ML20126E494
ML20126E494 | |
Person / Time | |
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Site: | Shoreham File:Long Island Lighting Company icon.png |
Issue date: | 05/30/1985 |
From: | Ebneter S NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
To: | Leonard J LONG ISLAND LIGHTING CO. |
References | |
NUDOCS 8506170098 | |
Download: ML20126E494 (4) | |
See also: IR 05000322/1984046
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MAY 3 01985
Docket No. 50-322
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Long Island Lighting Company
ATTN: Mr. John D. Leonard, Jr.
Vice President - Nuclear
P. O. Box 618
Shoreham Nuclear Power Station
Wading River, New York 11792
Gentlemen:
Subject: Inspection 50-322/84-46
This refers to your letter dated January 29, 1985, in response to our letter
dated December 21, 1984.
Thank you for informing us of the corrective and preventive actions documented
in your letter. A recent Region I inspection (50-322/85-23) followed up five
of the nineteen issues identified during the previous inspection (50-322/84-46),
including your corrective and preventive actions related to these issues. The
followup will be documented in our Inspection Report 50-322/85-23 which will be
transmitted under a separate cover letter. The remaining fourteen issues,
being licensing items, are being referred to the Office of Nuclear Reactor
Regulation (NRR) for resolution. You are urged to resolve these issues with
NRR and complete all related actions expenditiously. After your actions are
cor.plete, these items will be examined during a future inspection of your
licensed program.
Your cooperation with us is appreciated.
Sincerely,
Original Signed Byi
Jacque P.Durr
Stewart D. Ebneter, Director
Division of Reactor Safety
cc:
W. Steiger, Plant Manager
J. Smith, Manager, Nuclear Operations Support
R. Kubinak, Director, QA, Safety and Compliance
E. Youngling, Manager, Nuclear Engineering
Edward M. Barrett, Esquire
Jeffrey L. Futter, Esquire 8506170098 850530
PDR ADocM 05000322
Shoreham Hearing Service List
Public Document Room (PDR)
Local Public Document Room (LPOR)
Nuclear Safety Information Center (NSIC)
NRC Resident Inspector
State of New York
0FFICIAL RECORD COPY RL SHOREHAM 84-46 - 0001.0.0
05/07/85
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Director, DRSS
Director, DRS
J. Strosnider, Section Chief IB, DRP
B. Bordenick, ELD
R. Goddard, ELD
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SHOREHAM HEARING SERVICE LIST
ADDRESSES (just make labels the individuals are not listed in the ec's)
Gerald C. Crotty, Esquire Alan S. Rosenthal, Esquire
Ben Wiles, Esquire Chairman, Atomic Safety and Licensing
Counsel to the Governor Appeal Panel
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Executive Chamber U. S. Nuclear Regulatory Commission
State Capitol Washington, D. C. 20555
Albany, New York 12224 ,
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Mr. Jay Dunkleberger Fabian G. Palomino, Esquire
New York State Energy Office Suffolk County Attorney
Agency Building 2 Executive Chamber
Empire State Plaza State Capitol
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Albany, New York 12223 Albany, NY 12224
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Energy Research Group, Inc. Gary J. Edles, Esquire
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400-1 Totten Pond Road Atomic Safety and Licensing
Waltham, Massachusetts 02154 Appeal Panel
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U. S. Nuclear Regulatory Commission
Washington, O. C. 20555
W. Taylor Reveley, III, Esquire Howard A. Wilbur, Esquire
Hunton & Williams Atomic Safety and Licensing
Post Office Box 1535 , Appeal Panel
i Richmond, Virginia 23212 U. S. Nuclear Regulatory Commission
Washington, O. C. 20555
Honorable Peter Cohalan Robert Abrams, Esquire
Suffolk County Executive Peter Bienstock, Esquire
County Executive / Legislative Bldg. Department of Law
Veteran's Memorial Highway State of New York
Hauppauge, New York 11788 Room 46-14
Two World Trade Center
Martin Bradley Ashare, Esquire
Suffolk County Attorney
H. Lee Dennison Building
- Vetaran's Memorial Highway
- Hauppauge, New York 11788
James B. Dougherty, Esquire
3045 Porter Street, N.W.
Washington, D.C. 20008
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donstructior. 4
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50-322
MHB Technical Associates Dr. Peter A. Morris
n San Jose, California95125
1723 Hamilton Avenue,
Administrative Judge
Suite
Atomic K & Licensing Board
Safety
U.S. Nuclear Regulatory Commission
Stephen Latham, Esquire Washington, D.C. 20555
John F. Shea, Esquire
Twomey, Latham & Shea
Post Office Box 398 Eleanor L. Frucci, Esquire "
33 West Second Street Attorney
Riverhead, New York 11901 Atomic Safety & Licensing Board Panel
U.S. Nuclear Regulatory Ccmmission
Jonathan D. Feinberg, Esquire Washington, D.C. 20555
New York State
Department of Public Service Leon Friedman, Esquire
Three Empire State Plaza Costigan, Hyman and Hyman, P.C.
Albany, New York 12223 120 Mineola Boulevard
Mineola, New York 11501
Ezra I. Bialik, Esquire
Assistant Attorney General
Environmental Protection Bureau
New York State Department of Law
2 World Trade Center
Herbert H. Brown, Esquire Paul Sabatino, II, Attorney at Law
Lawrence Coe Lamnpher, Esquire Counsel to Legislature
Kirkpatrick, Lockhart, H.'1, Legislative Building '
Christopher & Phillips Veteran's Memorial Highway
1900 M Street, N.W. Hauppauge, New York 11788
Washington, D.C. 20036
Karla J. Letsche, Esquire
Kirkpatrick, Lockhart, Hill,
Christopher & Phillips
1900 M Street, N.W.
Washington, D.C. 20036
Lawrence Brenner, Esq. Administrative Judge
Atomic Safety & Licensing Board
U.S. Nuclear Regulatory Commission
Washington, D.C. 20555
Dr. George A. Ferguson
Administrative Judge
School of Engineering
Howard University
2300 - 6th Street N.W.
Washington, D.C. 20059
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LONG ISLAND LIGHTING COMPANY
SHOREHAM NUCLEAR POWER STATION
P.O. BOX 618. NORTH COUNTRY ROAD * WADING RIVER. N.Y.11792
JOHN D. LEONARD, JR.
VICE PRISIDENT NUCLEAR OPERAflONS
January 29, 1985 SNRC-1141
Dr. Thomas E. Murley
Regional Administrator
Office of Inspection and Enforcement
Region I
U.S. Nuclear Regulatory Commission
631 Park Avenue
King of Prussia, PA 19406
Fire Protection
Shoreham Nuclear Power Station - Unit 1
Docket No. 50-322
Reference 1: Letter NRC (Thomas T. Martin) to LILCO (J . D.
