audit. They requested this change to more accurately reflect the type of testing that satisfies the surveillance.

l

31. Specification 4.7.8.1.1.f.2 - The system head for the fire pumps was !

revised as a result of our validation effort. The previous value was inconsistent with the 120 psig system pressure requirement. )

32. Table 3.7 All the areas listed in the subject technical specification table have area temperature sensors which generate high temperature alarms on the plant computer. We have included the instrument uncertainty factor in our alarm setpoints. The maximum values now stated in technical speci-fications are the normal maximum temperatures from the service environment chart [FSAR Figure 3.11(B)-1} to which safety-related/IE Equipment in each area has been qualified. By not including instrument uncertainty in these values, we allow ouselves greater flexibility to verify unacceptably high area temperatures locally with more accurate instrumentation in response to the alarms described above. Furthermore, by including instrument uncertainty in the alarm setpoints, we ensure that indeterminable violations of the technical specification do not occur. Also, we have reduced the control room temperature requirement to be consistent with the service environment chart.

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33. Specification 4.8.1.2 - This change made as a result of the NRC Region I inspection audit. The inspectors requested that this change be made to reduce the amount of testing that would be required for the DG's to reduce unnecessary starts which could lead to potential unwarranted failures.

34. Table 3.8 Revisions reflect recent plant design changes and corrections for typographical errors. The valves FW-V346 and FW-V347 were recently added.

35. Specifications 3.9.6 and 4.9.6 - The overload cutoff limit was incorrectly revised in our previous submittal. Our validation effort has reverified the original values of 3900 lbs.

36. Specification 5.3.1 - As part of our validation effort we determined that the value for the initial maximum enrichment needed to be revised.

37. Specifications 6.2.3.1 and 6.2.3.4 - This change is made to show the correct reporting activity for the ISEC.

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'. 3 QUADRANT P M R TILT RATIO lik QUADRANT POWER TILT RATIO shall be the ratio of the maximum upper excore detector calibrated output to the average of the upper excore detector cali-

. brated outputs, or the ratio of the maximum lower excore detecter calibrated output to the average of the lower excore detector calibrated outputs, whichever ,

is greater. With one excore detector inoperable, the remaining three detectors shall be used for computing the average. . .

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RATED THERMAL POWER ;

1.25 RATED THERMAL POWER shall be a total reactor core heat transfer rate to the reactor coolant of 3411 MWt.

REACTOR TRIP SYSTEM RESPONSE TIME 1.h The REACTOR TRIP SYSTEM RESPONSE TIME shall be the time interval from

, when the monitored parameter exceeds its Trip Setpoint at the channel sensor until loss of stationary gripper coil voltage. .

REPORTABLE EVENT 2X .

1.27 A REPORTABLE EVENT shall be any of those conditions specified in Section 50.73 of a B ui' DsN G.

-/ CONTAINMENT ENCL REhNTEGRITY

w 1.28 CONTAINMENT ENCLOSURE INTEGRITY shall exist when:

a. Each door 4n-each-access-opening is closed except when the access g - opening is being used for normal transit entry and exit, then-at:- -

-l e a s t-o n e -do o r-s h a l-1-b e -c l o s ed r

b. The Containment Enclosure Filtration System is OPERABLE, and .

c. The sealing mechanism associated with each penetration (e.g., welds, bellows, or 0-rings) is OPERABLE.

l SHUTOOWN MARGIN 30

, 1.29. SHUTOOWN MARGIN shall be the instantaneous amount of reactivity by which l tne reactor is subcritical or would be subcritical from its present condition assuming all full-length rod cluster assemblies (shutdown and control) are fully inserted except for the single rod cluster assembly of highest reactivity worth which is assumed to be fully withdrawn. ,

SITE BOUNDARY 3f-1.30 The SITE BOUNDARY shall be that line beyond which the land is neither .,

owned, nor leased, nor otherwise controlled by the licensee. any area wi71g, N s N En.avj used fer se veakio^al prfases 61 ~n *: n .b e -s et -tv o. , M u s t , !! } ,~~1 bJ he hsyass 9., sh hadey Zoe pr p = 5<5 *+. "veNr7 ,2.s< m) c'os e SrMk~a +m > M" h.'E ocuf wy :ack stah he supplM .&-% loedic.o & R0 jI h

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REACTIV SYSTEMS

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LIMITING CONDITION FOR OPERATION

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3.1.2.5 As a minimum, one of the following borated water sources shall be ;

OPERABLE; A

a. A Boric Acid Storage System with:

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1) A minimum contained borated water volume eC .4,800 g lans,

2) A minimum boron concentration of 7000 ppm, a

3) A minimum solution temperature of 65'F.

b. The refueling water storage tank (RWST) with:

1) A minimum contained borated water volume of 24,500 gallons,

2) A minimum baron concentration of 2000 ppm, and

3) A minimum solution temperature of 50*F APPLICABILITY: MODES 5 and 6.

ACTION:

With no borated water source OPERABLE, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.

SURVEILLANCE REQUIREMENTS , 4.1.2.5 The above required borated water source shall be. demonstrated OPERABLE:

l

a. At least once per 7 days by:

1) Verifying the boron concentration of the water,

2) Verifying the contained borated water volume, and

3) Verifying the boric acid storage tank solution temperature when it is the source of borated water.

b. At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying the RWST temperature.

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BORATED WWFER SOURCES - OPERATING LIMITING CONDITION FOR OPERATION ;

3.1.2.6 As a minimum, the following borated water source (s) shall be OPERABLE as required by Specificatica 3.1.2.2:

a. A Boric Acid Storage System with:

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1) A minimum contained borated water volume of -??,,2^^- lons,

2) A minimum boron concentration of 7000 ppa, an

3) A minimum solution temperature of 65'F.

b. The refueling water storage tank (RWST) with:

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1) A minimum contained borated water volume of 479r000-ga11ons,

2) A minimum baron concentration of 2000 ppm, -

3) A minimum solution temperature of 50*F, and

4) A maximum solution temperature o1 gF.

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

ACTION:

a. With .the Boric Acid Storage System inoperable and being used as one of the above required borated water sources, restor'e the 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 borated to a SHUTDOWN MARGIN equivalent to at least ak/k at 200*F; restore the Boric Acid Storage System to OPERABL status within the next 7 days or be in COLD SHUTOOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

b.

& t.1 With the RWST inoperable, res are the tank to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

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UN80 RATED WATER SOURCES - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.1.2.7 The Baron Thermal Regeneration System shall be rendered incapable of performing its dilution function by:

% CS- V 30 *2-a BTRS &L+ O sh

a. -Removing. power- from-the-Chiller Compressor-(CS--E-18) -and . M M b.

rh CS- U 3os 87RS M Anat M Positioning-the-three-w,ay-valve-(HCV-387-)-to-bypass alt-flow around-

.the -The rma l-R e g e ne ra ti v e -Demi ne ra Mz e rs .-

APPLICABILITY: MODES 4, 5, and 6 ACTION-'

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operation of the Chiller Compressor or the three-way bypa.ss.. valve'is Tb. permitted'as-long_as the two components are not out of' Specification 3.1.2.7 simultaneously.~ 0uring such testing-the unaffected component ,

shallbeverifiedtobeincompliancewiththisspecificationthroughf-out the test. When the't~est is completed ~all-conditions for Specifi-cation 3:12.'7'shall_be_re-established-r SURVEILLANCE REOUIREMENTS 4.1.2.7 The above required conditions shall be verified at least once per 31 .

days.

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3/4.2.51 ' PARAMETERS .

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' LIMITING CONDITION FOR OPERATION <

3.2.5 The following DNS-related parameters shall be maintained within the the following ifnits: e e a. Reactor Coolant System T,yg, <

b. Pressurizer Pressure 1 2205 psig"

c. Reactor Coolant System Flow 1 391,000 gpm**

APPLICABILITY: MODE 1. "

ACTION:

With any.of the above parameters exceeding its limit, restore the parameter to within its limit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

SURVEILLANCE REQUIREMENTS

=

4.2.5.1 Each of the parameters shown above shall be verified to be within its limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . .

4.2.5.2 The RCS flow rate indicators shall be subjected to CHANNEL CALIBRATION at least once per 18 months.

4.2.5.3 The RCS total flow rate shall be determined by precision heat

! balance measurements at least once per 18 months.

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" Limit not applicable during either a THERMAL POWER ramp in excess of 5% of RATED THERMAL POWER per minute or a THERMAL POWER step in excess of 10%

of RATED THERMAL POWER.

- Includes a 2.1% flow measurement uncertainty. .

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dI ACTION STATEMENTS (Continuedl

, 39,a .

ACTION 3 - With the number of channels OPERA 8LE one less than the Minimum 1 Channels OPERABLE requirement and with the THERMAL POWER _ level:

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a. Below the P-6 (Intermediate Range Neutron Flux Interlock)

Setpoint, restore the inoperable channel to OPERA 8LE status- prior to increasing THERMAL POWER above the P-6 Setpoint, and p

b. Above the P-6 (Intermediate Range Neutron Flux Interlock)

Setpoint but below 10% of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 10% of RATED THERMAL POWER.

ACTION 4 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, suspend all operations involving positive reactivity changes.

ACTION 5 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE statuj within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the Reactor Trip System breakers,,3uspend'a11 operations involving positive reactivity changes,and-verify-Valves are-closed-and-

-securedin positionwithin-the-next-hour.- 4 ACTION 6 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 7, hout;- and ,

b 4

b. The Minimum Channels OPERABLE requirement is met;/,however, the inoperable channel may be bypassed for up to;2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of other channels per Speci fication 4.3.1.1.

ACTION 7 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed until performance of the next required ANALOG CHANNEL OPERATIONAL TEST provided the inoperable channel is placed in the tripped condition within'1. hour.~

(s ACTION 8 - With less than the Minimum Number of Channels OPERABLE, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months determine by observation of the associated permissive annunciator window (s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

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Insert for Table 3.3-1, Action 5 { .

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In modes 3f 4,.and 5 verify that valve RMW-V31 is closed and secured in I position within the next hour.

In mode 3 also ensure that the BTRS is removed from service in accordance with i the provisions of specification 3.1.2.7.

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TABLE 3.3-4 (Continued) ,

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,p 3; ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOIN 4~

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R TOTAL ERROR ALLOWABLE VALUE be3 (S) TRIP SETPOINT ' VY j ALLOWANCE (TA) Z ~ : ;,}f c- FUNCTIONAL UNIT ,

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7. Emergency Feedwater ,

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a'. Manual Initiation N.A. -T .-

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N.A. N.A. N.A. N.A.

(1) Hotor driven pump N.A. .l N.A. N.A. N.A. N.A.

(2) Turbine driven pump N.A. l' N.A. 'N.A. N.A. N.A.

b. Automatic Actuation Logic and Actuation Relays '

15.28 1,76 > 17.0% of > 15.9% of narrow E c. Steam Generator Water 17.0 narrow range range instrument t'

N Level--Low-Low Start Motor-Driven Pump instrument span.

span.

m .

