ML20092P358
| ML20092P358 | |
| Person / Time | |
|---|---|
| Site: | Shoreham File:Long Island Lighting Company icon.png |
| Issue date: | 07/02/1984 |
| From: | LONG ISLAND LIGHTING CO. |
| To: | |
| Shared Package | |
| ML20092P356 | List: |
| References | |
| NUDOCS 8407060203 | |
| Download: ML20092P358 (649) | |
Text
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i' ; I t , i i f ! 4 i E j i Y.- 5 e t i } (! .. . .. SHIFT (SRO) ADVISOR I ~ TRAINING PROGRAM i 1 , 1- 5 i L i-4 }. i 1-4 1 t 1 9' f l~
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A * (mv) The goal of the Shoreham Nuclear Power Station Shift (SRO) Advisor "' aining Program is to help maximize the effectiveness of the Shift-(SRO) Advisor. This goal will be accomplished by providing Shoreham specific instruction in the areas of Administrative Procedures, Technical Specifications, Plant Systems and-Emergency Operating Procedures. The instruction in each of these areas will. cover, as a minimum, the objectives listed in Appendix A. Training in each of these areas will be covered via one or more of the following methods: Lecture Instructor-led discussion
- Structured self study (i.e. problem sets)
In addition, plant tours will be used to reinforce systems training. The systems to be covered via a lecture type format will be selected based upon an evaluation of the candidates past experience. Data sheets (Appendix B) may,be used to oresent Shoreham specific data for those systems that are similar to those encountered within the candidates past experience (i.e. Core Spray, Reactor Protection System etc.). Systems that are significantly different from those encountered by the candidate in his past experience will be covered via a lecture format. Preliminary information concerning possible advisor candidates suggests _that the data sheet / lecture groupings will ba divided similar to that outlined in-Appendix C. It is anticipated that the Shift (SRO) Advisor training program will be 4 weeks
, in length. However, the actual schedule will be determined when the final selection of Shift (SRO) Advisor candidates occurs.
Quizzes will'be administered during the course of,the program to monitor the students grasp of re<.ently covered learning objectives. Results of these quizzes will be used to diagnose the need for remedial training but will not be used as a criteria for program completion. In addition an audit exam will be administered by an independent agency. The audit exam, based en the course learning objectives, will be used to diagnose possible areas that -tequire - remedial training prior to administration of the LILCO certificatien exam. The LILCO certification exam will consist of both a written and a plant walkthrough exam. Each exam will be similar in format and degree of difficulty to NRC administered exams with the exception that the theory section of the written exam will be waived. Successful completion of the uritten exam will require an overall grade of greater than or equal to 80? wits each section greater than or equal to 70%. The walkthrough exam will be graded on a pass / fail-basis. O b
AVYkhDLX A 4 y 4 SHIFT (SRO) ADVISOR TRAINING PROGRAM OBJECTIVES (} Administrative Procedures At the completion of the program the student should be able to:
- 1. State the station staffing requirements.
- 2. Given a sample shift roster identify situations in which the on-shift staff is less than that required by SNPS Administrative Procedures.
- 3. State the- responsibilities of all on-shif t operations personnel during both normal and abnormal operations.
- 4. Given a situation that requires the use of any of the below listed documerts correctly initiate any that are required.
- 1. Station Procedure Change Notice (SPCN)
- 2. Temporary Procedure Change (TPC)
- 3. Radiation Work Permit (RWP)
- 4. Maintenance Work Request (MWR)
O3 5. Reports of Abnormal Conditions (RAC)
- 6. Lifted Lead-and Jumper Permit (LLJ)
- 5. State the conditions that prohibit approval of a TPC.
- 6. State the conditions that require the cancellation of a RWP.
- 7. State the conditions during which a lead maybe lif ted or a jumper installed without a LL & J Permit being required.
- 8. Given a situation in which the Shift (SRO) Advisor and on-shift Watch Engineer are in a " stalemate" with regard to approoriate operating strategy, etate the recourse available to the Shift (SRO) Advisor.
Shoreham Systems At the completion of the program the student should be able to: 1.- ' State the initiation signals for the following systems.
- a. Core Spray )
- b. Low Pressure Coolant Injection l
- c. High Pressure Coolant Injection
-d. Automatic Depressurization=
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- e. Reactor Core Isolation Cooling I. Reactor Protection
- g. Emergency Diesel Generators
- h. Reactor Building Standby Ventilation
- 1. Reactor Building Standby Ventilation / Control Room Air Conditioning Chilled Water
- j. Control Room Air Conditioning
- 2. Given a sample control room panel and annunciator status for those systems listed under #1 above:
- a. Determine if a valid initiation signal is present.
- b. Determine if complete system initiation has occurred.
- c. For those situations in which a valid initiation signal is present and a complete initiation has not occurred, state the required operator actions.
- 3. State the isolation signals for the following systems:
- a. Nuclear Steam Supply Shutoff
- b. High Pressure Coolant Injection
- c. Reactor Core Isolation Cooling
- d. Primary Containment
~g e. Reactor Building Closed Loop Cooling Water
- f. Reactor Building Service Water
- g. Reactor Water Cleanup
- 4. Given a sample control room panel layout drawing _and annunciator status for those systems listed under #3.
- a. Determine if a calid isolation signal is present
- b. Determine if complete system. isolation has occurred
- c. For those situations in which a valid isolation signal is present and a complete isolation has not occurred, state the required operator action.
Technical Specifications At the completion of the program the student should be able to: When given a status of plant conditions via either. a written scenario and/or control panel- display state the correct actions for any of' the following type situations:
- a. Single component malfunction that causes a system covered in Technical Specifications to be made inoperable,
- b. Multiple malfunctions that cause redundant subsystems
, .of systems covered in Technical Specifications to be made i operable (i.e. Failure of electrical power supply to a /)
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. subsystem in conjunction with a. single component malfunction in - the redundant subsystem) .
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- c. Operations in excess of Technical Specification Limiting Conditions for Operation. (i.e. exceeding thermal limits, failure to meet surveillance' criteria).
i d. Multiple malfunctions that require the use of Specification 3.0.3. j -Procedures (Emergency / Operating) At-the completion of the program the student should be able to:
- 1. When given a status of plant conditions via either a written
, scenario and/or control panel display: 4
- a. Determine if a situation governed by an emergency procedure exists.
, b. For those situations governed by an emergency procedure:
- 1. State the automatic actions listed in the emergency _ procedure.
- 2. State the immediate actions listed in the .
emergency procedure. ' t 4 4 0 4
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HPCI SYSTEM N ~ DATA SHEET C
- 1. INITIATION LOGIC SETPOINTG Pouble Low Reactor water level (-38 inches off LT 157 A,B,C and D) or, High Drywell Pressure (1.69 psig).
- 2. ISOLATION LOGIC & SETPOI!!TS
- a. High Steam Line DP High Flow (2?O" of rated + 3 see TD)
- b. High Turb Exhaust Diaphragm Pressure (10 psig)
- c. Steam I sak (based on High Amb Temps (149 ,187)
-d. Manual
- e. Low Steam Supply (110 psig)
- 3. TRIP LOGIC & SETPOINTS
~
Turbine trips on
- a. Any isolation
- 5. Low Pump Suction Pressure (15" Eg Vac)
- c. High Exhaust Pressure (150 psig)
- d. High Reactor Water Level (54.5 inches)
- e. Manual
- f. Mechanical overspeed 4 SIGNIFICANT INTERLOCKS
- a. Overspeed at 5000 RPM,_ auto reset after time delay
- b. Manual isolation only closes outboard MOV's
- c. Suction auto swaps to suppression pool on a suppression pool high level or CST low level
- 5. DESIGN DATA
- a. 700 to 4000 RPM control range; Avoid operation below 2200 -RPM
- b. 4250 gpm at 400 RPM and 110 psig i
- 6. MIN FLOW DATA
' Opens' at 4800 gpm
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SYSTEMS COVERED VIA DATA SHEETS i Reactor Protection System Core Spray Low Pressure Coolant Injection Automatic Depressurization High Pressure Coolant Injection Reactor Core Isolation Cooling Nuclear Steam Supply Shutoff Neutron Monitoring Reactor Water Cleanup SYSTEMS COVERED VIA LECTURE Emergency Electrical Distribution s - Normal Electrical Distribution Reactor Protection System Power Supply Reactor Vessel Instrumentation Containment Reactor Building Normal Ventilation Reactor Building Standby Ventilation l Reactor Building Closed Loop Cooling Water Reactor Building Service Water Reactor Building Standby Ventilation / Control Room Air Conditioning Chilled Water Control Room' Air Conditioning-Radiation Monitoring-Rod Sequence Control t I O y ..e , , ,. , .I, , ,,,. - v- ,- -vw. ', - -
a 4 SHIFT (SRO) ADVISOR SYSTEM TRAINING INDEI y
- 118 RBCLCW 121 RHR 122 SERVICE WATER 308 NORMAL ELECTRICAL DISTRIBUTION 309 405 EMERGENCY ELECTRICAL DISTRIBUTION AND MALFUNCTION SUPP RBSVS AND CONTAINMENT VENT SUPPLEMENT 412 CRAC
*'9 RBNVS 421 1 RBSVS/CRAC SHILLED WATER AND SUPPLEMENT 607 RbH/RSCS 611 RPS AND RPS MG SETS 621 i
VESSEL INSTRUMENTATION 631 RADIATION MONITORING
- 654 CONTAIUME!C 9
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n _ f i SIIIFT (SRO) ADVISOR TRAINING PRCCRAM I i l WEEK T11REE ., . 5/28 5/29 5/30 5/31
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- M WEEK 2 QUESTION / RBSW/RM OUIZ MP EMERGENCY PROCEDURE ANSWEk SESSION TECF, SPEC PROBLEM OUIZ M?
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n n . I SHIFT (SRO) ADVISOR TRAINItit. "ROGRA_?' ll WEEK FOUR ., 6/4 6/5 6/6 6/7 6/8 MON TUES WED THURS FR1 8:00 L 4 g . WEEK 3 OUESTION/ TEC SPEC PROBLEM ADMIN PROCEDURE ADMIN PROCEDURE 'q ANSWER SESSION
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I l 1 REACTOR P.UILDING CLOSED LOOP COOLING WATER [ __ (R.B.C.L.C.W)
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( STUDENT HANDOUT FOR SHIFT (SRO) ADVISOR TRAINING PROGRAM l i l Prepared bv:/ 7 Md / w s/f/f y L Tr;. 'InstTut tor Qe' ' Date: 5/10/84 Approved by: g- g , y y v Rev. O_ " Training Spee'ialist' / Dag ,
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1.0 LESSON PLAN: Reactor Building Closed Loop Cooling Water (RBCLCW) ( 2.0 LECTURE DURATION: 2.6 hrs. min. 3.0 MATERIALS REQ 111 RED FOR STUDENT: 3.1 RBCLCW Lesson Plan 4.0 MATERIALS REQUIRED FOR INSTRUCTOR: 4.1 Associated Graphics 5.0 REFERENCE MATERIAL: 5.1 RBCLCV System Description and reference therein 5.2 FSAR 7.6.1.5. 9'2.2 5.3 FB-23B Dryvell Air Coolers 5.4 FM-15A/B 5.5 RBCLCV System Operating Procedure SP 23.118.61 [N 6 .0 SCOPE OF THE LECTURE: h Ik To inform the student of: 6.1 RBCLCW 1ayout in the plant 6.2 Major loads serviced by RBCLCW 6.3 Major Components 6.4 Normal and emergency operation 6.5 Alarms and Instrumentation 7.0 RBCLCW STUDENT OBJECTIVES: , At the end of this lecture the student should know: 7.1 State the purpose of the RBCLCW system as given in the student handout. 7.2 Given a diagram of the RBCLCW system trace out the flovpath for: a) Normal operation (Rx at power operation) b) Accident conditions (system split signal present) with the C RBCLCW j pump lined up to the same RBCLCW loop as the other runaing RBCLCW l .c pump. l [ l Y' # c) Accident conditions (system split signal present) with the C RBCLCW pump lined up to the redundant loop of the running RSCLCW pump. l l
% 1 (J 7.3 Given a RBCLCW control panel display & without the use of procedures:
- (
a) Verify automatic actions associated with a system split signal have occurred. b) Identify a failure of the system to split. c) Differentiate between a RBCLCW malfunction (i.e. pump trip etc.) and a total loss of RBCLCW. 7.4 Civen a total loss of RBCLCV state the immediate operator actions and any auto actions that are listed in SP 29.017.01. 7.5 List the station loads that can be cooled by RBCLCW loop A. t 7.6 List the station loads that can be cooled by RBCLCW loop B. 7.7 List the station loads that are isolated from cooling water due to an RBCLCW system split. 7.8 Given a diagram of the RBCLCW system and a RBCLCW control panel display identify the following system malfunctions: a) RBCLCW TCV f ailure (open/ closed) bl RBCLCW FCV failure (open/ closed) c) RBCLCW LCV failure (open/ closed) d) Flow disturbance that causes lov section pressure trip of P.BCLCW pumps (runnins; & standby) 8.0 LESSON OUTLINE: 8.1 Theory 8.1.1 Purpose of the system
.1 Provide cooling to Reactor auxiliary equipment and other equipment inside the Reactor Building.
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.2 Transfer heat from equipment to service water through heat exchanger.
.3 Provide nuclear safety related systems with redundant means of cooling during an accident condition to accomplish and maintain a safe shutdown.
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( A.1.2 Design Basis of the System (N-The RBCLCW system is designed ro: i
.1 Provide two independent cooling water paths to safety related systems that require cooling during an accident condition.
.2 Auto isolate non-safety related systems during an accident condition. t
.3 Isolations are accomplished via 2 series MOV's that are powered fror separate emergency electrical divisions.
.4 Seismic, Cat. I.
.5 Have RBCLCW pressure higher than Rx Bldg. service water To pressure and higher than pressure of most of its loads.
prevent inleakage of salt water and uncontrolled R/A material releases. 8.2 Physical Description 8.2.1 General System Description
.1 Redundant, closed loop system providing nuclear safety and
(~ ~ non-nuclear safety related components with reliable source of cooling water.
. [ ({ Three 50% capacity circulating water pumps *P075A (B) (C) a.
- b. Two 100% capacity M.G. set oil cooler circulating water cumps
- c. Two 100% capacity heat exchangers *E-911A/B
- d. Two RBCLCW head tanks *TK$26A/B
- e. Piping, valves, instruments and controls
.2 Nuclear safety related loops and loads
- a. Two redundant nuclear safety related loops
- 1) During an accident the system is automatically separated into two independent loops, each with one pump, heat exchanger and head. tank and each supplying one' safety related loop.