Leonard) dated 12/21/84 forwarding Inspection
Report 84-46
Dear Dr. Murley:
The purpose of this letter is to respond to the Reference (1)
letter which forwarded the report of your Fire Protection
Inspection held during the week of December 3, 1984. As you are
aware, LILCO had verbally requerted and was granted an extension
to the requested fifteen day response period. This extension was
requested to provide LILCO with an opportunity to present its
position on various items contained in the report. As a result
of our meeting with the Staff on January 15, 1985, it was agreed
that LILCO would, within two weeks after the meeting, respond to
the deviations as requested in Appendix A to Reference 1, and
would also provide its position or status, as appropriate,
regarding the other unresolved items contained in the report.
This information is contained in Attachment 1 (Response to
Deviations) and Attachment 2 (Remaining Unresolved Items). In
addition, Attachment 3 provides LILCO's position regarding the
issue of automatic suppression for areas of cable tray
concentration.
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Should you have any questions, please contact this office.
Very truly you s, ,
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\Leonard,
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Vic President-Nuhea Operations
RWG:ck
Attachments:
1. Response to Deviations
2. Unresolved Items
3. Cable Tray concentrations
4. Response to GL 81-12 Spurious Signals HighfLow Pressure
Interfaces
5. Diesel Generator Breakers
cc: R. Caruso
P. Eselgroth
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STATE OF NEW YORK )
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COUNTY OF SUFFOLK )
JOHN D. LEONARD, Jr., being duly sworn, deposes and says I am the
Vice President, Nuclear Operations for the Long Island Lighting
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Company. Attachment 1 to letter SNRC-ll41 provides our response
to Appendix A, Notice of Deviation, contained in NRC letter dated
December 21, 1984. I have read this response which was prepared
under my direction and dated January 29, 1985. The facts set
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forth in this response are based upon reports and information
provided to me by the employees, agents and representatives of
Long Island Lighting Company responsible for the activities
described in this response. I believe the facts set forth in '
this response are true.
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Jo n D. Leonard, Jr.
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. Sworn to before me this
E day of Jo.-o p 1985
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SNRC-ll41
. ATTACHMENT 1
Response to Deviations
The identification letters used correspond to those used in
Appendix A of Inspection Report 84-46.
Deviation / Departure
A. The Fire Hazard Analysis Report (FHAR), Revision 1, dated
June 1982 (an enclosure to your letter to NRC dated August
6, 1982), Section 1, Paragraph E.1.a., describes the
licensee commitment to design the fire detector systems in
the Reactor Building in accordance with NFPA 72D/E. '
Contrary to the above, your design does not conform to NFPA
72D/E, in that the number of detectors per square foot of
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floor space has not been met; the maximum distance between
! individual detectors is exceeded (120 feet instead of 30
feet); and the location of detectors relative to ceilings
does not conform to NFPA 72D/E. (Unresolved Item 84-46-05)
Corrective Steps Which Have Been Taken >
As noted during the 1/15/85 meeting, placement of fire detectors
at Shoreham had been approved by American Nuclear Insurers (ANI)
in 1981. LILCO had, however, initiated an engineering review of
fire detectors by a qualified fire protection consultant to
assess compliance with the literal requirements of NFPA 72D/E
regarding placement and spacing of fire detectors. A draft
report has been issued and a final report is scheduled to be
issued documenting this review. In addition, LILCO has taken
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interim compensatory measures in the Reactor Building consisting
- of hourly fire watch patrols.
Corrective Steps Which Will Be Taken
A physical walkdown of potential locations for additional detec-
tors to achieve literal NFPA 72E compliance has been initiated
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and a preliminary schedule for their installation has been
j developed. Departures from NFPA 72E requirements will be
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justified. In adding or relocating detectors, LILCO intends to
schedule work such that modifications are accomplished first in
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those radiation areas which provide the highest potential for
personnel exposure, in keeping with ALARA principles.
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The addition of detectors is a complex and time consuming task
which includes determination of suitable locations, for effective
operation and access for required maintenance and surveillance
activities. In addition, other aspects such as the routing and
installation of cable and the design and installation of seismic
supports must be addressed. Scaffolding and other installation
details (welding, grinding) demand a prudent approach to ensure
there is no potential for adversely affecting redundant trains of
plant equipment, thus constraining the number of areas which can
be worked at any one time. ;
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Date When Full Compliance Will Be Achieved
Initial design and installation planning has taken place for the
additional detectors. As stated previously, emphasis is being
placed on areas with high radiation zones and areas where
currently no detectors exist (Control Building corridor). This
overall ef fort requires the addition or relocation of about 300
detectors. LILCO expects to commence installation and relocation
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activities approximately the first week of February, 1985.
An ANI approved fire detection system exists throughout the
, Reactor Building. This has been supplemented by compensatory
measures prescribed in the Technical Specifications for inoper-
able fire detectors as described in letter SNRC-ll22. LILCO
believes that this system and the existing compensatory measures ,
provide an equivalent degree of protection such that compliance
r with GDC 3 is achieved.
A tabulation is attached dividing this effort into 3 phases and
showing the approximate number of detectors involved in each
phase.
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Phase I detectors will be installed by approximately June 1,
1985. Installation of detectors for Phases II and III is
targeted to be completed by December, 1985.
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'SNRC-ll41 - Attachm:nt 1
Pnga 3
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Fire Detector Installation
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New Relocated Existing
Area Detectors Detector Detectors
Phase I
Reactor Building 62 2 17
(Elevation S', Elevation 175',
RWCU Area, Main Steam Line
Tunnel Area)
Control Building Corridors 8
and 9, Computer Room ,
Phase II
Remainder of Control Building 48 12 116
and Screenwell
Phase III
Remainder of Reactor Building 178 0 33
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SNRC-1141 - Attachment 1
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Deviation / Departure ,
- B.- The FHAR, Revision 1, Section 1, Paragraph D.l.j., describes
the licensee commitment to provide fire doors having a fire
resistance rating at least equal to the required rating of
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the barriers in which the doors are located.
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Contra'ry to the above, the resistance rating of a signifi-
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cant number of fire doors in the plant is less than the
o' rating of fire barriers in which they are located in that
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the fire doors have been degraded due to their modifications ;
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9 for security reasons. (Unresolved item 84-46-07)
Corrective Steps Which Have Been Taken
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Prior to the NRC Inspection in December, LILCO had initiated an
Underwriter's Laboratory (U/L) fire door inspection'which
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identifiedH59 FHAR fire doors requiring repair. This work is ;
presently underway, and 13 doors are now repaired. In the *
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the: provisions of the Technical Specifications, Section 3.7.8. !
