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Notification of 820511 Meeting W/Util in Bethesda,Md to Resolve Tech Spec Open Items Re Remote Shutdown & Accident Monitoring Instrumentation,Steam Generator,Operational Leakage & Hot Vs Cold Shutdown
	ML20053B048
Person / Time
Site:	Summer
Issue date:	05/04/1982
From:	Kane W; Office of Nuclear Reactor Regulation
To:	Youngblood B; Office of Nuclear Reactor Regulation
References
	NUDOCS 8205270689
	Download: ML20053B048 (2)
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MAY18 MAY 4 1982 q

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'c Docket flo.: 50-395

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ca MEMORANDUM FOR:

B. J. Youngblood, Chief, Licensing Branch No.1. DL FROM:

W. F. Kane, Project lilanager, Licensing Branch No. 1, DL

SUBJECT:

FORTHCOMING !!EETING WITH SOUTH CAROLINA ELECTRIC & GAS COMPANY - VIRGIL C. SUMMER NUCLEAR STATION Qag llo %

l DATE & TIME:

L. Rubenstein - Item No. 5 - 9:00- 10:00 pm T. Speis - ItemsNos. I and 2 - 10:00 am - 12:00 pm J. Knight - Item No. 4 - 1:00 pm - 2:00 pm J. Knight /W. Johnston - Item No. 6 - 2:00 pm - 3:00 pm W. Johnston - Item No. 3 - 3:00 pm - 4:00 pm LOCATION:

Room P-422 Phillips Building Bethesda, !!aryland PURPOSE:

Appeal Meeting - See attached letter T. Nichols, Jr., to H. R. Denton, dated April 19, 1982.

PARTICIPANTS:

NRC Staff W. Kane, L. Rubenstein, T. Speis, J. Knight, W. Johnston, D. Skovholt, et. al.

South Carolina Electric & Gas Company,

0. Dixon, M. Whitaker, W. Williams, R. Clary, N. Clark, 0. Bradham, M. Quinton and M. Broane W. F. Kane, Project Manager Licensing Branch No. 1, Division of Licensing i

Attachment:

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-Mr. T. C. Nichols, Jr.

Vice President & Group Executive Nuclear Operations 1

South Carolina Electric & Gas Company Post Office Box 764 Columbia, South Carolina 29218 cc:

Mr. Henry.Cyrus Senior Vice President South Carolina Public Service Authority i

223 North Live Oak Drive e

Moncks Corner, South Carolina 29461 J. B. Knotts, Jr., Esq.

Debevoise & Liberman 1200 17th Street, N. W.

Washington, D. C.

20036 Mr. Mark B. Whitaker,.Jr.

Group Manager - Nuclear Engineering & Licensing i

South Carolina Electric & Gas Company Post Office 764 Columbia, South Carolina-29218 Mr. Brett Allen Bursey Route 1, Box 93C Little Mountain, South Carolina 29076 Resident Inspector / Summer NPS c/o U. S. NRC Poute 1, Box 64 Jenkinsv111e, South Carolina 29065 Mr. James P. O'Reilly U. S. NRC, Region II 101 Marietts Street Suite 3100 Atlanta, Georgia 30303 S

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a Mr. Harold R. Denton, Director

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Washington, D.C.

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Subject:

Virgil C. Suntner Nuclear Station Docket No. 50/395 l

NRR Itens Requiring Resolution

Dear Mr. Denton:

Through formal subnittal of docunentation, and continual meetings and discussions, South Carolina Electric and Gas Conpany (SCE&G) and the NRC have resolved a large number of items requiring resolution for the Virgil C. Sumer Nuclear Station. This number is probably in the range of over a thousand. A good rapport was needed to acccrrplish this task. Many times honest differences of opinion or points of view occurred, but we were able to work out a resolutian for nest.

At this time seven items exist which in our opinion need additional discussions to resolve. We have attempted to resolve these on the reviewer level and with sme iters at the branch chief level. Howver, it is our position that the seven items described below require resolution at a higher management level within the NRC. Six of the items involve the plant Technical l

Specifications.

1.

Remote Shutdown Instrumentation g

Technical Specification 3.3.3.5 (Page 3/4 3-53) i T. Seeis This Specification will require us to shut dom the Plant if any one V

of the instrumente on the Control Room Evacuation Panel is inoperable fcr over seven (7) days. After the DiI accident, the NRC changed the M"Cg-action for this Specification from 30 days to 7 days.

l TCS6 SCE&G contends that the ic;ss of one instrument, although it may conprcmise operation from the panel, does not prevent the safe shutdown of the Plant. Therefore, the action should not require a shutdown of the Plant but an evaluation of the effect on the function l

of Control Rotm Evacuation Panel. A report of the problem with l

corrective action addressed wmld be made to the NRC and, if necessary, I

te:porary reasures muld be provided to assure the plant can be l

safely shut down and maintained from outside the Control Rocm.

l SCE&G, in our Septs.ber 25, 1981, letter to Mr. Virgilio, regaested a change t'o this Specification.