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< Safety related loops are redundant to,' ensure at least one half of the nuclear safety related components serviced by RBCLCW are supplied in the ris. event of a single RBCLCW component failure.
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- 3) Loop isolation is assured by having series MOV's 1
that are powered from separate electrical divisions. i
'Therefore, if an EDG fails to start, the redundant MOV will isolate the loop.
- b. Nuclear safety related loads are:
- 1) RHR pump seals coolers
- 2) Spent fuel pool cooling water Hv.
. 3) Reactor Recire. Pump J a) Seal cooler l l
b) Motor winding c) Bearing coolers NOTE: RBCLCW may be isolated, during an accidant, from the
.- Rx recire pumps, at the operators discietion by j NOV's on the inlet and outlet of recire pump section
[. of RBCLCW piping.
.3 Non-Nuclear safety related loops and loads Fig. 2
- a. During an accident the non-nuclear safety related loads
' are isolated by NOV's,
- b. The loads are not always redundant.
- c. The loads are:
- 1) Reactor recire punp MG set oil cooler
- 2) RWCU Non-Regen Hx i
- 3) RWCU pump coolers
- 4) Drywell equipment drain cooler
- 5) CRD Pump i
l a) bearing cooler .. j b) gear oil cooler
\ 6) Drywell coolers i
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.4 Pumps Fig. 3
- a. Three 1690 gpm RBCLCW circulating water pumps *P905A-B-C
- 1) Common discharge header, and suction header
- 2) Two pumps normally operated third in stand-bv
- b. Two 1690 gpm reactor recirculating pump motor generator set fluid coupling cooler cooling water circulating pump.
- 1) Takes suction from Hx discharge
- 2) Through pump to common discharge to M.C. room
- 3) Return line to suction of B loop RBCLCW Hx.
- 4) Isolated on accident conditions
.5 RBCLCW Heat Exchangers *E0ll A/B
- a. Two 1007 capacity heat exchangers.
- b. Crosstied on inlet and outlet by series MOV's.
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- c. Upon an accident signal the Heat Exchanger Isolation valve *MOV42 A/B and service water valve IP41 *MOV37 A/B are given an open signal to ensure both heat exchangers are in service when split into two independent loops.
- d. Temperature is controlled by mixing flow through Ex and bypass flow to maintain constant 91*F.
- e. RBCLCW pressure higher than service water to prevent in-leakage of salt water.
.6 Head tanks *TK-926A/B
- a. Make-up is automatically controlled by level control valve (LCV-11A & B) supplying demin. water.
- b. Integrator on makeup line can be used to detect system out-leakage.
.7 Radiation monitor
- a. On discharge of pumps
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- b. Samples water and returns to pump suction.
- w. c. The monitor detects a failed system component leaking radioactive contaminants to the RBCLCW system.
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- .. .8 Alarms i
- s. Alarms for the RBCLCW system are on the BOP panel.
.9 Pressure control valve
- a. Recires from discharge to suction of pump to maintain constant differential pressure across system loads.
- b. By maintaining a constant differential pressure loads can be valved in and out of service without effecting other running equipment.
4
.10 System conductivity is monitored on Turbine Building sample panel, a.- High conductivity on RBCLCW system vill bring up " Turbine Bldg. Sample Panal" alarm.
8.2.2 Major Equipment Description
.1 RBCLCW circulation pump *P965 A-B-C *
- a. Single stage centrifugni pump
- b. Pumps located on elev. 151
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- c. Power supp1v *P975 Fig. 4 A-480V DIV I MCC B-480V Div II MCC C-480V DIV III MCC
- d. All pumps controlled from main control board (BOP). In addition. *P9053 can be controlled from the remote Shutdown Panel,
- e. Inter 1ncks Pump A, B & C Fie. 5
- 1) AUTO START-nn:
l a) lov system pressure or b) accident signal (not C pump)
- 2) AUTO TRIP due to:
a) low suction pressure (time delayed) [ u 4
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- f. Interlocks Pump B
- 4. (' '
Same as A & C above when RSP transfer switch is i 1) normal.
- 2) RSP control switch only functions if the associated RSP transfer switch is in emergency position.
.2 MG set cooler cooling unter circulating pump
- a. Single stage centrifugal pump
- b. Pumps are located on elev. 40 of Rx Bldg.
- c. Power supply P992A Normal 489V MCC (11 side)
P992B Normal 489V MCC (12 side)
- d. Control from Control Room (PNL-652)
- 1) AUTO START due to:
running pump trip
- 2) AUTO TRTP due to:
lov suction pressure (this interlock prevents pump damAFe due to accident isolation). {
.3 RBCLCW heat exchanger *E911A & B
- a. Each Hx is 1007. capacity
- b. Single pass counter flow shell and tube type heat exchanger with RBCLCW on the shell side and RB service water on the tube side.
- c. Elev. 8' of Rx Bldg.
4 Booster Heat Exchanger
- a. Cools RBCLCW prior to entering Drvve11 coolers
- b. Cooled by Rr Bldg. service water system.
- c. Further reduces RBCLCW supply temperature to increase DW cooling capacity,
- d. Booster Mx's isolates on an accident condition.
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.5 RBCLCW Head Tank *TKW26 A/B :
- a. Location Elv. 151 ft. near pumps
- b. Normal operation is @ atmospheric pressure
- c. Provide NPSH for pumps
- d. LCV operates to maintain proper level in head tank,
- e. Each makeup demin line is outfitted with a totalizer to its associated head tank that allows system outleakage to be detected.
8.3 Principles of Operation Fig. 5 8.3.1 System operational Modes
.1 Normal operation
.a. Two pumps running, third in stand-by I b. One M.G. set cooler cire water pump running one pump in stand-by.
-- c. One heat exchanger with cross ties open.
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- d. If *P905C is running it must be manually valved to the same loop.as the one it is replacing. Valve line-up can be confirmed on the MXP Panel.
- e. Valve line-up - All valves open except one Hx. and service water valve to that Ex.
.2 Abnormal Operation I
- a. Loss of Station Air j l
The following RBCLCW components fail OPEN upon loss 1) of station air. o- HX Outlet Temp. Control Valve-(*TCV-001W,Y) o Makeup Control Valves (LCV-011A, B) l 1 l 1 0
w . -. . . . - . . . . . . - - . - - -... - -
- 2) The following RBCLCW components fail. CLOSED upon q
N, '
~ loss of station air.
o Bypass Temperature Control Valves (*TCV-001X,Z) o RBCLCW Cire. Pumps d/p Control Valve (PCV-071)
- 3) Field operator must be dispatched to isolate Makeup Control Valves to prevent overflowing head tank.
- 4) RBCLCW HX outlet temperature can be controlled manually by use of manual handwheels on Temp Cont.
Valves
- b. . RBCLCW Detective or Leaking Equipment or Coolers LOADS RBCLCW LOADS o RBCLCW HX Ser. Wtr o RHR Pump Seal Cooler o F.P. Cool H.X. o Rx Recire Pump Seal Cooler o Drvvell Air Coolers o Rx Recire Pump
( Mr. Set Fluid Coupling 011 Cooler o Dr3vell Eqpt. Drain Clr o CRD Pump Mtr. Brg & Cearcase Oil o RWCU NRHX o Rx Recirc Pump Motor Cooler o RWCU Recire Pump Seal Cooler o Rx Recire Pump Motor Brg. Cooler
- 1) Redundant loads will be systematically secured starting with the RBCLCW HX's. Determine if leakage exists by monitoring pressure increase or decrease on loadside. If pressure change cannot be seen, vent load side for indication of leak.
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- c. Dryvell Air Coolers Cooling coils Leak
- 1) Leakage may be determined by:
o Drywell Floor Drain Tank Integrator o Drywell humidity increase with RBCLCW Head Tank decrease
- 2) Isolate leaking coil by closing its Inlet Valve
- d. Rx Recire Pump Motor Windings Air Cooler Leak
- 1) Leakage may be determined by:
o 1298(1299) RECIRC PUMP A(B) MIR COOLER
. LEAKAGE HI o 1300(1301) RECIRCPdMPA(B)MTRCLCWIRFLOW LO
- 2) Recire pump must be shutdown prior to isolating RBCLCW flow,
- e. Rx Recire Pump Motor Bearing Oil Cooler Leak
. 1) Leakage may be determined by:
o Visual inspection of the bearing oil of the lower bearing, o 1284 (1285) RECIRC PUMP A(B) MTR BRG OIL LEVEL HI/LO
- 2) Recire pump must be shutdown prior to isolating RBCLCW flow.
- f. Rx Recire Pump Mechanical Seal Coolers
- 1) Leakage may be determined by:
o Increase in seal temperature (TR-100) o Increasing level RBCLCW surge tanks End/or increasing rad levels RBCLCW rad, monitor.
- 2) Max allevable seal cavity temperature is 250'F. If this temperature is reached, it will be necessary to secure the affected pump. -
- g. Recirc Pump MG - Set Oil Cooler Leak
- 1) Leakage may be determined by:
y , , ..g.. _ , .
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- + - - - - - - - - . . . . . . _ ,ee*.-*wd 4e+A..m h l
l o Decreasing oil level in the fluid coupling ( oil reservoir and oil in the RBCLCW system.
- 2) An oil cooler leak will necessitate shutdown of the associated MG set. !
l
- h. RWCU NRHX Tube Leak
- 1) Leakage may be determined by:
o RBCLCW Surge Tank level increase with a corresponding increase in RBCLCW rad. level (Large leak may cause NRHX temp increase).
- 2) An NRHX tube leak will necessitate shutdown of the RWCU systen.
- i. Drvvell Eqpt. Drain Cooler Leak
- 1) Leakage may be determined by:
o RBCLCW Surge Tank makeup increase o Drvvell Eqpt. Drain Tank Flow increase
- 2) Isolate leaking cooler by shutting Inlet Valve tl
- j. CRD Punp Bearing and Gear Oil Cooler Leak
- 1) Leakage can be detected by visual inspection
- 2) A CRD Oil Cooler Leak will necessitate the affected CRD pump to be shutdown and RBCLCW to be isolated to it.
- k. RHR Pump Seal Coolers Leak
- 1) Leakage may be detected by:
- a. RBCLCW Head Tank level increase with an increase in rad levels with an RHR pump running.
- 2) Shutdown affected RHR pump and isolate RBCLCW flow to that pump.
- 1. RWCU Recire Pump Seal Cooler Leak
- 1) Leakage may be detected by: -
o Increase in cooling water rad, levels and an
/ increase in RBCLCW Head Tank level.
- 2) Refer to RWCU procedure to shutdown the affected
- pump.
o . . . _ _ . _ _ _- _
- m. RBCLCW Pipe Break :
- 1) Leakage may be detected by:
o Decrease in RBCLCW Head Tank Level o Increase in component temp. of RBCLCW Loads
- 2) Determine cause of leak by observing:
o Flows and temp. for RBCLCW component loads o Sump pump running frequency and level alarms
- 3) Isolate leakage by rotating affected equipment and isolating the pipe break
. NOTE: Removal of cooling water to supplied components will render those components inoperable. Check Tech Specs prior to their removal.
.3 Emergency Operations
- a. Loss of off-site power
~
M --
- 1) MOV's remain in their original position
- 2) All pumps stop
- 3) Pumps *P005 A&B will auto start (DG dependent)
- 4) M.G. set cire pump will not restart until normal power is restored.
- 5) Pump *P905C can be started manually after a 10 min, time delay. The operator must place the pump control switch in the-PTL-position after 10 min.,
then AUTO after START.
- h. Accident without loss of power Fig. 6
- 1) The accident condition actuation signals are:
a) Lov/ Low level in head tank ( 5'9") or b) High Dryvell Pressure 1.69 psig or c) Reactor lov level -132.5 .. If any of the above conditions should arise the following will occur:
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- 2) The system will isolate into two separate loops each
( '- with one pump, one Mx, and one surge tank.
- 3) RBCLCW pumps continue to run.
- 4) Non-safety related loops are automatically isolated
- 5) Heat exchanger that is out of service is put into service. Both Service Water and RBCLCW inlet valve auto OPEN.
- 6) M.G. set cooler circulating water pumps at: isolated and trip on low suction pressure (greater than 10" Hg VAC).
- 7) PCV is isolated.
- 8) A0V check valves will close
- 9) RBCLCW Heat Exchangers go to maximum cooling.
- d. Accident with loss of off-site power Same as above except:
(~ _ g'hs,-) --
- 1) Isolation and splitting is delayed until the diesel
., comes on (approximately 10 sec).
- 2) M.G. set cire, pump will stop on loss of power rather than low suction.
- 3) A & B pump will restart.
- 4) "C" Pump is prevented from starting for 10 minutes after the loss of power. After 10 minutes the C pump can be manuallv started by placing its control switch in -PTL-& then placing the control switch in the start position.
- e. Loss of RBCLCW (SP 29.017.01)
- 1) A loss of RBCLCW may be determined by any of the following annunciators:
o RBCLCW HX A(B) OUT TEMP HI/LO o RBCLCW SYS A(B) MDR PRESS LO o RBCLCW HD TK A(B) LEV LO-LO O
l l () ' o PLUID CPLG COOLING WIR PP A/B TRIP OR DISCH I (\ ~ LO. o RBCLCW SYS A(B) INOP o RBCLCW SYS A(B) DEGRADED
- 2) Other indication:
o RBCLCW header pressures low or fluctuating o Abnormal temp. on various eqpt. cooled by RBCLCW
- 3) RBCLCW system splits and isolates non critical loads on Lo-Lo Head Tank Level +1.69 psig drywell press, or -132.5" RPV level.
- 4) Upon verification that a su' stained Loss of RBCLCW has occurred:
o Reduce Rx Recire pumps to min, trip Recire MG Set, and initiate Emergency Shutdown (SP 29.010.01)
~
o Trip the RWCU pump and isolate system h- o When all control rods verified to be inserted and recire pumps are tripped, secure the CRD pumps. 4 8.3.2 Precautions
.1 RBCLCW should not be isniated simulteneously to both sets of redundant safety related equipment.
Eecognition o Field check of valve alignment 1 4
.2 RBCLCW Pump *P-995C should not be lined up to both RBCLCW l loops at the same time. l f
Recognition o Indicating lights on the MXP panel. l
.3 Cooling water to the RWCU NRHX's should not be lined up to I l
both RBCLCV loops at the same time. - l Recognition I ("' (m,/ o Field check of valve alignment j 15 -
s,. -- ~ . _ _. -,
/
.4 The Standby RBCLCW pump will auto start due te low discharge
\ 's pressure on either of the operating pumps.
Recognition o Low pressure ALARM, indication of ABCLCW pump trip.
.5 The Standby MG Set Fluid Coupling Cooler Recire Pump will auto start if the other pump trips or is shutdown.