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I Corrective Steps Which Will Be Taken !
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LILCO.will continue its effort _to repair the subject fire doors.
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It-is' anticipated that U/L reinspection and approval will be l
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sought.upon completion of the entire effort. It should be :
recognized 'that in order' to meet NRC regulatory requirements,
) - certain modifications were required to be made to the doors. An '
example of this is the addition of magnetic switches which
provide an indication of door closure. U/L is not expected to i
I. approve.this application. For these doors, LILCO will justify ;
! their acceptability for fire protection utilizing the following
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1) It is LILCO's position that a simply mounted magnetic ,
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switch of the type and size used at Shoreham will not
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2) Where welded' angle brackets have been utilized for l
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mounting of the switches, suitable. resistance of the
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-door is achieved if an automatic spray suppression l
system exists in close proximity to the door or an j
automatic gas suppression system exists in an adjoining ;
- room.
Date When-Full Compliance Will Be Achieved
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The remainder of the FHAR fire doors are scheduled to be repaired
in April, 1985.
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Deviation / Departure
C. The FEAR, Revision 1, Section 1, Paragraph E.2.c., describes
the licensee co=nitment to separate the diesel and electric
fire pumps and their associated co=ponents by a 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire l
barrier.
Contrary to the above, the cables fro = the diesel fire pump
controller and day tank pumps are routed through the sa=e
fire areas as the electric fire pump, thereby not teeting
the required 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire barrier separation. (Unresolved
item 84-46-08)
Corrective Steps Which Have Eeen Taken
LILCO has imple=ented an hourly fire watch patrol for the
electric fire pump room. In addition, engineering has been ,
initiated to relocate the subject cables to ensure cc=pliance
with the FRAR.
Corrective Steps Which Will Be Taken
As'noted above, the subject cables will be relocated to ensure
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compliance with the THAR.
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Date When Full Compliance Will Be Achieved
This codification will be corplete in April, 1985.
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SNRC-Il41 - Attechment 1
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Deviation / Departure
D. The FHAR, Revision 1, Section 1, Paragraph D.I.j., describes
the licensee's commitment to provide an adequately rated
fire damper where a ventilation duct penetrates a fire wall.
Contrary to the above, no fire damper is provided in the
ventilation duct penetrating the 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> fire wall between
the HVAC and chiller rooms at elevation 44 feet.
(Unresolved item 84-46-09)
Corrective Steps Which Have Been Taken
LILCO has implemented the provisions of the Shoreham Technical
Specifications, Section 3.7.8 as an interim compensatory measure.
In addition, engineering has been completed to install a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />
rated fire door in the opening between the HVAC Equipment Room
and the plenum located west of the Chiller Equipment Room.
Delivery of the door, which is the controlling factor for
completion of this fix, is being expedited.
Corrective Steps Which Will Be Taken
As noted above, LILCO will install a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> rated fire door.
This represents a suitable barrier between the HVAC Equipment
Room and the plenum to the west of the Chiller Room, thus
suitably inhibiting the propagation of fire from one of these
areas to the other. In addition, the FHAR will be revised to
depict this change.
Date When Full Compliance Will Be Achieved
This modification will be completed prior to exceeding 5% power.
An FHAR Revision will be submitted to the NRC by April 5, 1985.
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Deviation / Departure
E. The FHAR, Revision 1, Section 1, Paragraph E.5., describes
the licensee commitment to design the Carbon Dioxide
Suppression Systems in accordance with NFPA 12.
Contrary to the above, the Acceptance Test results for such
systems in the Battery Rooms and Cable Tunnel indicate that
the design objective was not achieved in that the carbon
dioxide design density was not achieved at the highest test
point. (Unresolved item 84-46-10)
Corrective Steps Which Have Been Taken
As an interim compensatory measure, LILCO has implemented the
provisions of the Shoreham Technical Specifications, Section 3.7.7.3 for the Battery Rooms A and B.
The inability to meet the CO, design objective in these rooms at
the high elevation was suitably documented as a test exception,
and resolved satisfactorily by engineering with the approval of
ANI. The concentration of CO 3 achieved during the test was
determined to be acceptable f$r the following reasons:
1) The locations where the combustibles are located
experienced a CO, concentration meeting NFPA 12
requirements (greater than 50% density).
2) The fire loading at the high elevation test points in
the room is minimal as combustibles are concentrated at
the lower room heights (batteries and cable trays) .
Thus, the actual CO 2 level at these points, though
below the level required by NFPA 12, will provide
adequate fire protection.
For the Cable Tunnel, this has been judged to be acceptable on
the basis that no safety related equipment is located in this
area.
Corrective Steps Which Will Be Taken
The FHAR will be revised to reflect this exception.
Date When Full Compliance Will Be Achieved
An FHAR revision will be submitted by April 5, 1985.
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Deviation / Departure
F. The FHAR, Revision 1, Section 1, Paragraph E.5., describes
the licensee commitment to design the Carbon Dioxide
Suppression systems in accordance with NFPA 12. ;
Contrary to the above, the design criteria for such system
in the Computer Room is not met in that the fire detectors
which actuate the system are located above the suspended
ceiling and such location would prevent timely successful
actuation of the system if a fire occurred. (Unresolved
item 84-46-11)
Corrective Steps Which Have Been Taken
Engineering has been initiated to install two additional fire
detectors in the Computer Room below the false ceiling, in order
to achieve compliance with NFPA 12.
Corrective Steps Which Will Be Taken
As noted above, two additional detectors will be installed in the
Computer Room.
Date When Full Compliance Will Be Achieved
The addition of these detectors will involve the installation of
supports and other operations which will create an environment
unsuitable for computer use. Experience has shown that shutdown
of the computer and protective covering is necessary to prevent
impact on this equipment. In view of the need for availability
of the computer during low power testing and the fact that the
computer room does not have a safe shutdown function, it would be
most beneficial to schedule this modification during a " window"
so as to impart a minimum constraint on the low power test
schedule. In any event, this modification will be completed by
June 1, 1985.
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SNRC-1141 - Attachm:nt 1
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Deviation / Departure
G. The FHAR, Revision 1, Section 1, Paragraph D.1.j., describes
the licensee commitment to provide a minimum of 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire
rating for ceiling / floor assemblies.
Contrary to the above, such protection was not maintained
for the structural steel which forms a part of the ceiling /
floor assemblies in the charcoal filter room and chiller
room in that their fireproofing protection ("pyrocrete"
coating) was found damaged at elevation 63 feet.
