ML20108D153

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Proposed Tech Specs Re Removal of Fire Protection Requirements
ML20108D153
Person / Time
Site: Point Beach  NextEra Energy icon.png
Issue date: 04/29/1996
From:
WISCONSIN ELECTRIC POWER CO.
To:
Shared Package
ML20108D149 List:
References
NUDOCS 9605070302
Download: ML20108D153 (25)
v • d • e


Text

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1

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u Unit 1 - Amendment No. H8 15.4.15-2 ^pM' 17, 1989 l

i Unit 2 - Amendment No. 4M

b. At least one licensed Operator shall be in the control room when fuel is in either reactor.

i c. At least two licensed Operators shall be present l in the control room during reactor start-up, scheduled reactor shutdown and during recovery from reactor trips.

l l d. An individual qualified in radiation protection procedures shall be on site when fuel is in either reactor.**

e. All core alterations shall be directly supervised by either a licensed Senior Reactor Operator or Senior Reactor Operator Limited to Fuel Handling  !

who has no other concurrent responsibilities during this operation. ,

f. A Fire Brisede of et ice:t 5 =c=ber: chc11 be
int:ined :::!t: :t :ll ti= :." Thi: xclud:: i 3 :::b r: Of th: mini := :hift er:w :::::::ry for
f: :hutd;wr, cf the pl:nt :nd :ny per::nn:1 required for other c::entici function during c fire c=crgency.

I l

  • SR0 = NRC Senior Reactor Operator License R0 - NRC Reactor Operator License
    • This shift may be less than the minimum requirements for a period of time not  ;

to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to accommodate unexpected absence of personnel, provided immediate action is taken to restore the shift makeup to within the

!- minimum requirements.

l l

l t

Unit 1 - Amendment No. 446 15.6.2-3 Unit 2 - Amendment No. 4 M J;nu:ry 27, 100' l

l l

i 15.6.4 TRAINING 15.6.4.1 A retraining and replacement training program for the facility staff shall be maintained under the direction of the Training Manager and shall meet or exceed the requirements and recommendations of Section 5.5 of ANSI N18.1-1971 and 10 CFR Part 55.

15.5.4.2 f, training progr:: for the Fire Brig:dc shall =cet er exceed the requirc=cnt cf Section 27 cf the NFP? Ccdc 1975, except th:t th: =ceting frequency ::y be qu:rterly.

15.6.5 REVIEW AND AUDIT 15.6.5.1 Manager's Supervisory Staff 15.6.5.1.1 The Manager's Supervisory Staff (MSS) shall function to advise the Manager on all matters related to nuclear safety.

15.6.5.1.2 The Manager's Supervisory Staff shall be selected and designated by the Manager from a list of qualified individuals in the following disciplines:

Operations I l Maintenance Health Physics

Engineering Licensing l Training i Chemistry 15.6.5.1.3 Each individual representing a MSS discipline shall meet or exceed the qualification requirements specified in Section 4.2 of ANSI N18.1-1971, except as described in Specification 15.6.3.2 for the Health Physics Manager.

Unit 1 - Amendment No. 446 15.6.4/5-1 Unit 2 - Amendment No. 4 M Anum y 27, 1994 l

D. Failure of Containment Hiah-Ranae Radiation Monitor A minimum of two in-containment radiation-level monitors with a maximum range of 10' rad /hr (10'/hr for photons only) should be operable at all times except for cold shutdown and refueling i outages. This is specified in Table 15.3.5-5, item 7. If the minimum number of operable channels are not restored to operable condition within seven days after failure, a special report shall  ;

be submitted to the NRC within thirty days following the event outlining the action taken, the cause of the inoperability and the  !

plans and schedule for restoring the ystem to operable status.

E. Failure of Main Steam Line Radiation Monitors If a main steam line radiation monitor (SA-11) fails and cannot be restored to operability in seven days, prepare a special report within thirty days of the event, outlining the action taken, the cab:c of the inoperability and the plans und schedule for restoring the channel to operable status.

