Text

Forwards Addl Info Re SEP Topic VI-7B,engineered Safety Feature Switchover from Injection Mode to Recirculation Mode,Per 810305 Request
	ML19347F462
Person / Time
Site:	Big Rock Point File:Consumers Energy icon.png
Issue date:	05/11/1981
From:	Vincent R; CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
To:	Crutchfield D; Office of Nuclear Reactor Regulation
References
	TASK-06-07.B, TASK-6-7.B, TASK-RR NUDOCS 8105190320
	Download: ML19347F462 (42)
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Tills DOCUMENT CONTAINS CORSUM8f8 POOR QUALITY PAGES 2)P

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General Offices: 212 West Michigan Avenue, Jacksor., MI 49201 * (517) 788 0550 May 11, 1981

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T/3 Washington, DC 20555 DOCKET 50-155 - LICENSE DPR l 3IG ROCK POINT PLANT - SEP TOPIC l

VI-73, ESF SWITCHOVER FROM INJECTION TO RECIRCULATICN 1

By letter dated March 5,1981, the NRC requested additional information on the switchover frem the In.jection mode to the Recirculation mode of emergency core cooling at the Big Rock Point Plant. The e.ttached information is provided as our complete response to this request.

Robert A Vincent (Signed) l l

l Robert A Vincent Staff Licensing Engineer CC Director, Region III, USNRC NRC Resident Inspector - Big Rc:k Point Attachment h1 pages i

rg10 519 0 DO P

m SEP Topic VI-TE, 2SF Switchover Response to NRC Questions for Big Rock Point 1ERC Request:

"By test, P6sID, and electrical schematics; describe the design provisions and procedures used in your plant to satisfy the requirements of Branch Technical Position ICSB-?O. The information provided should include, but need not be limited to the following:

(1) Describe the procedures used to switebover from the injection to the recirculation mode of emergency core cooling (ECC)."

Response

The applicable procedures and drawings that are necessary to describe the switchover from' injection to recirculation are listed below and cop'.es of these documents are included with this submittal:

1.

Emergency Procedure EMP 3 3 "Ioss of Reactor Coolant" 2.

System Operating Procedure SOP-8 " Post Incident System" 3.

P&ID drawing 0740G30103 rev M " Schematic Diagram, Motor Operated Valves" 4.

P6sID drawing 0740G30104 rey N " Schematic Diagram, Instrumentation" 5.

NID drawing 07kOG30ll4 sheets 1 and 2 rev T " Schematic Diagram, Air, Screen, Fire and Post Incident Systems" 6.

P& E drawing 0740106-SI.1-lC2A sheet 3, rev A "RDS Elementary Diagram, Sensor Channel" 7

P& E drawing 0740G40123 rev AF " Fire and Post Incident Ccoling Systems" 8,

P&E drawing 0740G41003 rev D " Reactor repressurizing System, Emergency Core Cooling System Modification" l

NRC Request:

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"(2 ) For each instrument, indicator, logic device and alarm that is used by the operator to perfom a manual function or l

that is used to initiate an automatic function in the switch-i over sequence; describe how that device is qualified and installed (e.g. indp endence and separation of circuits) as Class 12 equipment.

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Response

The changeover from core spray injection to the recirculation mode at Big Rock Point is accemplished manually by the operator. The sequence of actions and equipment used by the operater is described in procedurc D(P 3 3 "Ioss of Reactor Cociant", paragraphs 3 34.4 j thm q.

The qualification of equip-ment located in hostile areas has been discussed in detail in Consumers Power Company's submittal to NRC regarding SEP Topic III-12 "Environmenta3 Quali-fication of Safety Related Equiptaent" (EEQ) dated 10/30/80and1/30/81. La following listing of equirment, used by the operator during switchover to l

the recirculation ' node, includes references to the appropriate pages of :he

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' REQ" submittal. Equipment located in non-hostile areas do not require environmental qualification.

1.

Equipment Function - Containment Sump Level 3

Desired Status

- ?rovides Sump Level Indication a.

Primary Equipment Location Area Description EEC Page LI-3h00 control room non-hostile none LT-3171 contairanent hostile 76-78 E-3171 station power room non-hostile none Power Panel 34 station par room non-hostile acne Cable containment hostile 175-216 Elec Penetration H-42 containment hostile h2 h8 Teminations containment hostile 160-163b l

Electrical Schematic Drawing - 07kOG3010h rey N P&ID Drawing

- 07kOG40123 rev AF b.

Redundant Eauipe.ent Location Area Description EIO Page White Lights control room non-hostile none LS-3562 containment hostile 63-65 Redundant Ecuianent Iccation Area Description EEC Page LS-3563 containment hostile 63-65 LS-356h containment hostile 63-65 l

LS-3565 containment hostile 63-65 Power Panel 1Y station power room non-hostile none Cable containment hostile 175-216 Elec Penetration H-41 containment hostile 42-k8 Teminations containment hostile 160-163b Electrical Sd.putic Drawing - 0740G30114 rev T P&ID Drawing

- 0740G40123 rev AF 2.

Ec.uipment Functiod - Containment Sprav Desired Status

- Stop Spray, Close Valve a.