(Unresolved item 84-46-12)
Corrective Steps Which Have Been Taken
LILCO had implemented an hourly fire watch patrol in the above
areas of the Control Building. As stated at the January 15, 1985
meeting, LILCO has replaced or repaired damaged fire proofing
material. A reinspection of damaged areas was performed by LILCO
and subsequent inspection was performed by the Resident Inspector
on January 9, 1985.
Corrective Steps Which Will Be Taken
No further action is required on this specific item and the
hourly fire watch that had been initiated as a compensatory
measure has been terminated.
Performance of technical specification surveillance requirement 4.7.8.1 provides adequate assurance that fire proofed sections of
fire rated walls are suitably maintained or appropriate measures
taken.
Date When Full Compliance Will Be Achieved
Full compliance has been achieved.
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SNRC-1141 - Attach =cnt 1
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Deviation / Departure
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H. Supple =ent 1 to the Shoreha Safety Evaluation Report,
Section 9.5.4, docu=ents the licensee ec==it=ent to install
self-contained 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> battery pack e=ergency lighting in all -
areas of the plant which could be canned to bring the plant
to a safe cold shutdcwn. !
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Contrary to the above, such lighting in several such areas
in the Reactor Building was not installed. (see Inspection
Report 50-322/84-46, Paragraph 8.b. for exact locations). <
(Unresolved ite: 84-46-19)
Corrective Actions Which Have Been Taken
In letter SNRC-572, dated May 21, 1981, LILCO cc==itted to i
install 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> battery powered e=ergency lights in areas needed
for operation of safe shutdown equip =ent and in access and egress
routes thereto.
The equip =ent needed for safe shutdown in the event of loss of
habitability of the Control Roo= is described in the Shoreha:
, FSAR Section 7.5.1.4. This equip =ent is operable fro = the Re=ote
Shutdown Panel (RSP). Eight hour battery power lights have been
installed within the RSP roc = and in access and egress routes to
this roc =. Thus, LILCO =eets the cc==itment =ade in letter "
SNRC-572. <
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In the course of following plant procedures for re=cte shutdcwn, ;
certain precedural steps are taken which, while good practice in
te==s of minimizing potential plant perturbatic cr enhancing
future plant availability, are not needed and could be re=cred
from the procedure without affecting safe-shutdcwn. For exa=ple,
procedure SP 29.022.01, " Shutdown frc= Outside the Control Roc =
E=ergency Procedure", includes a step calling for verification of '
auto start of the Reacter Feed Pu=p Turbine (RFFT) turning gear.
This step requires an cperator to physically go to the RFFT; this
verification, however, is not required for safe shutdev- ci-4-
larly, the specific locations in the Reactor Building that were
noted as requiring operator action (unresolved ite= S4-46-19) are
for performance of actions such as verification of equipment
operation,syste= venting, or redundant instru=ent readcut. These
actions are not required for safe shutdown.
LILCO recognizes the importance of being able to deal with an
event such as loss of the Control Roc = and the desirability of
flexible operator capability and response. LILCO's design phil-
osephy relative to this issue has been defense in depth. The
following additional Shoreham plant features are pertinent.
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1) Eight hour battery packs are installed in the diesel
generator roc =s, energency switchgear rocns, Centrol
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Building and the Screenwell Building. (The 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> ;
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battery powered energency lights located in Diesel !
Generator Room 101 are being relocated to inprove '
illumination at the diesel control panel.)
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2) A 125 volt AC/DC energency lighting systen is located
j throughout the Reactor Building (this is not in lieu of
- 'the 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> battery packs, but supplemental). ,
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l' 3) In addition to the lighting noted above, LILCO has ;
l installed two (2) rechargeable handlights in the l
Control Roc = and two (2) rechargeable handlights in the
remote shutdown panel area.
Actions Which Will Be Taken
As stated above, LILCO will relocate the battery powered e=er-
gency lights in Diesel Generator Roon 101. i
Date When Ccepliance Will Be Achieved
Full ec=pliance will be achieved prior to exceeding 51 power.
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SNRC-Il41
ATTACHHENT 2
Unresolved Items
s
. The following provides the LILCO position or status on other
- unresolved items in Inspection Report 84-46 that were not
discussed.in Attachment 1 to this letter,
i
Unresolved Item 84-46-01 - Cable Separation Analysis Report
Per the agreement at the January 15, 1985 meeting, NRC Region I
' will be in communication with LILCO regarding the selection of
1
one or two zones of the Cable Separation Analysis Report and
- subsequent (approximately 3 weeks later) inspection of
- implementation of this analysis at the offices of Stone & Webster
Engineering Corporation, Boston.
! Unresolved Item 84-46-02 - Specific Locations of Components
i
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Procedures required for shutdown outside the control room have
i been revised to reflect the specific locations of various valves
! and components where local operation may be performed in the
- course of. implementing this procedure.
-Unresolved Items 84-46-17, 84-46-03 and 84-46-04 - Generic Letter
]
81-12, Spurious Signals, High/ Low Pressure Interface
.
Although not strictly applicable to Shoreham a response to
Generic Letter 81-12 was presented to the NRC at the January 15,
1985 meeting, and LILCO's position was provided via handout for
staff review. This included information on high/ low pressure
interfaces and spurious signals. A copy of this handout is
included as Attachment 4.
Unresolved Item 84-46-04 - Diesel Generator Breakers
In addition to-spurious signals, unresolved-item 84-46-04
. involved the cooling requirements for the TDI diesel generators.
Information on this item was also presented at the January.15,
i 1985 meeting and a handout was provided for staff review. A. copy
of this handout is included as Attachment- 5.
Unresolved Item' 84-46-06 - ' Controls for RCIC/HPCI Fire
,! . Suppression
1
As noted during the. meeting held on January 15, 1985,. control
panelsfand associated control cables for deluge valves associated
with the RCIC/HPCI PumpEareas-are offset from the deluge
protected. areas. ' Power cables have been located such that while
not necessarily offset, they are not within the deluge protected
area. The syster, however, is. designed such that the deluge
} valve, once.open, will remain open until manually closed. The
Shoreham design and' installation, therefore, meets the
requirements of NFPA 15.
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SNRC-1141 - Attachment 2
Page 2
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Unresolved Item 84-46-13 - Fire Hazards Analysis for Corridors
and Manhole
A fire hazard analysis for Control Building corridors and
Electric Manhole #1 had not been included in the FHAR. A revised
FHAR will be submitted by April 5, 1985.
As stated at the January 15, 1985 meeting, an analysis has been
conducted for these areas. The Control Building corridors
contain no redundant safety-related cables required for safe
shutdown and no loss of redundant systems is possible upon a fire
in these areas. Similarly, a fire in Manhole #1 could not affect
redundant trains for which credit is taken in the shutdown
scenario associated with such a fire.