';' u and Start Turbine-Driven ,

Pump U ---

See Item 1. above for all Safety Injection Trip Setpoints and

d. Safety' Infection Allowable Values, m Start Motor-Driven Pump and Turbine-Driven Pump -

N,A, -NrA. > 4800V >-4692V' '

NrA.

e. Loss-of-Offsite Power Start Motor-Driven Pump b h9 f- Jm.fu,y g Q -

and Turbine-Driven Pump ,

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8. Automatic Switchover to -

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TABLE 3.3-5

& &J ~ ENGINEERED SAFETY FEATURES RESPONSE TIMES

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INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS l

' 1. Manual Initiation

a. Safety Injection (ECCS) N.A.

b. Containment Spray N.A. p

c. Phase "A" Isolation p N.A.

d. Phase "B" Isolation N.A.

e. Containment Ventilation Isolation N.A.

f. Steam Line Isolation N.A.

g. Feedwater Isolation N.A.

h. .[u Feedwater N.A.

1. Essential Service Water 40 GCC2/ N.A.

j. Containment Cooling ' Fans N.A.

kon r h R N foTaYio '"'N N.A.

k.

1. Reactor Trip -

N.A.

m. Start Diesel Generator N.A.

2. Containment Pressure--Hi-1

a. Safety Injection (ECCS) 1 27I1) M

1) Reactor Trip i27 ,

. 2) Feedwater Isolation SN3)h

3) Phase "A" Isolation A17h27(U-Nh 0

4) Containment Vent Isolation 1 25 W b L i~

5) Emergency Feedwater 1 -60 N

6) Service Water System ) sh i , i - .2 / 0 i

7) Start Diesel Generator 5 < .10- //2

~

2) Cdh %3 p % )% $ $ di p.g Y

m a v . pp 3/4 3-31 SEABROOK - UNIT 1 , / s L' .

hbh p1.

,a i

d l [

MAR 1U886_

w^ ,

. .^If - T >';y i_ = . ..

j 1

$ f$:l;W TABLE 3.3-5 (Continued) ;

'fWff s +m 06/6 m '" ,

ENGINEERED SAFETY FEATURES RESPONSE TIMES

\.. b .

INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

3. Pressurizer Pressure--Low

a. Safety Injection (ECCS) 1 1)/12(5)

1) Reactor Trip <2 -

2) Feedwater Isolation <

3)h(I)N4 j

3) Phase "A" Isolation E-17 E/27

4) Containment Ventilation Isolation k 4dII/1/2) 3,g-

5) Emergency Feedwater < 60 M

6) Service Water System 5 4 / 13/1$2)- ,2, o

-7) ~-P r i ma ry-Compo ne n t-Cool i ng -Wa te r- [ nII)nh2E .

7 2-) Start Diesel Generators < .W /.2.

F) CG A Em W-7dIvbM7d 1 p .A. <

4. Steam Line Pressure--Low '

a. Safety Injection (ECCS) 1 12(5)/22I4)

1) Reactor Trip -

<2 f f

Feedwater Isolation 2)

3) Phase "A" Isolation 3)h )Vi

<-17(23 /27 II sr

4) Containment Ventilation Isolation 2dII/1M2)J.T

5) Emergency Feedwater < 6 0 - *>4 ,

atef System [2b2)/4N 2e O Start Diesel Generators 7 e.t Sn e u M caa r r p r G~/ r b team Line Isolation g, m ,a .. . v4$ A(3pgJ

5. Cont h ment Pressur h 'W

a. Containment Spray 2)/W 1)

b. Phase "B" Isolation . -65(1)/75(2) g

6. Containment Pressure--Hi-2 (N Steam Line Isolation s k3)[h v

7. Steam Generathe Pressure - Negative Rate--High Steam Line Isolation 1.NNA

8. Steam Generator Water Level--High-High (P-14)

a. Turbine Trip 5 25 No I3)

b. Feedwater Isolation 17

_~

7 MAy 171988 q W FM SEABROOK - UNIT 1 3/4 3-32

~

. L n :' _

g( ;' , y .- * .

7

. j 4. ,.,, '

i s p, , , _

~ 7* :k teg . , ,

~

g.n

TABLE 3.3-5 (Continued) -

. ; s .. ~

y ENGINEERED SAFETY FEATURES RESPONSE TINES RESPONSE TIME IN SECONOS

. INITIATING SIGNAL AND FUNCTION

9. Steam Generator Water Level--Low-Low

a. Motor-Driven f'aergency Feedwater Pump,s', $ 60

b. Turbine-Driven Emergency Feedwater Pump < 60

10. LN55ef0ff5

. ":t: -Crh;a L.. wency Feeuwater Fu-p g yvA

t. Turbin:-Or'v:n E.::.geacy F =u-aier Fump J 46 W

-11. T ri p -o f- Al Ma i n- Fee dwa te r- P ump s -

,All-Emergency-Feedwater-Pumps - N: A.- l I

jo ff'12'. RWST Level--Low-Low Coincident with Safety Injection l

) Automatic Switchover to Containment Sump $ -100' 29 f

j j 4[ g 13. Loss of Power 1@ Nh f a. 4.16 kV Bus E5 and E6 JLossofVoltage) -

NP

"( b. 4.16 kV Bus E5 and ES

<M k Degraded Voltage toincident l

l wi th -Safety-Injection ~

C y .w <. .te s , . 4 L f 6 I,)<.6, .

/ ~ ,) y c., te d.:. < , C < < .y na.Go.h.- t' ,

2) rc 4 ,< 1 2 .va [. . y e , y (<. sa l - Ay ,

, a na c <..e x , ,,

s t

h i .t J -

S.e e L n se.- F I) <

a , "n Dg

\ H4 .Tv 1r W Lt agi MAY 171988 a L.":..

SEABROOK - UNIT 1 3/4 3-33 gg y

, vu . - - -

's ; sr

~

.A+

fl . ' e 4

).;

Insert for Table 3.3-5, Action 12 and 13

.- .7 :).,

. pA' .. Y",. ~ 'n

y

'?

y

12. Low RCS).Tave' Coincident with Rx Trip '

t

. ' .; , . . .~,. j@,::

a. F Jwaier Isolation NA

-.,..~ .

13. Containment On Line Purge Ridiation - High

- ~~ ; -

4

. j.

~

.._ ,.n ,

a. -Containment Ventilation Isolation NA

-s m

'/

j ' s _ g k

6 c

. , MAY 171986

,* '"'- ~~

-r- - r -e ,

n . - - -

-wfyQ'

-r-- . , + - ..

.q .3, .

' &;r ",l((,

> 5 -;

-j t

. t si i

[y,; ::hML ' pg ' ' ,

-y M,j,th.; 5;

g; 5 y y; W 'L - TABLE 3.3-5 (Continued)

~ ..

TABLE NOTATIONS (1) Diesel generator starting and sequence loading delays included.

(2) Diesel generator starting and sequence loading delay M included.

Offsite power available.

(3) Air-operated valves.

(4) Diesel generator starting and sequence loading delay included. -AHR-

-?^^ 3 =t i = hded- Only cea l,-,fuy / e A *y hg (a, p In cle.ded.

1 (5) Diesel generator starting and sequence loading delays not included.

muo _.__. .. . u,. 3 , ,a.a

"- "'~ - ---

in/< /ed o,1, e ,, tn 6,a / e4< g.n; (< ya

_- O l MM ll1986 g '

p p,.g SEABROOK - UNIT 1 3/4 3-34 '

[1 l MAR'lilS86

TABLE 3.3-6 .

M RADIATION MONITORING INSTRUMENTATION FOR PLANT OPERATIONS '

c"o

, z 8

u MINIMUM .

_ .-e CilANNELS CHANNELS APPLICABLE ALARM / TRIP .G.

SETPOINT ACTION - 16.%yyy, e TO TRIP / ALARM DPERABLE MODES ...

FUNCTIONAL UNIT a g g/4, 'y ;g?

~ 1., Containment -f > " ^;

-l' N A -2 / -All/2,3 9 < 2-mR/h -23 2.~7

a. Containment-Atmosphere- '

1

-Radioactivi ty-liighwiu /lotuI*t

-+ ?.$ _

b. RCS Leakage Detection -

1 1, 2, 3, 4 N.A. 26

1) Particulate Radioactivity N.A. .

26 N.A. 1 1, 2, 3, 4 N.A.

2) Gaseous Radioactivity ' ~

T. C f

3:= 2. Containment Ventilation Isolation 23

'12. -A11 /, 2,3, y

a. PYrk.'ici$1'abeIfadIo# a 'ctivity- ,

w 1 0$3 1 1. 2_. All 4

4

b. /d5Te'ouE- R'a'dioacfi 0l tN " ##^^ $7 1/Velve- 1/Vehe 1, 2, 3, 4 N.A.4 co 3. Main Steant Line s t ,, t. u f p uu

- cn Fuel-Storage-Pool-Areas-

-4. - -

a.-Radioactivi ty-High-2 -**- 5-2-mR/hr 24 -

_ Gaseous-Radioactivity-2

- - - 15-mR/nr 25- -

.b. - Cri tic al i ty-Rad i a t i on - Level- fW :l '5.

Control Room Isolation /Mchn"h(6 p M A pt hj a. Air Intake-Radiation Level

1) East Air Intake 1/ intake 1/ intake 1/ intake All All

< mR/hr

~$-2-mR/he 24 24 (

2) West Air Intake 1/ intake "~ "" -' '

k[ p~ d 1-1 All ~<-2 mR/hr-- '

24-

" -b.-Control- Room - Atmosphere-

-Radiation-liigh_

$ -6. -Primary-Component-Cooling Water-l

[? 3

.a,--Loop A -- 1 1._._ - AI I < 2-x-

-Background-28 -

so 1 All < yt-----. b.- L00p B - d'-), - Background .

I a a--u,- .gQ a ,

i 4

b. :

, .c f ,, w-g R_EMOT 11T0b SYSTEM TOTAL NO. MINIMUM j READOUT OF CHANNELS j,-

l 8

X LOCATION CHANNELS OPERABLE N-INSTRUMENT 1

$ -IrPower-Range-Neutron - Fl ux-

' - ^[ ,

' YIy' i L Intermediate Range Neutron Flux CP-108 A and B 2 Fr 5

H Source Range Neutron Flux CP-108 A ar.d B 2 2 i ;

- s:M t.'3.

H -4'.-Reactor-Trip Breaker-Indication -1/ t r i p-b re a ke r--1/t ri p- b re a ke r- '

'3 'S. Reactor Coolant Temperature - E g -244-- -

Average War,$ qe % a Ti fo- w sa CP-108 A and B 2 - re .fj l

6.-Reactor Coolant-Flow-Rate- -2 <2:

9 7. Pressurizer Pressure CP-108 A and B 2 #2 1 .2 -2M' 2.