F. Fire Protection Sv:te: DC:r:d:tica 0 gr:d: tion ;f fir; pr: tecti:n :y;t :: Or ::;;;;:nt: :: d:: ribed in Sp::ific:ti n 15.3.14 which r:nd:r th: :y:te: inop:r:ble :h:11 be th: : bject Of : :p::ici r:p;rt, prep;r:d :nd ::b:itted within 30 d y:. The report will tline the ::tien t; ken, the ::::: Of the in:per:bility, :nd the pl::: :nd : hedule for r :tering the y:te: t: upecable :t:te:.  ;

l Unit 1 - Amendment No. 444 15.6.9-5 feril 17, 1000 Unit 2 - Amendment No. 4M

__ __ _ _ ~ _ _ _ . __ . _ _ _ _ _ _ _ _ _ _ __

i, _ -

s Wisconsin Electric Power Company. i  :

j 3. F. The licensee shall maintain in effect and fully implement all provisions of the NRC approved physical security plan, 3

including amendments and changes made pursuant to 10 CFR 50.54(p). The approved security plan, withheld from public disclosure pursuant to 10 CFR 2.790(d), is identified as

" Point Beach Nuclear Plant Physical Security Plan", dated May 24, 1977 as revised September 25, 1978, February 2, 1979, j March 29, 1979, December 7, 1979, and May 29, 1980. this plan includes 's the NRC approved Safeguards Contingency Plan the i

revised Cnapter 8, Revision 3 submitted with latter dated March 6, 1981 which, in accordance with 10 CFR 73.40(b), shall be fully implemented within 30 days of this approval by the Commission.

I l G. Safety In.iection Loaic 1

4 The licensee is authorized to modify the safety injection

! actuation logic and actuation power supplies and related

! changes as described in licensee's application for amend-i ment dated April 27, 1979, as supplemented May 7, 1979. In i the interim period until the power supply modification has j been completed, should any DC powered safety injection actuion channel be in a failed condition for greater than one hour, the unit shall thereafter be shutdown using normal. procedures

and placed in a block-permissive condition for safety injection i actuation.

l H. The 1i:==: ny prc =d with 3-i: = ;; ired t: :; .lete the

=dific tin: id = tifi0d in P r:'/:ph: 3.1.1 thr :; 3.1.33 Of the 920': Fin P= tecti = Sdety Enl=tica Rep rt (SER) for the f= ility d:ted ^ ;=t 2, 1070. The: =dific:t4 ens-shell be c a+1cted c: pecified in Tchle 3.1 ef the SER er

=ppl: =t: ther#ier The li:=::: i: =quind t: impl:=nt =d nint:in th:

dmini:tr:tiv: : ntr:1: identift:d in S::ti:n 5 Of th: NRC':

Fir: P= tecti = S:fety E*cl=ti= Rep =t = the F: ility dated

":;=t 2,1970 =d ::;;t;=t: th:=t:.

lHsE3EiiWiniistBRilii1RTsiirdiiisstTiisaisiifstiisifigiffiEUi11 pF6ffiiansisfuneiap7p svedgip4p6tici16skrop M sisiaffdesetibsO5 ro

[insthsiSERiditud!AugsstitM197dsid[Sspilenshisdatid[0ctob thsiFihaD$4fetylAnalystslRepodnfestheifaci i

21 fillsiasistisloal iremaisiiirsit3TsarsiiiissarfrarwereEsrss bMisslititnaht todippsosalis6thitcoimisisnionlydffttssi niinTEisiss3iiay@tfadserse1F@af chanjeWssuldIso

$1h3ainMLehMtjgwn! jilt jkish$5fighey

~ ~ ~~~~

"I. Secondary Water Chemistry Monitorina Proaram The licensee shall implement a secondary water chemistry monitoring program to inhibit steam generator tube degrada-tion. This program shall include:

l-Wisc,onsin Electric Power Company -

!  : 1 l disclosure pursuant to 10 CFR 2.790(d), is identified as i

" Point Beach Nuclear Plant Physical Security Plan", dated '

May 24, 1977 as revised September 25, 1978, February 2, 1979, March 29, 1979, December 7, 1979, and May 29, 1980. this plan includes as the NRC approved Safeguards Contingency Plan the revised Chapter 8, Revision 3 submitted with latter dated ,

l March 6, 1981 which, in accordance with 10 CFR 73.40(b), shall t

! be fully implemented within 30 days of this approval by the Commission.

G. Safety In.iection Loaic i l The licensee is authorized to modify the safety injection actuation logic and actuation power supplies and related changes as described in liceasee's application for amend-l ment dated April 27, 1979, as supplemented May 7, 1979. In i

the interim period until the power supply modification has been completed, should any DC powered safety injection actulon channel be in a failed condition for greater than one hour,

the unit shall thereafter be shutdown using normal procedures t

and placed in a block-permissive condition for safety injection

! actuation.