Although the results of the fire hazards analysis were favorable,
LILCO will nonetheless install fire detectors in Control Building
corridors 8 and 9. This will be accomplished by June 1, 1985.
Manhole #1 has existing fire detectors and a CO2 suppression
system.
Unresolved Item 84-46-14 - Single Header in the Reactor Building
Branch Technical Position 9.5-1 Appendix A requires that a single
failure not impair the fire suppression system. LILCO complies
with the BTP. With respect to the single header in the Reactor
Building, LILCO has utilized the guidance of MEB-1 in determining
l
that the postulated pipe failure for this moderate energy system
would result in a crack producing a leakage of 165 gpm. Such a
failure would not impair the fire suppression system in the
,
Reactor Building since each fire pump has a rated capacity of
2500 gpm.
The single header configuration utilized at Sho~reham was
inspected and reviewed by the NRC during the FSAR review process
(1979-1980). As a result of a staff question (FHAR Question 1),
a redundant feed to the Reactor Building was installed. With
this modification, the Staff accepted the design of Shoreham's
fire header for the Reactor Building.
A copy of drawing M-10661, Rev. 12, " Water Fire Protection
System" is enclosed, showing the water suppression system in the
Reactor Building. Shoreham Technical Specifications require that
if the fire suppression water system becomes inoperable, a backup
fire suppression water system must be established within 24
hours. From the enclosed figure it can be seen that certain
non-postulated circumferential breaks in the Reactor Building
could be isolated and backup suppression established via hose
reels or extinguishers. Depending on the location, certain other
non-postulated breaks could render the fire suppression system
temporarily inoperable. If backup suppression could not be
established, LILCO would bring the plant to the shutdown
condition.
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.SNRC-ll41 - Attachmsnt 2
.Pege 3
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The FSAR has always contained the single header configuration.
The NRC accepted this configuration and LILCO believes that a
backfit is not justified.
- Unresolved item 84-46-15 - Structural Integrity of Cable Tray .
Penetrations Seals
.
This item involves the concern that a cable tray penetration seal
.
may be damaged by imposition of dynamic loads imposed on the seal
l Hby failure of " unprotected" cable tray support in the case of a '
fire.
There are a total of 35 cable tray supports adjacent to
penetrations'in 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> areas. These supports are identified on
l Table 1. As indicated on Table 1, automatic fire suppression is
provided in the affected areas except for the screenwell and the
turbine building where a total of 8 supports are located. For
those areas where automatic fire suppression is provided, the
- potential effect of fire loading on the supports is not ,
4
considered for this analysis because the suppression system will
i minimize the severity of any fire that occurs, making damage to
- supports.unlikely.
Where automatic fire suppression is not provided, the combustible
,
materials which could contribute to a fire are primarily cables
and the fire loading is low, except for El. 37-6 in the turbine
}- building which has moderate fire loading. The actual fire
- loading for these areas is quantified on Table 1. Considering
that cables are the only significant combustibles in the area, it
is extremely unlikely that a fire could develop which would
affect the cable tray supports. The cable jackets are made of
flame retardant and self ' extinguishing material and even the
worst-case cable fault can not establish a deep-seated fire in
the cable tray. Even an exposure fire in the area resulting from
one gallon (see FHAR question 1) of gasoline will not establish a
- fire in the cable trays. If the fire takes place with the
gasoline container intact, the fire will last approximately 40-
'
g minutes and the temperature in the region of the cable trays will
{ be only about 250*F. If the container spills, the fire will last
less than one minute and the temperature at the cable trays will
j be less than 750'F. Conceivably, the gasoline could be poured
j- into the cable-tray in the vicinity of the support and ignited.
4
The resulting fire could establish a deep-seated fire in the
! cables themselves when the fire retardant materials are driven
-
out after an extended burning period. Should this unlikely event
- occur, it.has been determined that the temperature at which the-
! installed cables would burn is approximately ll50*F.-
This temperature is based on gesting performed by Factory Mutual l'
'
Research Corporation for EPRI and-the United States Department
of Transportation. Cables installed at SNPS are of similar l
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.- ,
SNRC-1141 - Attachment 2
Pcgn 4
materials as the majority of cable samples tested by Factory
Mutual. The temperatures recorded by Factory Mutual were the
surface temperatures at the cable during propagation of fire.
Actual temperature at the cable tray supports would likely be
less than the approximate ll50'F measured during testing.
Without regard for thermal lag and assuming the cable tray
support is exposed to that temperature for the duration of the
fire, the support will not fail. At 1150'F, the strength of
structural steel is approximagely 50 percent of the yield
strength at room temperature
Analysis of the cable tray supports show that the stresses due to
deadweight of the tray are within allowable limits at 1150*F.
Therefore, no additional protection of the cable tray supports in
the subject areas is required.
1. EPRI NP-1200, Categorization of Cable Flammability Table
5.1, Page 5-2
t 2n Steel _ Design Manual, U.S. Steel, January 1981.
!
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- TABLE 1
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AUTOMATIC
PENETRATION FIRE
NUMBER SUPPORT LOCATION SUPPRESSION FIRE LOAD
1 Scrr:enwell No 30,538 BTU /ft
SW 104 ( 4 0.5 hrs)
Screenwell No Same
SW 105
2 Emergency Switchgear Yes Not Applicable
Room 101
Emergency Switchgear Yes Not Applicable
Room 103
3 Emergency Switchgear Yes Not Applicable
Room 101
Emergency Switchgear Yes Not Applicable
Room 103
4 Emergency Switchgear Yes Not Applicable
Room 101
Emergency Switchgear Yes Not Applicable
Room 103
5 Emergency Switchgear
'
Yes Not Applicable
Room 101
Emergency Switchgear Yes Not Applicable
Room 103
6 Emergency Switchgear Yes Not Applicable
Room 102
Emergency Switchgear Yes Not Applicable
Room 103
7 Emergency Switchgear Yes Not Applicable
Room 102
Emergency Switchgear Yes Not Applicable
Room 103
I
8 Turbine Building No 83,786 BTU /ft
El 15 (4 1.5 hrs)
Normal Switchgear Room Yes Not Applicable
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- .- TABLE 1
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AUTOMATIC
PENETRATION FIRE
NUMBER SUPPORT LOCATION SUPPRESSION FIRE LOAD
9 Normal Switchgear Room Yes Not Applicable
Turbine Building No 83,786 BTU /ft
EL 15 ( < 1.5 hrs)
10 Turbine Building No 83,786 BTU /ft 2
El 15 ( 41.5 hrs)
Normal Switchgear Room Yes Not Applicable
11 Normal Switchgear Room Yes Not Applicable
12 Turbine Building No 142,650 BTU /ft
El 37-6 ( 42 hrs)
Normal Switchgear Room Yes Not Applicable
13 Turbine Building No 142,650 BTU /ft
El-37-6 (< 2 hrs)
Normal Switchgear Room Yes Not Applicable
14 Motor Generator Room Yes Not Applicable
Auxiliary Boiler Room Yes Not Applicable
15 Motor Generator Room Yes Not Applicable
' Auxiliary Boiler Room Yes Not Applicable
16- Motor Generator Room Yes Not Applicable
Auxiliary Boiler Room Ye s' Not Applicable
17 Motor Generator Room Yes Not Applicable
Auxiliary-Boiler Room Yes Not Applicable
18 Turbine Building No 142,650' BTU /ft
El 37-6 (4 2 hrs)
Normal Switchgear Room Yes Not Applicable
- The_other_ side.of.this. penetration is an_outside wall. _. , , _ _
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. ;Attcchment 2
Pcge 7
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Unresolved Ite= E4-46-16 - Sizing of Water 5 crac.e Cacarity
. .