S'8. Pressurizer Level CP-108 A and B

.L9 5. team Generator Pressure CP-108 A and B 9-og/sta. gen. q-ig/sta. gen.

g CP-108 A and B q tv7/sta. gen. 4-ist/sta. gen.

l'10. Steam GeneratoN Water Level g -11.-Control-Rod Position-Limit-Switches- 1/ insertion- 1/ insertion-1imit-limi-t-switch / switch / rod--

d -rod-

, :--*:= $ -12rRHR-Fl ow-Rate- - ;

l

[ "J, -13.--RHR Temperature -

co H 314. Steam Generator-Emergency Feedwater

$ Flow Rate CP-108 A and B -

'/E-fen /f5/** 6('l (t 15. Boric Acid Tank Level CP-108 A and B t- E. 2-/ /T' /t go c....w , A r. % r a M y SWITCH 2,_ '

1 TRANSFER SWITCHES 0 CATION l t _ _ _, ; . Ih Auxiliary Feedwater Control ,

-~ -

2. Safe Shutdown Equipment Power

. Nd a. Auxiliary Feedwater

b. Charging gcc g3geh) &d '

h~~9 c. Pressurizer..' Heaters

) g'Ik d. Valves ./ \ "'W'

3. CVCS Hakeup' Flow Control -

l ,b g 4. Diesel-Generator Control ,

, 7':s b 5._ Electrical Distribution System'Cqntrol

I CONTr3L CIRCUITS SWITCH y LOCATION ;

L f

' [g's ;. 5 IwAuxiliary FeedwaterJ10w i j- g 2. Pre'ssurizer Heaters

3. CVCS Hakeup,-Flow

'%p 4. Diesel Generators

'j 5.-Electrical Distributio (System f

.. w

Nnk;Wth n:-,.; -e'

. jn 2l

,a b , : L,?

f u;1 HQ;;.h L .;, i L,;;,6 a;QI , K,., :,

e. ;-

p 1

. a

.- -4

-y .-s ' 1 TRANSFER $rITCHES 1.0 CATION l l SiGi.& > a

' %;(y;~,%

Emergency 1Feedwater Pump Steam Supply Valves CP-108 A MS-V-393/127 Emergency Feedwater Pump Steam Supply Valves CP-108 B MS-V-394/128 Emergency Feedwater Pump Steam Supply Valves CP-108 A and B MS-V-395 V

Emergency Feedwater Pump FW-P-37 B BUS 6 SWGR Emergency Feedwater Recire Valve FW-V-346 CP-108 A Emergency Feedwater Recirc Valve FW-V-347 CP-108 B SG A EFW Control Valve FW-FV-4214 A CP-108 A SG A EFW Control Valve FW-FV-4214 B CP-108 B SG B EFW Control Valve FW-FV-4224 A CP-108 A SG B EFW Control Valve FW-FV-4224 B . CP-108 B SG C EFW Control Valve FW-FV-4234 A .

CP-108 A 4 SG C EFW Control Valve FW-FV-4234 B CP-108 B SG D EFW Control Valve FW-FV-4244 A CP 108 A SG D EFW Control Valve FW-FV-4244 B CP-108 B SG iNRf Atmos Relief Valve MS-PV-3001 CP-108 A SG BPW Atmos Relief Valve MS-PV-3002 CP-108 B SG EPW- Atmos Relief Valve MS-PV-3003 CP-108 A SG D Atmos Relief Valve MS-PV-3004 CP-108 3 MS Isol Valves MS-V-86/88/90/92 CP-108 A MS Isol valves MS-V-86/88/90/92 CP-108 B Pressurizer Heaters Group A CP-108 A Pressurizer Heaters Group B CP-108 B Charging Pump CS-P-2A BUS 5 SWGR Charging Pump CS-P-2B BUS 6 SWCR MAY 171986

m __-

$$khlhPW&!':,

~

e + -

.; , g.e v f., - _

o ,

.3

,Y i

N , 'Wd;"hh <

l INSTRUMENTATIS > .~* .. j ACCIDENT MONITORING INSTRUMENTATION

l

. LIMITING CONDITION FOR OPERATION ' !

3.3.3.6 The accident monitoring instrumentation channels shown in Table 3.3-10 _

j shall be OPERA 8LE.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With the number of OPERABLE accident monitoring instrumentation ~

channels less than the Total Number of Channels shown in~

Table 3.3-10, restore the inoperable channel (s) to OPERABLE status within 7 days, or be in at least HOT STAN08Y 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 following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. With the number of OPERABLE accident monitoring instrumentation channels except the containment atmosphere-high range radiation monitor, less than the Minimuni Channels OPERA 8tE requirements of Table 3.3-10, restore the inoperable channel (s) to OPERA 8LE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least NOT STAND 8Y 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 following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

c. With the number of OPERABLE channels for the containment atmosphere-high range radiation monitor less than required by the Minimum Channels OPERABLE requirements, initiate an alternate method of monitoring the appropriate parameter (s), within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and either restore the inoperable channel (s) to OPERABLE status within 7 days or prepare and submit a Special Report to the Commission, pursuant to Specifi-cation 6.8.2, within 14 days that provides actions taken, cause of the inoperability, and the plans and schedule for restoring the channels to OPERABLE status.

d. The provisions of Specification 3.0.4 are not applicable.

W C

wJ X om w J$ kd'1y~

SURVEILLANCE REQUIREMENTS y

.u. ~. w f

4.3.3.6.lE ch accident monitoring instrumentation chan el hall be demonstrated OPERA :

a. Every 31 days by performance of a CHANNEL CHECX, an

b. E ery months by performance of a CHANNEL CALIBRATION.

, mW b c( LLp % ^ L 'h.p iic

.aum h Lra.rs w+ e mLy s.4. e .eegtn./ap.-,urm.c .

_.. ,gucwn .- - ~

._rura 4.3.39.2 m Yeu. -l:

! in u M -

l hhb .

~ n z u '1 -

mannar- _-

wo-- . ,.

i j Tnse.vT - s

?

I 4.3.3.6.2 Each hydrogen monitor shall be demonstrated OPERABLE by the i performance of an ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, j and at least:once per 92 days on a STAGGERRED TEST BASIS by pe'rforming a 1 CHANNEL CALIBRATION using sample gas containing:

a. Approximately one volume percent hydrogen, balance nitrogen, and

b. Approximately four volume percent hydrogen, balance nitrogen.

amp 6

9 h

MAY 171980

d I

TABLE 3.3-10 (Continued) 'M

, . . .m; ui

E h ACCIDENT MONITORING INSTRUMENTATION y = .1 g .

7 R TOTAL HINIMUM.. & .

NO. OF CHANNELS t c- INSTRUMENT CHANNELS OPERABLE ^

. q-5*

4/ core quadrant

14. Core Exit Ther ymocou_]es- 2/corequadrant:fr/Fl.

" ' N .: '

lehdcI:s mn c0u M 1 ant-Vent M ascous=Radicactiv WA$~(-y-MonT op-- .M-A.- -NA m.g j w -_ _ _ .w

- -- Co n ta i nme n t- Encl o s u re - B u i l d i ng - E f f l ue n t- Ra d i oa c ti v i ty- 1 -NA- /

j3 ft 7. ContainmentIr - aN- d h 2 1 .

/ / .F1 . Reactor Coolant system Inventory (RVLIS) 2 1 I

1 w '

l&1 . Containment Hydrogen Concentration 2 3"

cI Aw t.' . Intermediate Range Neutron Flux 2 1

-< 4 .

' , *:7 $21. Intermediate Range Neutron Flux Rate 2 1

~2 E3 -22.--Source-Range-Neutron-Flux 2- cc 23 Power-Range-Neutron-Flux -

-- 2 -1 -

~

g 2/ Penetration 1/ Penetration j }Jfy4 Containment Isolation Valve Positio

f

- ' 11 Containment Enclosure Negative Pressure 2 1 .

'ltf 95..

4 -26. ensate-Storage-Ta 2 _ _

1 7

g}

, (/n.) ,a0 e s.s Jr.w. re > n .y r. r sn..e - u.a x -

! F Applies to penetrations with 2 active valves in series. These valves are moved to the closed lp ion by automat l j4 r~ c - t... r u... , n.n w.x w a .., ,,,,,x y n s a ,,,.- ,.~ & ? 7 7 t < < .h a. fc h ys,

.L.& co - ..

m -

g m -

a

n ___

a w ..y

?

y. . . . - .' ~1 -

s p

-6

'*7 ,.

{'

L'i p *(

{ .

I INSTRUNENTAT E W .

c, . - .

FIRE DETECTION INSTRUMENTATION

.LINITING CONDITION FOR OPERATION 1

3.3.3.7 As a minimum, the fire detection instrumentation for each fire detection l zone shown in Table 3.3-11 shall be OPERABLE.

Whenever equipment protected by the fire detection instrument APPLTCABILITY_:

is required to be OPERA 8LE.

ACTION:

a. With any, but not more than one-half the total in any fire zone, Tye. X -Function-A-fire detection instruments shown in Table 3.3-11 restore the inoperable instrument (s) to OPERABLE status within 14' days or within the next I hour establish a fire watch patrol to inspect the zone (s) with the inoperable instrument (s) at least once per hour, unless the instrument (s) is located inside the containment, then inspect that containment zone at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months (or monitor the containment air temperature at least once per hour at the locations listed in Specific _ n4.6.1p.

s X Feyn?:-

et fire detection instruments '

b. With more than one-half of th noperable, or with any in any fire zone shown in Table Type y -Function-s fire detection instruments shown in Table 3.3-11 Table 3.3-11 inoperable, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months establish a fir to inspect the zone (s) with the inoperable instrumen ment, then inspect that containment zone at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ',

(or monitor the containment air temperature at least once per hour

at the locations listed in Specification 4.6.1.j).

c. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

' SURVEILLANCE REQUIREMENTS 4.3.3.7.1 Each of the above required fire detection instrumentsEwhich areonce a'. teost acenssible durina plant operation shall be demonstrated OPERABL Tir&

per 6 months by performance of a TRIP ACTUATING UtVICE OPERATIOHF f detectors which are not accessible during plant operation shall le demonstrated I

OPERABLE by the performance of a TRIP ACTUATING DEVICE OPERATIO each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless performed in the previous 4.3.3.7.2 The NFPA Standard 720 supervised circuits supervision associated t I with the detector alarms of each of the above required fire detection instrumen s shall be demonstrated OPERABLE at least once per 6 months.

4.3.3.7.3 The nonsupervised circuits, associated with detector alarms, between the instrument and the control room shall be demonstrated g OPERA once per 31 days, 3/4 3-55 4 q SEABROOK - UNIT 1 MAY 171980 L; R 5 pf ,1,

h,, 3 ,

.. : {p

nt TABLE 4.3-5 '

$ .$[<

,M.