Recognition o FLUID CPLC f ,G WTR PP A/B TRIP o FLUID CPLG CLG WTR PP A/B DISCH PRESS LO 8.3.3 Instrumentation and Control
.I hain Control Board, BOP Section
- s. RBCLCW Pumps *P-995A, B and C SPRING RETURN 4 POSITION SWITCHES
- b. RBCICW System A and B Inoperative Alarm Switches
[)N k_ - Individual switches with NORMAL-TEST pesitions. purposes) (admin. l's
- c. RBCLCW Heat Exchanger Service Water Discharge Valves IP41*MOV037A and B are equipped with the following controls:
- 1) Open-Close pushbutton control switch
- 2) Override pushbutton & indicating light
- 3) Normal / throttle keylock switch
- 4) Intermediate pushbutton Operation of these controls is as follows:
- 1. Open/Close pushbutton switch during normal operation functions as a seal-in.
Valve : sill full stroke once either open or close pushbutton is depressed.
- 2. Normal / Throttle keylock switch placing the keylock switch to the THROTTLE position allows the open/close pushbutton switch to serve as
("s3j a momentary contact switch. (.~a l
+
[ 3. Intermediate pushbutton . ((' with keylock switch in NORMAL pressing the intermediate pushbutton will cause the valve to travel to a 50% position, if the intermediate pushbutton is pressed with the l NORMAL / THROTTLE keylock switch in THROTTLE no valve , motion will occur at that time. However, when the ] keylock switch is returned to NORMAL the valve will l travel to a 50% position.
- 4. OVERRIDE pushbutton a) pressing the override pushbutton allows the valve to be closed with an accident signal present.
b) the override pushbut, ton must also be pressed in order to reclos'e the valves efter a 4 sustained undervoltage has occurred on the associated 4KV emergency bus i.e., Bus 191 for 37A. (Same signal that initiates slow transfer).
.3 Miscellaneous Control Panel (MXP)
- a. Motor Operated Valve Control Switches p
Individual pushbutton switches, momentary contact, seal-in type, with integral' Red-Open and Green-Closed indicating lights. A small blue light (out for loss of control power and motor overload) is mounted above each switch,
- b. 1. blue light out & either green or red light on indicates motor overload.
- 2. blue light out & no_ green or red lights indicative of control power f ailure, j
if motor overload occurs valve can still be repositioned i c. by holding pushbutton down.' 4 Control Room Indication I
- a. System A&B discharge pressure (9-159 PSIC) (MCB-01) f
- b. Radiation monitor recorder 1
. i
- c. RBCLCh' discharge tem . recorder (MXP PNL) l l
l u O r
-_r. , - - . - - , - .
, , - = ,
;('~ d. Hand valve position indication ("C" Pump Discharge Valves) (MXP PNL)
.5 The Rx Bldg Closed Loop Cooling Water system contains the following annunciators ANN CONTROL ROOM TERIFICATION 0040 (41) (56) RBCLCW PUMP B(A)(C) AUTO TRIP o Pump ' green' light ill, with CS in Auto-After-Start 0340 (41) RBCLCW HX A(B) TEMP HI/LO o Temp recorder on MXP panel o Computer Point 0342 (3) RBCLCW HEAD TANK A(B) LEVEL LO-LO o Conpu*.er Point 0347 (8) RBCLCW HEAD TANK A(B) LEVEL HI-LO o Computer Point 0352 (3) RBCLCW SYS A(B) HEADER PRESS LO o RBCLCW P7 on MCB-01 0360 (2) RBCLCW SYS LOOP A(B) INOP o MAN-INOP switch sys A to INOP
(N _ _ hj - o Loss of control power to i critical valves o Loss of control power, motor overload, or CS in P-T-L for RBCLCW pumps 'A' (B) and either RBCLCW pump 'B' motor evid CS in P-T-L loss of control power, or HV-051A(B) Not full open 0361 (3) RBCLCW SYSTEM LOOP A(B) DEGRADED o Loss of control power to various RBCLCW MOV's o RBCLCW pumps A(B) or C motor ovld, P-T-L, or loss of control power and HV-051 A(B) closed 4 0407 RBCLCW VV INTERLOCK LCTL o Field verification by E.O. i 1380 FLUID CPLC CLC WTR PP A/B TRIP o CS in AUTO-AFTER-START and ' green' liF ht lit (~\ t ) 1381 FLUID CPLG CLC WTR PP A/B DISCH PRESS LO o Local Press indication. LJ l l l
.6 Remote Shutdown Panel (RSP) Controls (Rx Bldg 4 El 63')
[- 4 s. Maintained contact type transfer switch with NORMAL-EMERGENCY positions for pump *P-995B and valve "B" Ex inlet valve (MOV 42B)
- b. Control switch with START-STOP positions and indicating ,
lights for pump *P-995B. I
- c. Control switch with OPEN-CLOSE positions indicating lights for valve *MOV942B.
- d. Nbintained contact type transfer switch with NORMAL-EMERGENCY positions for RBCLCh' heat exchanger r *E-911B service water outlet valve IP41*MOV937B e.- Maintained contact switch with OPEN-CLOSE positions and Indicating lights for IP41*MOV937B.
.7 Interlocks NOTE: Valve motor overload protection will be cut out during accident signal to ensure that valves are able to travel to their accident configuration.
~
- 8.3.4 System Interrelations O
.1 Start-up
- a. Rx Bldg. Service Water
- b. Emergency buses
- c. Normal operation (normal electrical buses)
.7 Shutdown
- a. RHR systen I 1) Loss of RBCLCW - S/D of Pump effected, time of operation dependent on temperature of primary water.
4
- b. Spent Fuel Fool Cooling
- 1) Loss of RBCLCW - Time factor dependent on amount of spent fuel,
- c. Rx Recire System , ,
- 1) Cooling to pump should not be isolated until pumps have cooled to below limiting temperature.
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I
- 2) Pumps may run for 10 min. however the seals will be
( damaged in short order and pumps should be stopped immediately upon loss of cooling.
- 3) Loss of MG set fluid coupling cooling will result in a trip of MG due to high oil temperature.
- 4) With no Rx Recire. pumps operating the Rx Mode Switch must be placed in SHUTDOWN.
- d. Reactor Water Cleanup Due to loss of non-regen. Heat exchangers high temperature will cause isolation of system. Pumps should be shutdown to prevent damage, e.- CRD Loss of cooling water will require the stopping of the affected CRD pump.
- f. Drywell Air Cooler
-Upon loss of RBCLCW, temperature increases dependent upon I h . heat loads, causing possible shutdown due to excessive s-- -
operational temperature for equipment. ij 8.4 Sunmarv 8.4.1 The purpose of the system is to cool reactor suxiliary equipment
. and other systems in the reactor building.
8.4.2 The main flow is through the two loops of each subsystem to cool the safety and non-safety related equipment, returning to the heat exchangers and then goes to the suction of the pumps. 8.4.3 Actuation Signals Signals that will split the system include: Lov/ Low Level in Head Tank Hi,th Drywell Pressure 1.69 psig Reactor Low Level -132.5 8.4.4 Normal operation of the RBCLCW system removes heat from the equipment in service. The loss of the cooling to any of the equipment will necessitate operator action to correct the ,. condition. In some cases a shutdown of the reactor nay be needed. Loss of service water to the heat exchanger will cause the same end result as above. w
- . . _ _ . . _ . . . _ = . _ _ . . _ _ _ . _ . . _ _ _. - -
-_7 . _
9.0 TRANSPARENCIES CONTAINED IN THIS LESSON: . ( Fig. No. Description 1 RBCLCW (Nuclear Safety Related) 2 RBCLCW (Non-Nuclear Safety Related) 3 RBCLCW (Composite) 4 RBCLCW Electric Dist. (Safety Related) 5 RBCLCW Normal Operation 6 RBCLCW Accident Operation 7a,b RBCLCW Control Room Mimic ([J
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S R.B.C.L.C.W. MALFUNCTIONS FIG # 1a-b. Normal Operations e Both loops are cross connected with one HX. 2a-b. Accident Condition e (+L69psig drywell both loops split, non crit. loads isolated). 3e-b. Loss of RBCLCW pump 'B' Loss Hdr pressure. 'C' RBCLCW auto start.
) e Aa-b. Loss of Station Air e TCV's go to max cooling, head tank will overflow.
I i Sa-b. Total Loss of RBCLCW j e Head tank lo. lo levels, RBCLCW pumps trip on low suction pressure. 6a-b. Tailure RBCLCR to split e Rx water level -140, some non-critical isolations did t not close, system INOP and DEGRADED. i 1 e
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RESIDUAL HEAT REMOVAL STUDENT HANDOUT n- . Date: r./r/r y Prepared by [ M ,( M d % - z/z r/e v
// t"*-in';; lastpuctor Q/ Dafe /
Handout #: HL121 Reviewed by: b y dpMA h 8 Opgfations Training specialist / Date Revision f: 6 Approvad by:l' */ / Se l Date' 3 / 8! Training Supervisor /
O t- . 7-e I OBJECTIVES: The student shall be able to: A. State the purpose of the RHR system. B. State the purpose of each mode of the RHR system. C. Given a diagram of the RHR system, be able to trace out the flow path for:
- 1. Standby
- 2. Suppression Pool Cooling
- 3. Containment Spray
- 4. Steam Condensing
- 5. Shutdown Cooling
- 6. Tuel Fool Cooling Assist
- 7. Test D. Given any of the precautions, cautions, or limitations contained in ki SP23.121.01:
s
- 1. State the purpose
- 2. State how the operator can identify from control indications that the limit is being approached and/or exceeded.
E. Given control room indications and/or annunciators associated with the RHR system, identify and initiate corrective actions for condition which require use of the following Abnormal and Emergency procedures.
- 1. SP23.121.01 Steam Supply Isolation
- 2. SP23.121.01 Heat Exchanger Trouble
- 3. SP23.121.01 Leak Detection and Isolstion
- 4. SP23.121.01 Ops of "A" RHR Sys Prom RSP with Single Tailure of Bus 102.
- 7. Given SP23.121.01, be able to correctly operate the RHR system in the following modes: ,
- 1. Suppression Pool Cooling
- 2. Containment Spray
- 3. Steam Condensing
- 4. Shutdown Cooling
4
- 5. Fuel Fool Cooling Assist
(.
- 6. Test a- 1 C. Given the mode of operation of the RHR system, state any operatieff actions for RHR required upon receipt of an LOCA signal (1.69 psig dryvell and/or
; -132.5" RPV level).
i H. Given various plant conditions and/or indicators, determine which mode of RHR is required. I. Given appropriate RHR system parameters, be able to identii'y a leaking RHR heat exchanger and/or valves. i J. Given an annunciator (s), be able to verify its validity from available control room indications. K. Using associated RHR Alarm Response Procedures, and selected plant j parameter, diagnose cause for alarm and initiate corrective action. ! L. Given control room indications, immediately after a RHR pump start, identify a no flow condition. s State how *MOV-036A(B) can be verified to be approximately 10% open. p M. 4 I f i i y l l l e l I . __ _ . _ _ _ _ _ _ _ _ _ . . , _ _ . _ _ _ _ _ _ _____. _ _ _ _ _ _ _ _ _ . _ _ _ _ _
s -- _ , l l l' II PURPOSE: The purpose of the Residual Heat Removal System is to remove post power operational energy from the reactor under both operational and accident conditions. III SYSTEM DESIGN: A. GENERAL DESCRIPTION (Figure 121-1)
- 1. Process Flev Path The Residuni Heat Removal (RHR) system consists of two redundant loops, either of which contains the necessary equipment to enable each loop to provide most of the functions required of the RHR system.* Each loop contains two suction strainers, two pumps, a heat exchanger, and a dryvell spray header. The two loops are interconnected by a normally closed and de-energized Cross Hender Shutof f talve which joins the loop's discharge piping. The RHR system can be operated in seven (7) basic modes:
Lov Pressure Coolant Injection - (LPCI) (Figure 121-2) a. A (see LPCI (204) Lesson Plan).
= (Figure 121-3) b')
\ b. Containment Spray (see LPCI (204) Lesson Plan).
- c. Suppression Pool Cooling (Figure 121-4)
The Suppression Pool Cooling mode is used to cool the Suppression Pool following RCIC, HPCI, or S/RV operation to ensure the suppression pool's primary role as a quenching agent during a LOCA condition is not limited. Suppression pool cooling mode limits the suppression pool water temperature by using the RHR pumps and heat exchangers in a closed loop with the suppression pool. One or both loops can be utilizei in this mode. Steam Condensing (Figure 121-5) d. During conditions with the Rx shutdown and isolated from the main condenser, the steam condensing mode maintain the reactor vessel at or close to operating pressure and temperature. t l . 1
\n t./
l \
\
)
s- l l
_ - _ - _ . _ - - - - . . - _ - . . -. - .-. _. - _ _ = . _ - - _ _ . t . J (: NFCI steam supply line supplies steam to the RNR heat i ' exchangers through Pressure Control Valve. The steam is condensed in the heat exchanger via Service Water and is then directed to the RCIC pump which returns water to the reactor pressure vessel. One heat exchanger operating as a steam condenser has sufficiant heat transfer capacity to handle the 4 reactor decay heat after$51 hours of operation. Shutdown Cooling 4 (Figure 121-6) e. Utilized to remove the residual, sensible and decay heat from the reactor when vessel pressure decreases to less than 125 psig. This mode can reduce the reactor vessel pressure to i J 125'T within 20 hours after reactor shutdown and maintains or i reduces reactor temperature as desired. The RER pumps take a suction from the recirculation loop and
; pump reactor coolant through the heat exchangers. The cooled reactor water is returned to the vessel via the reactor i
recirculation system piping. Some flow may be diverted to the reactor head for condensing the system in the upper portien of the vessel. This ensures that the water level in the reactor vessel can rise without temperature stratification in the i vessel. i
~
- f. Tuel Pool Cooling (Figure 121-7)
If large quantities of fuel are to be removed from the fuel pool the decay heat generated would be greater than the heat removal capacity of the fuel pool cooling system. The RHR system may be aligned to supplement the fuel pool cooling system by closing the "A" loop suppression pool 1 suction valve, manually valving in suction from fuel pool to RHR pump and heat exchanger, and return to fuel pool via a manual isolation valve. I l Test Mode (Figure 121-4) l g. l The Test mode of RHR is utilized to test the LPCI mode of operation. Each loop is equipped with a test line capable of rated LPCI flow. I l The test mode taken suction from the suppression pool to its respective RER pumps and heat exchanger bypass valve, and returns to the suppression pool via a 100% capacity test return line.
- f L
. _ _ _ . . _ _ __ _ _ . _ . _ . _ _ . ~ . . _ _ . . _ _ _ _ _._ .- _ ._._._ _.. . _ _ _ _ __.__.~ .