- As noted in the Jan=ary 15,19E5 =eeting, the fire water stcrage
capacity is adegcately sized in accordance with D 9.5 c= the
basis of the largest sprinkler de-P d for safety related areas
-1=s
r an allevance of 1000 c.:.c.
,
Unresclved Iter E4-46-15 - 4 Enib Batterv. Pack for F2ergen:v.
! I.1geting
Specificaticcs for the 4 b=1b hattery pack req = ire E hecr capa-
- bility.
.
Testine. has been perfer=ed verifv. ine. this capability c
.
l the 4 h=1b battery packs in the plant. Test res=Its vill te
l provided to NPC Regics I.
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SNRC-ll41
ATTACHMENT 3
This attachment provides LILCO's position with regard to cable
tray concentrations in excess of 6 cable trays.
After review of the plant physical cable configuration, the Fire
Hazards Analysis Report and the Cable Separation Analysis Report,
LILCO concludes that the fire protection program provides assur-
ance that a fire will not prevent the performance of necessary
safe plant shutdown functions and will not significantly increase
the risk of radioactive releases to the environment. This is
based on consideration of the following points:
1. The SNPS Cable Separation Analysis Report (CSAR) demon-
strates that, in the secondary containment, sufficient
separation exists between safety related components of
redundant systems required for safe shutdown, and that
a postulated event causing the disabling of all cables
and raceways in the designated area will not prevent
safe plant shutdown. This considers the extreme case
where an event is assumed to disable shutdown equipment
whose cable terminate in or is routed through each
affected area. The report concludes that for the
postulated event, with the concurrent loss of offsite
power, hot and cold shutdown can be accomplished in
each case using only safety-related systems and equip-
ment.
2. As a result of the NRC's review of the FHAR, LILCO was
requested to describe the fire fighting techniques that
would be used to extinguish a cable tray fire. The
response, as contained in Rev. 1 of the SNPS FHAR, page
6-1, explains that water hose stations and portable
extinguishers are provided for fire suppression. In
the case of fire in the cable tray, water shall be
sprayed on the cable tray to keep it cool and thus
prevent the reignition of fire.
3. Cable tray automatic water suppression systems do exist
at two locations in the Reactor Building, in close
proximity to the HPCI turbine. Note: Category I MCC's
in the vicinity would not be detrimentally affected by
these existing suppression systems.
4. Manual hose standpipe systems are located strategically
throughout the Reactor Building to fight postulated
cable tray fires.
5. Cable tray fire breaks exist in vertical trays at 15'
intervals and in horizontal trays at 20' intervals.
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SNRC-ll41 - Attachmsnt 3
,Page 2
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6. The Reactor Building has two main safety-related
vertical tray risers located in separate quadrants.
The plant requires only one of these vertical risers to
be operational for safe shutdown (see CSAR) . The tray
risers have fire stops at each floor level, fire breaks
at 15' intervals, solid bottoms and carefully fitted
Covers.
7. The design configuration of the Reactor Building makes
water deluge systems in the many areas where six or
more cable trays exist inappropriate due to the close
proximity of motor control centers and other electrical
equipment. Water damage to this equipment could
propagate accident circumstances.
8. Many cable tray covers have been added to meet Regula-
tory Guide 1.75 requirements for electrical separation.
The effectiveness of a water suppression system would
be compromised by the existence of these covers.
Removal of the covers, however, is not compatible with
existing electrical separation requirements.
LILCO feels that, in view of the above points, the present
Shoreham design provides sufficient protection to fulfill the
requirements of the GDC. In light of this and the fact that
there was previous NRC concurrence on the acceptability of.the
Shoreham design, LILCO trusts that this issue remains resolved.
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- ATTACHMENT 4
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SHOREHAM NUCLEAR POWER STATION
FIRE PROTECTION EVALUATION
RESPONSE TO GENERIC LETTER 81-12 SPURIOUS SIGNALS
HIGH/ LOW PRESSURE INTERFACES
NRC 84-46-03, 84-46-04, 84-46-17
(K-1, F-1, T-2)
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-0173-1520101-B6 1
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RESPONSE TO NRC GENERIC LETTER 81-12
A requirement for the electrical design of the Remote Shutdown Panel (RSP)
is that the system must be isolated from all associated circuits as defined
in NRC Generic Letter 81-12 (including all circuits routed through the
control room and relay room) such that hot shorts, open circuits, or shorts
to ground in the associated circuits will not prevent operation of the safe
shutdown equipment or result in spurious operations which could adversely
affect the shutdown capability of the RSP. The NRC Generic Letter 81-12
defines three types of associated circuits: common power source, spurious
operation, and common enclosure. The electrical design methods for Shoreham
Nuclear Power Station (SNPS) are employed to protect the RSP from associated
circuits and their potential effects. An evaluation of the RSP performance
due to each type of associated circuit defined in Generic Letter 81-12 is
performed.
I. COMMON POWER SOURCE
.
Analysis for SNPS has shown that only safety-related equipment and circuits
are required to bring about a safe shutdown.
SNPS does not have associated circuits of the type having a common power
source with the shutdown equipment and the power source not. electrically
separated from the circuit of concern by coordinated breaker, fuses, or
similar devices. The RSp ' circuitry was specifically designed to avoid
introducing circuits of this type. Control circuits from the remote
shutdown . panel are either routed independently from the control room and
0173-1520101-B6 2
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relay room or ' transfer switches are employed to isolate wiring run through
these areas and to transfer the control circuit to a new power source.