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Mr. Harold R. Denton April 15, 1982 Page 2 2.

Accident Mcnitoring Instrumentation Technical Specification 3.3.3.6 (Page 3/4 3-56)

This Specification applies to the Post-Accident Monitoring (PAM)

Instrumentation and the contention concerning this Specification is 7"S)y:3 the same as for Specification 3.3.3.5, above. The major difference is U

that for the PAM instrunentation, redundant channels are required.

Oftbad The action for the loss of one channel is the same as for Specification 3.3.3.5, i.e., shut the Plant down in 7 days. However, if toth channels fail, one will have to be repaired within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or the

-fCC6 Plant will have to be shut down.

Exceptions to the redundant channels are the position indications for the pressurizer PORV's, PORV block valves, and safety valves. Only one position indication exists for each valve and if it fails and is not repaired within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , the Plant will be shut dom. SCE&G, in our Scptenber 25, 1981, letter to Mr. Virgilio, requested a change to this Speci'fication.

3.

Steam Generator Technical Specification 3.4.5 (Page 3/4 4-13)

This Specification requires that all steam generators be operable prior A/D -

to increasing the average tenperature of the reactor coolant above 200*F. The iten of contention concerns the surveillances for this ggh Specification which establishes the requirenents for determining if the steam generators are operable.

6 fuck After a loss-of-coolant accident which causes a safety injection, M'760 Surveillance 4.4.5.3.c requires an unscheduled inspection of at least

-3% of the tubes in each steam generator. This inspection will have to be c:enpleted before returning the Plant to power.

SCE&G contends that if during a loss-of-coolant accident the safety j

injection ptmps are able to maintain the reactor coolant systen pressure above the secondary systen pressure in the steam generators, there is no undue stress on the tubes. Therefore, no justifiable

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reason exists for the unscheduled inservice inspection which will require about 10 or 12 days of shutdown to perform.

If a safety injection is caused by a loss-of-colant accident, it is e.xpected that in the majority of the cases the safety injection punps will maintain the reactor coolant pressure above the secondary coolant pressure.

1 SCE&G, in our Septenber 25, 1981, letter to Mr. Virgilio, requested a change to this Specification.

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Mr. Harold R. Denton April 19, 1982 Page 3 4.

Operaticnal Leakeage Technical Specification 3.4.6.2 (Page 3/4 4-19)

This Specification requires that the reactor coolant leakage brem each g-reactor coolant systen pressure isolation valve be limited to 1 GPM.

The basis for this requirement is the NRC proposed scenario that the

$g valves muld fail and cause an cuerpressurization and rupture of the low pressure piping producing a loss-of-coolant accident outside of containnent. The NRC contends that valve leakage greater than 1 GPM is indicative of an inpending gross failure and that the leakage should Smel.

be checked at least once per refueling and the valve repaired if the leakage is greater than 1 GPM.

MB SG&G initially contended that this requirenent was not needed because the Specification already requires that the reactor coolant system leakage be limited to 1 GPM unidentified leakage and 10 GPM of identified leakage and that although 1 GPM leakage through the reactor coolant systen pressure boundary may be indicative of an inpending gross failure, leakage of 1 GPM across a valve seat certainli is not indicative of impending gross failure of the valve. However, the forner position was conceded and we agreed to include the reactor coolant system pressure isolation valves in this Specification with some major changes. Details of the SCE&G position are described in our Decerter 8,1981, letter to Mr. Urgilio.

l 5.

Hot vs. Cold Shutdown Specification 3.7.3 (Page 3/4 7-11) 3.7.4 (Page 3/4 7-12)

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3.7.5 (Page 3/4 7-13) 3.8.1.1 (Page 3/4 8-1, 3/4 8-2)

L.dubCa3 b 3.8.2.1 (Page 3/4 8-9) 3.8.3.1 (Page 3/4 8-13)

These Soecifications are for systems that are required to keep the AS$ (3.7)

Plant in cold shutdown. The NRC contends that cold shutdom is the safest condition for the Plant and requires that when the redundance of PSA(3N these systems is lost that the Plant be placed in cold shutdom.