. . _ . _ . _ . ~_
y l I
.( '
( A. COMPONENT DESCRIPTION
- 1. The RER Pumps, located in the Rx Blds at elevation 8', ase supplied power from 4160V DIV I "A" RHR, 4160V DIV II "B" RRR, 4160V DIV III "C"+"D" RHR pumps. The motors are supplied with standard 4KV motor protection relaying. The RHR pumps are rated at 10,000 gym each against 9 psig reactor pressure. Each pair of pumps must l deliver 15.400 spm assinst 20 psi reactor pressure. Fump sealing is provided by a mechanical seal which uses injection water from the RHR pump discharge. The injection water must first pass through a cyclone seperator to remove impurities and then is cooled in a seal cooler which uses RBCI.CW as its cooling mediur. and finally to the mechanical seal of the pumps. High temperature for extended periods of time can cause accelerated degredation of the mechanical seals.
- 2. The Core Sprav/RHR Ioop I.evel Pumps, one per division, mair.tains l
JO40 psig on the RHR pump discharge piping to assure prompt
- injection time and to help prevent water hanseer from occurring.
Electrical power is supplied to each pump by its respective Division Motor Control Center (MCC). ! 3. The RHR Heat Exchangers, located in the Rx Blds at elevation 40', are vertical, inverted U-tube heat exchangers. The tube side of the heat exchanger, constructed of CuNi, uses service water to make (O. a double pass through the heat exchanger. The shell side is for reactor water and is only single pass.
< 4 There are two Drvwell Sparsers located in the primary containment
- drywell. Each sparger is a 12" circular stainless steel pipe with "A" sparger supplied by A loop and "B"'sparger supplied by B loop.
j Each sparger, located in the Rx Bids at elevation 109'-A and
' 106'-B, contains nozzles pointed inward towards the reactor to give ' a uniform spray pattern and thereby ensure containment atmosphere i mixing during containment spray mode.
- 5. There is one Suppression Pool Sparger, located inside the suppression chamber area at elevation 51', which can be supplied by either RHR loop. The sparger is a 5" circular stainiens steel t pipe, with stainless steel nozzles pointed outward from on top of the pipe spraying away from reactor. There are holes on the bottom of the sparger to permit drainage.
, 6. The Head Sprav Norrie, supplied * .'ie "B" loop only, is bolted to the reactor vessel head, and is * .d to condense steam bubble during a flood up of the Rx vessel. The head sprey nossle points i
inward towards the center of the reactor vessel to avoid spraying the Rx vessel wall and causing thermal stress. l l l _ . _ _ - _ . . . _ , - . . . . _ _ . . . _ _ . . _ _ _ _ _ . _ ~ . _ _ . _ ~ _ . _ . _ , _ _ _ _
O<
- l { IV CONTROLS AND INSTRUMENTS A. CONTROLS The following RHR system controls are located in the control room.
- 1. Key Lock Switches:
Supp. Pool Suct (*MOV-031 A-D) . Ex shell inlet (*MOV-033 A.B) Hx shell outlet (*MOV-035 A.B), Cross tie har (*MOV-050). Cont spray outboard (*MOV-038 A.B). Test & Supp pool spray isolation (*MOV-040 A.B). E' recombiner supply (*MOV-057 A.B).
- 2. The Manual Isolation Valves (HV-071 A (B)) located in the drywell, have position indication available in the control room.
- 3. The Testable check Valve and Motor Operated Bvpass Valve A0V-081 A (B) has a five position switch; Test - EM. close - close - open -
EM. open. In the Test position, the motor operated bypass valve J opens and the A0V actuator solenoid energizes to admit air to operate the actuator. The air actuator position is indicated in the Control Room (red - open, green - closed). Actuator movement i during test proves freedom of movement of check valve operating , shaft. The EM. close - close - open - and EM. open positions only affect motor operated bypass valve, not A0V air actuator. If a low O(( _ RPV level (+12.5") is sensed when the motor operated bypass valve vill be given a close signal and the air actuator will reposition to the close position.
- 4. RER Switches
- a. Manual initiation A&B Cutler - Hammer armed pushbuttons (Loop A&B) which has a pushbutton collar which must be rotated to are the switch, and once the pushbutton is armed, depressing the switch will result in loop initiation.
- b. Initiation reset A&B pushbuttons (loop A&B) allows operator to return system to standby status.
- c. RHR System I (II) Inop which causes a RHR System I (II) inoperative alarm when placed in INOP. INOP switch used to i give alarm indication of RHR logic status during logic testing.
I Steam condensing mode selector switches (A&B) which allows i d. energizing of solenoid to supply air to PVC 003 A (B) and PVC 007 A (B). O
._. _= _ - - _ - - _ -- . --.__. _..
r h -- h -emme m . , .ee- -m .e. # t
\
B. The Following RHR system parameters are monitored in the control room on t-Panel 601:
- 1. Flow
- a. Loop A(B) Flow Indicators and Recorders
- b. Head Syray Plow Indicator (B Loop).
- c. Meat Exchanger A(B) Service Water Flow Indicator.
- 2. Pressure
- s. RHR Loop A(B) Heat Exchanger Shell Pressure.
- b. RER Mx Pressure Controller.
- 3. Level i
l a. Suppression Pool Level
- b. RHR Ex Shell Level
- c. RHR Hx Shell Level Controller.
- 4. AMPS
- a. A, B, C, D RHR pumps
- 5. RHR Hx Vent Valve Position (1E11 *MOV-055A(B), 056A(B))
- 6. Indicating lightst
- s. Service Water pumps
- b. Ultimate cooling valves (1P41 *MOV-033 C.D) 4
- c. Initiation signal seal in
- d. Automatic isolation for *MOV-037
- e. Containment Spray Permissive
- f. RHR pump automatic override.
i
- - - .- - ~ .. . - .-- _ _ . . . .
l l i (' INTERLOCKS
*~ C.
- 1. Auto Initiation
- a. Auto initiation of the RHR system vill occur due to the following signalst Signal Identification Coincident Hi DW +1.69 psig Dryve11 pressure o Dryvell sys A(B)
Press Hit ARP 1128 (9) OR Coincident to-Lo-Lo -132.5" RPV Water Level Level. o RHR sys A(B) Rx to (or MANUAL pustibutton) Level Init ARP 1130 (1)
- b. System Response The RHR system vill align itself to the LPCI injection mode from standby or other operating modes except during Puel Pool Cooling Assist (requires manual valve alignment) and Shutdown Cooling (SHUTDOWN COOLING RESET pushbuttons must be depressed). The trip is sealed in and the following occurst v
)
0 1) Close signal to containment spray valves.
- 2) Open signal to injection valves *MOV-036A(B) and *HOV-037 A(B) (*MOV-037A(B) vill not open until Rx pressure (46$
psig. *MOV-036A(B) norm. open).
- 3) Start signal to respective EDG101 (2) and 103 and its associated Emergency Bus Loading Program.
- 4) RHR pumps A. B. C start 2 see T.D.
- 5) RHR pump D start 7 see T.D. (Loss of offsite power. vait for diesel to pick up bus)
- 6) Ex bypass valve (*MOV-034A(B)) int. open for 3 min.
- 7) Steam condensing mode valves interlocked closed.
- 8) Min. Flow VV open with RHR bkr. closed +10 see T.D. (2200 gpm. Min. flow shuts > 2200 gpm.
- 9) WhenRPVpressure(465psig.*MOV-037A(B) opens.(MOV-036 **
A(B) int. open for 5 min.). e !
- 2. Auto Isolation (o)
's ' a. Auto isolation of the RHR system vill occur due to the l following signalt l 1
1 l
. .~.--.. --
Signal ~ Identification o Lo level trip (12.5") o Shutdown Cooling VV 125 psig Rx Rectre " white ind. light with suction pressure and system in Shutdown Cooling either MOV-047 or MOV048 mode. is open.
- b. System Response The Inboard Injection Valve *MOV-037. Shutdown Cooling Suction Valves *MOV-047.048, and Head Spray Valves *MOV-053,054 will close.
- 3. Component Interlocks
- a. Pumps A.B.C. and D
- 1) Auto Start Identification Initiation signal Dryvell Sys A(B) Press Hit ARP 1128(9)
RHR SYS A(B) RX LO LEVEL INIT: ARP 1130(1)
- 2) Auto Trips o PW.P KIR OVLD A'.G.
a) 4KV motor protection o Double brilliant ' white' light b) Suction valve o Valve position on PNL601
*MOV-031 not fully open and any of the o RHR PUMP TRIPPED ANN.
following valves not fully opent Shutdown Cooling Inlet Valve (*MOV-047(8)). Shutdown Cooling Pump Suction valve *MOV-032.
- 3) Initiation override - o Pump Stop Signal placing control switch to stop with initiation SEAL - IN (' white' light) signal present.
- b. Shutdown Cooling Suction o Valve position on *PNL-601 Valves (*MOV-032 A-D): will not open unless Suppression Pool Suction and Test Line Isolation viv (*MOV-040A(B))
to that loop are closed. (Prevents
- draining the Rx vessel to the
__ Suppression Pool).
's
[O O 9( (- ' c. RNR Heat Exchanger Bypass o DRYWELL SYS A(B) PRESS Valve (*MOV-034A(B)) hit AKP 1128(9)
- 1) Auto Opent on LPCI o RHR CTS A(B) RX 10 LEVEL initiation signal and INIT: ARP 1130(1) is interlocked open for three (3) minutes after o Valve position on *PNL601 signal received
- d. Outboard Injection Valve
(*MOV-036 A(B))
- 1) Auto Opent on LPCI o LPCI LOW PRESS PERMISSIVE initiation signal and SYS A(B): ARP 1433(4)
Rx pressure ( 465 psig
- 2) Can be opened manually o Valve position if *MOV-037 A(B) fully closed or Rx pressure
{ 465 psig
- 3) Closet manually with no o Initiation signal reset LPCI initiation or after
)
- 5 min. T.D with U CI initiation signal
- e. Inboard Injection Valve o LPCI LOW PRESS PERM
(*MOV-037A(B)) SYS A(B): ARP 1433(4)
- 1) Auto Opent Rx pressure o Initiation signal light f465psigandLPCI illur.inated initiation signal present, and Shutdown Cooling o Shutdown Cooling isolation Isolation not present light not illuminated (Rx level lov ( 4,12.5")
with Rx Rectre Suction pressure (3125psig)and both shutdown cooling valves (*MOV-047 and *MOV-048 not fully closed) and sealed in.
- 2) Can be opened manually o Valve position if *MOV-036A(B) fully closed or Rx pressure f465psig l
I
. i I
l ;
' f' 3) Auto Close: No auto open signal present and o Rx VESSEL LO' LEVEL A(3) TRIP ARP 1191 (1207) shutdown cooling isolation signal present a) Low Rx water level o Rx Press ind. '
l (f12.5")and
. b) Low Rx Rectre Suet. o Valve indication Press. (.(125 pois), and c) Shutdown Cooling valves
(*MOV-047 and *MOV-048) not fully closed. 7 l N07Er This isolation is sealed in and must be reset after any one isolation j signal has cleared by depressing Shutdown Cooling *MOV-037A(B) RESET
- pushbutton in order for the injection valve to be able to auto open on a subsequent LPCI initiation signal.
1
- 4) Valve will manually close
; if no auto open signal present.
l lJ f. Minimum T1ow Valves o Valve position
, (*M0V-045 A(B))
- 1) Auto Opent with loop o Loop flow indication on flow 1 2200 ppm. pump *FNL-601 i A or C (3 or D) breaker closed after a 10 sec. T.D.
i NOTE: The purpose of the 10 second time delay is to inhibit the l ainimum flow valve free opening during RHR pump starting in the shutdown cooling mode or fuel pool cooling assist mode. This prevents introduction of reactor water or fuel pool water into the suppression pool via the ninteum flow line. During RHR pump starting in the shutdown cooling mode or fuel pool cooling assist mode, sufficient i flow should be generated to send a elese signal to the minimum flow valve .. i ()2200 spa)within10secondsofthe i pump starting. The RHR pumps are designed { O to operate for at least 10 seconds with j p> no discharge flow path with no pump or actor desage resulting. i i 1 I
- l O
( _ 4
} 2) *MOV-045 A(t) will close with either the switch in close or the switch in auto and 2200 spe 3 Discherse to Radvaste v1ve
(*MOV-051, 052) and Heat Exchanger Shell Sample Vivs (*A0V-061 A(3), 062 A(R)) 1
- 1) Auto closes MS$$$ o REAC VESSEL L0 LEVEL isolation signal (*12.5") TRIP A(5)
- 2) Open manually if no MS$$$ isolation signal
- h. The following valves will o DRYVELL SYS A(B) PRESS automatically close upon MI: ARP 1128(a) receipt of an LPCI initiation signals o MR SYS A(R) RX LO LEVEL INIT: ARP 1130(1)
RCIC SUCT *M0V-043 A(5) HLAT R DM TO SUPP POOL o Valve position *PNL-601
- *MOV-044 A(B) MFCI STM
. SUPP. *MOV-049 MFCI STM l ( TO M R MX A(B) *PCV-003A(5)
RCIC SUC TROM MR MX A(3)
*PCV-007A(B)
- 1. The followinR valves will o RX VESSEL LO LEVEL automatically close if either_ A(B) TRIP: ARP 1119(1207)
Rx Rectre Loop Suction >125 pais or Rx Level (12.5": SUCT o Rx Pressure Ind. PROM RECIRC *MOV-047(8) MEAD SPRAY *MOV-053(4) e Valve position D. V A.NUNCIATORS The following parameters are annunciated in the Main Control Room: Annunciator ARPd Control Room Veriftention
- 1. MR MX All DISCM COOL trTR TEMP MI 1120 1.a) 1E41-TR-100 on *PNL
-614 b) 741*MOV-034 A(8) valve position.
- 2. MR SYS A(B) DISCM MDR/SDC 1122(3) 2.a) A(3) MX SHEtt ' PRES-SUCT PRESS M1 sure
,O b) *MOV-047(408) valve position i
[m) L_
l O v ' t t* D. ANNUNCIATORS (con't) Annunciator ARPf Control Room Verification
- 3. RX SYS A(t) PRESS LO 1126(7) 3.a) Rm Press on PAMS
*PNL-601
- 4. DRYWELL SYS A(5) PRESS MI 1128(9) 4.a) PRI CNTMT M1 PRESS TRIP A(B) b) Drywell Press. ind.
or *PNL-602 c) Drywell Press, recorder en
*PNL-PCM.
