ML20078B625

Forwards Info for Resolution of SER Outstanding Issue 13 Re Remote Shutdown Capability

ML20078B625
Person / Time
Site:	Clinton
Issue date:	09/22/1983
From:	Nelson R ILLINOIS POWER CO.
To:	Schwencer A Office of Nuclear Reactor Regulation
References
RTR-NUREG-0853, RTR-NUREG-853 0982-L, 982-L, U-0669, U-669, NUDOCS 8309270175
Download: ML20078B625 (38)

Text

U-0669 Dlinois Power Company 0982-L t30_83(09-22)-L 500 SOUTH 27TH STREET, P. 0. BOX 511, DECATUR. ILLINOIS 62R25-1805 Docket No. 50-461 September 22, 1983 Director of Nuclear Reactor Regulation Attention: Mr. A. Schwencer, Chief Licensing Branch No. 2 Division of Licensing U.S. Nuclear Regulatory Commission Washington, D.C. 20555 Subj ect : Clinton Power Station Unit 1 SER Outstanding Issue #13 (NUREG-0853)

Remote Shutdown Panel

Reference:

IP letter dated December 2, 1981 (U-0639),

J. D. Geier to J. R. Miller, NRC

' The referenced letter provided the Illinois Power Company position relative to the remote shutdown capability. Subse-quently, a meeting was held in Bethesda on March 30, 1982 to discuss with NRC personnel of the Instrumentation and Control Systems Branch the requirements for the Remote Shutdown Panel.

Recent telephone conversations were held with NRC Staff (Messrs. H. Abelson and R. A. Kendall) and IP personnel (Messrs. J. P. O'Brien and G. E. Wuller) to discuss resolution of SER Outstanding Issue #13, Remote Shutdown Panel. This transmittal provides the information for the Clinton remote shutdown panel which we understand will resolve the subject SER issue. Included are the following:

1) Material on remote shutdown system (RSS) used in the IP presentation at the 3/30/82 neeting.

2) Table (4 sheets) of Locations of Division I and II Remote Controls for Shutdown.

pol I 8309270175 830922 PDR ADOCK 05000461 E PDR

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U-0669 0982-L L30-83(09-22)-L September 22, 1983 Page 2

3) Supplemental Information on the Qualification of the Instrumentation Mounted on the Remote Shutdown Panel (RSP).

4) General Arrangement (S&L Drawing M01-1109, Rev. C) showing the location of RSP and Backup MCCs and 4 Kv Breaker.

5) Clarifying Information on the operation of the Remote Shutdown Panel.

We trust that this information will resolve SER Outstanding Issue #13 for closeout in the next SER supplement . Copies of the RSP drawings will be submitted when they are finalized.

Sincerely, v.5

. Nelson '

Director-Nuclear Licensing and Configuration Nuclear Station Engineering GEW/lt attachment I cc: H. Abelson, NRC Clinton Licensing Project Manager R. A. Kendall, NRC ICSB Illinois Department of Nuclear Safety H. H. Livermore, NRC Senior Resident Inspector i

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REMOTE SHUTDCWN SYSTEM (RSS) 0 SAFETY DESIGN BASES RSS IS NOT A SAFETY SYSTEM 0 LOCA OR OTHER ABNORMAL EVENTS ARE NOT ColNCIDENT WITH CONTRCL ROOM EVACUATION O NOT REQUIRED TO MEET SINGLE FAILURE CRITERIA 0 NO OPERATOR ERROR IS ASSUMED PROVIDED TO MEET REQUIREf/ENTS OF GDC 19 RSS COMPONENTS WH1CH INTERFACE WlTH OTHER SYSTEMS ASSUl/E THE DESIGN CRITERION OF THOSE SYSTEMS 0 FUNCT10N THE RSS PROVIDES THE MEANS FOR A PROMPT CONTROLLED HOT SHUTDOWN BY MANUAL CONTROL OF .

m O RCIC WATER MAKE-UP 0~ ' RHR SUPPRESSION COOLING MODE AND SUBSEQUENT COLD SHUTDCWN BY MANUAL CONTROL OF 0 RHR REACTOR SHUTDCWN C0 CLING MODE O NUCLEAR BOILER SYSTEM (3 SRV'S) 3

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REf/.0TE SHUTDOWN SYSTEM (NSS)

(CONTINUED) 1 0 SIGNIFICANT INSTRUMENTATION AND CONTROLS INSTRUi/ENTATION, VALVE POSITION, REACTOR VESSEL LEVEL ANC PRESS, RCIC AND RHR FLOW, CONTAINMENT FRESS N4D TEMP, AND SUPPRESSION l

POOL LEVEL AND TEMP -

USE OF THE RSS CAUSES AN ALARM IN THE CONTR0'. ROOM  !