H. The 1i == =y pr==d with = i: r:quir:d t: :::;lete the

=di f f =ti=: id = tified in P:r:gr:ph: 3.1.1 thr= ;; 3.1.33-Of th ""C' . Fire Pr: tecti = S:f:ty E=1=ti= P.:p;rt (SERF-for th: f= ility d:ted ". ;=t 2, 1970. Th: = = difi u ti = s-05:11 be egleted = :p=ified in T:ble 3.1 ef the SEP er

=;;1;;=t: th:r ::.

The li:==: i: requir:d to i:pi;;=t =d = int:in th:

drini:tr:tive ::.tr:1: id::tified in S:: tic 5 Of the "P4':

Fir: Pr:t:cti= S:fety E=l=ti= ",:p;rt = th: F =ility dated Aug=t 2,1979 =d =;;n= : ther:te.

WriE5HsWEhiEfMEgiK11~ iiiiTsiiiiitissa?iiiilitil"h]TsisYfiEfis1T if1Mpfatsa4oi# riiiiiisidsscri6i@i ths!Eis4R$afetyi

[sifettilsh$1Mineiff"ys_is!Reportjifo%j stdithdf 0ctobsW21 u p1si thelfacil tPinndissijappWved inMhsiSERidatedlAngust@(l979dsid S pJi]h21n1888@McMtsitk 1980LiJissiff@inical$!sjs M lell!!s a m $n tiiimEiEsssisiFiiEETEE3iiiiiii3?iliifiierovedif . EH65 pjiip aliEstthouM Mio (appreis MofsthslCommiss(ssi ~ hifhtho H chhadeihiisild?not

! insisuaisisafsis@iadierselyihffittithitabiliti!'t6ih tMidtijidsjenhoffhjiffrej

^ ~"~ ~ ~ " -

levetand' j "I. Secondary Water Chemistry Monitorina Proaram i

! The licensee shall implement a secondary water chemistry l j monitoring program to inhibit steam generator tube degrada- j tion. This program shall include:

.l 1. Identification of a sampling schedule for the critical parameters and control points for t"sese parameters; l 2. Identification of the procedures used to quantify parameters 1 that are critical to control points; j 3. Identification of process shmpling points 4

,m . , - - . - -

i l

l 7.2 FIRE PROTECTION TECHNICAL SPECIFICATIONS Wisconsin Electric Power Company applied for amendments to Facility Operating Licenses DPR 24 and DPR-27 for Point Beach Nuclear Plant, Units 1 and 2 to i remove fire protection requirements from the Technical Specifications and incorporate them in PBNP's Final Safety Analysis Report and Fire Protection Evaluation Report (FPER).

The following sections of the FPER provide the technical specifications for:

1. the PBNP Fire Protection Program, regarding Fire Brigade Staffing and l Training requirements, (FPER Section 7.2.1) .

l

2. Limiting Conditions for Operation and Surveillance requirements associated' with the plant fire protection systems. (FPER Sections 7.2.2 and 7.2.3)
3. Reporting requirements should degradation of fire protection systems or components occur rendering the system (s) inoperable. (FPEI4 Section l 7.2.2.5) l 1

l l These sections provide all the operational conditions, remedial actions and test I requirements for plant fire detection systems, fire suppression systems, fire barriers, and fire brigade staffing necessary to maintain nuclear safety and safe

! shutdown capability in accordance with 10 CFR 50 Appendix R.

The following aspects of the fire protection program are still maintained in the Plant Technical Specifications. The Manager's Supervisory Staff (MSS) is the group responsible for the review of the fire protection program and implementing procedures, and submittal of any recommended changes to the Off Site Review Committee (OSRC). The MSS is responsible for reviewing the fire protect;on I

program every 24 months to ensure the program continues, to meet established 4

7.2-1 August 1995 i

i

commitments and requirements in accordance with Plant Technical Specifications (TS) 15.6.5.1.8.h.

Plant Technical Specifications (TS) 15.6.8.1.8 requires that the fire protection program be implemented and maintained using approved plant procedures.

TS 15.3.5.3 describes the inspection and audit requirements associated with the fire protection program. Specifically that:

I a. an independent fire protection and loss prevention inspection and audit be performed annually by qualified personnel.

b. an inspection and audit of the fire protection program be performed by a qualified fire consultant at least every 3 years.