- 5. RHR SYS A(B) RX L0 LEVEL INIT 1130(1) 5.a) wide Range level A(5) on PAMS recorders on
*PNL-601 b) Wide Range Level ind, on *PNL-602
- 6. MR SYS A(8) MAN INIT SV ARMID 1132(3) 6.a) Arsing collar rotated O 7.
M R PUMP A(3.C.D) TRIPPED 1134(5.6.7) 7.a) Creen stop light illuminated b) White light 'dtm' c) ' Red' Plag on control switch for pump
- 8. MR PUMP A(3.C.D) MOTOR OVLD 1138(39,40,41) 8.a) White itsht
' bright' b) Creen indicating light.
c) Red flaR on control switch for pump.
- 9. MR SYS A(3) LOGIC POWER PAIL 1142(3) 9.a) Puses PIA and P2A on *PNL-617 b) Other 125VDL ann.
c) RSSVS initiation signal
- 10. RX SYS A(5) LEVEL LO 1144(5) 10.a) Wide Range level A(B) on PAMS on
*PNL-601 b) RCIC, MFCI Auto Start
[ _ . . . . _ . _ . . . . _ h
!' D. ANNUNCIATORS (con't)
Arnunciator ARPA Control Room Verification 11.a) Blue light for
- 11. MR SYS A(B) DECRADED 1146(54) thermal overload extinguished b) Position indicating lights extinguished 1147(55) 12.a) Blue light for
- 12. RHR SYS A(B) INOP thermal overload extinguished b) Position indicating
- lights extinguished c) Discharge XCONN
(*MOV-050) not closed d) INJ. VLV. MAN. 150L. (*HV-71A(B)) not full open 13.a) Local indication 9 13. .. RHR SYS HX A(B) OUTLET CNDCT HI
- 14. RHR SYS B(A) CNTMT SP VV MAN 1148(49) 1150(1) 14.a) Override evitch OVERLOAD position on
*PNL-601
- 15. RHR SYS A(B) IN TEST 1152(3) 15.a) Field check
- 16. RHR SYS COMMON VALVE TROUBLE 1370 16.a) Blue thereal overload light extinguished b) Indicating lights extinguished c) Normal alarm Cond
- 1. 2. or 3
(*MOV-050 else, disabled) 1379 17.a) *MOV-050 rey lock
- 17. RHR SYS CROSSTIE VV SW IN OPEN switch in open pos.
POSN.
- 18. LPCI LOW FRESS PERM. SYS A(9) 1433(4) 18.a) Rx Press A(B) on FAMS on *PNL-601 b) *MOV-037A(B) opens if LOCA signal present & no ~ SDC isolation.
/']- - - - - _ _ . _ . _s_ _ - -- - , , , _ . . . _ _ , _ __ _ _ _ _ , _ _
e I t V SYSTEM PROCEDURES A. SYSTEM PRECAtTf!ONS. CAUTIONS. AND/0R LIMITATIONS
- 1. As a part of the BCCS (LPCI Mode). conformance with Technical Specifications is required under all conditions (including Standby). Technical Specifications shall be consulted prior to rendering any part of RHR inoperable.
- a. Purpose Ensure mininua number of systems available for plant operating condition to cope with a design basis accident.
- b. geoanition Consult Tech Specs as part of SECF's
- 2. The Core Spray and RHR loop level system pumps should be kept in service at all times during standby status to maintain RHR discharge tiping full.
- a. Purpose V
- Shorten response time for injection and prevent water hammer from occurring.
- b. Recognition The following annunciators may be illuminated:
- 1) RHR MX shell pressure i
- 2) LINE TILL PUMP A/S DISCM PRESS LOW (ARP 1116)
- 3) LINE FILL PUMP A/S FLOW MICH (ARP 1117)
- 3. In Shutdown Cooling and Fuel Fool Cooling mode. RHR flow shall he i
maintained greater than 2400 sps to prevent the minimum flow valve (s) opening. Failure to do so will result in pumping reactor or fuel pool water to the suppression pool. .
- a. Recoanition
- 1) Shutdown Cooling Suction Valves (*MOV-047.048) open.
Minimus Flow Valve (*MOV-045A(5)) open, and Rx water level decreasing. ,,
- 2) Fuel Fool Supply senual valve (*HV-073) open with Minimus O Flow Valve (*MOV-04SA(3)) open.
k" 4. When Shutdown Cooling. Fuel Fool Cooling or Steam Condensing modes, the CS and RHR loop level pumps e. hall be isoleted from RNR. Failure to do so will result in and/or 3 loop level pumps pumping I ~ - - - . - - - - - - . - . - -. ('^
) suppression pool water into the reactor if RHR pressure becomes less than loop level pump pressure.
- a. Recognition Increasing Rx water level without any makeup water to the RPV.
- 5. Before initiating Stean Condensing. Tuel Fool or Shutdown Coeling modes, the RHR shall be flushed to the suppression pool and/or to Radvaste until water is of sufficient purity for RPV use.
- a. Purpose To avoid introducing tapure water into the RPV and exceeding chemistry Tech Spec requirements.
- b. Recognition RHR HX A(B) OUTLET CNDCT HI annenciator clear and/or local conductivity indication within limits.
- 6. Heat all steam lines and the RHR heat exchanger slowly with stgam traps open when entering the steam Condensing mode.
(o) ..
- a. Purpose Prevent causing thermal stress to RHR component.
- b. Recognition Loud noises in RER components if water not adequately drained when warning up steam lines.
- 7. Exercise care not to inadvertently spray the dryvell, particularly during testing modes. Even with the RHR pumps shut down, system pressure would cause spray activation with incorrect valve alignments.
- a. Purpose To prevent damage to components in the drywell
- b. Reentnitten Valve position on erb 1-601. ,.
- 8. When venting, filling, flushing or draining limit and control spillage since this water is potentially radioactive.
(t, '
- a. Purpose Prevent personnel and equipment contamination
.~ --. __
. l
. 1 , b. Reccanition When operating RHR system. operator should know system is potentially radioactive.
- 9. Maintain suppression pool temperature in compliance wit's Technical Specifications in all operating modes.
- a. Purpose Insure adequate heat sink available for the reactor coo!6at system energy release following a postulated rupture of the system,
- b. Reccanttion
- 1) SUPP POOL TEMP N1 (ARP 0467)
- 2) SUPP POOL TEh? H1 H1 (ARP 0468)
- 3) Temp Ind. on PKL-601
- 10. Manual valves to the fuel pool cooling system shell net be opened
( F-while containment integrity is required. L a. Purpose To prevent comproeising primary containment due to no automatic isolation.
- b. Recognition Field check by E.0. to ensure valves are locked closed.
- 11. When opening reactor Shutdi*m Cooling valves *MOS-047 and *MOV-048, open them one at a time and maintain close surveillance of reactor water level,
- n. Purpose Insure Rx water level does not decrease to Rx trip setroint (e12.5"),
- b. Reconnition
- 1) REACTOR WTR LEV H!/LO (ARP 1246)
- 2) Rx Level Narrow Range indicator on *PNL-603. *
-'s 12. If a RHR pump suppression pool suction valve is opened while that f J loop is in Shutdown Cooling Mode, a rapid Rx water level decreate will occur - until the NS$55 interlock shuts *HOV-047 and 048, at+12.5 inches reactor water level.
- a. Purpose Prevent draining Rx vessel to the suppression pool.
_7-b
. b. Recognition
- 1) REAC VESSEL LO LEVEL TRIP B(A) (ARP 1191. 1207)
- 2) Rx Water Level Narrow Range ind on *PNL-603
- 13. Do not allow steam and water to be simultaneously admitted to the shell side of the RHR heat exchanger. l
- a. Purpose Prevent water ham.er from occurring which could damage components.
- b. Recognition 3
- 1) RHR Heat Exchanger Inlet and/or Outlet valve open with PCV-003 , controlling steam pressure to Hx as indicated on
*PNL-601.
l d
- 2) SP 23.121.01 procedure
- 3) Valve lineup
! ! - 14. If the Steam Condensing mode is inadvertantly isolated, be prepared g to immediately and intermittently actuate a relief valve to maintain reactor pressure nearly constant. i a. Purpose To prevent a pressure transient on Rx plant.
- b. Recognition
- 1) Valve position on *PNL-601
- 2) Rx pressure increa'ses as indicated on PAMS recorders ' A',
'B' on *PNL-601.
- 15. Maintain constant surveillance of reactor water level, heat exchanger water level, and RCIC inlet pressure in the Steam Condensing mode.- _
l l a. Purpose , To maintain parameters within their normal ope' rating ranges.
- b. Recognition .-
s l . .&" f 1) REACTOR UTR LEVEL HI/LO (ARP 1246)- A 5 > ? Rx Wer Level Wid'e Range recorder ' A', 'B' on PAMS on f ' 2)
*PNL;601 v.
~
- a
- 3) -Rest Exchadger Level ind on =PNL-601
- 4) RCIC pump. Suction Pressure ind on *PNL-602 s
m.
p B. NORMAL OPERATION
- 1. The Residual Heat Removal system is in Standby during operating conditions 1, 2, and 3 with two pumps and one heat exchanger per loop and a flow path es previously described. In this standby mode of operation the RER system is lined up in anticipation of Low Pressure Coolant Injection actuation.
- 2. Suppression Pool Cooling mode (Figure 7) of RHR is used during RCIC, HPIC, or safety / relief valve operation, following a LOCA, or during steam condensing mode (heat build-up from RCIC exhaust).
The 'A' RHR loop is the preferred loop for this function since it can more readily be " lined up" to reject water to Radwaste. l Established Service Water flow thru the selected RHR loop Heat Exchanger, close the loop's injection valve and heat exchanger by pass, and open Supp. Pool Cooling and Spray Shutoff valve. Start a l RHR pump in the selected loop and open Supp. Pool Inlet throttle valve. Cooldown rate is established by throttling the heat i exchanger bypass valve. If LPCI initiation occurs, the system will automatically line up for LPCI and inject. i 3. Shutdown Conling mode (Figure 9) of RER is used to remove decay
! heat from the reactor in the shutdown condition with reactor pressure (109 psig. Shutdown Cooling can be put into service when
~
Rx recirc suction pressure decreases (125 psig and no LPIC initiation signal present. The 'B' RHR loop shall normally be used p since the 'A' loop can then be simultaneously used to cool and/or reject water from the Suppression Pool. A Rx Recirculation pump in the opposite loop should be left running for even mixing. Lineup a , suction flow path from the 'B' recirc loop while carefully . l' sonitoring RPV level. Throttle Injection Valve 10% open and start a RHR pump in the selection loop. Note: The Operator must establish > 2400 gpm flow to the RPV within 10 seconds to prevent the Minimum Flow Valve from opening and discharging water form the RPV to the Suppression Pool. Throttle the LPCI injection valve to the desired flow rate. Slowly close the Heat Exchanger Bypass Valve to establish the required cooldown rate. Use Hood Spray valve to decrease Rx pressure and maintain an even RPV cooldown rate. Do not exceed 100*F/hr nor 140*F flange-to-shell f T.
- 4. The Steam Condensing Mode (Figure 3) may be used when the reactor ~
is isolated from the main condenser (MSIV's closed). The objective is to maintain the reactor at or close to operating pressure and ' temperature so if the existing problem or condition is corrected within 8 hours, the reactor can be placed on line with a minimum loss of time required to bring reactor to normal operation temperature. O _ _ ._ __ ._.____ - _.~__ _. .___.~_ _. _..- _ _. _ . _ _-
- a. For the first 30 minutes of operation, condensate from heat exchangers is rejected to the suppression pool to warm up the RHR system, establish heat exchanger water level, and flush )
the heat exchanger shell side.
- b. E en the conductivity is within limits, condensate is sent to the RCIC Pump suction. There are two limits on the condensate to RCIC; 140'F limit to prevent flashing in the suction of the pump, 45 psi to protect low pressure piping.
- c. PCV 003 A(B) keeps steam pressure to Heat Exchanger at 200 psig.
- d. PCV 007 A(B) controls heat - X level and RCIC Pump suction pressure (less than 45 psig). Varying HX level will vary the exposed heat transfer surface and thereby vary Rx pressure
( 9 ft. above tube sheet = 68,000 lbu/hr). l I Caution: Heat exchangers shell side shall not exceed 400'F nor 450 psig at any time during this operational mode.
- e. After 1 1/2 hours of operation, one HX can handle the load and the other HX should be used to cool the suppression pool (heat buildup from RCIC Turbine exhaust).
, g O if a LPCI initiation signal occurs, the RHR systems will revert to the LPCI mode of operation. RCIC auto initiation willoccuratf38"Rxwaterlevel(LPCI-132.5"). The operator shall increase RCIC flow controller to 425 gym in AUTO. Before opening Heat Exchanger Inlet and Outlet valves, secure the Steam Condensing mode of RHR. E en securing from the Steam Condensing mode, ensure RCIC Supply valve (MOV-043A(B)) closed prior to securing steam due to possibility of drawing a vacuum in the heat exchanger. Indicated by no pressure on heat exchanger pressure indicator. i 1
O( (-. 5. The Fuel Fool Cooling Assist mode of RHR is used wh'en the Rr. is shutdown, and the fuel pool cooling system cannot handle the heat load (caused by full core load of fuel in the fuel pool). Indication in the control room to direct the operator to use fuel pool cooling assist are: SPENT YUEL POOL RI TEMP ann. (ARP-0355), and Spent Fuel Fool temperature indicator on MCB*01.
- a. This mode requires manual valve lineup (HV-072 and 073). This lineup renders LPCI loop A inop.
- b. 'A' loop should be used since return line taps off of loop
'A'. Crosstie header, valve MOV-050 closed.
- c. Suction from Fuel Fool Cooling Assist valve (*HV-073) to the RHR Pump and H1 3 RHR PP Disch to Fuel Fool Cooling valve
(*HV-072),
- d. When the RHR pu p is started, operator must have *HV-073 opened to pass 2400 gpm within 10 seconds to prevent draining the f 1 pool to the suppression pool.
- 6. The Test mode (Figure 12) of RHR provides a functional test of the LPCI mode.
- a. The test consists of taking a suction from the suppression
( pool, through the RHR Pumps, and returning to the suppression pool through one of the two 100% capacity lines.
- b. The test can be performed during plant operation and conducted from the control room.
- c. During the test, MOV-042A or B is throttled to a position where 15.400 gpm is attained at a total pump discharge head equivalent to 20 psig reactor backpressure.
- d. If an auto initiation signal is received during the test, the system will reposition valves as necessary to auto revert to the LPCI Mode.
- 7. Reactor Pressure Vessel Draining mode should only be used if RWCU reject is unavailable or inadequate (pump down after refuel).
CAUTION: Fission Product gases may be present and could be re' leased to the Raduaste Bldg. Ventilation System. l
- a. The ' A' loop should be placed in the Shutdown Cooling mode.