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! - CONTROL ROOM LOGIC, PERMISSIVES, AND INTERLOCKS FOR THE FUNCTIONS CONTROLLED BY THE RSS ARE BYPASSED BY MANUAL INITIATION OF VALVES AND PUMPS e

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Issue

Title:

Remote Shutdown Panel Issue:

The remote shutdoun capability should meet the following criteria:

To Meet GDC-19 (As interpreted in SRP Section 7.4)

1. The design should provide redundant safety grade capa-bility to achieve and maintain hot shutdown from a location or locations remote from the control room, assuming no fire damage to any required systems and equipment and assuming no accident has occurred. Credit may be taken for manual actuation (exclusive of contin-uous control) of. systems from locations that are rea-sonably accessible from the Remote Shutdown Panel.

Credit may not be taken from manual actions involving jumpering, rewiring or disconnecting circuits.

2. The design should provide redundant safety grade capa-bility for attaining subsequent cold shutdoun through

,7 the use of suitable procedures.

h To Meet Appendix K (ECCS Requirements)

3. The design should be such that the manual transfer of control to the remote location (s) should not disable any automatic actuation of ESF functions while the plant is attaining or maintained in hot . shutdown, other

~

than where ESF features are manually placed in serv..ce to achieve or maintain hot shutdown. It is permissible to disable automatic LPCI actuation in this manner only

?$en necessary in order to enable control of the RHR

- system to effect cold shutdown from hot shutdown.

To Meet Appendix R (Fire Protection Requirements)

4. The design should provide, as a minimum, non-redundant safety grade systems necessary to achieve and maintain hot shutdown from either the control room or from a remote location (s) assuming a postulated fire in any fire area, including the control room or the Remote Shutdown Panel. Credit may be taken for manual actuation (exclusive of continuous control) of systems from loca-tions that are reasonably accessible from the control room or the Remote Shutdoun Panel, as applicable. Credit

, may not be taken for manual actions involving jumpering, rewiring or disconnecting circuits.

. Page 2 5 ,

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5. The design should provide, as a mininum, non-redundant safety grade systems necessary to achieve and maintain cold shutdown from either the control room or from a remote location (s) . The design should be such that in the event of fire damage in any fire area, systems could be repaired or made operable within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> if required for cold shutdown.

Response

General Design Criteria 19 in Appendix A of 10 CFR 50 reads as follows:

'Driterion 19 - Control Room . A control room shall be provided from which actions can be taken to operate the nuclear power unit safely under normal conditions and to maintain it in a safe condition under accident conditions, including loss-of-coolant accidents. Adequate radiation protection shall be provided to permit access and occupancy of the control room under accident conditions without personnel receiving radiation exposures in excess of 5 rem whole body, or its equivalent to any part of the body, for the duration of the accident.

Equipment at appropriate locations outside the control room "1. shall be provided (1) with a design capability for prompt Ns hot shutdown of the reactor, including necessary instrumen-tation and controls to maintain the unit in a safe condition during hot shutdown, and (2) with a potential capability for subsequent cold shutdown of the reactor through the use of suitable procedures."

~

The control room and remote shutdown panel design for Clinton Power Station fully meet the req,uirements of GDC 19. .

The design bases used in the design of the remote shutdown capability to meet the requi,rements o.f GDC 19 are as follows:

1. The plant is operating initially at, or less than, design power.

/

2. The plant is not experiencing any transient situations.

Even though the loss of off-cite ac power is considered unlikely, the remote shutdown panel is powered from a Class 1E power system bus so backup ac power would be automatically supplied by the plant diesel generator.