Primary Eauipment Incation Area Descriptien EEQ Page

1) MO-706h containment hostile 67-90 DC Power Panel D-10 station power room non-hostila none Motor Starter station power room non-hostile none RMC-551h control room non-hostile none Cable containment hostile 175-216

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Elec Pene'tra-tion H-75 contai=ent hestile h2 h8

'4 -163b Teminations centaiment host' ' =

0 Closed Valve Indications Lights control room non-hostile none Electrical Schematic D* awing - 07 HCG 30103 rev M P&!D Drawing

- 07hCGh0123 rev AF Primary Ecuitment Location Area Descriptien EEC Page

2) MO-7068 containment hostile 96-97 MCC-22 station power room non-hostile none Motor Starter station power reem non-hostile none PMC-5525 control rec =

ncn-hostile none Cable containment hostile 175-216 Elec Penetra-tion H-kl containment hostile h2 h8 Teminations centainment hostile 160-163b Closed Valve Indications Lights control roem non-hostile none Electrical Schematic Drawin - 07h0G30103 rev M P&ID Drawing

- 07hCGh0103 rev AF 2(b.

F.edun, dant Ecuim.ent Iccation Area Description EEC P&ge 1)

VFP-2c+

cachine shop ncn-hostile none

This valve is manually operated.

PLD Drawing

- 0740Gh0123 rev A?

Closed Valve Indicaticcs FI-2333 control reem non-hostile none FS-2520 control room non-hostile none ES-2160 station power room non-hostile none FT-2164 containment hostile 60-63 Power Panel lY station power room non-hostile none Power Psnel 3Y station power reen ncn-hostile none Cable containment hostile 175-216 Elec Penetration H h2 containment hostile h2 h8 Terminations centainmeit hostile 160-163b Electrical Schematic Drawing - 07h0030104 rey N P& E Drawing -

- 0740Gh0123 rev AF

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Redundant Ecuintcent beation Area Description EEC Page 2)

VFP-30*

machine shop non-hostile none

'This valve is ~mm="y operated.

Chsed Valve Indications FI-2334 control room non-hostile none FS-2521 control room non-hostile none ES-2161 station power room non-hostile none FT-2161 containment hostile 60-63 Power Panel 1Y station power room non-hostile none Power Panel 3Y station power rocs non-hostile none Cable containment hostile 175-216 Elec Penetration H-k2 containment hostile 42-48 Terminations containment hostile 160-163b Ilectrical Sche =atic Drawing - 07h0G30104 rev 3 P&ID Drawing

- 07h0Gh0123 rev AF 3

Equipment Function - Provide fire water to core spray heat exchanger Desired Status

- Valve open a.

Primarr Ecuitment kcation Area Description EEQ Page MO-7066 core spray reem hostile ol c2 MCC-2A station power rocm non-hostile none Motor Starter core spray reem hostile ich-lc5 EMC-5521 control room non-hostile none Cable core spray room hostile 175-216 Ter=inations core spray roc =

hostile 163a-163b Valve Position Indication Lights control rocm non-hostile nene Electrical Schematic Drawing - 0740G30114 rev T P&ID Drawing

- 07h0Gh0123 rev AF b.

Redundant Ecuireet.1 Location Area Descrittien EED Page VPI-5*

core spray room hostile none

This valve is manually operated.

Valve Position Indication FR-2108 centrol room non-hostile none Power Panel 1Y station power room non-hostile none Power Panel 3Y stat,1on power room non-hostile none ES-2108 control. room non-hostile none ES-?.162 control room ncn-hostile none ES-2163 control room non-hostile ncne FT-2162 contairment hostile 60-63 FT-2163 contain=ent hostile 60-63 FI-2335 control reem non-hostile none

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FI-2336 control rocm non-hostile none FS-2522

entrol roce non-hes;i'e none 73-2523 control room non-hostile none Cable containment hostile 175-216 Elec Penetration H-42 containment hostile 42-48 Teminations containment hostile 160-163b Electrical Schematic Drawing - 0750G30104 rey N PfID Drawing

- 0740G40123 rey AF 4.

Equipment Function - Alternate fire water to ccre spray heat exchanger DesiredStatus

- Valve verified closed a.

_ Primary Fouitment Iccation Area Description EEG Page Ks-7072 core spray room hostile 10L-103 Power Panel 3-10 station pcwer room non-hostile none Motor Starter station power room non-hostile none Cl4C-5529 control room non-hostile none Cable core spray room hostile 175-216 Valve Position Indication Lights control roce non-hostile none b.

Redundant Ecuirment None is required since the normal position for this valve is closed.

5 Equipment Function - Provide core spray water Desired Status

- Core spray pump running a.

Primary Ecuiment Locatien Area Description EEC Page, P2A core spray room hostile 1C6-107 i

MCC 1A station power room non-hostile none h2/CS control room non-hostile none I

Cable core spray reem hostile 175-216 l

Teminations core spray room hostile 163a-163b 1

l Equipment Indication l

Lights control rocm non-hostile none Electrical Schematic Drawing - 07h0G30114 rev I P&ID Drawing

- 0740Gh0123 rev AF b.

Redundant Ecuitment Location Area Descriptien EEC Page FZB core spray room hostile 106-107 MCC-2A station power room non-hostile none 42/CS contzel room non-hostile none Cable core spray room hostile 175-216 Teminations core spray room hostile 163a-163b L,

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(continued)

Eauipt:eno Indication Lights control room non-hostile none c.