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1 0 i
- l. . - . . . . - . - . - , .
O (e g CAUTION: Rither there must be a positive pressure in the RPV, the head removed, or adequate venting established to prevent 1 a negative pressure in the RPV which could damage or ' decalibrate instrumentation.
- b. Open Radwaste Drain Isolation (*MOV-051) and throttle flow with Radweste Drain (*MOV-052) to obtain desired RPV level.
- 8. Suppression Pool Draining can be accomplished by first placing the '
_'A' loop it. Luppression Pool Cooling. l
- a. Drain to Radwaste via the Radwaste Drain Isolation (*MOV-051) and throttle with Radweste Drain (*MOV-052),
- b. A very large drop in Suppression Pool Level may result in a negative pressure in the Suppression Pool. To prevent this, the Suppression Pool should he vented to the RENVS.
C. ABNORMAL OPERATIONS
- 1. Heat Exchanger Trouble The two RHR heat exchangers are supplied with Service Water form separate headers. In the event of loss of one Service Water r -
header, the RHR loop in which the heat exchanger is affected loses its function in Shutdown Cooling, Fuel Pool Cooling Assist Steam
- Condensing and Suppression Pool Cooling.
A heat exchanger tube leak of such severity as to result in off-site releases of radioactivity in excess of limits necessitates shutdown and isolation of that heat exchanger. This does not preclude operation of the LPCI or Dryvell Spray modes, since flow can be bypassed through *MOV-034A(B). Radiation monitors monitor service water flow through the respective heat exchangers whenever service water is passing through their discharge lines.
- a. If a high radiation alarm occurs on the service water outlet, the operator must immediate1v close the HX Discharge valve
(*MOV-033A(B)). This results in a Loss,of Service Water.
- b. If Service Water is lost in a cooling mode of RHR, but down the loop in accordance with the station procedure.
- 2. Leak Detection and Isolation
- s. System leakage can be indicated by any of the following listed parameters. The leak should be located by systematically l ..
_2, 1 .; , c_ .. .;__._ . . _ . - _ . _ . . . _ _. . . . . . . . - - ,
. 1 1
(' observing parameters, moting any abnormalities' .
- 1) Beat exchangers service water side temperature in consistencias.
- 2) Abnormal RER system flow for mode of operation.
- 3) Abnormal RHR system pressures for mode of operation.
- 4) Reactor water level inconsistencies for mode of operation.
- 5) Sump high level alarm.
- 6) Reactor building flooding alarm,
- b. Iselate the leakage by shutting down the affected loop.
- c. Systematically shut valves to isolate areas of the system found above to be possible sources of leakage.
- 3. Operation of the 'A' RER System when there has been a single failure at the Remote Shutdown Panel of Bus 112
~
- a. This procedure addresses a condition whereby the Control Room i;
~
has become uninhabitable and a single failure of Bus 102 at I the Remote Shutdown panel has occured.
- b. The kPV will be placed in alternate shutdown cooling by taking a suction from the suppression pool with the ' A' RER pump, discharging through the RHR Heat Exchanger, LPCI Injection Va*ve and returning the water to the Suppression pool via the safety relief valves.
- 4. Steam Supply Isolation (Steam Condensing)
- a. Maintain Rx water level with RCIC.
- b. Open SRV's operate HPCI as necessary to control RPV pressure,
- c. Maintain heat exchanger levels to the extent possible. Do not allow sudden level changers.
- d. If possible, reset steam isolation.
! e. If steam supply cannot be reestablished, shutdown the Steam Condensing mode. l L
P .___. . . . M O kc 5. Loss of Shutdown Coolina (SP29.020.01) l
- a. Indicated by any of the following:
- 1) RHR SYS I DISwtl HDP. or SHUTDOWN SUCT HI PRESS
- 2) RHR PUMP TRIP I I
- 3) RHR HX DISCH CW HX A or B HI TEMP
- 4) RX Cooldown rate decreases
- 5) RHR loop flow indicator drops to zero.
- b. The operator should immediately attempt to restore the af.fected shutdown cooling loop to operation.
D. EMERGENCY OPERATION Upon receipt of a LOCA signal (High DW Pressure and/or low Rx Water Level). RHR will invert to the LPCI mode of operation. For this discussion, we are assuming the 'B' RHR loop is in Shutdown Cooling.
- 1. The Shutdown Cooling mode of RHR will respond to a LOCA durinir shutdown cooling operations as follows: REACTOR WATER LEVEL -
O. I r
-132.5"
- a. Assume the following RHR system lineup:
- 1) RHR 'B' loop in shutdown cooling with RHR Pumps 'B' and
'D' operating.
- 2) Suppression pool suction valves closed (MOV-031 B/D)
- 3) Shutdown Cooling inlet valves open (MOV-047, 048)
- 4) Shutdown Cooling pump suction valves open (MOV-032. B/D)
I 5) Heat Exchanger inlet & outlet valves open (MOV-033B, 034B)
- 6) Heat Exchanger Bypass valve throttled (MOV-034B)
I
- 7) Injection and Injection Isolation valves open (MOV-036B, 037B)
- 8) Loop 'A' in Standby condition J.
H y i
n -, a a 9 f' b. With Rx Recire auction pressure /.125 psig and' Rx water level normal (+36"), assume the Rx veter level begins to decrease ' due to a primary leak.
- c. When Rx water level decreases to +12'.5", the following vill
. occur:
- 1) Shutdown Cooling Suction valves (MOV-047, 048) Head Spray valves (MOV-053, 054), and LPCI inboard injection valves (MOV-037 A/B) close.
- 2) RHR pumps B. D will trip when MOV-047 or MOV-048 comes from full open anticipating a loss of suction path,
- d. M en Rx level decreases to -132.5", the LPCI initiation logic is, actuated,
- e. This will auto start RHR Pumps A and C, but not 3 and D because no suction path is available (MOV-031B and D and MOV-047, 048 not full open).
- f. Suppression Pool Suction valves (MOV-0313/D) do not auto open on a LPCI Initiation signal.
Heat Exchanger Bypass valve (MOV-034B) will auto open and be
] -
~
g. interlocked open for 3 minutes due to the LPCI initiation signal.
- h. Injection valve (MOV-036A(B)) will receive auto open signal when both the LPCI initiation signal and reactor pressure signal are present which will result in interlocking the valve open for 5 minutes.
- i. RHR RX service water outlet isolation valve (1P41-MOV-034A.B) will isolate.
- j. Injection isolation valves (MOV-037A.B) will not auto open due to seal in closed signal,
- k. RHR Pumps A and C will be running with flow through the minimum flow valve (MOV-045A) since no injection flow path is l
j available. l l In order to complete the LPCI injection flow path for both RHR loops. I
- 1. Suppression Pool Suetion valves (MOV-031B.D) must be manually opened. E en they are full open RHR pumps B and D will auto start and provide flow through the Minimum flow valve ,
(MOV-0455). O l
(3
- m. In order to open the injection valves (MOV-037A.B). the los reactor level (12.5") shutdown cooling mode isolation seal in must be reset by depressing both isolation reset switches on Panel 601. The isolation signal no longer exists because the shutdown cooling inlet valves MOV247. 048) have been closed,
- n. When these pushbuttons have been depressed, the isolation signal is removed and MOV-037A and B will auto open (Rx pressure isf465 psig) to commence injection into the vessel in the LPCI mode.
- 2. RHRsystemresponsetoaLOCAduringshutdowncoolkoperation DRWELL PRESSURE 1.69 psig,
- s. Assume RHR Loop B in Shutdown Cooling as per previous example,
- b. Rx Rectre Suction pressure ( 125 psig and reactor level is normal (+36").
- c. Assume dryvell pressure increases to 1.69 psig
- 1) RHR shutdown cooling loop 'B' vill remain in shutdown cooling status, r 2) Bus loading program vill initiate the RHR pumps in
( sequence.
'A', 'B', 'C' RHR pumps - 2 seconds.
'D' RHR pump - 7 seconds.
- 3) LPCI injection valve MOV-036 A/B and 037 A/B will receive an open signal on 1.69 dryvell pressure in conjunction with reactor pressuref,465 psig. (MOV-036 A/B han a 5 minute time delay sealed in).
- 4) RHR HX bypass valve (MOV-034 A/B) vill receive an open seal in signal on 1.69 psig dryvell pressure (sealed in for 3 minutes).
- 5) RHR HX service water outlet valve (IP41*MOV-034A/B) vill isolate.
- 6) RHR Loop 'A' will be in the LPCI Mode and RHR Loop 'B' vill remain in shutdown cooling modes.
t I V l l l l . _ _ . _.
- h. . . . . _ . _ _ . . _ . _ _ .. .. - . . ..
l J 1 VI SYSTEM INTERRELATIONS A. POWER SUPPLIES
- 1. Pumps
\
- a. 4160V. Bus 101 'A' RHR pump
- b. 4160V. Bus 102 'B' RHR pump
- c. 4160V. Bus 103 'C' + 'D' RER pump
- 2. Motor Operated Valves
- a. Most RHR valves supplied from its appropriate Divisional Motor Control Center except for some RER valves necessary to operate in the LPCI mode. The following valves are powered from the LPCI M-G sets discussed under LPCI student handouts.
I
- 1) LPCI INJECTION TO RX VESSEL *MOV-036A(B)
- 2) OUTBOARD LPCI ISOLATION TO RX VESSEL *MOV-037A(B)
- 3) RHR PUMPS MIN FLOW *MOV-045A(B)
I B. LOGIC POWER
- 1. 125V DC Div I ' A' Loop Logic
- 2. 125V DC Div II 'B' Loop Logic j 3. 125V DC Div III 'C' + 'D' pump breaker control i
- C. ADS RHR system sends a pump discharge pressure signal permissive to ADS at 119 psig to ensure ADS does not activate until adequate low pressure ECCS pumps l
are available for injection. D. RBCLCW Supplied to RHR pump seal coolers to keep sechanical seals cool. E. INSTRUMENT AIR Provided to the Pressure Control Valves for use in the Steam Condensing mode. , , F. SERVICE WATE% Used as the heat transfer medium for the RHR heat exchangers and also f) t supplies ultimate cooling in the unlikely event of a sustained Loss of All A.C. When all forms of decay heat removal has been exhausted. I i 1
~~ .. . ._
J g( . I' C. REACTOR RECIRCULATION Rx Recire Discharge valves receives a close signal from LPCI initiation logic. (Will close when recirr pressure decreases (310 psig and accident signal actuated).
; B. RADWASTE RHR system has flushing connections with Radvaste and a path from the 'A' RHR loop to drain to Radvaste, I. NSSSS NS isolations used to close RNR valves previously mentioned under Interlocks section.
J. RD!OTE SHUTDOWN PANEL Contains controls to operated the 'B' RHR loop in the event of the Main Control Room becoming uninhabitable. VII TECHNICAL SPECIFICATIONS _A . ECCS INSTRUMENTATION s b 3.3.3 The emergency core cooling system (ECCS) instrumentation channels shown in table 3.3.3-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint, column of Table 3.3.3-2 and with DiERGENCY CORE COOLING SYSTEM RESPONSE TIME as shewn in Table 3.3.3-3. APPLICABILITY: As shown in Table 3.3.3-1. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM Reactor Vessel Water Level - Low Low Low, Level 1 2(b) 1, 2, 3, 4 , 5 30 a. 2(b) 1,.2, 3 30
- b. Drywell Pressure - High 2 1,2,3 31
- c. Reactor Steam Dome Pressure - Loir (Permissive) 4,5 32
- d. LPCI Pump Discharge Flow - Low (Minimum Flow) 1/ pump 1, 2, 3, 4 , 5 33 f
- e. Manual Initiation 1/subsyster. . .
1, 2, 3, 4 , 5 34 ,w l
. .-. ~. _,..., _ ..,_ .~. _ . _ . . _ . . _ . . _ . . . _ . . . _ __
- 1. - __
~~.-.-n. - . ~ . . . . . . ' '~~
w - ( B. RESIDUAL REAT RDt0 VAL (SHUTDOWN) 3.4.9.1 Twof shutdown cooling mode loops (subsystems) of the residual heat removal (RHR) system shall be OPERABLE and, unless at least one recirculation pump is in operation, at leasg one shutdown cooling mode loop (subsystem) shall be in operation if with each loop (subsystem) consisting of at least:
- a. One OPERABLE RHR pump, and I
- b. One OPERABLE RHR heat exchanger.
APPLICABILITY: OPERATIONAL CONDITION 3, with reactor vessel pressure j less than the RHR cut-in permissive setpoint.fff l ACTION:
- a. With less than the above required RHR shutdown cooling mode loops (subsystems) OPERABLE, immediately initiate corrective action to return the required loops (subsystems) to OPEP OLE status as soon as possible. Within I hour and at least once per 24 hour thereafter, demonstrate the operability of at least one alternative method capable of decay heat removal for each inoperable RHR shutdown cooling mode loop,{ subsystem).
- Be in at least COLD SH11TDOWN within 24 hours.
7
- b. With no RHR shutdown cooling mode loop (subsystem) in operation, immediately initiate corrective action to return at least one loop (subsystem) to operation as soon as possible.
Within I hour establish reactor coolant circulation by an alternate method and monitor reactor coolant temperature and pressure at least once per hour. D. ECCS - OPERATING 3.5.1 The emergency core cooling systems shall be OPERABLE with:
- a. The low pressure coolant injection (LPCI) system of the residusi heat removal system consisting of two subsystems with ,
each subsystem comprised of:
.. Two OPERABLE RHR pumps, and An OPERABLE flow path capable of taking suction from the i
l
- 2. l suppression pool and transferring the hot water to the reactor vessel.
O, _ 30 _
r ^ i
@ OPERATIONAL CONDITIONING 1. 2 .
. f. and 3 .
. II.
APPLICABILITY:
*The HPCI system is not required to be OPERABLE when reactor steam dome
[ pressure is 3.150 psig.
**The ADS is not required to be OPERABLE when reactor steam dome pressure E
- is less than or equal to 113 psig. E
#See Special Test Exception 3.10.6.
##0ne LPCI subsystem of the RHR system may be inoperable in that it is t_ aligned in the shutdown cooling mode when reactor vessel pressure is less I than the RHR cut-in permissive setpoint.
E. ECCS - SHUTD0kT 3.5.2 At least two of the following four subsystems shall be OPERABLE:
- a. Two core spray subsystems (CSS) with a subsystem comprised of:
E 1. One OPERABLE CSS pump. and 6 An OPERABLE flow path capable of taking suction from at 2. least one of the following water sources and transferring [ the water through the spray sparger to the reactor , ( , vessel: a) From the suppression pool, or b) When the suppression pool water level is less than f the limit or is drained, from the condensate storage
- tank containing at least 100.000 available gallons of
, water, equivalent to a level of 9 feet. ?