Manual controls of the diesel generator are also avail-able outside the main control room.

S

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3. The plant is not experienc2ng any accident situations.

No design basis accident (including a LOCA) shall be assumed, so that complete control of engineered safe-guard feature systems from outside the main control room is not required.

4. All plant personnel have evacuated the main control room.

5. The main control room continues to be inaccessible for several hours.

6. The initial event that causes the main control room to becone inaccessibic is assumed to be such that the re-actor operator can manually scram the reactor before -

leaving the main control room. If this was not possible, the capability of opening the output breakers of the RPS logic from outside the main control room can be used as a backup means to achieve initial reactor reactivity shutdown.

7. The main turbine pressure regulators may be controlling reactor pressure via the bypass valves. However, in the interest of demonstrating that the plant can accommodate even loss of the turbine controls, it is assumed that this turbine generator control panel function is also lost.

.c Therefore, main steam line isolation is assumed to occur at a specified lou turbine inlet pressure and reactor pressure is relieved through the relief valves to the suppression pool.

8. The reactor feedwater system which is normally available is also assumed to be inoperable. Reactor vessel water inventory is made up by the RCIC system.

e

9. Dc power services are expected to be supplied from dt least one plant de power system for each essential system or equipment item in the remote shutdown system.

~ ~ ~ ~ ' ~ For remote shutdown operation, no off-normal operation is

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assumed. The remote shutdown capability, by itself, does not perform any safety related or protective function. This system interfaces with safety related systems, such as RHR and RCIC and meets the design criteria fcr those systems. No additional design criteria for the remote shutdown capability are necessary since they are already addressed in the res -

pective design requirements.

The capability to achieve and maintain hot shetdown and sub-sequent attainment of cold shutdown is enumerated as follows:

1. The capability provides remote control for reactor systems needed to carry out the shutdown function from outside the main control room and bring the reactor to cold condition in an orderly fashion.

- - - --n - , -,

Page 4 I 2. It provides a variation to the normal system used in the main control room permitting the shutdown of the reactor when the normal heat sinks (turbine and condenser) are assumed to be unavailable.

3. Automatic activation of relief valves and the Reactor Core Isolation Cooling (RCIC) system will bring the reactor to a hot shutdown condition after scram and isolation are achieved by removing Reactor Protection System power.

During this phase of shutdown, the suppression pool will be cooled by operating the Residual Heat Removal (RHR) system in the suppression pool cooling mode. Reactor pressure will be controlled and core decay and sensible heat rejected to the suppression pool by relieving steam pressure through the relief valves. Reactor water inven-tory will be maintained by the RCIC system.

4. Manual operation.of the certain safety relief valves will cool the reactor and reduce its pressure at a controlled rate until reactor pressure becomes so low that the RCIC system will discontinue operation. This condition will be reached at 50 to 100 psig reactor pressure.

5. The RHR system will then be operated in the shutdown cooling

.., mode using the RHR systcm heat exchanger in the reactor water circuit to bring the reactor to the cold low pressure condition.

6. Essential equipment cubicles cooling systems vill maintain the design basis environmental conditions for equipment operated from the remote shutdown panel.

The remote shutdown capability is designed to control the re-quired shutdown systems from outside the main-control room irrespective of shorts, opens, or grounds in the control'cir-cuit in the main control room that may have resulted from an event causing an evacuation. The functions needed for remote shutdown control are provided with manual transfer devices

" "~ ~ ~ ~w~ hich override controls in the main control room and transfer the controls to the remote shutdown panel. All necessary power supplies are also transferred. Remote shutdown control is not possible without actuation of the transfer devices.

Operation of the transfer devices causes an alarm in the main control room.

1 Access to areas in which the remote shutdown panel is located is under the control of the security system. Communications with other areas of the plant are being provided.

The following indicators are provided to enable the operator to monitor the status of the shutdown.

. - . . . - - - - - -- - .. = - . , -

Page 5

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l. Reactor water level indactor.

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2. Reactor pressure indicator.