3; RADI0 ACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS .M g J:.. a.9j, , , ; v; j o -

,~

x MLDGQ lp , . ' +

.=l3 e

SOURCE CHANNEL CNANNEL 4 OPERATIONAL Q', ;- pt: y;-

> i.t CHANNEL 5

CHECK CHECK CALIBRATION . TEST W - 6 k '

~

INSTRUMENT i; f,M ' f?

1.

Radioactivity Monitors Providing 4 .Y.fj[ N

I. - ;

Alarm and Automatic Termination '" <

of Release 1p . 4.;. ~

a. Liquid Radwaste Test Tank Discharge D - P R(3) ' 'Q(1)

I

b. Steam Generator Blowdown Flash Tank Drain D M R(3) ' Q(1)

E c. Turbine Building Sumps

> w M R(3) Q(1)

-< 1 Effluent Line D w

a 2. Flow Rate Measurement Devices f

E* D(4) N.A. R T 2) co a. Liquid Radwaste Test Tank Discharge a

D(4) N.A. R N.A.

b. Steam Generator Blowdown Flash Tank Drain ,

Circulating Water Dischar0e

N.A. N.A. N.A.

i, ,

c.

,' jf. *Tr$ e

. .y l

" Pump curves may be used to estimate flow.

, i

~ .

. .x >

. .g a

. p' f I' -

5

; co

- Crs 7

i . . p 4

t L 2 ,

a ?x . A:., :

TABLE 3.3-13 (Continued)

M g; RADIDACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION 8

9 = -

, MINIHUM CHANNELS e ,

INSTRUMENT OPERABLE APPLICABILITY ACTION ; ..

5

-4 O ~'

4.. TURBINE GLAND SEAL CONDENSER EXilAUST

~

'a . Iodine lSamplerthritada:(

1 *M 35

- t, . Particulate-Sampler - -1 *-

35 h h. Sampler Flow Rate-Monitor

- L*ne)t&t ***

1 .

NA7

Ew

x s

=<

w

Yo, W

Co C")

i

&' ) .

. l h.7,p 1 l >m

.:2P t. ..- - ;

y' 1 -

as -

esj ..- s ce en q e ;: -

5.,

bUl a T.

j ..4 e i

. . . , J udM. -

. {'l s ,y. s Sjf[ J' .

'[ , ,ij]

, ay : ,- .

~ -

_ 4 _:,

4 _, , ~

4 3/4.5 " DEASENCY CORE COOLING SYSTEMS 3/4.hN+ TORS ' -

an; .

HOT STANOSY, STARTUP AND POWER OPERATION

' LIMITING CONDITION FOR OPERATION .

3.5.1.1 Each Reactor Coolant System (RCS) accumulator shal1 be OPERA 8LE with:

a. The isolation valve open, [(,/.2 / 4 r96

m - an 6 ns,

b. A contained borated water volume of betwee$p and -

19C0 2l00 .

c. A boron concentration of between 2000-and 2600 ppe, 677

d. A nitrogen cover pressure of between 600 and:680 psig, and:

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

ACTION:

a. With one accumulator inoperable, except as a result of a closed isola-tion valve, restore the inoperable accumulator to OPERABLE status g within-1houndr 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 pT ssurizer 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 4.5.1.1.1 Each accumulator shall be demonstrated OPERABLE:

D

a. At least once per 12. hours by

1

1) Verifying, by the absence of alarms, the contained borated l water volume and nitrogen cover pressure in the tanks, and

[

l 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 l

volume increase of greater than or equal to 1% of tank volume by l verifying the boron concentration of the accumulator solution; and l

l

Pressurizer pressure above 1000 psig.