7.2.1 FIRE BRIGADE ORGANIZATION 7.2.1.1 Fire Briaade Staffina A Fire Brigade of at least 5 members shall be maintained onsite at all times. This excludes 3 members of the minimum shift crew necessary for safe shutdown of the plant and any personnel required for other essential functions during a fire emergency.

NOTE: This shift may be less than the minimum requirements for a period of time not to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to accommodate unexpectec absence of personnel, provided immediate action is taken to restore the shift makeup to within the minimum requirements.

7.2-2 August 1995

l 7.2.1.2 Fire Briaade Trainina A training program for the Fire Brigade shall meet or exceed the requirements of j Section 27 of the NFPA Code - 1976, except that the meeting frequency may be quarterly.

7.2.2 OPERABILITY OF FIRE PROTECTION SYSTEMS 7.2.2.1 Apolicability l

Applies to the fire protection components which provide fire protection capability i for equipment required for safe plant shutdown at all times when those systems are required to be operable.

7.2.2.2 Obiective l This section specifies the requirements for fire protection components which would be employed to mitigate the consequences of fires which could affect equipment required for safe plant shutdown.

7.2.2.3 Specification A. Fire Suppression Water System

1. Fire Main Loop Water Supply
a. Both fire pumps shall be operable; or l b. One fire pump may be inoperable provided that the second fire pump i

i is tested to demonstrate operability and is tested once every 24 i hours thereafter; or,

c. Both fire pumps may be inoperable provided that a backup fire main loop water supply is operable within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
7.2 3 August 1995 1
d. If a, b, or c cannot be fulfilled, both reactors shall be placed in hot standby within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in cold shutdown within the following thirty (30) hours.
2. Water Sprinkler System
a. The water sprinkler systems listed in Table 7.2-2 shall be operable whenever equipment protected by the system is required to be operable.
b. A water sprinkler system listed in Table 7.2-2 may be inoperable provided that:

(1) Within one hour of determining that one or more of the above required spray and/or sprinkler systems are inoperable, for those areas in which redundant systems or components could be I damaged, establish an hourly fire watch inspection and provide backup fire suppression capability. For other areas, establish an hourly fire watch inspection. Restore the system to operable status within 14 days or prepare and submit a special report to the NRC in accordance with FPER Section 7.2.2.5.

3. Fire Hose Stations
a. Fire hose stations for the areas listed in Table 7.2-2 shall be operable whenever equipment in the arcas protected by the fire hose stations is required to be operable,
b. Within one hour of determining that one or more of the fire hose stations shown in Table 7.2-2 are inoperable, route backup water suppression capability or provide portable fire suppression capability to the unprotected area (s). Restore the fire hose station to operable status within 14 days or prepare and submit a special report to the NRC in accordance with FPER Section 7.2.2.5.

u i

7.2-4 August 1995

1

4. Halon Gaseous Suppression Systems
a. The Halon Gaseous suppression systems listed in Table 7.2-2 shall be operable whenever equipment protected by the Halon system is required to be operable.
b. One supply source of Halon for the gaseous suppression systems in

]

Table 7.2-2 may be inoperable provided that within one hour of determining the condition, fire hose station suppression capability for the affected area is provided,

c. Both supply sources of Halon for the gaseous suppression systems listed in Table 7.2-2 may be inoperable provided that:

(1) Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of determining the condition an hourly fire watch inspection is established and that backup fire suppression capability is provided for those areas in which redundant systems or components could be damaged; for other areas,

  • establish an hourly fire watch inspection. Restore the system to operable status within 14 days or prepare and submit a soecial c report to the NRC in accordance with FPER Section 7.2.2.5.

B. Fire Detection

1. Fire Detection Systems
a. The fire detection system components for each area listed in Table 7.2-2 shall be operable whenever equipment protected by the fire detection components is required to be operable.
b. The control room annunciation for the fire detection system may be inoperable provided that within one hour of determining the con-dition, the area control panels for each area listed in Table 7.2-2 are surveilled hourly.
c. Area control panels for the areas listed in Table 7.2-2 may be inoperable provided that:

7.2-5 August 1995 I

I (1) Within one hour of determining that the area control panelis i i

inoperable, the affected area is inspected to assure that potential j

!. fire hazards are minimized; j 4

1 (2) Activity in the affected area is restricted to that which is j l necessary for continued operation; 3

(3) A fire watch inspection is performed in the affected area hourly. l i d. For each area listed in Table 7.2-2 which is not protected by a Halon gaseous suppression system:

(1) A single detection device may be inoperable.