Eculpment indicatien redundant to both core spray pumps:

Ps-638 core spray room hostile 108-109 6.

Ec,uipment Function - Backup core spray valves (nozzle)

Desired Status

- To be enerstable by remote manual for at least one closelcpsn c.ycle a.

Pri=arr Ecuiment location Area Descrittien-EEQ Page MO-7070 containment hostile 98-101 FO-7071 containment hostile 98-101 MCO-23 station power reem non-hostile nene RMC-5527' control room non-hostile none RMC-5528 control room non.nostile none Motor Starters station power room non-hostile none Junction Boxes containment hostile 158-159 Terminal Blocks containment hostile 16h-172 Terminations containment hostile 160-163b Cable containment hostile 175-216 Elec Penetration H-76 contain=ent hostile h2 h8 Elec Penetration H-c4 containment hostile L2 L3 Primarr Eauiment Lccation Area Descriptien EEQ Page Valve Position Indication Lights control room non-hostile none Electrical Schematic Drawin6 - 07h0G30103 rev M P&D

- 07h0G40123 rev AF b.

Redundant 7., quit-ent If the primary core spray line is not broken, 50-7070 and MO-7071 are redundant to each other in that closure of either one vill provide the desired function. If the primary ore sprar line is broken, both MO-7070 and MO-7071 must re-open and there is no redundancy.

Valve Position Indication The closed or open status of these valves can be verified by observing core spray flow. See paragraph 3.b.

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Equipenent Function - Reactor ater level indication Desired Status Providing indication a.

Primary Eoui scent Location Area Descrittion E20 Page LI-3380 control room non-hostile none LI-3381 control room non-hostile none LI-3382 control room non-hostile none LI-3383 control room non-hostile none LT-3180 contaireent hostile 79-82 LT-3181 contaiment hostile 79-82 LT-3182 contaiament hostile 79-82 LT-3183 containment hostile 79-82 Elec Penetrations H ho containment hostile 49-50,53-55 H-65 centainment hostile 49-50,53-55 H-81 containment hostile 49-50,53-55 H-83 containment hostile h9-50,53-55 Cable containment hostile 175-216 Te minations containment ho. stile 16k-166,173-174 Junction Ecxes containment hostile 158-159 Power Supplies eachine shop non-hostile none Sensor Cabinet computer room non-hostile none Schecatic Drawing - 07h0-lC8-S1.1-102A rav A P&D Dradng

- 0740Gh1003 rev D b.

Redundant Fruitment The four level indicators provide redundancy in that the operator uses 3 c1' the 4.

Each indicating device is completely separate frem the other three.

8.

Equipment Function - Primary cora spray valves (ring spray)

Desired Status

- To be opersble (remote-manual) for one close cycle j

a.

Pri.arv Ecuitment Location Ares Descrittion EE0 Pace 50-7051 containment hostile 83-86 50 -7061 contain=ent hostile 83-86 MCC-D01 station power :-r non-hostile none RMC-5519 control roem non-hostile none CMC-5501 control roem non-hostile none Junction Boxes contain=ent hostile 158-159 Teminal Blocks contain=ent hostile 16ca-172

?eminations containment hostile 160-163b C.ble containment hostile 175-216 Elec Penetrati^n H-kh contaire.ert; hostile h2 h8 H 45 containment hostile h2-h8 Valve Position Indication Li6 hts control room non-hostile none Electrical Schematic Drawing - 07h0G301h rev T l

P&ID Drawing

- 07h0Gh0123 rev AF l

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Redundant Eauinnent Either MO-7051 or 10-7061 can provide the desired status valve position indication.

The cicsed or open position of these valves can be verified by observing core spray flow. See paragraph 3.b.

9 Equipment Function - Concainment pressure indication Desired Status

- Providing indication a.

Primary Ecuinnent Iccation Area Description EZO Page PI-367 control room non-hostile none PT-174 else penetration rm hostile 117-118 E -8512A control room non-hostile none Pcreer Panel 1Y station power room non-hostile none Cable elec penetration m hostile 175-216 Electrical Schematic Drawing - 0740G30114 rev T P&D Drawing

- 0740040123 rev AF b.

Redundant Diuinnent Location Area Description II0 Par:e FIS-173 control room non-hostile none IS-1 control room non-hostile none ES-6501A control room non-hostile none E-8501 control room non-hostile none MCO-DC2 station power room non-hostile none FT-173 elee penetration r=

hostile 117-118 Cable elec penetration m hostile 175-216 Electrical Schematic Drawing - 0740G30114 rev T PhD Drawing

- 0740040123 rev AF NRC Request:

" (3 )

Describe the level sensing system that is used to indicate or detect the level in the containment sump. This descrip-tien should include sensor and date column location, freeze protect, ion power supply and those items specified in (2) above.

Response

Two containment level monitoring / indicating systems currently exist at Big Rocic Point. System 1 consists of four level switches (LS-3562 through LS-3565) located at elevations 574', 579', 587' and 595'.

Each switch utilizes a float that causes a switch contact to be closed, illuminating a white light in the control room. These switches are located in the containment building and thus do not require freeze protection.

Svetem 2 consists of an IIT Barton Model 386 level transmitter (LT-3171).

This transmitter, located in containment, utilizes a 20 foot capillarf tube, the icwer end of wnien is located at elevation 575*.