Thus short or open circuits or a blown fuse in the control circuit due to
events in -the control room or relay room will not disable the control
capability at the remote shutdown panel. Therefore, it is not necessary to
perform an evaluation for this type of associated circuit.
.
0173-1520101-B6 3
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II. SPURIOUS OPERATION
The following sections describe the analysis performed to demonstrate that
spurious operation will not prevent the RSP from achieving cold shutdown
during a fire in the control room or relay room. The analysis was presented
for four categories of equipment located in the control room or relay room:
'(1) Remote Shutdown Panel (RSP)
(2) S/RVs
(3) Non-RSP Equipment
(4) High-Low Pressure Interface
Spurious operation was evaluated for its potential consequence in
accordance with the assumptions described below:
(1) Spurious operation occurs simultaneously with other fire effects.
(2) Spurious operation for any equipment in the control room or relay
room is considered unless the equipment is protected.
(3) A motor-operated valve or any other electrical equipment that has
its power supply disabled during normal operation will not
spuriously operate.
RSP Equipment
The RSP was designed to handle spurious operations for equipment within its
- own system. Manual control of the RSP components is available at the remote
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shutdown panel,(RSP). Therefore, it is possible to correct any undesirable
spurious operations once the manual control transfer from the control room
to the RSP is accomplished. For example, spurious operation of an RHR
system valve may divert the makeup water away from the reactor vessel.
However, once the control is transferred to the RSP, the valve can be
closed to provide sufficient makeup flow for the reactor vessel. Following
transfer of control, all RSP equipment will be isolated from both the
control room and the relay room.
Safety / Relief Valves
Spurious S/RV operation, where the valve fails open, can reduce reactor
coolant inventory and increase suppression pool temperature. The RSP
design considers the spurious operation of one S/RV as outlined in FSAR
Chapter 15.
Other Non-RSP components
Other non-RSP components include all the equipment in the control room and
relay room' which is not a component of the RSP, a high-low pressure
interface, or an S/RV. Examples of these components are the Division I and
Division II of core spray, high pressure coolant . injection (HPCI), and
Division I of the . RHR. These components will not prevent the RSP from
achieving cold shutdown for the following reasons:
(1)- No credit is taken for operation of these components. Spurious
stop of a component is equivalent to the loss of the component.
0173-1520101-B6 5
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Spurious start of any of these components will not degrade the RSP
performance.
(2) Effects of spurious operation are bounded by other events. For <
example, spurious operation of the HPCI system could lead to
inventory loss because of the steam-driven turbines. However, the
amount of inventory loss due to these spurious operations is
bounded by the spurious opening of a single S/RV. Therefore,
consideration of spurious operation of these non-RSP components is
not required.
Any spurious operation of the non-RSP components in the control room or
relay room will not prevent the RSP from achieving cold shutdown.
High-Low Pressure Interface
A high-low pressure interface is a special case of spurious operation which
may result in a. breach of the barrier between a low pressure system and. the
reactor coolant pressure boundary. A list of. all high-low pressure
interfaces is provided in Table 1. These components were identified by
tracing through all the paths on the nuclear boiler system which may lead to
a low pressure system. The significance of the high-low pressure interface
was then evaluated to identify the necessary corrective actions. The
following types of high-low pressure interfaces do not require corrective
action:
0173-1520101-B6 6
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- (1) One-inch or smaller line because the amount of inventory loss is
minimal.
(2) Lines which have check valves to prevent potential inventory loss.
(3) Lines that contain an isolation valve which has its power disabled
during normal operation.
(4) Lines bounded by events previously analyzed and bounded by
Shoreham design basis. (single stuck open SRV)
Based on this method, the fire protection analysis concluded that only five
sets of valves would require corrective actions. These valves are: ,
(1) 1E11*MOV051 and 052 on the RHR line to the radwaste system.
(2) IB21*MOV083 and 084 reactor vessel head drain valves.
(3) 1G33*MOV037, 038, 039, on the reactor water cleanup (RWCU) line to
the main condenser and waste collector tanks.
(4) 1E11*MOV081A,B - RHR testable check bypass valves
(5) 1E21*MOV081A,B - CS testable check bypass valves
The corrective actions for (1) and (2) above is to remove the overload
heater for one of the valves (1E11*MOV052, 1B21*MOV083) when the plant is at
0173-1520101-B6 7
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power operation. The overload heater will be returned to these valves under
controlled conditions when their services are required during plant
shutdown. -For (3) above, the identified corrective action is to remove the
overload heater for valve 1G33*MOV037. This valve is in parallel with a 3/8
inch restricting orifice (1G33*R0050) which is upstream of valves
1G33*MOV038 and 039. The 3/8-inch orifice will limit the amount of
potential inventory loss through the downstream high-low pressure
interfaces. This corrective action allows the plant to retain the required
services of the valves 1G33*MOV038 and 039 during normal plant startup
operations without sacrificing plant protection.
For (4) and (5) above, the corrective action is to recalibrate the limit
switches such that the valves will be limited to open equivalent to a
1-inch line sfze. This allows these valves to open as required during
plant operation.
The RSP will not affect any of these components or their
corrective actions; therefore, the high-low pressure interface has no impact
on the RSP .
III. COMMON ENCLOSURE
The electrical separation design basis at SNPS allows associated circuits of
the common enclosure type in the control and relay rooms.
To ensure that these associated circuits will not affect the RSP operation,
it is necessary to:
0173-1520101-B6 8
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(1) provide appropriate measures to prevent propagation of the fire,
and
(2) provide electrical protection (e.g., breakers, fuses, or similar
devices).
Fire in the control and relay rooms will not propagate to the RSP area or to
the MCC area with which the RSP interfaces. This is because the control and
relay rooms are in a different building than the RSP and MCC areas. The RSP
circuitry is also protected from any damage from the fire in the control and
relay rooms by cable routing. Therefore, adequate protection has been
provided for the RSP, and associated circuits of the common enclosure type
will not affect the RSP,
.
0173-1520101-B6 9
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TABLE 1
- High/ Low Pressure Interface Components
System Reference Equipment Corrective Action.
RHR FM-20A,B IE111PMOV051,52 Remove overload heater
(F040,F049) for MOV052 during normal
plant operation.
RWCU FM-24A IG33-MOV037,038, Remove overload
039 HCV004 on MOV037 heater
(F031,33,34,35) during normal plant
operation. 1G33*R0050
(3/8 in. orifice) in
parallel with this valve,
upstream of valves
MOV038,39.