- b. Two low prersure coolant injection (LPCI) subsystems with a
_ subsystem comprised oft
- 1. At least one OPERABLE LPCI pump. and
=
- 2. An OPERABLE flow path capable of taking suction from the suppression pool and transferring the water to the
" reactor vessel. APPLICABILI"T: OPERATIONAL CONDITION 4 and 5 . r 6
*The ECCS is not required to be OPERABLE provided that the reactor vessel head is removed, the cavity is flooded, the spent fuel pool gates are removed, and water
- level is maintained within the limits of Specification 3.9.8 and 3.9.9.
1 a
~
b
------sem . -
? , - . . - . O - ACTION:
- a. With both of the above required subsystems inoperable, suspend CORE ALTERATIONS and all operations with a potential for draining the i reactor vessel. Restore at least one subsystem to OPERABLE status within 4 hours establish SECONDARY CONTAINMENT INTEGRITY within the next 8 hours.
F. SUPPRESSION CHAMBER SPRAY 3.6.2.2 The suppression chamber spray mode of the residual heat removal (RHR) system shall be OPERABLE with two independent loops, each loop consisting of:
- a. One OPERABLE RHR pump, and
- b. An OPERABLE flow path capable of recirculating water from the suppressior chamber through an RHR heat exchanger and the suppression chamber spray spargers.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. G. SUPPRESSION POOL COOLING 3.6.2.3 The suppression pool cooling mode of the residual heat removal (~ (RHR) system shall be OPERABLE with two independent loops, each loop consisting of:
- a. One OPERABLE RHR pump, and
- b. An OPERABLE flow path capable of recirculating water from the suppressior chamber through an RHR heat exchanger.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. VIII REFERENCES A. System Description 1020.121 B. FSAR 6.3 Vol 8 C. Technical Specifications - Proof & Revi-v Rev. 2 D. Drawings
- 1. MFSK's - 20A, 205 - Rev. 7 e._ 1 1
i 1
, ,,_x - . . . - - . , , - , , - ,
.m -. .,-.- - . . , . . _ , , . , _ -
( ' ._ - ____ . _ _ . _ -_ _- . .
~ - - - - . - - . . . . _ _ _ _ . _ __
I
\
l
)
( 2. ESK's - 5E1101 thru 5E1104 1.' 6E1101 thru 6E1148 11E1101 thru 11E1103
- 3. GE Prints 791E418TF Sh. 1-18 E. Operating Procedures
- 1. 23.121.01 Rev. 6
- 2. 24.121.01 Rev. 4
- 3. 24.121.02 Rev. 3
- 4. 24.121.03 Rev. 4
- 5. 24.121.04 Rev. 9
- 6. 29.020.01 Rev. 2
- 7. ARP's ARP $20 RHR HX A/B DISCH COOL WIR TEMP HI Rev. 2 ARP 1121 RHR A/B INLET WIR TEMP HI Rev. 2 ARP 1122 RHR SYS A DISCH HDR/SDC SUCT PRESS HI Rev. 2 ARP 1123 RHR SYS B DISCH HDR/SDC SUCT PRESS HI Rev. 3 ARP 1126 RX SYS A PRESS LO Rev. 4 ARP 1127 RX SYS B PRESS LO Rev. 4 ARP 1128 DRYWELL SYS A PRESS HI Rev. 3 ARP 1129 DRYWELL SYS B PRESS HI Rev. 3 ARP 1130 RHR SYS A RX LO LEVEL INIT Rev. 2 i ARP 1131 RHR SYS B RX LO LEVEL INIT Rev. 2 ARP 1132 RHR SYS A MAN INIT SW ARMED Rev. 1 ARP 1133 RHR SYS B MAN INIT SW ARMED Rev. 1 l
ARP 1134 RHR PUMP A TRIP Rev. 2 ARP 1135 RHR PUMP B TRIPPED Rev. 2 l l i
. . _ - . . _ _ . _ __ _ _ .._ _ _ _ __ _ i._ .I _ _ _ _ . . . .[ .. l l l J . (- ARP 1136 RHR PUMP C TRIPPED Rev. 2 ARP 1137 RHR PUMP D TRIPPED Rev. 2 ARP 1138 RHR PUMP A MOTOR OVLD Rev. 2 l ARP 1139 RHR PUMP B MOTOR OVLD Rev. 2 ARP 1140 RHR PUMP C MOTOR OVLD , Rev. 2 ARP 1141 RHR PUMP D MOTOR OVLD Rev. 2 ARP 1142 RHR SYS A LOGIC POWER FAIL Rev. 2 ARP 1143 RER SYS B LOGIC POWER PAIL Rev. 2 ARP 1144 RX SYS A LEVEL LOW Rev. 3 ARP 1145 RX SYS B LEVEL LOW Rev. 3 . ARP 1146 RHR SYS A DEGRADED Rev. 2 ARP 1147 RHR SYS A INOP Rev. 3 ARP 1148 RHR HX B OUTLET CNDCT HI Rev. 2 ARP 1149 RHR HX A OUTLET CNDCT HI Rev. 2-ARP 1150 RHR SYS B CNTMT SP VV MAN OVERRIDE Rev. 2 ARP 1151 RHR SYS B CNTMT SP VV MAN OVERRIDE Rev. 2 ARP 1152 RHR SYS A IN TEST Rev. 1 , ARP 1153 RHR SYS B IN TEST Rev. 1 ARP 1154 RHR SYS B DEGRADED Rev. 2
- ARP 1155 RHR SYS B INOP Rev. 2 ARP 1370 RHR SYSTDi COMMON VALVE TROUBLE Rev. 1 ARP 1379 RHR SYS CROSSTIE VV SW IN OPEN POSN Rev. 1 ARP 1433 LPCI LOW PRESS PERMISSIVE SYS A Rev. 9 ARP 1434 LPCI LOW PRESS PERMISSIVE SYS B Rev. $ ..
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o-- _ V l I Q. l' W APPENDIX A A. DATA SHEET
- 1. RHR Pump
- a. 10,000 spa 0 0 psig
- b. 2 pumps - 15.400 gym e 20 psi Rx press,
- c. Shutoff head - 238 psig ,
- 2. RHR Pump Motor
- s. A - Bus 101 ,
- b. B - Bus 102
- c. C & D - Bus 103
- 3. LPCI Initiation Logic
- a. Reactor Low Level -132.5" 1
w b. High Drywell Pressure +1.69 psig 1
- 4. Minimum Flow Valves
- a. Opens: 12200 gpm with a pump breaker closed in its loop and a 10 sec. T.D.
- b. Close: }2400spm
- 5. Injection Valve Permissive: 4465 psig
- 6. Permissive to ADS: 119 psig RHR discharge pressure
- 7. RHR Heat Exchangers
- a. tube bundle 70/30 CuNi
- b. 2 pass tube side, single pass shell side
- c. 9 f t above tube sheet = 68,000 lbs/hr.
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l E e A l 4 i i l SERVICE WATER STUDENT HANDOUT i
.. FOR SHIFT (SRO) ADVISOR I
- /
! TRAINING PROGRAM 1
1 Date: f[fe Prepared by: Training Ins.tructor/D e Approved by: * # Revision:f . n.+.t - s ,r y v '.c.ascicat. r
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LESSON PLAN: SERVICE WATER
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3.0 MATERIALS REQUIRED FOR STUDENTS: 3.1 Service Water System Lesson Plan l 1 3.2 Service Water Operational Procedure 23.122.01 l 3.3 Technical Specifications 3/4.7.1 4.0 MATERIALS REQUIRED FOR INSTRUCTOR: 4.1 Related Graphics 5.0 REFERENCE MATERIALS: 5.1 Service Water System Description 1020.122 5.2 Service Water System Procedure 5.3 FSAR Sections 2.4.12, 7.3 - 7.3.1.1, 7.3.2.8 and 9.2.1
, 5.4 Technical Specifications 3/4.7.1 5.5 Flow Diagrams FM-47A to 7N b 5.6 Logic Diagrans LSK-9-7A to 7N 5.7 . Electrical Elementary Diagram ESK-5P4101 6.0 SCOPE OF LECTURE:
I To teach the student the piping arrangement, major components, instrumentation system operation, and system interrelationships of the Service Water System. 7.0 STUDENT SYNOPSIS: At the end of the lecture the student should: i 7.1 State the purpose of the Reactor Building Service Water System. 7.2 State the purpose of the Turbine Building Service Water System. 7.3. Given a diagram of the system or control panel display, trace out the j flowpath for: a) Normal Operation , b) Loss of Offsite Power c) LOCA D I - (
? _ u.. . . _ . _ _
.( ) 7.4 Given a diagram of the Service Water system and a control panel
( display, identify the following Sib / sisnri AtK Ankurst a) Loss of offsite power b) LOCA 4 7.5 State the condition that will cause the RBSWS to split. 7.6 List the heat loads supplied by the RBSUS. 7.7 List the heat loads supplied by the TBSWS. 8.0 LESSON OUTLINE: 8.1 Theory
8.1.1 Purpose
.1 Transfer heat from various plant components to the Long
, Island Sound.
.2 The Reactor Building Service Water system provides a reliable, unexhaustable source of emergency cooling water for the reactor core and the spent fuel in the spent fuel k pool.
.3 The RBSW system transfers heat from the reactor building loads during normal operations and also provides heat removal capacity from safety related loads during a LOCA.
.4 The TBSW system transfers heat from BOP plant components.
8.1.2 Design Bases:
.1 Reactor Building service water is designed to supply adequate cooling during a LOCA with L.I. Sound at its maximum Tech. Spec. limit & any single failure.
.2 Reactor Building service water is nuclear safety related and must be:
- a. seismic Cat I
- b. protected from Tornado Winds & Missiles
- c. protected from floods
- d. seet single failure criteria
( r'% s-]
, 8.2 Physical Description
-/
8.2.1 General 8.2.1.1 Reactor Building Service Water FIG. 1,2 l
.1 Consists of:
- a. four motor driven, vertical, vet pit, centrifugal pumps
- b. four motor operated strainers
- c. necessary pipes, valves and instrumentation i
- 1) piping is copper nickel:
compatability with sea water
- 2) Valves are carbon steel lined with rubber for same reason.
- 3) all buried piping is encased in
- concrete
, 4) screenwell components have cathodic _ protection
.2 RE service water pumps
- a. each in a separate bay in the intake structure
- b. 8,600 gpm 9 65 PSIG
- c. suction is in the forebay after the traveling screens
- d. capacity: 50% during DBA & for normal ops.
.3 Flow Path:
- a. through motor operated discharge valve (MOV-31A-D) i
- b. through automatic self cleaning rotary type strainers
- c. through a check valve
- d. to a common header -
i V _4_
1
,/~'} e. discharge valve has a 4" normally open bypass
{ ,,, valve: Provides for min flow & system fill
- f. the header can be divided by two series motor operated valves (MOV-32A & B) i
, 1. 32A supplied by DIV I MCC
- 2. 32B supplied by DIV Il MCC
- 3) normally open
- 4) auto close during LOCA
- 5) pumps A&C supply header A
- 6) pumps B&D supply header B
- g. One 20" supply line comes off each header to supply one set of the redundant safety related loads and either line can supp1v:
- 1) each diesel l
- 2) main chill water condenser
- 3) ultimate cooling connection
- 4) fuel pool emergency makeup
- h. One 24" tie line comes off the B header and goes to the TB service water through two series motor operated valves.
- 1) normally closed i
- 2) auto close during a LOCA
, 3) has a locked closed 16" manual bypass valve around the MOV's.
- i. loads:
- 1) RBCLCW heat exchangers
- 2) Drywell Booster heat exchangers
- 3) RBSYS & CRAC chill water condensers
- 4) main chill water condensers .
( ___r- -
l 5) emergency diesel jacket cooiers
- 6) RNR heat exchangers
- 7) ultimate cooling supply
- 8) spent fuel pool emergency supply
- 9) aux boiler blevdevn tank cooling
- j. The outlets of loads 1 through 6 above, go to the discharge tunnel and return to the sound.
Standpipes on discharge lines ensure flow path,
- k. If the emergency cooling supplies are used the water would be contaminated and retained in the reactor building for processing.
- 1. Blowdown tank will have phosphates and therefore drains to the sanitation system.
- m. The heat exchangers and diesel coolers have relief valve protection. Thermal relief in event service water is isolated to a cooler that is still rejecting heat.
- n. Samples for radiation monitors are taken on the
(~-
~ outlet of each RHR heat exchanger to detect tube leak:.
8.2.1.2 Turbine Buf1 ding Service Water FIC.3
.1 Consists of:
- a. three motor driven, vertical, vet pit centrifugal pumps
- b. two motor operated strainers
- c. necessary piping valves and instrumentation
- 1) piping copper nickel l
- 2) buried pipe is concrete encased
.2 Pumps:
l
- a. separate suction on cire water cubicles l l 1
- b. 8000 gpm at approximately 50 PSIG.
- 1
[ k
< ]
v
O .w
- ~ se-~ -
- w. .ww. _.
, c. capacity: 50% at rated operating conditions 100% when shutdown or with low inlet 4
temperature
.3 Flow Path
- a. expansion joint
- b. check valve
- c. motor operated discharge valve (MOV-112A-C)
- d. common header
- e. two parallel strainers with individual motor operated inlet isolation valves (MOV-113A & B)
- f. to the supply header
- g. pump discharge valve has a 6" normally open
- bypass valve
- h. loads
- 1) TBCLCW heat exchangers
~
i
; 2) Cir water pump bearing cooling
- 3) screen wash pumps motor oil coolers
- 4) vacuum priming pump seal water coolers
- 5) supply to fish retention pool
- 6) supply to vacuum priming drain tank
- i. the outlet from loads 1 and 4 go to the
. discharge tunnel
- j. outlet from 2 and 3 go to screenwell while 5 goes to the intake canal
- k. outlet from 6 goes to the salt water drain tank
! before returning to the discharge tunnel 1.. TBCLCW heat exchangers have 100 psi relief valves for overpressure protection when their ', outlet is shut i . k
8.2.1.3 Both systems receive hypochlorite injections at
- s. timed intervals to prevent fouling of heat exchanger tubes 8.2.2 Major Components
.1 RB service water pumps
- a. vertically mounted, wet pit, dual stage centrifugal type pumps
- b. 8600 gpm
- c. shutoff head 252 ft. (96 psi)
- d. minimum required flow 800 gpm e.- self-lubricating
- f. has vibration monitor
.2 RB service water pump notor
- a. 450 horsepower, full load current 58.1 amps
- b. powered from 4160V emergency buses
~) _
- 1) A - Bus 101 (DIV I) qs_/
- 2) B - Bus 102 (DIV II)
- 3) C&D - Bus 103 (DIV III)
- c. control switches on RSP and in main control room
- d. has a non-reversing ratchet
- e. has a 200 watt space heater
.3 Strainers:
- a. prevent fouling of Ex's l b. self-cleaning: Requires 450 gpm during backwash
- c. motors powered from 480V Normal MCC's
- d. flashing light on MCB-91 indicates 4 PSID
- e. alarm at 8 PSID -
l
- O g e w ,- v -
.4 Turbine Building service water pumps ,
- s. single stage, vertically mounted wet pit centrifugal 1 type pumps
- b. 8,000 gpm
- c. shutoff head approximate 1v 50 PSIG
- d. air release valve, vent air from pump and auto close when liquid pumped. Also prevents vacuum forming in the pump discharge when the pump is stopped
.5 TB service water pump motor
- a. 350 HP b ." power supp1v: 41607 normal bus
- 1) A-Bus 11
- 2) B&C-Bus 12
.6 Strainers
- a. automatic backwashing, 100% flow capacity strainers
~
- b. requires 420 gpm during backwash
- c. clean dp 2.2 psig
- d. power supply: 480 Volt Normal MCC's 8.3 PRINCIPALS OF OPERATION 8.3.1 System operating modes 8.3.1.1 Normal operation
.1 Two RBSW pumps operating to supply:
- a. one Drywell Booster heat exchanger
- b. one RBCLCW HX
- c. one RBSYS & CRAC chill water condensers
- d. Main chill water condensers (3
Y .)