m m SEABROOK - UNIT 1 3/4 5-1 1 hE7 $ e$' ' 'M P MM 17 IBBB

~~~ ~

93. b' I t MAR 131988

tr a -

.% 4 . /- y - .

w llpF;lp;aC .% ,. _ e ,

_u . . ,

, O . -

? *.

~ - . 1 m.. . N Q ; X.Q ,. .m. l

~

EMERGENCY CORF C00 LING SYSTEMS ,

g;yy #. , .

, y ,rt ,

SURVEILLMCE REQUIREMENTS (Continued)

[ At least once per 31 days when the RCS pressure is above 2000.psig by verifying that power to the isolation valve operator.is disconnected, dy<r.emo v aLo f-the4re a ke r-4 rom -the -ciccuitNnd -

At least once per 18 months by verifying that each accumulator isola-tion valve opens automatically under each of the following conditions:

~

1) When an actual or a simulated RCS pressure signal exceeds the P-11 (Pressurizer Pressure Block of Safety Infection) Setpoint, and

2) Upon receipt of a Safety Injection test signal.

4.F. I . I. x 4.5.1.2- Eac accumulator water level and. pressure channel shall be demon- ,

strat m.ASLE: _

a. At least .... e per 31 days by the performance of an ANALOC C:!ANNEL OPERATIONAL TEST, and ,

b. At least once per 18 months by the performance of a CHANNEL CALIBRATION.

.*e--e - - * -

9 4 O W 9 68*O**N O*h O 6

mg O

O e

MAY 171986 WOMR_o mutiL3 3/4 5-2 j

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4

]

BORON INJECTION SYSTEM

. mQ #9 s . *3 .

3/4.5.4 REFUELING WATER STORAGE TANK LIMITING CONDITION FOR OPERATION 3.5.4 The refueling water storage tank (RWST) shall be OPERABLE with:

/'/'1 e d

a. A minimum contained borated water volume of 479, 0 gallons,

b. A minimum boron concentration of 2000 ppe of baron,.

40

c. A minimum solution temperature of 35'F, and

d. A maximum solution temperature oo.100*F.

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

ACTION:

With the RWST inoperable, restore the tank to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT STANDBY within 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 4.5.4 The RWST shall be demonstrated OPERABLE:

a. At least once per 7 days by:

1) Verifying the contained barated water volume in the tank, and

2) Verifying the baron concentration of the water,

b. At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying the RWST temperature.

F- -

~ - - - . -

MAY 171980 l

.p. D ; gg a SEABROOK - UNIT 1 3/45-)0 ,- >

I( '

MAR 131888

o . . - .

}j;ph!{b g a

.Q s vs. wp

+

y t

3/4 M M AIh dNT SYSTEMS

, ,p*;.w 3/4.6.1" PRIMMtY CONTAINMENT ,

CONTAINMENT INTEGRITY 5

LIMITING CON 0ITION FOR OPERATION An.y u v.s

3. 6.1.1 , CONTAINMENT INTEGRITY shall be maintained.

APPLICA81LITY: MODES 1, 2, 3, and 4.

o ACTION: g '

Without urima CONTAINMENT INTEGRITY, restore PRIMARY CONTAIlG9ENT INTEGRITY within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least NOT STAN08Y 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 4.6.1.1 ONTAINMENT INTEGRITY shall be demonstrated:

a. At least once per 31 days by verifying that all penetrations

not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or deactivated autoe stic valves secured in their posi,tions except.as provided in Tabla 3.6-2 of Specification 3.6.3.1;

b. By verifying that each containment air lock is in compliance with the requirements of Specification 3.6.1.3; and

c. After each closing of each penetration subject to Type B testing, except the containment air locks, if opened following 'a Type A or B 99 test, by leak rate testing the seal with gas at a pressure not less than P 46:8 psig, and verifying that when the measured leakage rate for these seals is added to the leakage rates determined pursuant to Specification 4.6.1.2d. for all other Type B and C penetrations, the combined leakage rate is less than 0.60 L,.

Except valves, blind flanges, and deactivated automatic valves which are located inside the containment and are locked, sealed, or otherwise secured in the closed position. These penetrations shall be verified closed during each COLD SHUTDOWN except that such verification need not be performed more often than once per 92 days.

7O SEABROOK - UNIT 1 M.y/3,~1980

- 1

p px o iQ k.] .'l pA j.

MAR 131986

~

}

. $ v i CONTAIN E SYSTEMS 1 -

l CONTAINNENT LEAXAGE g

~

LIMITING CONDITION FOR OPERATION ,

.j 3N.1. Containment leakage rates shall be Ifmited to: *

a. An overall integrated leakage rate of:

Less than or equal to L,, 0.15% by weight of the containment air per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months at P,,- ;p ,

M Vf. 4

b. A combined leakage rat __ ' - '2; . .60 L, for all penetrations and valves subject to Type B and C tests, when pressurized to P,.

No individual penetration will be allowed to exceed 5% of the total allowed (0.05 L,); and

c. A combined leakage rate of less than or equal to 0.60 L, for all penetrations identified in Table 3.6-1 as secondary containment

) bypass leakage paths when pressurized to P,.

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

ACTION:

With (a) the measured overall integrated containment leakage rate exceeding 0.75L,,or(b)themeasuredcombinedleakagerategrallpenetrationsand valvessubjecttoTypesBandCtestsexceeding.h.-75L,,or(c)thecombined bypass leakage rate exceeding 0.60 L,, restore the overall integrated leakage rate to less than or equal to 0.75 L, as-applicable, the combined leakage rate for all penetrations and valves subject to Type B and C tests to less

.so '

than c75'L,, and the combined bypass leakage rate to less than 0.60 L, prior to increasing the Reactor Coolant System temperature above 200 F.

l e'

p -

j y n -

~

MAY 171986 c , I' i

~ ' ~ '

SEA 8 ROOK - UNIT 1 3/4 6-2 l _

' h !4 lf88 . _ - -

% gy z y a ;4 s' ~

p -

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p yl

4 1

- n an: , s CONTAINfENT' $YSTEMS * ,

, g s@ w SURVEILLANCE REQUIREMENTS 4

4.6.1.2 The c.ontainment leakage rates shall be demonstrated at the following test schedule and shall be determined in conformance with the criteria specified in Appendix J of 10 CFR Part 50 using the methods and provisions of ANSI /

N45.4-p972[:

a. Three Type A tests (Overall Integrated Containment Leakage Rate) shall be conducted at 40 + 10 month during shutdown at a pressure not less than either P,, 46.-& psig, . ring each 10 year service period. The third test of et sh be conducted during the shutdown for the 10 yea ervice inspection;

b. If any periodic Type A fails to meet 0.75 L,, the test schedule for subsequent Type A tests shall be reviewed"and approved by the Commission. If two consecutive Type A tests fail to meet either-0.75 L,, a Type A test shall be performed at least every 18 months until two consecutive Type A tests meet either 0.75 L, at which time the above test schedule may be resumed;

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

1) Confirms the accuracy of the test by verifying that the supple-mental test result, L ,cminus the sum of the Type A and the super gu:S ;

imposed leak, L,, is equal-to-orbess-than 0.25 L,; -

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

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

d. Type B and C e ss conducted with gas at a pressure not less than P* 46.8' psig, at intervals no greater than 24 months M

except for t,ests invo% <lving:

1) Air lock ,

2) Purge supply and exhaust isolation valves with resilient material seals, 3)-Penetrations-using continuous Leakage Monitoring-Systems. -

--a n d -

MAY 171980 SEABROOK - UNIT 1 3/4 6-3 g

h. l[)A

!- Q .lQ t

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m i k

. 210' ?!' , S TABLE 3.6-1 -

. .(

~

SECONDARY CONTAIN:-iENT BYPASS LEAKAGE PATHS (continued) ,

~ -

PENETRATION-NO. FUNCTION RELEASE LOCATION Chemical and volume Control Primary Auxiliary Building

)(-37B (Excess Letdown) e p Fire Protection Fire Water Pumphouse/ Fire X- 38/76A Water Tanks

)(-38/76B Combustible Gas Control fld" 6d M M 1^

Pipe c.h.se-Spent Fuel Pool Cooling and Fuel Storage Building K-39 Cleanup Nitrogen Gas (Low Pressure) Primary Auxiliary Building

[-40A PRT Sample Primary Auxiliary Building K^- ~6L 408 cael Texasfe r Ta bc. n.s % ss,ga ex;ldins

% - 67 Service Air Main Steam and Feedwater Pipe Chase ,

Lead Detection Ma,;it 5 tea.M (L.A J Fe.edwud e r

%-710/740 Pi p s C.ht;.S=-

HVAC-1 Containment Air Purge Primary Auxiliary Building HVAC-2 Containment Air Purge Primary Auxiliary Building Ep;pment t!.dc. h Da tsi d e

- p_ ,,c / ti d d /da:n stum ud ?" W "

-- P;p_s Chx e-Y U MbUSh(Ak) C hl1S (DNf0 NcLhrt $ fem am<l l'kt)k/tt CV A)e Gase.

kN MAY 171930 3 i g ,7 SEABROOK - Ut!IT 1 3/4 6-6 .

}'j 1 4

tr- 3 - .

x',%' }ll;L .,. <[

-~

37 ,

i" 4

. v

QMW '"

4 h t Q Q M.s e +

CONTAI :$YSTEMSj ' .

V CONTAINMENT AIR LOCKS LIMITING CONDITION FOR OPERATION

3. 6.1.,3 Each containment air lock shall be OPERA 8LE with:

a. Both doors closed except when the air lock is being used for normal transit entry and exit through the containment, then at least one air lock door shall be closed, and

b. An over r lock leakage rate of less than or equal to 0.05 L*

at P, g.

49 G APPLICABILITY: , 2, 3, and 4.

ACTION:

a. With one containment air lock' door inoperable:

1. Maintain at least the OPERABLE air lock door closed and either restore the inoperable air lock door to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or lock the OPERABLE air lock door closed,

2. Operation may then continue until performance of the next required overall air lock leakage test provided that the OPERABLE air lock door is verified to be locked closed at least once per 31 days, ,

3. 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 SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , and

4. The provisions of Specification 3.0.4 are not applicable,

b. With the containment air lock inoperable, except as the result of an inoperable air lock door, maintain at least one air lock door closed; restore the inoperable air lock to OPERABLE status 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 SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

to rep.:e ca a mc.u/e P E.<e y t 6 .r;,,.s egry iu w dn r a cumg\a%ie -%e no ygg33gggg

+o uc.eed ikoav pe y ear. /

p ?, f]

&L SE R 9 ' \ [.\

Nti 1 MAY 17 IB00 } _ _ . . - .

n - - - - - -

6 O-

. . t g.9 ~ ,

MRpy _ l

. CONTAll8E S SYSTEMS' SURVEILLANCE REQUIREMENTS 4.6.1.3 Each containment air lock shall be demonstrated OPERA 8LC:

a. Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months following each closing, except when the air lock is

,then at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , by being used verifying for seal that the multfple entries,'is less than 0.01 L,as determined leakage by precision flow measurements when measured for at least 30 . . . .

within the volume between the seal at a constant pressure of 78'ps g, b

. By con ting overall air lock leakage tests at not less tha ,

, (, '46.8 g, and verifying the overall air lock leakage rate is wi in imit:

1) At least once per 6 months

and FQ,M -

2) Prior to establishing CONTAINMENT INTEGRITY when maintenance has been performed on the air lock that could affect the air lock sealing , capability.**

c. At least once per 6 months by verifying that only one door in each air lock can be opened at a time.

The provisions of Specification 4.0.2 are not applicable.

- This represents an exemption to Appendix J, paragraph III.D.