3. Drywell temperature indications (two).

. 4. Suppression pool temperature (three - one near each of the ,

1 three safety relief valves controlled from the remote shut-down panel). ,

5. RCIC Flow Controller and indicator.

6. RCIC Turbine Speed.

j 7. Indicating lights are provided for:

I

a. Turbine tripped

b. Turbine Bearing oil low pressure

c. Turbine governor'end bearing oil temperature high

d. Turbine coupling end bearing oil temperature high l 8. RCIC storage tank level.

L 9. Suppression pool level.

10. .SSUS Strainer discharge pressure.

11. Indicating light for SSUS strainer high differential

. pressure. .

In addition, status lights are provided for equipment op'erated from the panel and for other equipment important to the shut-down.

following description of the shutdown operation identifies contingencies which provided for in the operation of the remote shutdown panel:

1. If evacuation becomes necessary, the operator will scram the reactor by depressing the scram switches at the Prin-cipal Plant Console as he leaves the main control room.

2. Under normal conditions, the main turbine pressure regulator

! will control the reactor pressure while rejecting heat (s team) through the turbine bypass valves, and the feedwater control system will control water level.

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I Page 6

3. Opening the output breakers on. feeders from the NSPS buses and the auxiliary 120 Vac bus to the Reactor Protection System trip logic channels can be used as a backup means of scramming the reactor and closing the containment and reactor vessel isolation valves. The controls for this function are located on the Reactor Protection System power distribution panel.

4. The remainder of the procedure assumes that the automatic pressure regulator is not available and the main steam line isolation valves are closed.

5. Operate transfer switches to transfer control to the remote shutdown panel.

6. Relief valves not used in the Remote Shutdown System may open automatically and cycle to control reactor pressure.

Reactor level starts to drop rapidly or slowly depending on prior power level and clapsed time from scram.

7. The operator starts the RCIC system manually before the RCIC system comes on automatically on reactor vessel low water level initiation and monitors water level thereafter.

8. One relief valve is manually operated maintaining reactor pressure.

9. Reactor level reached RCIC initiation set point level if the RCIC system was initiated at low level. This is well above LPCS or RIIR system initiation level. Level starts to rise as a result of RCIC system flow. Pressure relief is through one relief valve in manual intermittent operation.

10. Water level is returned to normal by operation of the RCIC system.

_ _ , , , 11. Star _t reduction of reactor pressure by manually actuating two relief valves.

12. While activating these relief valves, observe reactor level, reactor pressure, and suppression pool level and tempera-ture. The relief valves are closed when level drops below the low level alarm point. The reactor cooldown rate shall not exceed 100 F per hour, as determined by observing re-actor pressure.

13. Use the RIIR system with one pump and one heat exchanger and associated uater systems to cool the suppression pool. Op-erate the shutdown service water system to supply essential cooling water.

Page 7

14. The operator activates two relief valves to maintain re-duction of pressure while observing pool temperature.

15. Reduce reactor pressure to 100 psig.

16. Place the RHR system in the shutdown cooling mode. Flush the system for several minutes _by pumping reactor water into the supprest ion pool. Then route reactor water back to the vessel, and continue cooldown until the reactor is in the cold low-pressure condition.

17. Hold reactor water level normal.

In addition to the RHR and RCIC controls required to perform the above functions, controls of shutdown service water and essential equipment cubicle HVAC systems are provided.

The following Shutdown Service Water System (SSUS) equipment /

functions have transfer and control suitches located at the remote shutdown panel for proper operation of the remote shut-down system:

One control switch is provided for each of the follouing:

SX0lPA - SSWS Pump

'SX014A - Motor Operated Valve (Plant Service Water /SSW Systems interconnection)

SX063A - Motor Operated Valve (diesel generator cooling water)

One control (selector) switch is provided which is common to the following: ,

SX003A - Motor Operated Valve (SSWS Strainer Inlet)

SX004A - Motor Operated Valve (SSWS Strainer Outlet)

SX008A - Motor Operated Valve (SSWS Strainer Bypass)

Controls-for the strainer motor are available on a motor control center remote from the main control room.