(2) As icng as at least 75% of an area's detection devices remain i

eperable, multiple non-adjacent detection devices may be i j inoperable.

t l

(3) More than 25% of an area's detection devices or multiple i

4 adjacent detection devices may be inoperable provided that:

j (a) Within one hour of determining that the detection devices j are inoperable, the affected area is inspected to assure that potential fire hazards are minimized.

(b) Activity in the affected area is restricted to that which is
necessary for continued operation; l c (c) A fire watch inspection is performed in the affected area  !

l' hourly. j 1

e. For each area listed in Table 7.2-2 which is protected by Halon '

gaseous suppression system, any number of detection device (s) may j be inoperable provided that:

(1) Within one hour of determining that the detection device (s) are inoperable, the affected area is inspected to assure that potential fire hazards are minimized; (2) Activity in the affected area is restricted to that which is necessary for continued operation; j (3) A fire watch inspection is performed in the affected area hourly.

7.2-6 August 1995

l

l
f. Restore the inoperable instrument (s) to operable status within 14 days, or prepare and sub'mit a special report to the NRC in accordance with FPER Section 7.2.2.5.

(

I C. Fire Barriers l 1. Fire Barrier Penetration Seals  ;

a. All fire barrier penetration seals protecting safety-related areas shall be operable.
b. A fire barrier penetration seal may be inoperable provided that:

I (1) Within one hour of determining that the fire barrier penetration l seal is inoperable, the immediate area on each side of the fire barrier is inspected to assure that potential fire hazards are l minimized; *

(2) Activity in the immediate area on each side of the fire barrier is restricted to that which is necessary:

(a) for continued operation; (b) To enable restoration of penetration sea' operability.

(3) A fire watch inspection shall be performed or, each side of the fire barrier hourly.

(4) Restore the inoperable fire barrier to operable status within 7 days or prepare and submit a special report to the NRC in accordance with FPER Section 7.2.2.5.

7.2.2.4 Basis The overall fire protection program at Point Beach Nuclear Plant utilizes the principles of defense in depth. This includes early warning fire detection and

. redundant fire suppression capability. Collectively, these measures ensure equipment operability, provide adequate capability to prevent and minimize damage to safety-related equipment, and allow safe plant shutdown in the event of a fire occurrence. Should a portion or component of the fire protection system be 4

j 7.2-7 August 1995 li

-c - - - - . . . - - ,

1 I

inoperable, these specifications provide assurance that redundant methods of fire protection are readily available and that the capability to mitigate the consequences of a fire is maintained.

-7.2.2.5 Reportability i

Degradation of fire protection systems or components as described in FPER Section 7.2.2 present a failure to maintain the plant fire protection systems as previously

approved by the NRC. Such tailures shall be the subject of a special report, l prepared and submitted within 30 days to the NRC. The report shall outline l

action (s) taken, the cause of the inoperability, and the plans and schedule for  ;

l restoring the system to operable status. ,

l i 7.2.2.6 Docementation -

i 1

Fire protection system and component operability is verified by periodic tests. Test procedures and completed tests are maintained by plant staff for future review, i

7.2.3 SURVEILLANCE OF FIRE PROTECTION SYSTEMS I I

7.2.3.1 - Acolicability Applies to the periodic inspection and testing requirements of fire protection equipment specified in FPER Section 7.2.2.

7.2.3.2 Objective To verify the operability of fire protection system components.

)

l i

1

)

7.2-8 August 1995 4

l.

l l 7.2.3.3 Soecification A. Fire Suppression Systems

! T311 Freauency

1. Fire Main Loop 'Nater Supply
a. Flowpath valve position verification Monthly  ;
b. Fire pump functional test Monthly
c. Fire pump capacity test Yearly
d. Diesel driven fire pump engine (1) Fuel volume verification Monthly (2) Diesel fuel sample analysis Quarterly I (3) Periodic inspection 18 months
e. Diesel driven fire pump battery and charger l (1) Battery voltage verification Weekly .