of 10 CFR Part 50. (li,)lh86

.J

~~

SEABROOK - UNIT 1 3/4 6-8 5 p 7q

)

MAY 171986 b] i _ b( 2I

m ..

. I

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3-

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. l CONTAIW WIT SYSTEMS l INTERNAL PRESSURE a' i

LIMITING CONDITION FOR OPERATION e

3.6.1.4 ' Primary containment internal pressure shall be maintained between 14.6'#and 16.2 psia.

APPLICA8ILITY: MODES 1, 2, 3, and 4.

ACTION:

With the containment internal pressure outside of the Ifmits above, restore the internal pressure to within the limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least NOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REOUIREMENTS 4.6.1.4 The primary containment internal pressure shall be determined to be within the limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

A

^ ~ s P-cu,n f ee:.s mea Fg u ess we ^"n 3 t There ,, ,, a lowe.- Ik;f en

%e u.r { a: u, c. 1 o., l, n e p . y e s.gp ly fa., is of al:3 a.ul tkt s% p t, n /sc s ute c p e,, a s, <, tf a w a. ,4 f

i

,,,(e ,fic c. I' c 1 1. 4 .1. 7

' *. In,, . .I .n, >v v .,!. sia

- JI-cn=

i ,

z a,, ; z un sns

s. MAR 13198

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f - -( ' .

l if ROOK - UNIT 1 MAY 171980

. ., l . ,

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1 3/4.6.2 DEPRESSUR!.;ATION AND COOLING SYSTEMS ' ,t

, . . w ,e . ~ '

- CONTAINMENF iPMY'SYSTE'M LIMITING CONDITION FOR OPERATION ,

.. m-- .--

3.6.2.1 Two independent Containment Spray Systems shall be OPERABLE with each Spray System capable of taking suction from the RWST and transferring suction to the containment sump.

c APPLICA8ILITY: MODES 1, 2, 3, and 4.

ACTION:

qg g_yS WithoneContainmentSpraySysteminope,rable,restorethhinoperableSpray System to OPERABLE status within 72-hours-or be in at least HOT STANOBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the inoperable Spray System to OPERA 8LE 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 REOUIREMENTS 4.6.2.1 Each Containment Spray System shall be demonstrated OPERABLE: -

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

b. By verifying, that on recirculation flow, each d':'v a g , discharge pressu m of greater than orOsig' m when equal to< g mp ddv tested pursuant to Specification 4.0.5; g,g! d

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

1) Verifying that each automatic valve in the flow path actuates to its correct position on a Containment Pressure-Hi-3 test signal, and

2) Verifying that each spray pump starts automatically on a Containment Pressure-Hi-3 test signal. ,

d. At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

MAR 131988 MAY 171930 1 -

SEABROOK - UNIT 1 3/4 6-14 1

i'&4 ak 3 n Wtji

_ _ _ _ _ _ . _ .J

.... o y s

.x .

y

+ I CONTAINMENT SYSTEMS

. ^ , hfht.

4 SPRAY ADDITIM SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.2 The Spray Additive System shall be OPERABLE with: f l 9WD j As ay additive tank:tontaining a volume of betweel JL500- 1d j n,

g p 326e gallons of between 19 and 21% by weight NaOH si e

and 4

. wo gravity. feed paths each capable of adding NaOH solution from the chemical additive tank to the Refueling Water Storage Tank.

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

ACTION:

l With the Spray Additive System inoperable, restore the 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 Spray Additive 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 REOUIREMENTS 4.6.2.2 The Spray Additive System shall be demonstrated OPERABLE:

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

b. At least once per 6 months by:

1) Verifying the contained solution volume in the tank, and

2) Verifying the concentration of the NaOH solution by chemical analysis,

c. At least once per 18 months, during shutdown, by verifying that each automatic valve in the flow path actuates to,its correct position on a Containment Pressure-Hi-3 test signal;.and.

MAR 131986 MAY 171930 T h T ?) p, 3/4 6-15

N! I.\ "N A u

SEABROOK - UNIT 1 .___

J l

n _

y > +; T , , . ,

i ,

. , w

)

- .r- -

TABLE 3.6-2

?g.qf z,- ~

l

~

CONTAINMENT ISOLATION VALVES

[$s'~

^; (continued)

B. PHASE "B" ISOLATION MAXIMUM ISOLATION TIME FUNCTION (Seconds)

VALVE NUMBER 10

< * ** CC-V57 PCCW Loop A Supply 10 CC-V121 PCCW Loop A Return 10 CC-V122 PCCW Loop A Return 10 CC-V168 PCCW Loop A Supply 10 CC-V175 PCCW Loop B Supply 10 CC-V176 PCCW Loop B Supply 10 CC-V256 PCCW Loop B Return 10 CC-V257 PCCW Loop B Return

-RCP--Thermal-Barrier-Cooling 30__

CC-V10929 RCP Thermal BaTrieTCooling 20___.

4C-V1095# -

RCP-Thermal-Barrier-Cooling - 30 -

CC-V1101# -

RCP7hiirmal Barrier Cooling 20 -

CC-V1109#

C. CONTAINMENT PURGE AND EXHAUST MAXIMUM ISOLATION TIME FUNCTION (Seconds)

VALVE NUMBER Containment Refueling Purge & Exhaust /q 3 CAP (W' -u.- /1) c CAP-V2 Containment Refueling Purge & Exhaust M3 Containment Refueling Purge & Exhaust /f3 CAP-V3 CAP-V4 Containment Refueling Purge & Exhaust th Containment On-Line Purge

,2' 8 2 CDP-V1

,2 *8 d COP-V2 Containment On-Line Purge Containment On-Line Purge

,2 's 2-COP-V3 A

COP-V4 Containment On-Line Purge M48 }$ lggg ,2' i - - - - - - . . _

MAY 171930 , .

3/4 6-20

f ,~ g SEABRC0K - UNIT 1 b[,,.,. ,

v' . -- -

7 _,

, , 1

+ ..

g TABLE 3.6-2 }

,neQl,a;.u ~, ,w j

f80 , CONTAINMENT ISOLATION VALVES l

' 4. .; , ~ (continued)

E. OTHER (CONT'0) MAXIMUM I

ISOLATION TIME l FUNCTION (Seconds)

VALVE NUMBER NA CC-V474 PCCW Loop B Return Relief NA CC-V840' PCCW Loop B Supply Relief PCCW Loop A Supply Relief NA CC-V845 NA CGC-V4# Hydrogen Analyzer Outlet IRC Check '

NA CGC-V25# Hydrogen Analyzer Outlet IRC Check NA CGC-V46 Compressed Air Supply IRC Check l0hY RsRd NA CS-V794 RCPSeal/ExcessLetdownReturnCheck-Containment Demineralized Water Supply NA DM-V18 Relief NA FP-V588 Containment Fire Protection Header #

IRC Check Pressurizer Sample Relief NA RC-V312 NA RC-V314 RCS Loop 1 Sample Relief ,

NA RC-V337 RCS Loop 3 Sample Relief Reactor Makeup Water IRC Check NA RMW-V29 Refueling Cavity Cleanup Relief NA SF-V101 NA SI-V247 Accumulator Fill / Test Header Relief

- < t ,4c1I d en f NA SC-v?71 Samnlo Finsh Tank Drain IRC Check NA WLD-V209 Sump "B" to FOT Relief NA WLD-V213 POT to RC Drain Tank Relief NA RC-FV2894* RCS Loop 1 Sample

' NA RC-FV2896* RCS Loop 3 Sample

'k

{%

Not subject to Type C leakage test

May be opened on an intermittent basis under administrative.contr.o.l_...___,_

SEABROOK - UNIT 1 g4j67Q06 ,J h }\ ~T" $

M ._ C p- ;I y hahk -

M TABLE 3.6-2 CONTAINMENT ISOLATION VALVES (continued)

E. OTHER (CONT'D) MAXIMUM ISOLATION TIME VALVE NUMBER FUNCTION (SECONDS)

MS-V86 Main Steam Isolation 5 MS-V88 Main Steam Isolation 5 MS-V90 Main Steam Isolation 5 MS-V92 Main Steam Isolation 5 MS-V204 MainSteamIsolationBypash 15 MS-V205 Main Steam Isolation Bypass 15 MS-V206 Main Steam Isolation Bypass 15 MS-V207 Main Steam Isolation Bypass 15 MSD-V44 Main Steam Drain Isolation 15 MSD-V45 Main Steam Drain Isolation 15 ,

MSD-V46 Main Steam Drain Isolation 15 MSD-V47 Main Steam Drain Isolation 15 FW-V30 Feedwater Isolation 20 FW-V39 Feedwater Isolation 20 FW-V48 Feedwater Isolation 20 FW-V57 Feedwater Isolation 20 FW-V76 Feedwater Isolation Check Valves NA FW-V82 Feedwater Isolation Check Valves NA FW-V88 Feedwater Isolation Check Valves NA FW-V94 Feedwater Isolation Check Valves NA 3/y g _ MAY 171930

-o _.

l, v; ,, ~

[a,s, .h,;'

' - s 4 f.

.j' hN .

s: F .. .

CONTAINMENT SYSTEMSS 4

gi ;;;pW' A w ;t: .,

u s ~

ELECTRIC HY000SEN RECOMSINERS l

' LIMITING CONDITION FOR OPERATION' 3.6.4.2 Two independent Hydrogen Recombiner Systems shall be OPERA 8LE.

APPLICA8klITY: MODES 1 and 2. c ACTION: , g, With one Hydrogen Recombiner System inoperable, rest $r' s the inoperable system to OPERABLE status within 30 days or be in at least HOT STANOBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILl[NCEREQUIREMENTS

. 4.6.4.2 Each Hydrogen Recombiner System shall be demonstrated OPERABLE:

11,

a. At least once per,6 months by verifying during a Hydrogen Recombiner System functional test that the minimum heater sheath temperature increases to greater than or equal M ~within 90 minutes, fy g g 73tfr'Upon reaching 7008F, increase the power setting to maximum power ,p . \

for 2 mirid Q and verify that the power meter reads greater than or 80 "y T

equal 50'k ; and _ .

se Hin; c, c At least ce per 18 months by:

c En40.

b. j

1) Performing a CHANNEL CALIBRATION of all recombiner instrumentation and centrol circuits,

2) Verifying through a visual examination that;. there is no evidence of abnormal conditions within the recombinar enclosure (i.e., loose wiring or structural connections, deposits of foreign materials, etc.), and

3) Verifying the integrity of all heater electrical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than or equal to 10,000 ohms.

A sEABROOK - UNIT 1 3/4 6-24 _

Mkk))$$$

t g; c :

r L4C , f i

> d FLANT SYSTEMS }

J EMaaGENCY FREDWATER SYSTEM j LIMITIU kTIONFOROPERATION 37.l.1* %

1 SgtH W f . At least two independent steam generator emergency feedwater pumps and associated flow paths shall be OPERABLE with:

a. One actor-driven emergency feedwater pump capable of being powered from an emergency bus, and

- s.

b. ; e One steam turbine-driven emergency feedwater pump capable of being powered from an OPERABLE steam eupply system.

2. TA, da.hp feedpump anCst associafeJ flow pilh fa rk, emeryency

.gs edes+e.~ s y s i erm s 4 ll b e capa ble of bes ' kmens hwfed.

APPLICABILITY: IODES 1, 2, and 3. dAE448(f. win its er 6et suppli-d Svem an wurqt*e1 el .

ACTION:

a. With one emergency feedwater pump inoperable, restore the required emergency feedwater pump 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 . -

b. With two emergency feedwater pumps inoperableYi- 2. 4, f-'tfet :;;;;;;i.; ;;;i : :; ;.e;er; et '---* a-- -- ;;;;;

-- f::h:t : 7 ; :; ^"E = m ' -t::.. . ;;:

= = a^- 8 M : ::, 5:

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

C. uk% kath emen.n,ndM e "' M

5

ad' " $ ""*4 S u h *be i 6HfC*rech" f rnepera6IciGn SURVEILLANCE REQUIREMENTS Icot7one cenera r.w fec$terde** ous A WTkf 5Mup

-Ceed pa smo +o APE 448LE dnh'< h < s oo n asp elk'.

Thr p.vusiions cri SpectVtinftb4 3fd.3 are n't 8/p bic.

4.7.1.2.1 Each emergency feedwater pump shall be demonstrated OPERABLE:

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

8460 h

1) Verifying that the motor-driven pump evelops a discharge pressure of greater than or equal to psig at a recirc-ulation line flow of greater than or equal to itFgpm; 3.70

2) Verifying : hat the steam turbine-driven pump develops a discharge pressure of greater than or equal to MeedFsTg~/WO at a recirculation line flow of greater than or equal to 170 M gpm when the secondary steam supply pressure is greater than 500 psig. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3; g" ,

(Tits t we 5mfe -t% dekup -feeb f "'*P O '""'M'"N ad alqn h flow pd W "'M #' *E AO k nn A u < ~ -

mns I/1U00

_ = _ _ .

. , , l FLANT SYSTEMS ,

~

1 SURVEILLANCE REQUIREMENTS (Continued) r,

..,f.o g -

. t 4!L.,-y 31I Verifying that each non-automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in its correct position; and