The following essential equipment cubicle HVAC systems have transfer switches located on the remote shutdown panel. Controls

are provided by local instrumentation remote from the main con-trol room.

i VH01CA - Fan (SSWS Pump Cubicle)

VYO2C - Fan (RHR Pump Cubicle) 1 l

i Page 8 VYO3C -

Fan (RHR Heat Exchange Cubicle)

VYO4C - Fan (RCIC Pump Cubicle) 4 VY0lCA - Fan f(Diesel Cenerator Cubicle) l VD02CA - Fan (Diesel Generator Cubicle) 1 l

VX03CA - Fan (Essential Switchgear Cubicle) 4 VX05CA - Fan (Battery Room)

, Status (indicating) lights are provided on the remote shutdown panel for each of the fans listed.

One control switch is provided which is common to all of the following. This switch allows closing of all valves listed.

] SX0llA - Motor Operated Valve (SSWS Div. 1/2 Crosstie Isolation)

] SX082A - Motor Operated Valve (RHR-A heat exchanger de-j mineralized water inlet)

SX012A - Motor Operated Valve (Fuel Pool Heat Exchanger w-Inlet)

SX062A - MOV (Fuel Pool Heat Exchanger Outlet)

SX016A - MOV (Fuel Pool Make-Up Motor)

SX073A - MOV (SGTS Train A Charcoal Bed Water Supply)

SX076A - MOV (Control Room HVAC~ Unit A Deluge) .*

SX107A - MOV (Control Room HVAC Unit A Deluge)

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Page 9 Response to Issue Points t

Issue 1: General Design Criteria No. 19 does not require that redundant safety grade shutdown capability remote from the control room be provided.

GDC No. 19 does not require redundant safety grade Issue 2:

! capability for attaining cold shutdown from outside the control room.

Issue 3: Operation of the. transfer switches at the remote shut *

< down panel transfers control of the systen involved to the shutdown panel including power supply for these controls. This is done so failures in the control room such as shorts and/or opens will not affect manual ,

' operation of the shutdown equipment from shutdown 4 panel.

Issue 4: The design of the control room and the shutdown panel is such that they provide independent means

- of shutdown assuming a postulated fire at either location.

. Issue 5: The design of the control room and the remote shut-down panel is such that they provide independent <

means of shutdown to the cold shutdown condition. .

- assuming a postulated fire at either location.

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6 LOCATIONS OF DIVISION I & II REMOTE CONTROLS FOR SHUTDOWN DIV. I EQUIP. DIV. II BACKUP OPERATED EQUIPMENT CONTROL LOCATION AT RSP EQUIPMENT .

Nuclear Boiler System 1821-F051C Yes Div. II RSP Division I and Division II controls for three non-ADS air 1B21-F051D operated relief valves are provided on different sections 1821-F051G of the panel to provide the capability to manually depressurize the reactor from either division. (The valves are 125 Vdc solenoid pilot operated.)

IC61-R010 IC61-R509 Div. II RSP Reactor water level indicators (Div. I and II) IC61-R0ll 1C61-R510 Div. II RSP Reactor pressure indicators (Div. I and II)

Miscellaneous Instrumentation Drywell temperature indications (two) Yes IC61-R501 IC61-R502 1C61-R506 1C61-R512 Div. II RSP Suppresion pool temperature indicators (Three each -R507 -R513 in Division I and Division II associated with the -R508 -R514 three safety relief valves controlled from each division)

Indicating lights for:

a. Diesel Generator Status Yes -

! b. Diesel Fuel Oil Transfer Pump Status IC61-DS502 -

i l

I 1

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LOCATIONS OF DIVISION I & II REMOTE CONTROLS FOR SilUTDOWN 1 DIV. I EQUIP. DIV. II BACKUP OPERATED

.J AT RSP EQUIPMENT CONTROL LOCATION EQUIPMENT .