,
NSSS < FM-29A IB21*MOV083,084 Remove overload heater
/ (F001, F002) for MOV083 during normal
plant operation
'
RHR FM-20A,B IE11*MOV047,048 No action required
(F008, F009) Note 4
NSSS FM-29A IB21*A0V081A-D No action required
082A-D Note 5
RHR FM-20A,B IE11*MOV036A,B No action required
037A,B Note 1
(F015A,B, F017A,B)
RHR FM-20A,B IE11*MOV053,054 No action required
(F022, F023) Note 1
RHR FM-20A,B IE11*MOV081A,B Limit valves to opening
(F050A,B) equivalent to 1 in. line
size
CS FM-23A 1E21*MOV033A,B No action required
(F005A,B) Note 1
^
CS FM-23A 1E21*MOV081A,B Limit valves to opening
(F047A,B) equivalent to 1 in. line
size
HPCI FM-25A,B IE41*MOV035 No action required
(F006) Note 1
RCIC FM-22A' IE51*MOV035 No action required
(F012) Note 1
1
0173-1520101-B6 10
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System Reference' Equipment Corrective Action
HPCI FM-25A,B IE41A0V081,082 No action required
(F028,29) Note 2
RCIC FM-22A 1E51A0V081,082 No action required
(F025,026) Note 2
RHR FM-20A,B IE11*MOV049 No action required
(F052) Note 3
CRD FM-27B IC11*A0V081,082 No action required
051,05 0 Note 5
(F010,011,0180,181)
HPCI FM-25A,B IE41*MOV043 No action required
(F001)- Note 6
NOTES:
1. Check valve in series to provide protection.
2. One-inch line size limited, no unacceptable release.
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3. Release would be comparable to SRV release which is bounding.
4. Reactor pressure interlock (outside control room) provides ,
protection.
5. Numerous - interlocks in the Reactor Protection System (outside
control room) provides protection. ,
6. Rupture disc rupture results. in isolation of HPCI turbine.
Pressure switch between the two rupture discs in series will
close both the steam inlet valve and the HPCI turbine stop valve,
either of which will isolate the HPCI steam line from atmosphere.
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ATTACHMENT 5
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SHOREHAM NUCLEAR POWER STATION
FIRE PROTECTION EVALUATION
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DIESEL GENERATOR BREAKERS
NRC 84-46-04
(T-1)
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MULTIPLE FAILURE OF EMERGENCY DIESEL GENERATORS
DUE TO A FIRE IN THE MAIN CONTROL ROOM
.The following conditions would have to be assumed for a fire in the main
control room to disable all three emergency diesel generator breakers by
shorting out the " closed" indicator light. For the purpose of this
evaluation three different scenarios were developed.
I. INTERNAL PANEL FIRE ASSUMPTIONS
1. The limited amount o# combustible material in a diesel generator
section of the main control board is ignited.
2. The ionization fire detector within that section fails to respond
to the fire.
3. The smoke and heat generated by the fire are not noticed by (sight
or smell) any of the personnel in the control room which is
continuously manned.
4. The fire continues to burn, generating sufficient heat to ignite
the combustibles in the adjacent diesel generator sections.
5. The adjacent sections burn undetected by the individual smoke
detectors, and the fire is not detected by any of the personnel in
the main control room.
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This is not considered to be a credible event since there are only limited
amounts of combustibles in these sections, each section has an individual
ionization fire detector, and the sections are completely barriered off from
each other by 1/8 in. steel plate and 1/8 in. of fiberglass reinforced
plastic as a thermal and fire barrier.' Finally, it is extremely unlikely
that the fire would go undetected by operating personnel.
II. EXPOSURE FIRE ASSUMPTIONS
1. A combustible material of sufficient quantity to cause
considerable damage to wiring and components inside the main
control board is placed directly in front of the diesel generator
section.
2. The combustible material is ignited, and the fire is large enough
and intense enough to penetrate through the louvers of all three
diesel generator sections.
3. The control room personnel are unable to extinguish the fire with
hand-held fire extinguishers or CO hose reels. (It is not
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credible to assume that the fire is undetected by operating
personnel.)
4. Control room personnel are forced to evacuate the main control
room because of the smoke and heat generated by the fire.
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S. The flames penetrating the louvers in each of the three diesel
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generator sections go beyond the air space behind the panel steel
and ignite the combustibles in these sections.
This is not considered to be a credible event since the amount of
combustible material (either solid or liquid) allowed in the main control
room is strictly controlled by plant procedure. The amount of flammable
liquid is restricted to one pint unless specifically approved by upper plant
management in accordance with the Shoreham fire protection program. This
control also extends to ignition sources such as open flame, welding
equipment, and other equipment which could ignite combustible material.
Additionally, the opening on the individual louvers is small (1/2 in. by 5
in., approximately) and is angled such that the louvered openings are not
completely horizontal thus reducing the effective open area.
Fire extinguishers are available in the main control room, and CO hose
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reels are provided just outside the control room door. Breathing equipment
is provided in the form of self-contained air packs and breathing air lines
from a breathing air system of nominal six hours capacity. It is not
credible to assume that the fire could start and reach such an intensity
that it could not be rapidly extinguished by control room personnel.
III. EXPLOSION AND FIRE ASSUMPTIONS
1. A large quantity of combustible liquid is brought into the main
control room and placed near the diesel generator sections of the
main control board in violation of written plant procedures.
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2. The liquid is ignited and explodes, rapidly spreading the fire
throughout the control room.
3. Control room personnel are driven out of the room without being
able to take corrective action.
4. The fire affects all three emergency diesel generator sections of
the main control board.
This is not considered to be a credible event since the amount of
combustible liquid allowed in the main control room is strictly limited as
are potential ignition sources. Also, flame retardancy of material was
considered in the design of the main control room.
IV. LOSS OF OFFSITE POWER
Each of the above three postulated events also assumes a simultaneous loss
of offsite power such that the diesel generator breaker control circuits are
disabled prior to closing onto their respective emergency buses. Once the
breakers have closed, disabling the control circuit will have no effect.
V. HIGH JACKET WATER TEMPERATURE TRIP
Even if the loss of all three emergency diesel generator output breakers is
assumed with the consequent loss of service water to the diesels, the
diesels will not be damaged, since during a loop event without a LOCA the
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diesel generator protective trips are not disabled. The diesels would trip l
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on high jacket water temperature. This would result in a station blackout l
event (no credit taken for mobile diesels or gas turbine generators).
Approximately three hours are available in which to manually start the
diesel generators from the diesel generator rooms and manually close the
diesel output breakers from the emergency switchgear rooms.
VI. CONCLUSION
For the reasons stated in Sections I, II, and III above, the events
postulated are not credible, and the current design of the Shoreham control
room is sufficient to prevent unacceptable levels of danage from any
credible fire affecting control of the emergency diesel generators.
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