The uuper end is at

9 elevation 595'. The water level is indicated in the control room on LI-3h00.

This equipment is not subjected to a freezing environment and thus does not require freeze protection.

The equipment for both of these systems was also addressed in question 2 above.

Due to required modifications resulting from TMI (NUREG-0737 item II.F.1),

a new containment level indicating system is planned to be installed by January 1962. It is expected that the new system will be similar to system 2 described above.

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ATTACFFSITS TO BIG ROCK POIIiT PIRIT SEP TOPIC VI-TB IATI'ER i

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1 Rev. 12 Ioss of Ber.ct:r Coolant - DtP 3.3, i

D2' 3.3 LOSS OF REACTOR COOIART Leaka6e from the Primary System may re nge from a fraction of a gallon per minute to a complete rupture of a recirculation loop. The severity of the consequences, automatic actionn and operation actions vill be dependent upon the size and nature of the leak encountered.

These emergency procedures are subdiv!.ded into three categories to provide broader coverage of the various leaks that may be encountered.

The subdivisions are:

a.

inor Loss of Reactor Coolant Ins:.de Containment I

b.

Major Loss of-Reactor Coolant Insf.de Containment Major Loss of Reactor Coolant Out::ide Containment l

c.

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NOTE: If one or more of the fol3owing ccnditions exist, proceed to EMP 3.3s3, Loss of Coolant, outside Containment.

1.

Rapid increase in pipe tunnel dew point, pipe tunnel leak alarm.

2.

Turbine sump hi level alarm. er continuous sump running time.

3.

Extreme level of noise from escaping steam.

4.. Area monitor alarms, outside containnent.

NOTE: If one or more of the following conditions exist, proceed to EMP 3.3.2, Loss of Coolant,Inside Containment.

1.

Rapid increase of humidity in sphere exhaust air, and alarm.

2.

Containment pressure increases PI/367 and PIS/173 in Control Room.

3.

Arte =onitor alarms, inside containment.

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ev.12 Loso of Rctetor Coolant - EMP 3.3, 5/15/80 I

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Prceautions This section provides guidelines which are common to all subdivisions listed above. These items must be kept in mind at all times during the course of a loss of reactor coolant condition.

t Item _1. Operators should be prepared,to take immediate actions as neces '

sa'ry to protect the core and containment. Immediate Operator

. actions include verification of automatic actions and taking manual action to initiate an automatic function uh'enever an automatic action did not occur that should have occurred.

i Item 2. Continuously monitor reactor vessel level, drum level and re-actor pressure from. multiple indicationa.

Item 3. On any automatic initiation of a safety function, assume a true ~

initiating event has occurred, until otherwise confirmed by two.

or more independent process indications.

Item 4. Automatic controls should not be placed in luNUAL mode unless

1) misoperation in AUTOMATIC mode is confirmed by at least two independent process parameter indications; or 2) core cooling is assured, and these guidelines state specifically en do otherwise. When manual operation is no longer needed, restore the system to automatic operation if possible. If a system is switched from automatic to manual operation, frequent checks of the controlled parameter must be made.

Iten 5. Any Emergency Core Cooling System should not be shut off unless i

there are multiple indications (such as'several level indicators) that the core and containnent are in a safe stable condition.

I Item 6. During LOCA conditions when observing level indications utilizing Yarway level sensors, use caution. Although the instruments will perform their safety related functions (ie scram reactor and initiate ECCS), indicated water level may bc erroneously high.

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Lo,;n of Reactor Coolrnt - E!U' 3.3 16 03/03/31 Item 7.

"LOCA conditions may result in high radiation levels in Plant areas outside the control room. Evaluation of the need to perform any action outside the control room should be made 1

whenever the containment r.2diation monitors have alarmed.

See Procedure C4 to Appendix C in Site Emergency Plan entitled,

" Procedure to Determine the Extent of Core Damage."

Item 8.

Do not manually initate RDS if fire main pressure is unavailable for the core sprays. Fire system uater is available from the electric fire pump, which can be run from station power or from the emergency dicsc1 generator, and from the dicsci fire pump 'see S0p 26).

Item 9.

When there is a rapid depressurization of the Nuclear Steam Supply System from a pressure and temperature mode, the Bailey steam drum Icvel recorder (lD12) and the Bailey steam drum 1cyc1 indica-tor (IA19) on CO2-1 will go full scale.

(This will be caused by the Bailey reference icgs flashing.)

If this condition exists, the feed water control valve will have to be placed in manual to make the feed water condensate available to the steam drum, reactor.

D!P 3.3.111INOR LOSS OF REACTOR COOLANT. IN3IDE C0;iTAllT.CT EMP 3.3.1.1 Syrmtoms Daily Primary System leahage calculations a.

(plant limits are 0.8 6?m unidentified and 9 apm identified).

b.

Increased humidity in sphere exhaust air.

(TR9623 in Control Room) c.

Noise from blowing steam or water.

d.

Increased sump pump running times.

(Timers in Control Room)

Pipe way steam leak alarm on C-20 panel.

e.

f.' Possibic steam drum reliof valve seat 19.aknc,c Observe percent of full scale mater and If eten to audio monitor to check for increased noise Icycis at the relief valve monitor.

EMP 3.3.1.2 Aut e.a cle Actionn There are no automatic actions for minor leaks.

,EMP 3.3.1.3 Immedinte Operator Action a.