SG&G contends that when the reliability of systems needed to keep the Plant in cold shutdown is questionable, it is safer to maintain the Plant in hot shutdown. Hot shutdown provides the maximum number of options available to remove the decay heat of the core. Under this condition, 5 possible paths ror heat retoval exist: tm residual heat renoval locps and three reactor coolant loops. In cold shutdown the only rethod of retoving heat is the tm residual heat rareval loops l

Mr. Harold R. Denton April 19, 1982 Page 4 tecause the reactor coolant tsperature is less than 200*F and heat can no longer be reeved by steaming the steam generators.

The above Specifications require the Plant to be placed in cold shutchwn when any one of the systems (including electrical power) that is needed to rseve heat via one of the residual heat renoval loops fails. This means that the one reaining residual heat renmal loop has to be used to maintain the reactor coolant system tsperature below 200*F.

However, if the Plant was maintained in hot shutdown (reactor coolant systs tsperature between 200*F and 350*F) in addition to having the one reaining residual heat remwal loop, there would also be three reactor coolant loops, any one of which could be used to rsove heat.

If the service water pond is lost, Specification 3.7.5 requires the Plant to be placed in cold shutdown. However, this pond is the ultimate heat sink for both residual heat rs oval loops without which there is no way to remove the decay heat or comply with the requirments of the Specification. However, the Plant could be maintained safely in hot shutdown under these conditions by steanung the steam generators. SCE&G, in our October 14, 1981, letter to Mr.

Virgilio, requested a change to this Specification.

6.

Steam Generators Technical Specification 3.4.5 (Page 3/4 4-14) 5-This criteria specifies a tube plugging margin of 40%. As discussed in

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3. U' the FSAR, SCE6G had Westinghouse determine the degraded steam generator tube plugging margin in accordance with Regulatory Guide 1.121.

N $ nsh Applying the sane design philosophy for the Virgil C. Summer Nuclear Station as previously used for RESAR-414, which was accepted by the NRC staff in NORM 0491 (November 1978), pertinent portions attached, gdes Westinghouse determined the tube plugging margin to be 55%. On Novaber 30, 1981, SCE&G subnitted ICAP 9912 (Properietary) and iCAP Mf6 9989 (Non-Proprietary) which provided technical justification to Mg support a 55% steam generator tube plugging margin for the Virgil C.

Summer Nuclear Station. Technical Specification 3.4.5 was changed and sent by SCE&G to the NRC reviewer on May 15, 1981.

However, in April 1982, the NRC reMed this analysis because a factor of safety of three was not used. Discussions revealed that the NRC intended for the factor of safety of two to apply only to the case of through-wall cracking and not to tube thinning (wastage). SCE&G pointed out that NUR m 0491 accepted the Westinghouse position with no exceptions. The NRC reviewer stated that even though NUR m 0491 did

Mr. Harold R. Denton April 19, 1982 Page 5 not clearly state it, that this new interpretation was what the NRC meant.

SCE&G finds this difficult to understand.

In good faith, and at considerable expense, we took written NRC positions to provida a basis for the Reg. Guide 1.121 analysis and support the 55% tube plugging limit. We are now being told that the NRC position stated in NUREG 0491 is invalid.

It is the position of SCE&G that the factor of safety of two is justified and acceptable. We find no valid basis for the subjective, contradictory interpretation of a previous NRC review.

7.

Accumulator Discharge Valves (SER Licensing Condition 1.8.2)

In Supplement 3 of the Safety Evaluation Report (SER), NURH3 0717, the THs$ HAffgg NRC required SCE&G to instan power lock-out devices as part of the controls for the accumulater discharge valves since the current design I $ @ l 0MM violates Branch Technical Position RSB 5-1 requirements.

Supplement 3 1

NE Mggy f the SER also states that the nedification is to be accmplished -

prior to startup after the first refueling outage.

Of AN WN It is our position that as a Class 2 category plant within RSB 5-1, Virgil C. Sum m r Nuclear Station is not required to be in full empliance with the Staff docunent. As stated in our letter of March 15, 1982, SCE&G's position is that the present plant design and procedural methods for plant cooldom are an acceptable alternative to BIP RSB 5-1 requirements for a Class 2 plant. On April 2, 1982, the Staff indicated in a conference call that they did not accept our position as stated in the March 15, 1982 letter, and that resolution of this matter was required prior to fuel load.

Ibth SCE&G and Westinghouse will be present to offer justification for the original position at our neeting with you.

SCE&G would like to neet with the Staff in Bethesda during the week of April 26, 1982, to resolve the above itens. If this week is unacceptable, we i

l suggest the seek of May 3,1982. We feel that with the proper levels of l

managemnt present at this neeting, final disposition of these items can be acmnplished.