4) Verifying that each automatic valve in the flow path is in the fully open position whenever the emergency Feedwater System'is placed in automatic control or when above 10%

RATED THERMAL POWER.

b. At least once' per 18 months during shutdown by:

1) Verifying that each automatic valve in the flow path actuates to its correct position upon receipt of an Emergency Feedwater System Actuation test signal.

L,

2) Verifying th' ta each emergency feedwater pump starts as de-signed autcmatically upon receipt of an Emergency Feedwater System Actuation test signal. f, p4 h

l

c. At least once per 18 months during shutdown, or following com-pletion of EFW System modifications which alter the system flow characteristica, verify flow from the condensate storage tank to each steam generator.

4.7.1.2.2 Emergency feedwater flow paths to each steam generator shall be demonstrated OPERABLE folt.owing each COLD SHUTDOWN of greater than 30 days prior to entering MODE 2 by verifying flow to each steam generator, 4.l. .2 3 The. Atedup ?.udweh PM M k JcMJ 6eE8&E1

n. a.f Jm # m p 3 I Q by

1. M .d d & FW-l% & f"*'O

E-m h n @ % q25cg m

, _ . b. e w m g tk % on-tb by .

h( #A b.4 NY* T I'Y e h**

]

A e~e n- J MAY 171930

n ______ ;

,kkib.hf lQ y: '

3

d@ @ c

, , 3

vjjm@,l@ . If, m, ' '

b

.g h$Q T -

PLANT SV ,

COHOENSATE STORAGE TANK ..

~

j LIMITING CONDITION FOR OPERATION m.

tank (CST) system shall be OPERABLE with

~

3.7.1.3 The condensa

a. A volume o lions of water contained in the condensate C' storage ta ,

-th--. A-concrete-CST-enclosure-that-is-capable-of-retaining-210;000-13al-

-lons of--water:

c. -The condenser ndt vell-and-the-deminerattf1RI Water'stTFTgartank-0PERABLE-as-backup-supply of-210;000 gaHons of wateer APPLICABILITY: MODES 1, 2, and 3.

ACTION: ,

With the CST or-the. CST-enclosure inoperable, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either:

a. Restore the CST .and -the-CST enclosure to OPERABLE status or be in at least HOT STANCBY 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 folicsing 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , or

b. -Demonstrate-the-OPERABILITY-of-the-condenser-hot-wel-1-and-the-demin -

eralized-water-storage-tank-as a backup supply-to-the-auxiliary-feed--

water pumps and restore-the-CST-to-OPERABLE-status-within-7-days--

.cc be-in -at-least-HOT-STANDBY-within-the-next-6-hours-pnd-in-HOT ~

-SHUT 00WN 71 thin the-fo11cwing-6-hours.

SURVEILLANCE RECUIREMENTS 4.7.1.3.1 The CST and-the-CST-enclosure-shall be demonstrated OPERABLE at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying the contained water volume is within it:

limits -and-the -CST-enclosure--integri ty-is--maintained- when the tank is the supply scur:e for the auxiliary feedsater pumps.

4.-7.-Ir3.2 -The-condansa _ hot _well and the damineralized-water-storage tank.-.,

-shall-be-demonstrated OPERABLE at_].eas.t_onca-per-12-hours-by -verifying..the -

-availability o f -210,-000 gallons .cf.-water-whenever-the condenser-hot-well-and-the-demineralized water-storage-tank-is -the-supply-source-for-the auxiliary -

-f e edwa t e r pump s .--- -.

MAR 131986 MAY 171986 Ti'3 7 l P. ~~3. ?T,i Mal-s -. &

m . . - .

~ .- ;

)]

PLANT SYSTEM 57

. g ? XM : ,s i

3/4.7.3 ' PRDIARY COMPONENT COOLING WATER SYSTEM -

1 LIMITING CONDITION FOR OPERATION I

.i 3.7.3 At least two independent primary component cooling water loops shall be OPERABLE.

APPLICA8ILITY: MODES 1, 2, 3, and 4.

e ACTION:

With only one primary component cooling water loop OPERA 8LE, restore at least two loops 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 STAN08Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REOUIREMENTS 4.7.3 At least two primary component cooling water loops shall be demonstrated OPERABLE:

a. At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured in position is in its correct position; and

b. --- At least once per 18 months during shutdown, by verifying that:

1) Each automatic valve servicing safety-related eq0ipment actuates to its correct position on its' associated Engineered Safety Fea-ture actu gnal, and lemy

2) Each pri ary Co nent Cooling Water System pump starts auto-matica11, f oss u o' start of-the r~edundant pump'

.within the. loop. * <; - n .-

t l

powee +esy l

l l MAR 131986 .

7 g _

'. W t '. ,! ,J MAY 17193G 1 7 !.

_ ./. , .. . a 2Q y,'

SEABROOK - UNIT 1 3/4 7-11 ,

{

y -_-,_.,.w._. --.--.-y , _ _ - . - - . -

/s .- .

~

l ~. '~. 3 _.

Oif;~y y[]'

y Q' ' }7c 3 ,(

3

.m

. v,a.. . , -

' b 3 I..

~

}

PLANT SYSTEM 5s M s,, +

}.- p fji]. 8 ."? . - -

)

~ _!

3/4.7.4*St . WATER SYSTEM - -

~

y ;>.u -

LIMITING CONDITION FOR OPERATION , )

joa ps 3.7.4 At least two independent service water systems shall be OPERA 8LE.

APPLICA8ILITY: MODES 1, 2, 3, 4.

ACTION:

With only one service water loop OPERA 8LE restore two loops 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 STAN08Y 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 4.7.4 At least two , Station Service Water ys s- shall be demonstrated OPERABLE:

a. At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured in position is in its correct position; and

b. t least once per 18 months during shutdown, by verifying that:

1) Each automatic valve servicing safety-related equipment actuates to its correct position on its associated Engineered Safety Fea-ture actuation test signal, and ,

2) Each Station Service Water System pump starts automatically 9

-thuredundant pump within the-loss of e- ail c 2 ." av 1oop.. hower kk, ::J: y [

i i r -- -MAR 131986 -

I i .;

l MAY 171986 ' 3 .

I. .

SEABROOK - UNIT 1 3/4 7-12 ,J', - l.i

l

-. : c l

i PLANT SYSTEMS , .

t .A.

SURVEILLANCE pavu!REMENTS 4.7.8.1.1 The Fire Suppression Water System shall be demonstrated OPERABLE: ,

a. At least once.per 7 days by verifying the contained water supply volume,

b. At least once per 31 days by starting the electric motor-driven pump and operating it for at least 15 minutes on recirculation flow,

c. At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) in the flow path is in its correct position, IL

d. At least once per',d months by performance of a system flush,

e. At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel, f.

At least once per 18 months by performing a system functional test which includes simulated automatic actuation of the system throughout-its operating sequence, and: .

1) Verifying that each automatic valve in the flow path actuates to its correct position, Verifying tha develops at least 1500 gpm at a 2) system head f -250 feet, W A77 ow path that is not testable during

3) Cycling each v in the_

plant operation through at least one complete cycle of full travel, and

4) Verifying that each fire suppression pump starts sequentially:

to maintain the Fire Suppression Water System pressure greater than or equal to 120 psig.

g. At least once per 3 years by performing a flow test of the system in accordance with Chapter 5, Section 11 of the Fiie Protection Handbook, 14th Edition, published by the National Fire Protection Association.

MAY 171986 3j886 . _ _

% m, e T' '

~-

' I

fI '

/\

3/4 7-24 SEABROOK - UNIT 1 7~n [

^

l

J-j ~ , ' - ,

g, ;,

- l s ,

,s i 3 l

- , . ~

~

a ,

, , . w .

9;ym ,

.x_.

sw -

d.!

4

.s 4 % ;f!h -.w

sM' </ Table 3.7 *

~ @* RQgp/:

Mqt:E Area Temperature Monitoring Area Temperature Limit (*F) 97 'l f

1. Control Room 49,5-soy ;

2 .- Cable Spreading Room *

-99,& soy

3. Switchgear Room - Train A* 99,& 40Y

4. Switchgear Room - Train B* 15-

90. 5. Battery Rooms - Train A 9&d 9#

6. Battery Rooms - Train B

7. ECCS Equipment Vault - Train A S94 e# T ECCS Equipment Vault - Train B -9975 /* Y

8. 9915 /dY

9. Centrifugal Charging Pump Room - Train A Centrifugal Charging Pump Room - Train B 99r5 /0V

10. / o '/

11. ECCS Equipment Vault Stairwell - Train A <* Y

12. ECCS Equipment Vault Stairwell - Train B 49 ,5 /dY

13. PCCW Pump Area Cooling Tower Switchgear Room - Train A* 99T3- / /

14. 99,5 /dV

15. Cooling Tower Switchgear Room - Train B*

16. Cooling Tower SW Pump Area

M 1 A*7

17. SW Pumphouse Electrical Room - Train A* 99 $ IJY SW Pumphouse Electrical Room - Train B* 99r5- t o V 18 997$ id Y

~

19. Sw Pump Area

4Mr5 t 'o

20. Diesel Generator Room - Train A*

Diesel Generator Room - Train B* 1+5v4 # M

21. 99v5 /?1 _. .

22. EFW Pumphouse _

23. Electrical Penetration Area - Train A 9-3vr TI

24. Electrical Penetration Area - Train B SGW 6

25. Fuel Storage Building Spent Fuel Pool 99r5-'#/

Cooling Pump Area

26. Main Steam and Feedwater Pipe Chase - East IMd /JO Main Steam and Feedwater Pipe Chase - West 12-sv5- e30 27.

Mild Environment Area MAY 1719B6 w w&M 3jv p 33

<a __ _

g. . ;; c, '

l 2?g. ' ' ' ' ' :. - :

e q -

g; ; m ~

. ELECTRICAL POWER SYSTEMS *

.i1

~

m. m .m

. A.C. SOURCE 5M;'jy[y') >j f- .

. . e. '

SHUT 00WN LIMITING CONDITION FOR OPERATION

/

e*

3.8.1.2 As a minimum, the following A.C. electrical power sources shall be OPERABLE:

a. One circuit between the offsite transmission network and the Onsite Class 1E Distribution System, and

b. One diesel generator with:

1) A day fuel ' tank containing a minimum fuel volume fraction of 3/8 (600 gallons of fuel),

60/0C0

2) A fuel storage system containing a minimum volume of S57000 gallons of fuel,

3) A fuel transfer pump, ,

4) -Lubricating oil storage containing a minimum total volume of 275 ga11ons of lubricating oil, and

5) Capability to transfer lubricating oil from storage to the diesel generator unit.

APPLICABILITY: MODES 5 and 6.

-ACTION:

With less than the above minimum required A.C. electrical power sources OPERABLE, immediately suspend all operations involving CORE ALTERATIONS, positive reactivity changes, movement of irradiated fuel, or crane operation with loads over the fuel storage pool, and within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , depressurizegd_.-/.f3 vent the Reactor Coolant System through a greater than or equal to 3:2 square inch vent. In addition, when in MODE 5 with the reactor coolant loops not filled, or in MODE 6 with the water level less than 23 feet above the reactor vessel flance, immediately initiate corrective action to restore the required sources to OPERA 8LE status as soon as possible.

SURVEILLANCE REQUIREMENTS

4. 8.1. 2 The above tequired A.C. electrical power sources shall be demonstrated 0PERABLE_by_the_ performance of each of the requirements of Specifications

[-_4r8-1--l--1, ' ' '

fexcept for Specification 4.8.1.1.2a.6)), and 4.8.1.1.3.

'.? 1.1 / n v. 7. /. /. 2 q\ i f}l gQ SEABROOK - UNIT 1 3/4 8-9 MM l)ll$$ j j,k ,{g ~1 /

s

. f.

- ~ - . - _ . _ _

O --

~

xy y .. 6-L

.- 7 .

.,4' 7

r += , .

i

. . 1 w%pikf,ei < ;,2 ..y..e.*

k* ;h y ,

tp_" TABLE 3.8-2 .. :

MOTOR OPERATED VALVES WITH TERMAL OVERLOAD ,

m _

PROTECTION DEVICES OPERABLE AT ALL TIMES l Valve Numb Function / System J MS-V204 l

Main Steam Isolation Bypass * *

{ MS-V205 f Main Steam Isolation Bypass MS-V206 Main Steam Isolation Bypass j M1-V207 Main Steam Isolation Bypass

% y -V22 Reactor Coolant Loop 1 (RHR) pf-RC-V23 Reactor Coolant Loop 1 (RHR)

M RC-V87 Reactor Coolant Loop 4 (RHR) pfrRC-V88 Reactor Coolant Loop 4 (RHR) ffrRC-V122 l Reactor Coolant Pressurizer pfRC-V124 Reactor Coolant Pressurizer RH-V35 Residual Heat Removal f . . . . ..