The on-duty P3nnt Superintendent shall be notified of the inercuced lenhage.

b.

The Shift Supervisor shall notify Power Control that the lenhage limitu have

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, Loss cf R:cct,0r Coolant - EMP 3.3 Rev.12 5/15/80 c.

If the primary coolant system leakage exceeds 1 gpm and the source of leakage

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is not identified, the reactor shall be placed in the hot shutdown condition witnin 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and cooldown to a cold shutdown condition shall be initiated within 2h hours, d.

If leaha6e from the primary coolant system exceeds 10 gpm, the ree.ctor shall be pla:cd in.the hot shutdown condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and cooldown to a cold shutdown condition shall be initiated within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

r DP 3.3.1.h Subseouent Operator Action a.

Maintain the steam drum vater level at or above center line.

. b.

Place the reactor in the hot standby condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and cool to cold shutdown within 2h hours.

c.

Hold the levels in the condensate storage, O

demin water and vaste hold tanks at maxi-mum.

D P 3.3.2 MAJOR LOSS OF REACTOR COOIRIT, INSIDE CONTAINICIT l

EMP 3.3.2.1 Symotons a.

Abrupt load drop.

b.

Feed-vater flow could bc in execss of that needed to maintain a corresponding steam flow.

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c.

Increased humidity in sphere ciheust air.

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.LoIs cf B act:r Coolant - EMP 3 3, Rsv.14 f >. *

'01/15/S1 d.

Reactor building ventilating system trouble alarm.

~ Radwaste trouble alarm (from reactor buildin6 e.

sumps high level).

f.

Flooding in containment (LI/3400 in Control Room).

g.

Recire pump vilcation alarm due to cavitation.

h.

Core D.P. G.iuge may go to 0 or fullscale.

i. Decreased primary system pressure. (PI/IA05).

j. Noise from blowing steam or water.

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'~~~' " If courec ~cf Icakage 10'.frcm an open ' relief valve, the relief valve monitor high alarm lamp shoule. illuminate and the high alarm

" should annt.nciate.

k.

Con *,ciument pressurized (pressure indicator PI/367 & PIS/173 in Control Room).

1.

Steam drum low level alarm (main console).-4".

Containment evacuation alarm (RDS console) -4".

Steam drum low level scram at 8" below centerline.(1 m.

n.

Channel (A-D) steam drum level lov alarm

,I (RDS console). Channel (A-D) fire main pressure available (RDS console). Channel (A-D) time delay starts (RDS console),

Prina y enclosure spray actuation alarm at R2.2psit c.

'p. Reactor low vater level scram alarm (main console).

Channel (A-D) reactor water level lov alarm (RDS console)22'9" above core.(l) g.

Channel (A-D) alarm time delay trip in 30 seconds (RDS console).

r.

Channel (A-D)' time delay trip (RDS console).

s.

Area monitor alarms, t.

High stack-gas monitor alarm.

EMP 3.3.2.2 Automtic Actions a.

Containment evacuation alarm sounds when steam drum vater level is h" below conter line.

Steam drum low vnter Icycl scram at S" (

b.

below cen.ter line.

U) At 13';0 p,cu,.g.cchnical Dara P.nnk. Section 15.5.F

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.' ' Loss 'of R act:r C)clant - EMP 3.3, 9/25/S0 i.

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RDS.:tuation sequence commenecs at 17"(

EMP 3.3.2.2 (contd) c.

below drum centerlina.

NOTE: Time delay relay can be reset to 120 at any time within 120 seconds remaining, if desired, by operator action at RDS con-sole. This reset feature is to be used only if the RDS actuation has been inadvertently initiated or initiation has taken place but the drum level is back to normal or recovering.

NOTE: During LOCA conditions when observing level indications utilizing Yarway level sensors, use caution. Although the instruments will perform their safety related functions (ie scram reactor and initiate ECCS), indicated water

' level may be erroneously high.

Reactor lov vater level scran at2 '9" II) l d.

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above core.

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At this point, the requirenents have been met for the RD3; ie, steam drus low level

(~17")(

for two minutes, fire main pressure i

available > 100 lb, and reactor water level at.12'9" (1) above core', and it vill r

initiate automatically to depressirize the reactor as follows:

(1) Channels A, B, C and D Trip (Annunciator)

(2) Channels 1.1, 2.1, 3.1 and h.1 Output Trip (Annunciator)

(3) Channels 1.2, 2.2, 3.2 and 4.2 Output Trip (Annunciator)

(h) Channels 1, 2, 3 and b Icolation and Depressurization Valves Open Simul-taneously ( Annunciator)

(1) At 1350 PSIA, see Technical Data Book Section 15.5.F l

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Rev.15 u ro ef Rracter Coolant - EMP 3.3,

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gMr 3.3.2.2 (contd) f.

RDS discharge pipe temperature high al2rm will come in at 187.6 + 13*F.

3 Ent*1osv.re high-pressure scram occurs at 1.5 psig end primary enclosure spray a:cua-tfon starts at R2.2 psig.

h.

CoresprayvalveswillopenwhenreactEr pressure is 200 psig or icss and water level is22'9"(1} above the core, admit:ing fire water when primary system pressurit is less than fire system pressure.

NOTE: CV-4101 FPS substation deluge isolation ~

valve should close. Visually check closure on CO2-2 HS-7049 to verify IIS-7049 is in

" auto" position and CV-4101 indicates closed.