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l Mr. Harold R. Denton April 19, 1982 Page 6 If you have any questions, please let us know.

Very truly yours, 9

4 T. C. Nichols, Jr.

RBC:TCN:lkb cc:

V. C. Sumer (w/o attach.)

G. H. Fischer (w/o attach.)

H. N. Cyrus T. C. Nichols, Jr.

(w/o attach.)

M. B. Whitaker, Jr.

J. P. O'Reilly H. T. Babb D. A. Nauman C. L. Ligon (NSRC)

W. A. Williams, Jr.

R. B. Clary O. S. Bradham A. R. Koon M. N. Browne G. J. Braddick J. C. Ruoff J. L. Skolds J. B. Knotts, Jr.

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INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION J

LIMITING CONDITION FOR OPERATION 3.3.3.5 The remote shutdown monitoring instrumentation channels shown in 4

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SURVEILLANCE REOUIREMENTS i

4.3.3.5 Each remote shutdown monitoring instrumentatfori channel shall be l

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ACCIDENT MONITORING INSTRUMENTATION LIMITING CO'NDITION FOR OPERATION

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3.3.3.6 The accident monitoring instrumentation channels shown 'in Table 3.3-10 shall be OPERABLE.

APPLICABILITf:.. MODES 1, 2 and 3.

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the Required Number of Channels shown in Table 3.3-10 the fac,.crabk har.r.c1(:) tc. 0?".**2' ~ :t:tu:

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-at ich:t HOT SU"0'cl" uith'- the. ext 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .within 7 d:y:, or i:. in-

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f SURVEILLANCE REOUIREMENTS 4.3.3.6 Each accident monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-7.