Residual Heat Removal (RFR) System j

• Residual heat removal puttp E12-C002A E12-C001B 4KV. Breaker IBl

lleat exchanger shell side outlet MOV E12-F003A -

1 RifR pump suction MOV E12-F004A -

4 Shutdown cooling MOV E12-F006A E12-F006B Div. II RSP Outboard shutdown isolation MOV E12-F008 -

Inboard suction isolation MOV E12-F009 -

RllR heat exchanger flow to suppression pool MOV E12-F0llA -

l lleat exchanger cooling water inlet MOV E12-F014A E12-F014B MCC IB2 RHR test line MOV E12-F024A E12-F024B MCC 1B2 l RilR heat exchanger flow to RCIC !!OV E12-F026A -

Injection shutoff MOV E12-F027A -

l Containment spray MOV E12-F028A -

{ Shutoff upper pool cooling MOV E12-F037A -

j RilR injection MOV E12-F042A E12-F042B MCC IB3 r

', lleat exchanger shell side inlet MOV E12-F047A -

j ifcat exchanger shell side bypass MOV E12-F048A E12-F048B MCC IB2 1 Steam line isolation MOV E12-F052A -

l RilR injection MOV E12-F053A -

i RllR pump minimum flow MOV E12-F064A -

IIeat exchanger cooling water outlet !!OV E12-F068A E12-F068B MCC IB2 i

Ri!R Flow indicator IC 61-R005 -

I 4

i i

l i

o LOCATIONS OF DIVISION I & II REMOTE CONTROLS FOR SHUTDOWN DIV. I EQUIP. DIV. II BACKUP OPERATED CONTROL LOCATION AT RSP EQUIPMENT EjUIPMENT Shutdown Service Water System SW0lPA SSWS Pump SX0llA SSWS Div. 1/2 Crosstie Isolation MOV SX082A RHR-A heat exchanger demineralized water inlet MOV SX012A Fuel Pool Heat Exchanger Inlet MOV SX062A Fuel Pool Heat Exchanger Outlet MOV SX016A Fuel Pool Make-Up Motor MOV SX073A SGTS Train A Charcoal Bed Water Supply MOV SX076A Control Room HVAC Unit A Deluge MOV SX107A Control Room HVAC Unit A Deluge MOV SX014A 2

Plant Service Water /SSW Systems Interconnection MOV SXO63A Diesel Generator Cooling Water MOV SX003A SSUS Strainer Inlet MOV SX004A SSWS Strainer Outlet MOV SX008A SSWS Strainer Bypass MOV IC61-R503 SSWS Strainer Discharge Pressure Indicator IC61-DS501 Indicating Light for Strainer High Differential Pressure Reactor Core Isolation Cooling (RCIC) System E51-F010 Pump suction MOV from condensate storage E51-F013 RCIC injection shutoff M3V E51-F019

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Minimum flow to suppression pool MOV E51-F022 Test bypass to condensate storage MOV 4 Gland Seel System Air Compressor E51-F031 Pump suction from suppression pool MOV E51-F045 d

Steam to turbine MOV E51-F046 Lube oil cooling MOV E51-F059 Test bypass to condensate storage 4

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i LOCATIONS OF DIVISION I & II REMOTE CONTROLS ^

4 FOR SilUTDOWN l

1 DIV. I EQUIP. DIV. II BACKUP 1 OPERATED EQUIPMENT CONTROL LOCATION

AT RSP EQUIPMENT .

! Reactor Core Isolation Cooling (RCIC) System (cont'd)

Steam supply line isolation inboard MOV E51-F063 -

! E51-F064 -

j RilR cond heat exch steam line isolation MOV E51-F068 -

Turbine exhaust to suppression pool MOV Steam line warm up line isolation MOV E51-F076 -

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i Vacuum breaker isolation outboard MOV E51-F077 -

E51-F078 -

! Vacuum breaker isolation inboard MOV E51-C002 -

i Turbine trip and throttle valve MOV IC61-R001 -

RCIC Flow Controller and indicator IC61-R003 -

RCIC Turbine Speed Indicator Indicating lights are provided for: Yes -

a. Turbine tripped Turbine Bearing oil low pressure Yes -

j b. Yes -

c. Turbine governor end bearing oil temperature high Yes -

d. Turbine coupling end bearing oil temperature high .