(1).At 1350 PSIA, see Technical Data Book Section 15.5.F t

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EMP 3.3.2.2 (contd) 1.

Primary enclosure sprays will actuato at I

%E2.2 psig. enclosure pressure.

j The turbiac generator will trip on the first

-scram.

k.

Ventilation valves will close on tht: first scram.

1.

Isolation valves will close on enclosure high pressure or low reactor water icvel.

EMP 3.3.2.3 Immediate OpcTator Action a.

Ensure re.netor scram has occurred from low water condition, if not, scram reactor manually.

Verify scram by noting control rod posit-ion lights at 00, neutron flux de-caying anl dump tank isolated.

b.

Continuously monitor steam drum and reactor water lev 51 usinh all available instrumentation.

1.

Yarway drum 1cvel indicators LI 3384-3387 2.

Yarway reactor water level indicators LI 3380-3383~

NOTE: 'During LOCA conditions when observing level indications utilizing 'larway level sensors, use caution.

Although the instruments will perform their safety related functions (ie scram reactor and initiate ECCS), indicated water icvel may be erroneously high.

3.

Bailey drum 1cyc1 indicators.

c.

If unable to maintain primary system water inventory (rapidly falling drum level) isolate the containment using the S5 switch.

I d.

Verify the RDS system sequencing properly, I

sound RDS evacuation alarm if not already actuated.

e.

Sound the plant siren and implement the Site Emergency Plan.

f.

Fire fighting activitics using fire water are to stop until long term cooling is es-tablished (after Step 3.3.2.4.0).

EMP 3.3.2.4 Subsequent operator Action a.

Leave feedwater controls in automatic and allow the condensate and feedwater pumps which are running to continue running until they trip on hotwell low level or low suction

pressure.

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6 Loss of Reacter Coalcat - EMP 3.3, Rev. 13 9/25/80 EMP 3.3.2.4 (contd) b.

Check vent valves closed.

c.

Trip reactor recirculation water pumps

. when vibration or cavitation occurs.

d.

Open the emergency condenser outlet valves.

(Emergency condenser vent alarm may be in, due,to background radiation at the two.

sensor locations - do not valve out the emergency condenser on the strength that this alarm is in.)

e.

When the enclosure pressure reaches 1.5 psig, Control Room operator will check that the automatic isolation valves close.

(Indicating lights on left main pancl.)

If they don't close, attempt to close them remote manually, f.

At 17" (1) below steam drum center line, check that RDS actuation has star ted; ie, two-minute time delay timer has started, fire pumps (electric and diesel) have started.

NOTE: If fire pumps have not started automatically, attempt to start either or both manually from the RDS console.

If i

1 unsuccessful, open M0/7066 long enough to start the pump, then close.

If unsuccessful, send an operator to the screen house and attempt to start them locally (Reference SOP 26 procedures). Establish dose rates in area of screen house and plan workman's allowable time.

NOTE: Have operator carry a radiation detection instrument with him when travelling

':o and from screen house to survcy the potential radiation field he may be in.

(1) At 1350 PSIA, see Technical Data Book, Section 15.5.F T.--

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.. Lo;a cf R acter Crelant - EMP 3.3, R:v.,15 }

7 01/24/81)

When low secam drum level, -17" II)belov center EMP 3.3.2.4 (contd) 3 line, two-minute time delay timer has timed out, fire main pressure available, and low reactor water level t2'9" above top of active fuel, are all in coincide'ce, chack that RDS n

has actuated automatically.

If ic hasn't, manually place it in service using the manual trip switches on the RDS console.

NOTE: The RDS may be initiated prior to this

' point, if deemed necessary, by use of the manual trip switches on the RDS console. One or both fire system pumps must be on before ini:iating the RDS blowdown.

h.

As recator pressure decays to approxima:cly 200 psig as indicated on PI/IA05, verify:

MO-7070, MO-7071,'MO-7051, MO-7061 open and ri[th$ Nnclosure spray actuates alarm, the i.*(1) e Control Room operator shall check that enclosure spray valve MO-7064 is open.

NOTE: MO-7068 the secondary containment spray set may be manually initiated upon failure of the primary containment spray set.

(2)

MO-7068 is to be manually actuated 15 minutes following a break in order to remove airborne iodine.

j. As the water level in the sphere reaches 587' clevation (LI/3400 and/or three white lights on console), cl se MO-7064 and M0-7068.

NOTE: Water icval must not exceed 590' elevation to protect the core spray

~

sensors and control circuits.

This it accomplished in step "n".

(1) At 1350 PSIA, :ce Technical Data Book, Section 15 5.F l

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Loss of Reactor Coolant - EMP 3.3, R:v.12

'I 5/15/60 -I EMP 3.3.2.4 (contd) k.

Open MO/7C66 to supply fire water to the core spray heat exchanger.

Insure that the position indication for the valve shows open. Also, a small change in core spray flow should be scen on FR-2103 as a result of opening M0/7066 which assures fire water flow to ttc heat exchanger. If unable to open M0/7066, open manual by pass valve (VPI 5).

(Do not close M0/7066 until LOCA is complet e as you risk not being able to reopen thu valve.)

1.

Check M0/7072 closed and pull its RMC to the pull-to-stop position and caution tag.