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I SURVEILLANCE REOUIREMENTS (Continued)
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l 4.4.5.3 Insnection Frecuencies - The above required inservice inspections of steam generster...~.,...... be performed at the following frequencies:
The first inservice inspection shall be performed after 6 Effective a.
Full Power Months but within 24 calendar months of initial criticali Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection.
If two consecutive inspections following service under AVT conditions, ne including the preservice inspection, result in all inspection txsults falling into, the C-1 category or if two consecutive inspections demonstrata that'previously observed degra-dation has not continued and no additional degradation has occurred, the. inspection. interval may, be extended to a maximum of once per 40 months.
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conducted in accordance with Table 4.4-2 at 40 month intervals fall in Category C-3, the inspection frequency shall be increased to^at least once per 20 months. -The increase in inspection frequency shall apply until the subsequent inspections satisfy the biteria of Specification 4.4.5.3.a; the interval may then be extended to a
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maximum of once per 40 months.
Additional, unscheduled inservice inspections shall be perf rmed on c.
each steam generator in accordance with the first sample inspection specified in Table 4.4-2 during the shutdown subsequent to any of the following conditions:
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Primary-to-secondary tubes leaks (not including leaks originating from tube-to-tube sheet welds) in excess of the i
Timits of Specifi' cation 3.4.6.2.
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A seismic occurrence greater than the Operating Basis Earthquake 3.
A loss-of-coolant accident safspam, e5 sacL may h.de the. h:st head c.fef taj,dran t
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A main. steam line or feedwater line break.
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OPERATIONAL LEAKAGE LIMITING " CONDITION FOR OPERATION 3.4.6.2 Reactor Coolant System leakage shall be limited to:
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No PRESSURE BOUNDARY LEAKAGE, b.
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h 1 GPM total primary-to-secondary leakage through all steam c.
generators not isolated from the Reactor Coolant System and 500 gallons per day through any one steam generator not isolated from the Reactor Coolant System, d.
10 GPM IDENTIFIED LEAKAGE from the Reactor Coolant System, and 33 TPM CONTROLLED LEAKAGE at a Reactor Coolant System pressure e.
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APPLICABILITY: ' MODES 1, 2, 3 and 4 9:
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With any PRESSURE BOUNDARY LEAKAGE, be in at least HOT STANDBY a.
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 he'urs, b.
With any Reactor Coolant System leakage greater than any,one of the
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above limits, excluding PRESSURE BOUNDARY LEAKAGE and Leakage from Reactor Coolant System Pressure Isolation Valves, reduce the leakage rate to within limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hour3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months '.
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SURVEILLANCE REQUIREMENTS 4.4.6.2'.1 Reactor Coolant System leakages shall be demonstrated to be within each of the above limits by;
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Monitoring the reactor building atmosphere (gaseous or particulate) a.
radioactivity monitor at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .
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With any Reactor Coolant Syste= Pressure Isolation Valve not i
L?ERABLE per 4.4.6.2.2. provide at least one additienal closed I
isolation valve between the RCS and low pressure portions of the system for each Reactor Coolant System Pressure Isolation valve not OPERA 3LE. or reduce RCS cressure to 1 600 esir
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REACTOR COOLANT SYSTEM Ci,$2 [/,[."[
SURVEILLANCE REOUIREMENTS (Continued) t I
nitoring'the reactor building sump inventory at lekst once^per b.
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Measurement of the CONTROLLED LEAKAGE' to the reactor coolant pum;i l
seals when the Reactor Coolant System pressure is 2235
~~20 least once per 31. days with the modulating valve fully open.psig at The provisions of Specification 4.0;4 are not applicable for entry into MODE 3 or 4.~~
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Performance of a Reactor Coolant ' System water inventory balance at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .
Moni,toring the reactor head flange leakoff system at least once per e.
24 h6urs.
4.4.6.2.2.-Each Reactor Coolant System Pressure Isolation Valve'specified in Table 3.4-1 shall be demonstrated OPERABLE pursuant to Specification 4.0.5, except that in lieu of any leakage testing required by Specification 4.0.5, each valve shall be demonstrated OPERABLE by verifying leakage to be within f4e 4te limit 3.rpec.f,./. A 7E I, /a s,4 - /;,.. -
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,_Eyery_ refueling outage during startup.
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Prior to returning the valve to service following maintenan a repair or replacement work on the valve.
Prior to entering MODE 2 following ' valve actuation due to automatic q.
or manual action or flow through the valve for valves denoted on Table 3.4,-1 by an asterisk.
d.
The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4.
e O
e 9
SUMMER - UNIT 1 3/4 4-20
TABLE 3.4-1 Reactor Coolant System Pressure Isolation Valves Valve No.
Description Miximum Allowable Leakage (1) 8993A SI to Hot Legs Loop 10 GPM 89935 SI to Hot Legs Loop 3 10 GPM
.t.h 8993C SI to Hot Legs Loop C 10 GPM 8988A SI Lov Head to Hot Legs A 10 GPM 8988B SI Lov Head to Hot Legs B 10 GPM-8998A SI to Cold Legs Loop A 10 GPM 89983
'iSI to Cold Legs Loop 3 10 GPM 8098C SI to Cold Legs Loop C 10 GPM 8973A RER Lov Head to Loop A
~
10 GPM 8973B RHR Low Head to Loop 3 10 GPM 8973C RHR Lov Head to Loop C 10 GPM 8948A*
Accumulator to Loop A 10 GPM 8948B*
Accumulator to Loop B 10 GPM 8948C*
Accumulator to Loop C 10 GPM 8956A*
Accumulator to Loop A 10 GPM 8956B* +
iccumulator to Loop B 10 GPM 8956C*
Accumulator to Loop C 10 CPM
+-
.:t
.'. 2 2
(1)
Leakage measurements shall be conducted persuant to 4.0.5. 'tThe minimum differential pressure shall be 1 1000 psid and the leakage rate shall be corrected to 2235 psid.
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i PLANT SYSTEMS 00 UU]"*
n om, M ".s 3/4.7.3 COMPONENT COOLING WATER SYSTEM n:.i;;y Clie" LIMITING CCNDITION FOR OPERATION
~
z.
*. At least two.iridep'endent component cooling wa.ter 1, oops sha.l.1 be OPERABLE,
~~3.,7. 3 s ; v i < *~.~~
s~r* e. ' * -
l,., :
~~-l.".~~
APPi.ICAB'ILITY:. MODN5'l..,,2, 3 r.d.'. :*..
l*
..a
,...s f.*
~r.
. gcy3cy:
7, With only one comporient cooling water 1oop OPERABLE, 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 hou s and in SHtJTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
SURVEILLANCE REOUIRE ENTS p
. N;:. '.4,.7.3 AtAeast two. component 'ecolind.kater loops 'sha'll bei, demonst' rated OPERA 8U$
q At least once per 31, days by. verifying thati each valve (manual, a.
power operated or automatiel servicing.saf,ety r. elated equipment t, hat is not 1 cRed, 'ssaled*, cr istherwise secured in p'osition, is in its
' correct position.
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PLANT SYSTEMS
....m-o y v r"} ne.-'.V 3/4.7.4 SERVICE WATER SYSTEM
'fnWi G '.MU EII LIMITING CONDITION FOR OPERATION 6
3.7.4 At
....: ~,.least, t:wo indep.endent serv. ice water lo. ops,.shall.be. 0PE.RAB
... ;..^:
~~:* ~. ~.~~
/. -
APPLICABILITY:
MODES 1. t.2,: 3..=.d. "/,. /
~
s.-
~~u..e~~
. ACTION:
With only one service water loop OPERABLE, 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 STANDBY w 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and iri HUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
SURVEILLANCE REQUIREMENTS
.>. h.... a ~.. '... :..
.. :. ;.. :.~ n L-
?
~~" ' -. :. '.d ;~~
4.7.4 At least two service water iceps shall be demonstrated.0PERABLE:
At least on~ce
~~\\'~~
a.
power ope' rates' per 31 days by 'vsrifying that each" valve (manual, or automitic) servicing safety relateil equipment that -
~
is not locked, sealed, or otherwise secured'in, position', is in its correct position.
b.
, At least. once per 18 months during shutdown, by veri that each-automatit:
valve ' servicing safety related squi~pment' actuate appl.icable. correct position on a simulated 'SI test signal or o'n an ESFLS.,,as i
~.
At least once per 18 months, by verifying that each service water c.
system booster pump starts automatically on a safety infection signal.
i i
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SUMMER - UNIT 1 s
3/4 7-12
7 PLANT SYSTEMS
~
,D}{<fp,p*:qpjjpgfi, u.., J.s c.t: u j
3/4.7.5 ULTIMATE HEAT SINK LIMITING CONDITION FOR OPERATION 3.7.5 The service water pond (ultimate heat sink) shall be OPERABLE with:
~
..a..
.A minimum wat.er. level at pr atiove. elevation'415 Mean~ Sea Epei,'%
i *. *
~~USGS datum, and~~
~.
,'.1
......~ *. ~.
l
^ ' ' '
bl A. water temperature of.less than or equal to 95"F at the discharge
, of t,he service water pumps.
APPLICAEILITY:
' MODES 1,-2,3c.dd".
.. ACTION:
With the' fehuirements of the above specification not satisfied, be'in at least
,.