RCIC storage tank level indicator IC61-R505 -

IC61-R504 1C61-R511 Div. II RSP ,

Suppresaion pool level indicator (Div. I and II) <

Essential Equipment Cubicle llVAC Systems VII0lCA t -

i SSWS Pump Cubicle Fan VYO2C -

i RHR Pump Cubicle Fan VYO3C

! RilR lleat Exchange Cubicle Fan VYO4C -

RCIC Pump Cubicle Fan VY0lCA r

l Diesel Generator Cubicle Fan l VD02CA Diesel Generator Cubicle Fan VX03CA -

j Essential Switchgear Cubicle Fan -

Battery Room Fan VX05CA 4

1

Illinois Power Company Clinton Power Station Unit 1 Supplemental Information on the Qualification of the Instrumentation Mounted on,the Remote Shutdown Panel (RSP)

The CPS FSAR contains the statement "The components of the remote shutdown panel were designed and 7urchased to the requirements of the interfacing systems." To be more specific regarding qualification, all of the switches on the panel are classified as essential items that have active safety functions. The power supplies, DC-AC inverter, square-root converter and RCIC flow controller are classified as eseential items with active safety functions. The RCIC tach, RHR flow, RCIC storage tank level and RPV pressure and level indicators are classified as essential items that have no active safety function. The RHR flow and the RPV pressure and level transmitters dedicated to the RSP are classified as essential items that have no active safety classifi-cation. The RCIC flow indicator is classified as a non-essential device. .

Instrumentation which is classified as essential and having an active safety function has a seismic classification, during the seismic event, of Category I and shall be operable after the seismic or design event. Non-essential devices are Seismic

Category I and have no safety function.

In general, the switches and indicators , with the exception of the transfer switches, are the same devices as used in the main control room. There are no main control room applications which use the transfer switches.

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Illinois Power Company Clinton Power Station Unit 1 Additional Clarifying Information on Operation of the Remote Shutdown Panel I. Division 2 equipment, that does not automatically operate when required, includes the following:

Equipment Operating Location B RHR Pump 4KV 1B1 - Auxiliary Building 781, NW 1E12-F024B AB MCC 1B2 - Auxiliary Building 781, NW lE12-F042B AB MCC 1B3 - Auxiliary Building 781, NW 1E12-F048B AB MCC 1B2 - Auxiliary Building 781, NW 1E12-F014B AB MCC 1B2 - Auxiliary Building 781, NW lE12-F068B AB MCC IB2 - Auxiliary Building 781, NW SRV's Will be added to Remote Shutdown Panel This Division 2 equipment is operated from the MCC's or switchgear listed above in an area on the opposite side of the Auxiliary Building from the Remote Shutdown Panel, at the same elevation. The ventilation system serving both of these areas is independent from the Control Room HVAC system and communications would consist of hand-held radios and the plant Gai-tronics System. While reliance '

is placed on automatic operation of Division 2 and Division 3 equipment and on normal valve line-ups, if it i becomes necessary to override such operation, Division 2.

equipment can be operated from the MCC's and switchgear already described. Division 3 equipment can be operated i on 781 Control Building, an area in close proximity to

! the Remote Shutdown Panel and also independent from the Control Room HVAC. Furthermore, most of the equipment that might be operated locally from MCC's is located outside containment and could be manually operated.

II. The existing remote shutdown procedure will be revised to require transfer of functional capabilities to the Remote Shutdown Panel only as they are needed, unless damage to circuitry is anticipated, such as a fire. In that-case, all transfer switches will be operated immediately. The procedure will also be revised to address remote shutdown with Division 1 inoperable. This will generally consist of monitoring and controlling reactor pressure front the Remote Shutdown Panel, as it will be modified. Automatic systems in the remaining operable divisions will maintain reactor vessel level, which can be monitored at the Remote Shutdown Panel as modified; the reactor will be depressurized using SRV's.

l l Suppression pool cooling will be effected through operation

of the' equipment listed above and when the reactor is i sufficiently depressurized a mode of shutdown cooling l will be entered, again, through operation of the equipment i listed above. Monitoring will be accomplished from the L

4 I

i II . . (continued)

Remote Shutdown Panel, as modified, no continuous function of any component remote from the Remote Shutdown Panel will be required, and the plant will be maintained in cold shutdown.

III. The commitment to test the existing remote shutdown capability is in subsection 14.2.12.2.25 of the FSAR.

Additionally, operators will be trained on remote shut-down with Division 1 inoperable; each operating shift will conduct a procedure walk-through of this capability during the startup test program.

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