(For long-term cooling and the normal source of water for the Post Incident System @I5]

g has been verified.)

m.

Sthrt one core spray pump. The " Core Spray Low Discharge Pressure" alarn will sound if the pump fails.

(Do not run two pumps in parallel.)

Close the 6" and 4" fire water supply valves n.

in'the machine shop (FP29 and FP30).

l 3

7 M T~

~ ' ' ~

j'*.

Rev.15 Lots of Rcretor Coolant - EMP 3.3 -

i 01/24/

,,1

/9*

t EMP 3.3.2.4 (conte) p.

If both the ring spray and nozzle spray are still operating, close M0/7070 and ' 0/7071.

~~

H

, Monitor RDS reactor water level indicators closely. If a decreasing level is indicated by at least three of the four indicators, open H0/7070 and M0/7071 and close M0/7051 and H0/7061.

~

l NOTE: These levels must be monitored close-1 ly to prevent uncovering of the core

. if the wrong spray line has been isolated.

q.

Use. enclosure spray 1D/7064 intermittently to control the sphere pressure to below ap-proximately 1.75 psi.

(Approximate reset' l

pressure on " Primary Enclosure Spray Actua-tion", alarm.)

r.

One core spray pump shall be operated contin-uously until cuch ti=e as it is determined that the core sprays are no longer necessary.

s.

In the event that a fire system break or de-ficiency occurs during the long-term cooling segment of the incident that jeopardizes the c.ooling water to the core spray heat ex-changer, a fire hose is stored in the screen-hose an1 can be used to tic'the hose manifold on the west wall of the screenhouse to the shell side of the core spray heat exchanger.

Instructions:

1.

Establish. dose rates in the areas of the screenhouse, the north' side of the sphere and the core spray heat exchanger room and plan workman's time allowed in the

~

areas.

2.

Connect fire hose between the hose mani-fold at screenhouse and Valve PI-10 in core spray heat exchanger room.

.3. Open the manifold va7ve and pl-10.

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10 Lono of Reactor Coalant - EMP 3.3 -

Rev. i5 01/24/81 DIP 3.3.2.4 (contd) 4.

Close M0/7066 and/or M0/7066 bypass sanual valve.

5.

If freezing weather, do not isolate this flow until LOCA is complete.

t. 'In the event a substation transformer fire occurs during the long term LOCA where the core spray system is on " Recycle".

The sub-station deluge isolation valve CV-4101 aay be manually opened from the control room tc extinguish a *ubstation fire by placing 11S-7049 on CO2-2 to'the manual position.

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11 loss of Reactor Coolant - DIP 3 3 - Rev.12, 5/15/00 EMP 3.3.3 MAJOR LOSS OF RhACTOR C00I.WT, OUTSIDE CONTAIN!ENT This condition would be de 'ined as 'a major break in the main steam piping outside the contair. ment building. It could be in the steam line to the turbine 'or the bypass valve piping to the condenser. Because this type of break will cause severe blovdown of the pri:tary system and possibly uninhabit-able conditions in the Con:rol Room, it must be dealt with as quickly as poasible.

EMP 3.3.3.1 'Symntoms a.

Extreme lovel of noise from escaping steam.

b.

Rapid dec.-ease in steam drum vater level.

c.

Decrease f.n reactor and steam drum pressures.

d.

Decrease in turbine load.

e.

Zero pressure on turbine inlet pressure gauge, f.

Increase in feed-vater flow.

g.

Pipe tunnel leak alarm.

h.

Increase in pipe tunnel humidity reading on TR-9c23

i. Turbine. Room CAM high.

,j. Area monitor alar =s.

b DfP 3.3.3.2 Automatic Actions The automatic actions vill be similar t'o the

~

symptoms.

a.

Decrease in turbine load, b.

Increase in feed-water flow.

Containment evacuation alarm and annuncia-tion on RIE console if steam drum water level drops to 4" below center line.

d.

Possible reactor scram from lov steam drum water level (-8" below center line).

e.

Damper CV/h190 vill close, preventing a back-i feed into the ventilation duct coming from clean arcas of the plant.

Setpoint:

15" of wato: (.5 psig).

(1)

At. 1350 PCIA, see Technien! Data Book, Section 15 5.F

.. /'

33 Rev.12 Lo;a ef Reactcr Coolant - EMP 3.3 -

5/15/B0 EMP 3.3.3.3 (contd)

'e. (contd)

The Bio-Packs should be used by two persons (a tank is good for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ), who would have to remain in the Control Room and full face masks with canisters for others.

Entry into the Turbine Room should only be in extreme emergency; ie, injury, until it is permitted by Radiation Protection.

f. Continue to cool primary system with the j

taergency condenser and/or shutdown system.

EMP 3.3.4 LOSS OF C001RIT ACCIDENT IN CCNJUNCTION WITH LOSS OF OFF-SITE POWER In the event of a loss-of-coolant accident at the same ti=e as a loss of off-site power supply, the MCC 23 bus will be energized by the diesel generator.

EMP 3.3.4.1.

Open Breaker 52-1A feeding power to the MCC lA bus.'

EMP 3.3.4.2 Open Breaker 52-2A feeding power to the MCC 2A bus.

EMP 3.3.4.3 Open all breakers on bus lA, except screenhouse l

1 l

bus lc and RDS-UPS power supply "A" (52-1A-64) l and "B" (52-1A-13).