n.., HOT...STAN.DBY.,- w.s g. in..6. hour..s. and in. C::'QSHU.TDOWN.'.w.i..th.ip ith
. s.......p fr..
.- r, - -
~
s 5URVEILLANCE REQUIRMENTS o
4.725 The service wa. tar pond shall be determined.-OPERABLE at least.oncec-
~~'24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by veri'fying the water' tem'perature ind water level' to' be withi'n'per limits.~~
the'i'r.
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SU!EER - UNIT 1 3/4 7-13
PLANT SYSTEMS 3/4.7.4 SERVICE WATER SYSTEM hu.d.N $ me r"; nc-.y
.s.- - 3
!. M D ULII LIMITING CONDITION FOR OPERATION 3.7.4 At
,..m..... : e,.least. two ind.e.p.endent,. serv.i.ce, water 1qops.shal-l'
-: -... ~.
p - ;,:.. -
APPLICABILITY:
MODES 1,.2,;.3.. rd C /.,
. ~.,,
.'..s
...,.s n.. :.. -
, ACTION:
?
~.
s.-
With only one service water loop OPERABLE, re' store '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 STANDBY 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and fri HUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
SURVEILLANCE REQUIREMENTS s
)
.a ~
.... :.......:. '...:: u
~~.*- ?~~
?M '.:.." -l
, : ' ' :'A' i
At least two' service water loops shall be demonstrated.0PERABLE:.
4.7.4
\\'.
At least orice per 31 days by virifying that each" valve (manual, a.
.4' power ope' rate'd' or automatic) servicing safety related equipment that -
is not locked, sealed, or otherwise secured'in, position' is in its correct position.
~~b.. At least once per 18 mor$ths during shutdown, by verifying that each -~~
s automatic valve ' servicing' safety re' lated e' qui'pment'actuat'es to its correct p6sition on' a simulated 'SI test signal or on an ESFLS.,,as appl.icable.
At least once per 18 months, by verifying that each service water c.
system booster pump starts automatically on a safety injection signal.
i i
1 s
SUMMER - UNIT 1 3/4 7-12
l 2WF^.P"5'Y"t.mf in C u$.
W.;Y 3/4.8 ELECTRICAL POWER SYSTEMS.
3/4.8.1 A.C. SOURCES OPERATING LIHITING CONDITION FOR OPERATION
~
~
3.8.1.1 As a minimum, the following A.C. electrical' power sources shall be OPERABLE:
a.
Two physically independent circuits between the offsite transtifssich network and the onsite Clan 1E distribution system, and b.
Twos eparate and independent diesel generators, each with:
1.
A. separate day fuel tank containing a minimum volume of 300
' gallons of fuel, 2.
' A separat'e fuel storage system ontaining a minimum volume of
'42,500 gallons of fuel, and i
\\.
~
'3.
A separate fue1 transfer pump.
v'
~ -
+
~
APPLICABILITY:. MODES 1, 2, 3. r.d '.
ACTION:
a.
With either an offsite circuit or! diesel gene'rator. of the above required A.C. electrical power sources faccerable, demonstrate the OPERABILITY of the remaining A.C. sourer by performin~g Surveillance Requirements 4.8.1.1.1.a and 4.8.1.1.2.a.4 within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter1 restors at least two offsite circuits and two diesel generators to CPE3ABLE status within 72 bours
~
or be in at least HOT STANDBY wi. thin the next 6-hours and in N g(
SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ..
b.
With one offsite circuit and dne diesel genarator of the above required A.C. electrical power sources inoperable, demonstrate the 1
OPERABILITf of the remaining A.C. sources by performing Surveillanca Requirements 4.8.1.1.1.a and 4.8.1.1.2.a.4 within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; restore at least one of the Inocerable sources to OPERABLE status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or be in at.
least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
Restore at least two offsite' E
t circuits and two diesel generators to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the time of initial loss 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 19t% SHUTDOWN within the following 30
~~hours, gof J'~~
4 SU.u.MER - UNIT 1 3/4 8-1
l a
~
l ELECTRICAL POWER SYSTEMS i
f' ACTION:-(Continued) i With one diesel generator inoperable in addition to Action a or b
~.c above, verify that:
i L
(1) All-required systems,. subsystems, trains, cer,,cnants and devices j
that depend on the remaining OPERABLE diesel generator as a -
j source of emergency power are also,0PERABLE, and
/(2) Vnen in MODE 1,~ 2, or 3; the steam-driven auxiliary feed pump isNPERABLE.
1
-If these I:enditions are not satisfied within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months be in at least i.~
- HOT STANDBY within. the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 'and in Est:hSHUTDOWN within the followng 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
No7-j d.
With two of the above required offsite A.C. circuits. inoperable,
, demo.nstrate the OPERABILI'iY of two diesel generators by performing i s Surveillance Requirement 4.8.1.1.2.a.4 within one hour and at least 4
once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter, unless the diesel generators are already-eperating; restore at least one of the inoperable offsite sources.to..
OPERABLE status.within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in it least HOT STANDBY within.
the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .
With only one'offsite source restored, restore at.
least two offsite circuits to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from time of initial loss or be in at least HOT STANDBY withinithe.next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in-eSthSHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
nor-y
e. ' With two of the above required' diesel generators ' inoperable, demonstrate the OPERABILITY of two offsite A.C. circuits by performing Surveillance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter;' restore at least one of the irioperable diesel ganarators to OPERABLE status within 2. hours or be in at
(
least HOT. STANDBY within'tte 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 .- Res. tore at least.two diesel generators to'00ERABLE:st.atus withint72 hours from time of initial loss or be
-in 1. east HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in f3t9 SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , HST y
SURVEILLANCE REOUIREMENTS 1i 4.8.1.1.1 Each of the above required independent circuits between the offsite I