(2) Electrolyte level Weekly (3) Electrolyte specific gravity Quarterly  ;

(4) Periodic inspection 18 months

2. Water Sprinkler Systems
a. Flowpath valve positior, verification Monthly
b. Inspector's test Yearly
c. Visual header and nozzle inspection 18 months 1

i 3. Fire Hose Stations

a. Visual inspection Monthly
b. Hose Hydrostatic test 2 years
c. Valve cycle test 3 years
4. Halon Gaseous Suppression Systems

! a. Halon quantity verification 6 months I

b. Functional test Yearly
7.2-9 August 1995 4

l

c. Visual header and nozzle inspectiun Yearly B. Fire Detection i l

l

1. Fire Detection System
a. Channel functional test 6 months i

C. Fire Barriers  !

1. Fire Barrier Penetration Seals l
a. Visual inspection 18 months I l

l 7.2.3.4 Easis j l

I Normally, the fire protection is not in use. However, the system components are required to perform as designed in the event of a fire emergency. The National Fire  ;

Protection Association and the plant insurance carrier have specified periodic tests I and inspections to demonstrate fire protection equipment operability. The listed 1 l tests and inspection are based upon the requirements of these organizations.

Testing more frequently than that listed is not considered necessary to ensure 1 operability and performance.

l l

l 7.2-10 August 1995 l

TABLE 7.2-2 SAFE SHUTDOWN AREA FIRE PROTECTION I

AUTOMATIC SUPPRESSION MAWJAL SUPPRESSION WATER GAS SPRINKLER SUPPRESSION FIRE MOSE FIRE AREA ELEVATION SYSTEM SYSTEM STATION DETECTION

1. Au=ittary Building South 8' (X) Partial X 15
2. Auxiliary Building Center X 13 A. Saf ety injection Ptsps 8' X
8. Conponent Cooting Water Punp X
3. Auxiliary Building North 8' (X) Partiet X 9
4. Auxiliary Building West 8' & Below X 16
5. Auxiliary Building South 26' X 3
6. Auxiliary Building Center 26' N 17
7. Auxitiery suitding North 26' X 7 i S. Auxiliary Building Center 46' X 6
9. Auxiliary Feedwater Ptsp Room 8' X X 11
10. Vitat Switchgear & Battery Room 8' X X 8
11. G01 Diesel Generator Room 8' X X 4
12. G02 Dieset Generator Room 8' X X 4
13. Cable Spreading Room 26' X X 17 6
14. Circulating Water Ptsphouse X 15 A. Service Water Ptaps 8' X
15. G03 Dieset Generator Room 28' X M* 3 l
16. G04 Dieset Generator Room 28' X M* 3 .

f

17. G03 vital Switchgear Room 28' X* 2
18. G04 Vital Switchgear Room 28' X* 2 l
19. CO3 Fuet Oil Day Tank Room 28' X X* 1
20. G04 Fuet Oil Dey Tank Room 28' X X* 1 y
21. G01/G02 Fuet Oil Tra'ufer Pupp Room 28' X X* 1
  • Diesel Generator Building fire hose stations are located in Mechanical Equipment Room. ,

7.2-11 August 1995

u 7.3 FINAL SAFETY ANALYSIS REPORT (FSAR)

The PBNP Final Safety Analysis Report (FSAR) describes PBNP's safety analysis in support of WE's application for operating the facility. It discusses the design and

safety objectives to be used in operation of the plant.

FSAR Section 9.6.1 describes the overall fire protection design and license bases for the PBNP fire protection program to ensure that the probability of events such as fires and explosions and potential consequences of such events will not result in undue risk to the health and safety of the public.

The FSAR identifies the FPER as the controlling document for the fire protection program.

l The FSAR allows Wisconsin Electric to make changes in accordance with the guidelines in Generic Letter 86-10 to this approved program without prior NRC approvalif those changes will not adverseiy affect Point Beach's ability to achieve and maintain safe shutdown in the event of a fire. In such cases, an evaluation  !

l must be performed in accordance with 10 CFR 50.59 to determine if an unreviewed safety question is involved. This evaluation must include a fire hazards j analysis and an assessment of the change's impact on the existing fire protection program. The assessment must also include a review of the effects on l combustible loading and distribution and the consideration of whether circuits or i components, including associated circuits, for a train of equipment needed for safe shutdown are being affected. If the valuation finds that the change could result in Point Beach not being in conformance with Appendix R or some other aspect of J

l the approved fire protection program, or being outside the basis for an existing exemption, Wisconsin Electric must make modifications to achieve conformance or j justify and request exemptbn from the NRC in accordance with 10 CFR 50.12.

i 5 7.3-1 August 1995 1

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