f RH-V22 Residual Heat Removal .

RH-V14 Residual Heat Removal l

RH-V70 Residual Heat Removal RH-V36 Residual Heat Removal RH-V21 Residual Heat Removal f M C-V323 Reactor Vessel Head Vent Residual Heat Removal

[dK-V26 p.AC-V32 Residual Heat Removal pE-hCV-611 Residual Heat Removal Residual Heat Removal

$.N/-CV-610 -

MAR 131986

-- ~

pfSI-V3 Safety Infection Accumulators F g g n 1986 ~ ]. ~ '

~ ' ' " ' ~

SEABROOK - UNIT 1 3/4 8-58 . . _.[ . !

~ .~ -- -.

w.. t 4 _, ;,; ..

-g y - :& v . m .- _

1

<- ~

.y _ ,

~ng, <... , i au(/,.; 4 Mia.g2..31

. . 3 TABLE 3.8-2 (Continued) ,,

ValveNumberN Function / System

.ff5I- '

Safety Infection Accumulators ,

ffSI-V32 Safety Injection Accumulators SI-V47 5 Safety Injection Accumulators . .

s. ' s- 'A , ; p C36-et@-V47 Safety Injection Cold Leg C36-GtWV49 Safety Injection Cold Leg .

CS-V460 Safety Injection Cold Leg Safety Injection Cold Leg

( CS-V461 CS-V475 Safety Injection Cold Leg .

I 61 -G9-V90 k Safety Injection Cold Leg SI-V112 Safety' Injection C'old Leg SI-V114 Safety Injection Cold Leg

(', M 4R$-V51 Safety Injection Cold Leg c.,66GRG-V53 Safety Injection Cold Leg SI-V89 Safety Injection Cold Leg ,

t FW-FV-4214A Feedwater FW-FV-42148 / Feedwater V

Feedwater FW-F)f-4224A l'

l FW-F 42248 i Feedwater

, FW-FV-4234A Feedwater

/

FW-FV-4234B ; Feedwater FW-FV-4244A Feedwater In se F FW-F -42443 Feedwater LV-

--~)

SI-V93 Safety Injection Safety Injection _. ._

- - g g j3 l g .

{

MAY 171986 b _iN

)g ,

^'

{i l

i i

~

3/4 8-59 ;j / ~ - ^ ~~

i SEABROOK - UNIT 1 l

L _ _ _ - - -

[

t I

l

. . . - ]l j,

mag 2. -

, . jigyr,;+- ,- ".^ ;

aE8.&

. ~' ,

e TABLE 3.8-2 (Continued) .,

g alve Number Function / System C V-- ": :- I-j eth-l C VC- Evi v . I..j;;thr SI-V138 Boro'n' Injection - -

SI-V 9 Boron Injection SI-V10.2 -Boron Injection SI-V77 Boron Injection CS-V142 Chemical and Volume Control CS-V143 Chemical and Volume Control

-YRS-V149 Chemical and Volume Control

-V154 Chemical and Volume Control CS-V158 Chemical and Volume Control CS-V162 Chemical and Volume Control CS-V166 Chemical and Volume Control S-V167 Chemical and Volume Control .

Chemical and Volume Control ffCS-V168 CS-LCV-112B Chemical and Volume Control CS 1CV- Volume Control

/ m

, -CS-V544 Bus v . Injectiv..

-GS- V545 Evi vi. Isijeuiva CS "040 Scr r hjmuvi.

j iO47 Ov vi. Inject. ion VV .

CS-V196 Chemical and Volume Control CS-V197 Chemical and Volume Control CS-V426 Chemical and Volume Control - Eemergency Boration .

MAY 171986 m- '

SEABROOK - UNIT 1 3/4 8-60 -

~ ~ -

. MAR 131986 ,

s -

~~

, , , . -, a :# '

P-4

[ ' ', ' , < > (_ , f[f, .^ ,

- (. 3

, < ,7 4

.{ , ~ . . .

y; g '

j Y#' ~ h: fp[4gg.

. . N-l;ld n3/,r g$ Wb'ih%iY TABLE 3.8-2 (Continued) ,,

ValveNumbeb.E- Function / System

. SW-V54. Service Water SW-V25 Service Water SW-V4 Service Water .- .

SW-V5 SfrviceWater n -. ace-SW-V74 Service Water SW-V76 Service Water r SW-V19 Service Water SW-V2 Service Water ,

SW-V22 Service Water s SW-V29 Service' Water SW-V31 Service Water SW-V20 Service Water SW-V27 Service Water SW-V56 Service Water .

SW-V23 Service Water SW-V34 Service Water SW-V15 Service Water SW-V17 Service Water SW-V26 Service Water f

f SW-V55 Service Water

/ -

Combustible Gas Control l ((CGC-V14 fMGC-V28 Combustible Gas Control

-V38 ECCS/CS Fluid Supplies f

CBS-V43 ECCS/CS Fluid Supplies _. _ MAR.131986 a f

s 7g l

MM 171BBB

_ ,_T . . . '

n . ' r, ' q l l

1 i

3/4 8-61 L.: / s a c. J. A *, -a

{

SEABROOK - UNIT 1 l

f

.- p m.g.;;bqi5 . ..

q n . . a x. ; 4 +_ s c;- . .

A

, . M a.; v 7 - N .c ,

y -

1 .

i>

a i . a uk e .c.....V

~ rqg?;y4 s ; :;

a;jf,,t ? g~

TABLE 3.8-2 (Continued) i ValveNumbed:5 ,

Function / System CS-LCV-1120 ECCS/CS Fluid Supplies CS-LCV-112E ECCS/CS Fluid Supplies .

CBS-V2 ECCS/CS Fluid Supplies . .

P CBS-V5 ECCS/CS Fluid Supplies CBS-V8 ECCS/CS Fluid Supplies CBS-V14 ECCS/CS Fluid Supplies CBS-V11 ECCS/CS Fluid Supplies CBS-V17 ECCS/CS Fluid Supplies CC-V266 Primary Component Cooling iveg 5 CC-V272 Primary Component Cooling L: p S CC-V145 Primary Component Cooling

- 37 Primary Component Cooling ffCC-V395 Primary Component Cooling Thermal Barrier

~

ffCC-V428 Primary Component Cooling Thermal Barrier ,

pfCC-V438 Primary Component Cooling Thermal Earrier MC-V439 Primary Component Cooling Thermal Barrier 092 Primary Component Cooling Thermal Barrier CC-V1095 Primary Component Cooling Thermal Barrier CC-V1101 Primary Component Cooling Thermal Barrier gV11hP4marponent _C_oo,l i ng The r3aLBarri e r

> V dldo Mog O &

" p<aTd VA lluond O S m3 k Af "'

dS@

. MAR 131986 ;

MAY 17 l986 FT, .. ,

SEABROOK - UNIT 1 3/4 8-62 , ,

. ; w, . s __

~ ~ ~ ~ '

ww __,

c,., . , * . *.. >; . a "i':Qyi :C'{l. - . :.wi , __ l ' %

, a p = .a , ,....mf 6s.d f- - +

"4--

I_'t . ^*3r j ,

u_x _

j

. Inserts for Table 3.8-2

> : :.. d q

]~ ,"[:[' [~ ;ffy l.h Insert I^y,2 ' ' - - Valve Number Function / System i MSD-V44 Main Steam Drain I 5

MSD-V45 Main Steae Drain MSD-V46 Main Steam Drain MSD-V47 Main Steam Drain Insert II -

Valve Number Function / System AS-V175 Auxiliary Steam Isolation AS-V176 Auxiliary Steam Isolation Insert III -

Valve Number Function / System SW-V139 Service Water SW-V140 Service Water Insert IV -

Valve Number Function / System FW-V346 Feedwater FW-V347 Feedwater MAY 171986

n - - -

f.;fR.[ ~

f .; .

((?

e , f q 1

}

REFUELING OPERATIONS i

]

~

3/4.9.6* w e mMPUELING MACHINE i 1

y.gs_..

LIMITING CONDITION FOR OPERATION 3.9.6 The refueling machine and auxiliary hoist shall be used for movement of drive rods or fuel assemblies and shall be OPERABLE with:

,., a . The refueling machine used for movement of fuel assemblies having:

1) A minimum capacity of 4000 pounds, and Jfoo p

2) An overload cutoff limit less than or equal 9 - unds.

b. The auxiliary hoist used for latching and unlatching drive rods having:

1) A minimum capacity of 3000 pounds, and

2) A load indicator which shall be used to prevent lifting loads in excess of 1000 pounds APPLICABILITY: During movement of drive rods or fuel assemblies within the reactor vessel.

ACTION:

With the requirements for refueling machine and/or hoist OPERABILITY not satis-

.fied, suspend use of any inoperable refueling machine and/or auxiliary hoist from operations involving the movement of drive rods and fuel assemblies within

the reactor vessel.

SURVEILLANCE REQUIREMENTS Tl1 o 4.9.6.1 Each refueling mac.*.ine used for movement of fuel assemblies within the reactor vessel shall be demonstrated OPERABLE within 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior to the start fg y h operations by performing a load test of at least 4000 pounds and de nstratin automatic load cutoff when the refueling machine load exceeds 3900 pounds.

'% HoO 4.9.6.2 aux Di ia hoist and associated load indicator used for movement of drive rods nin the reactor vessel shall be demonstrated OPERABLE within 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior to the start of such operations by performing a load test of at least 3000 pounds.

Man

"-" 131986 ..

MAY 171986 .

.F i

SEABROOK - UNIT 1 3/4 9-6 a

Le o hf h. hpy m :w:R y e :+

" . A.[ >m

.L -

.- 1

<- p

.,.jb . j[

q , n, j = ; > y, r,

p. c K

-. c - 3 a

. DESIGN FEATURES :

k3 oc 5 :p ,< j 5.3' R N O,W1 Mi m

4

~~

FUEL ASSEMBL <

-5.3.1D The core shall contain 193 fuel assemblies with each fuel assembly ,q.

f containing 264 fuel rods clad witn Zircaloy-4. Each fuel rod shall have '.

a nominal active. fuel length of 144 inches and contain a maximum total weight '

/1/pf'5T4748 grams uranium. The initial core loading shall have a maximum enrichment Reload fuel shall be similar in physical design .

weight percent U-235.

d. he initial core loading and shall have a maximum enrichment of*f.d. ~ '

weight percent U-235.

CONTROL ROD ASSEMBLIES 5.3.2 The core shall contain 57 full-length control rod assemblies. The full-length control rod assemblies shall contain a nominal 142 inches of absorber material. The nominal values of absorber material shall be 80%

silver, 15% indium, and 5% cadmium. All control rods shall be clad with stainless steel tubing.

5.4 REACTOR COOLANT SYSTEM DESIGN PRESSURE AND TEMPERATURE 5.4.1 The Reactor Coolant System is designed and shall be maintained:

a. In accordance with the Code req'uirements specified in Section 5.2 of the FSAR, with allowance for normal degradation pursuant to the applicable Surveillance Requirements,

b. - For a pressure of 2485 psig, and

c. For a temperature of 650 F, except for the pressurizer which is 680 F. .

VOLUME-12 :2 ?5" .)e 5.4.2 The total water and steam volume of the Reactor Coolant System is 12,-350:

cubic feet at a nominal T,yg of 588 F.

5.5 METEOROLOGICAL TOWER LOCATION 5.5.1 The meteorological tower shall be located as shown on Figure 5.1-1.

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6.2.3 INb SAFETY ENGINEERING GROUP (ISEG) ,

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FUNCTION * .

6.2.3.1 The ISEG shall function to examine station operating characteristics, NRC issuances, industry advisories, Licensee Event Reports, and other sources of station design and operating experience information, including units of similar design, which may indicate areas for improving station safety. The ISEG shall make detailed recommendations for revised procedures, equipment modifications, maintenance , activities, operations activities, or other means of improving station safety tovos thec ."g:7 '--;' 7-Lo c7: -_

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6.2.3.2 The ISEG shall be composed of at leaMedicated, full-time engineers located on site. Each shall have a bachelor's degree in engineering or related science and at least 2 years professional level experience in his field, at least 1 year of which experience shall be in the nuclear field. '-

RESPONSIBILITIES 6.2.3.3 The ISEG shall be responsible for maintaining surveillance of station activities to provide independent verification

that these activities are performed correctly and that human errors are reduced as much as practical.

RECORDS 6.2.3.4 Records of activities performed by the ISEG shall be prepared, main-tained, and forwarded each calendar month to-the " _--hWe rvices-Manaae r-V; e ' c , ,' & L iL

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6.2.4 SHIFT TECHNICAL ADVISOR oyg/tet s--,_.- -

&c sil 6.2.4.1 The Shift Technical Advisor shall provide advisory technical s b to:the-Shif_t _ Superintendent

in the areas of thermal hydraulics, reactor engi-neering, and plant analysis with regard to the safe operation of the station.

6.3 TRAINING SbbiM 6.3.1 A retraining and replacement licensed training program for the unit-staff shall be maintained under the diraction of the Training Center Manager -

-7' and shall meet or exceed the requirements and recommendations of Section 5.5 )F / g and Appendix A of 10 CFR Part 55 and the supplemental requirements specified I in Sections A and C of Enclosure 1 of the March 28, 1980 NRC letter to all licensees, and shall include familiarization with relevant industry operational expe ri ence. f , 2 je& I;16wt

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ML20197J487

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