transmission network and the onsiti Class lE distribution system shall be:
Detarained OP*iRABLE at least once per 7 days by verifying correct
- a.
breaker aligt.ments; indicated power availability, and b.
Demonstrated MPERAP.LE at least once per 18 months during shutdown by p
man 6 ally transferring unit power supply from the normal circuit to the ilternate circuit.
e~
c
, y. 4. 8.1.1. 2 Each diesel generator shall be demonstrated OPERABLE:
In accordance with the frequency specified in Table 4.8-1 on a a.
STAGGERED TEST BASIS by:
'l.
Verifying the fuel level in the day tank,
..c SUMMER-UNIT 1/
3/4 8-2
---mg--,.-_,e,_
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ELECTRICAL POWER SYSTEMS
~~n.. -~~
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3/4.8.2 0.C. SOURCES h % i C i. V 5.\\
ts d i OPERATING LIMITING CONDITION FOR OPERATION 3.8.2.1 As a minimum the following 0.C. elect."ical sources shall be OPERABLE:
125-volt Battery baE No. IA and its associated full capacity charger.
. a.
125-volt.' attery bank Nh.1B and its associated full capacity charger b.
B
..-e APPLICABILITY:
HODES 1, 2, 3 e d '.
ACTION:
With one E the required battery banks inoperable, restore the inoperable a.
battery bank to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .or be in a't least HOT STAND 8Y with'in the 'next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in-cebfbSHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
~~dE.~~
~
With one of 'the required full capacity chargers inoperable, demonstrata b.
the OPERABILITY of its associated battery bank by performing Surveillance Requirement 4.8.2.1.a.1 within one hour, and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter.
If any Category A limit in Table 4.8-2 is not met, declare the battery inoperatis.
SURVEILLANCE REOUIREMENTS 4.8.2.1 Each 125-volt battery bank and charger shall be demonstrated OPERABLE:
l At least once per 7 days by verifying that:
a.
1.
The parameters in Table 4.8-2 meet the Category A limits, and 2.
The total battery terminal voltage is greater than or equal to 129 volts on float charge.
SUMMER - UNIT 1 3/4 8-9
i l...,
a ELECTRICAL' POWER SYSTEMS 3/4.8.3 ONSITE POWER DISTRIBUTION OPERATING LIMITING CONDITION FOR OPERATION 3.8.3.1 The following electrical busses.shall be energized in th's specified manner with tie breakers open between redundant busses:
a.
. Train A A.C. Emergency-Busses consisting of:
1.
7200 voit Emergency Busses # 1DA_and IEA.
2.
480 yolt Emergency Busses i IDA1, IDA2 and 1EA1.
b.
Train B A.C. Emergency Busses consisting of:
1.
7200 voit Emergency Busses # 1DB and 1EB.
2.
480 volt Emergency Busses # -1DB1,1DB2, and 1EBl. -
c.
120 volt A.C. Vital Busses i 5902, 5907 and 5901 energized from an associated inverter connected to D.C. Bus # 1HA*.
d.
120 volt A.C. Vital Busses # 5904, 5908 and 5903 energized from an
,./
associated inverter connected to D.C. Bus # 1HB".
<=
e, 125 voit 'D.C. Bus 1HA energized from Battery Bank #1A..
~
f.
125 volt D.C., Bus 1HB, energized from: Battery. Bank #18.
~
APPLICABILITY: MODES 1, 2, 3,'
=d ',-
.c c
.Q P'-
ACTION:
i g
a.
With one of the required trains of A.C. Emergency busses not fully i
energized, re-energize the division within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least-HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in tet:9, SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
Nor 4
b.
With one A.C. Vital Bus either not energized from its assocIat.ed inverter, o.' with the inverter not connected to its associated 0.C.
Bus:
(1) re-energize the A.C. Vital Bus within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in at _go7-i least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in set:i/ SHUTDOWN l
within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and (2) re-energize the A.C. Vital Bus from its associated inverter connected to its associated D.C.
l Bus within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within the.next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ..
~
c.
With one D.C. Bus not energized from its associated Battery Bank, re-energize the D.C. bus from its associated Battery Bank within i
2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-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 MSHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .
Hof Three inverters may be disconnected from their 0.C. Bus for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months as necessary for the purpose of performing an equalizing charge on their associated battery bank provided (1) their vital buses are energized, and (2) the vital busses associated with the other battery bank are energized
,f f rom their associated inverters and connected to their associated 0.C. Bus.
SUMMER - UNIT 1 3/4 a-13 N
. MAR 0 3 i 2
---w
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--,,r,
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Jd Ih-MEETING NOTI _CE DISTRIBUTION (bo[ket.' File J. Stolz
~
NRC PDR S. Hanauer Local PDR MAY 4 1982 H. Thompson TIC /NSIC ACRS (16)
D. Ziemann TERA W. Minners LB#1 Rdg.
F~. Schroeder E. Case K. Kniel D. Eisenhut/M. Jambor D. Skovholt G. Knighton T. Novak M. Ernst S. Varga L. Hulman D. Vassallo E. Adensam R. A. Clark A. Thadani Attorney, OELD J. Youngbloo' OIE A. Schwencer OSD (7)
F. Miraglia Project Manager WKane J. R. Miller Licensing Assistant M. Rushbrook G. Lainas Receptionist D. Crutchfield W. Russell J. LeDoux, I&E J. Olshinki R. Vollmer I&E Headquarters R. Bosnak I&E Region I F. Schauer I&E Region II R. E. Jackson I&E Region III G. Lear I&E Region IV W. Johnston I&E Region V S. Pawlicki V. Benaroya NRC
~~Participants:~~
Z. Rosztoczy W. Haass W. Kane, L. Rubenstein, T. Speis, D. Muller J. Knight, W. Johnston, D. Skovholt, R. Ballard et. al.
W. Regan V. Moore R. Mattson F. Congel
~~0. Parr bcc: Applicant & Service List F. Rosa W. Butler R. W. Houston W. Gammill L. Rubenstein T. Speis M. Srinivasan B. Grimes S. Schwartz F. Pagano S. Ramos~~

ML20053B048

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ML20053B048

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Dear Mr. Denton:

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