EMP 3.3.4.4 Open all breakers on bus 2A, except #3 air com-

~

pressor, RDS-UPS power supply "C" (52-2A-65) and "D" (52-2A-16).

EMP 3.3.4.5 Close bus tie breaker 2A-2B.

EMP 3.3.4.6 Switch channel I reactor protection channel to alternate power (56 switch).

EMP 3.3.4.7 Connect hose from the well water system to #3 air compressor and valve into service.

EMP 3.3.4.8 Co to screenhouse and open all breakers except:

a.

canal sampic pump b.

well house NOTE:

Establish dose rates in area of screenhouse and plan workman's time.

E}iP3.3.4.9 Close the 1A-2B bus tic.

EMP 3.3.4.10 Close the station battery charger breaker on bus 2A.

J W EN. -

,--w.

10 I

Rev.lo Lo2s of Reactor Coolant - DIP 3.3 -

5/1 5/80 DIP 3.3.4 (contd) dip 3.3.4.11 For long term cooling a'.

assure stendby diesel generator is on site.

b.

Close breaker 52-1A-44 or 52-2A-44 for core spray pump.

c.

Refer to DfP 3.3.2.4 (L.) to establit.h long term cooling.

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POST-INCID.0IT SYSTEM System Operuting Procedures - SOP-8 i

Rev. 14 01/15/81 1.0 PURPOSE The post-incident system operating procedtres outline the steps required to make the system ready for operation.

The purpose of the post-incident system is to prevent core acitdown by use of core spray.

In the event of a rupture in the reactor vessel or

' primary system, the enclosure sprays will prevent subsequent overpressure in the containment sphere.

'2.0 TECHNICAL SPECIFICATIONS AND PLANT REQUIREMENTS

1. TECllNICAL SPECIFICATIONS a.

Section 3.0 b.

Section 4.1.2.a c.

Section 5.2.1 d.

Section 11.3.1.4 e.

Section 11.3.1.5 f.

Section 11.3.3.4, Section 11.4.3.4, and Table 11.4.3.4 with bases: page 145 l g.

Section 11.3.5.3

2. PLANT REQUIREMENTS a.

The containment sphere water level shall not exceed cicvation 590 feet on icyc1 indicator LI-3400 to protect core spray valve control circuits.

b.

The backup core spray valves, MO-7070 and M0-7071, shall be closed during refueling operations and their 480 V breakers (MCC-2B43 and MCC-2B42 ) opened, and tagged with red Workmen's Protective Tags.

c.

The containment spray system is actuated by pressute switches PS-7064A, PS-7064B, PS-636, and PS-637 in a one out of two taken twice trip system logic when enclosure sphere high pressure is equal to but 1 css than 2.2 psig.

I d.

A suspected primary system Icak shall be investiga'ted immediately l

to determine the size and location.

Isolate the Icak if possibic.

If the 'cak proves to be a line break, the reactor shall be shut dcwn and cooled as rapidly as possible; cooling may exceed 300 F per hour is necessary.

NOTE:

The reactor feed pumps could possibly maintain the reactor water Icvel if less than a two-inch diancter break occurs. When the reactor water 3cvel can be maintained, cooling at 100 F per hour auf be carried out.

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2.0 TECllNICAL SPFCIFICATIONS AND PLANT REQllIREMENTS (Contd)

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2. PLANT REQUIREMENTS (Contd)

Operatior,of the core spray system and enclo,sure spray system e.

requires all reasonable precautions to be observed to minimize pumping fission products into the enclosure spray system if an accident occurs.

f.

The backtp containment spray system is remotc-manually operated and is to be used when the containment spray primary system is unavailable.

,, HO-7068 is to be manually actuated 15 minutes following a break in order l

to remove dirborne iodine.

3.0 PRECAUTIONS /ND LIMITATIONS

1. The normal and backup core spray systems are both initiated automatically simutaneously if the reactor water level is below elevation 610 feet 5 inches and the reactor pressure is below 200 psig.

2. The reactor enclosure normal spray system is initiated automatically when the containment sphere pressure is 2.2 psig. The operator can manually initiate core spray at any time but reactor pressure must be less than the

. fire water system pressure to allow the sprays to operate.

3. A 1/16-inch telltale hole drilled in the gates of the normal core spray supply drain valve PI-ll6 and the backup core supply drain valve PI-118 gives an indication of Icakage through:

a.

Valve MO-7051 b.

Valve MO-7061 and check valve c.

Valve MO-7070 d.

Vnive MO-7071 and check valve

4. The MO-7069 tie valve has been disabled open and position indicating lights are operable through breaker ACB-2B44.

5. Fire water can be supplied to the core spray or reactor enclosure spray system from the core spray heat exchanger shell side inlet thro.:gh valve MO-7072 if all normal fire water supply is lost.

6. When the core spray fire. water system supply basket strainer BS-5760 differential pressure execeds 2 psig, switch to the alternate strainer and clean the dirty one.

7. Whan tha turbine building fire water system supply basket strainer BS-5761 differential pressure execeds 2 psig, switch to the alternate strainer.and

'cican the dirty one.

8. When the turbine building fire water system supply basket strainer BS-5759 differential pressure execeds 2 psig, isolate the strainer and c1can immediately, per SOP 26, Secticn 6.4.1.

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ML19347F462

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