~
J
.2 Two TBSW pumps operating to supply:. j
- a. cne TBCLCW heat exchanEer
- b. Cire water bearing cooling
- c. Vacuum Priming seal water EX
.3 All other loads can be valved in as necessary 8.3.1.2 Abnormal operation: Loss of off site power
.1 All SW pumps trip
.2 EDC start and close in on emergency buses
.3 When diesels are up to speed, pumps P-003A, B, C and D start
.4 RBSW will supply:
- a. F.DG coolers
- b. Beth RBCLCW HX
- c. One Drvvell Booster HX
'N d. RBSYS & CRAC chill water condensers
.5 The following will be available to the operator:
- a. RHR HX
- b. Spent Fuel Pool Emergency Supply
- c. Ultimate cooling supply 8.3.1.3 Accident Condition: Loss of Coolant
.1 The A, B, C & D RBSW Pumps receive start signals from the emergency Bus Program (12 see From time bus is energized)
.2 RBSW will supply water to:
- a. Both RBCLCW HX i
l b. All Four RBSVS and CRAC chill water
- condensers l ,m c. EDG t \
\__ ! ,
lt
- 1 .,
6
-- -- . . . - ~ . . . . , .
,( .3 RBSW will be available to the following:
- a. RHR MX
- b. Ultimate Cooling
- c. Spent Fuel Fool 8.3.2 Instrumentation and Controls FIC 4,5 & 6 8.3.2.1 Control Room
.1 Major instrumentation
- a. RB Service Water (on MCB)
- 1. Motor Current
- 2. Header Pressure
- 3. RHR RX Flow
- 4. RBCLCW MX Flov
- 5. Strainer dp
) - 6. RBCLCW Outlet Valve Position
- 7. RHR Hx Outlet Valve Position
- b. TB Service Water (on MXP)
- 1. Motor Current
- 2. Header Pressure
.2 Controls
- a. Individual Pump Control switches
- 1. spring return to auto or neutral pos.
- 2. targets are red after start, green after stop
- 3. PTL/STOP/AUT0/ START positions (Note RBSW-C has neutral vice auto) .
O
l
~
- 4. RBSW on MCB; TBSW on MXP
((s . 5. White liett near -en*rol' switch goes right when motor lockout r occurs. (Note: sust reset at switchgear)
- b. TBSW standby pump select switch
- 1. Maintain contact
- 2. OFF/A/B/C
' 3. on MXP
- c. The following valves have control switches of various types for position
. control. (open or close)
- 1. on the MCB MOV 31 A - D RBSW Pump Discharge MOV 32 A - B RBSW header isolation
~
MOV 33 A - D Ultimate i k Cooling Supply isolation MOV 34 A - B RHR HX outlet MOV 35 A --B RB - I s ola . ...i MOV 36 A - C Main Chill Water
' MOV 37 A - B RBCLCW HX OUTLET MOV 39 A - B Ultimate Cooling Line Drain MOV 129 A - B Drywell
- Booster HX outlet ,
1 A0V 16 A - C EDG Cooler Outlet s b i
._m .
l _ _ . - _ _ . . _ . ~ _ . _ _ , . . , . _ _ . . _ _ _ l l
- 2. on the MXP MOV 42 A - B Spent Fuel Fool Emerg.
Supply Isol. 1 MOV 43 Spent Fuel Fool Emerg. Supply Drain MOV 111 A - B TBCLCW HX outlet MOV 112 A - C TBSW Strainer inlet
- 3. MOV 33 and 42 valves have keylock control switches
- 4. MOV 35 valves also have
- a. Keylock switch and an override switch to allow the operator to open these valves during a LOCA
- 5. MOV 34 and 37 valves also have
(')) (,
- a. Keylock switch (Normal / Throttle) and a pushbutton (intermediate) to throttle the valves to 50%
- b. An override switch to allow the operator to open these for post LOCA cooling 8.3.2.2 Remote Shutdown Panel (RSP)
.1 Control switches for
- a. P41-P-003 B&D: RBSW Pumps B&D
- b. MOV - 31 B&D: B&D RBSW Pump Discharge Valves
- c. MOV - 32B: Service Water header isolation
- d. HOV - 34B: 'B' RHR HX Discharge -
- e. MOV - 35B: 'B' RB-TB SW Cross tie y j f. MOV - 37B: 'B' R3CLCW HX Discharge
.2 Transfer switches: (Norm /Emerg Positions)
I
- s. a. one for the B RBSW pump & discharge valve
- b. one for the D RBSW pump & discharge valve
- c. one for MOVs 32B, 35B, 37B
- d. one for MOV 34B
.3 Indication: RBSW header B Pressure 8.3.2.3. Local Controls
.1 RB Service Water pumps have target type control switches at their respective switchgear
.2 All strainers have control switches in the screen well (Hand /Off/ Auto) 8.3.3 Interlocks
.1 RBSW Pumps
- a. Auto Trip
- 1. sustained bus undervoltage
- 2. Motor Fault (86 Lockout)
- b. Auto Start
- 1. CS in Auto
- 2. Either
- a. LOCA Signal Present and Bus Powered and up to Voltage for 12 ser
- b. No LOCA Present and Diesel 400 RPM for 7 see NOTE: either of the above vill supply start signals to the SW pumps but pump discharge valve must be closed in order for breaker to be closed.
- c. RSP Transfer switch in emergenev overrides CR
- Control Switch and Auto Start signals for B & D Pumps 1
[N f I l LJ l 1
()
*^-
- d. Pump discharge valve
- 1. Opens 20 see after Breaker closes k
- 2. Shuts when Breaker opens
.2 RHR & RBCLCW MX Outlet Valves 4
- a. Go to 50% Position if key lock switch is in Normal and intermediate Pushbutton Pressed,
- b. Can be throttled if its keylock switch is in throttle and the open or close pushbutton is pressed
- (releasing push button stops the valve)
.3 LOCA Interlocks a .' LOCA Signal Cause
- 1. MOV 34 (A,B) Close RHR MX OUT
- 2. MOV 37 (A,B) Open RBCLCW HX OUT
- 3. MOV 32 (A.B) Close RBSW HEADER ISO.
- 4. MOV 35 (A B) Close RB-TB XCON
- 5. MOV 36 (A,B,C) Close MAIN CHILL WATER SUPPLY
- 6. MOV 129 (A.B) Close DRYWELL BOOSTER HX
- b. Override switches allow MOV 34, 35 & 37 to be repositioned
- c. Depressing their override pushbutton allows the RHR i
Hx outlet MOV's 34 and the RBCLCW Hx outlet MOV's 37 l to be repositioned even if a LOCA signal is present. 1 MOV's 35 cross tie valve has a keylock override switch. I
- d. White light above override pushbutton indicates LOCA signal has been overridden.
- e. Other valves are interlocked closed (32,35,36 & 129) 4 RBCLCV head tank levels are lov low *
- a. RBCLCW Mx service water outlet MOV's 39 open 1
i .5 Loss of Power Interlocks ! a. Loss of Power Causes same valve lineup as
+ _ + - - . . . - _
- . . - - . - - . . . . - . - , - - , ,_. . -.-r~ . ._
., . - , , , . . . - . .,,.my.-
\
l l l l l LOCA except for MOV 129 (A&B)
- b. If Diesel supplies the bus, MOV 35 & 36 are interlocked closed
- c. Once condition clears & the valves reach their intended position valves can be repositioned (except for 34 & 37 valves)
- d. After loss of power clears, the RHR Hx outlet valves and the RBCLCW Hx outlet valves override pushbutton must be depressed in order to be able to reposition the valves.
.6 DC cooling supply valves open when diesel starts; close when diesel shuts down
.7 Energency open on MOV - 33 (A-D) and both emergency open and emergency close on MOV-42 (A & B) override the motor overloads
.8 TB SW Punps
- a. Trip D
g
- 1. Bus U.V. for 2 sec p_}
- 2. Motor Fault (86 lockout)
- b. Auto Start
- 1. No Pump Running
- 2. Selected for Standby
- 3. CS in Auto after Stop & Disch Valve Shut
- 4. Motor Fault on either of other pumps
- c. Discharge Valve
- 1. Opens 2 min after pump starts
- 2. Shuts when pump stops
.9 TBCLCW Hx Dutlet MOV 120 i
- n. Opens with 2 or 3 pumps running .
- b. Closes with 1 or 0 pumps running O~
1 1 l
a d (q) 8.3.4 SYSTEM INTERFELATIONS 8.3.4.1 STARTUP
.1 The RB service water system is nuclear safety-related and requires no support, other than p>wer avetlable to the emergency buses, for start-up and operation. The TB service water system is not safety-related and requires support from the normal buses.
.2 The following systems should be operational to support the service water system during normal operation:
- a. Traveling water screens and screen wash system
- b. Hypochlorination system 8.3.4.2 SHUTDOWN
.1 The loss of service water cooling to nuclear safety-related components supplied by this system will result in the inability of these components to function during an accident. The I' ) effects are as follows:
gJ
- a. Emergency Diesel Generators. The emergency diesel generators will overheat and trip out due to loss of cooling water, resulting in the loss of all a-c power during an accident if off-site power is not available.
- b. RBCLCW. Loss of service water during an accident will prevent the RBCLCW system from cooling the RHR pumps and the spent fuel pool. Loss of cooling to the RHR pumps will result in immediate loss of those pumps and a reduction in core cooling capability. Loss of cooling to the spent fuel pool will have less immediate effects but will result in I
high temperatures and potential radioactive release from the spent fuel pool. j (
- c. RBSVS and CRAC Chilled Water.
i Loss of service water during an accident j will cause loss of the RBSVS and CRAC Chilled Water System, resulting in above D-e atmospheric pressures in the secondary i containment and potential unmonitored i 1 L
L- - _ I
.()
( radioactivity release to the environment. ,
- d. Emergency Service Water (Ultimate i Cooling). Loss of emergency service !
water should have no effect during an ' accident, as it is normally not used. However, there will be no backup cooling supply to the ultimate cooling connection or to the spent fuel pool.
.2 Loss of service water cooling during normal operation will result in the operational failure of the following systems due to lack of cooling. The effect will be to require immediate plant shutdown.
- a. TBCLCW ;
- b. RBCLCW f
- c. RBSVS and CRAC chilled water
- d. Main ventilation chilled water
- e. Main circulating water (loss of pump
- bearing cooling) 8.4
SUMMARY
; 8.4.1 The service water system is divided into two systems, one supplying the Raactor Building and Control Building; the other supplying the Turbine Building.
- 8.4.2 The Reactor Building service water system is safety related and therefore is powered from the emergency buses. Two pumps are required during operation and two during accident conditions. Its supply header can be divided into two redundant systems to insure a supply to at least one of every safety related load and all three diesels. The supply header is equipped with series MOV's for isolation purposes. Power to the "A" valves is from DIV I and power to the "B" valves is from DIV II. Therefore, if a EDG fails to start the loops will still isolate.
8.4.3 The Turbine Building service water system requires two pumps during normal operations. It is not safety related and 4 therefore is powered by the normal station buses.
, . , _ , , - - --- - - ~ * - - - - ~ ~ * - +
TABLE 9.1 LOSS OF COMPONENT NO NORMAL OFFSITE POWER LOCA
- 1. EDG HX Outlet A0V-16 (A-C) Closed Open Open
- 2. Discharge Header MOV-32 (A.B) Open Closed Closed Cross Connect
- 3. Ultimate Cooling MOV-33 (A.D) Closed Closed Closed Isolation
- 4. Ultimate Cooling MOV-39 (A.B) Open Open Open Drain
- 5. RHR HX Outlet M0y-34 (A B) Closed Closed Closed
- 6. Main Chill Water MOV-36 (A-C) Open Clo' sed Closed Supply
- 7. RBCLCW HX Outlet MOV-37 (A.B) 1 Open Both Both Service Water 1 Closed Open Open
- 8. RBCLCW HX Inlet MOV-42 (A B) 1 Open Both 1 Closed Open
. Spent Fuel Pool Drain MOV-43 Open Open Open
- 10. Drvvell Booster Heat MOV-129 (A.B) 1 Open 1 Open Both Closed Exchanger 1 Closed 1 Closed O m l
t l
i I SERVICE WATER STUDENT SUPPLDIENT O - Date: 4/16/84 Prepared By: M /////f'p Training Instructor /Date Handout: EL-122 Revision: 0 Approved By: Training Oper'ation Speci st/Dats f O v
*f ANNUNCIATOR ARP VALIDATION k'- )1. I RBSW STRAINER DIFF P HI 0032 1. Verify strainer DP red light illuminated.
- 2. Verify pump strainer DP 8 PSID.
- 2. RBSW PUMP A AUTO TRIP -
0074/0075/ 1. Check pump control switch indicating (Same for all 4 pumps) 0076/0205 lights on MCB-01
- 2. Verify pump amps decreased + "0"
- 3. Verify service water header pressure decreases.
- 4. Verify RBSW pump strainer DP decrease
- 3. RB-TB SERVICE WTR ISOL
- 158 1. Verify position indication of VV OPEN 1P41-MOV35A/B shows Red
- 2. Return control switch to shut
- 4. RBSW HEADER A/B PRESSURE 0193/0194 1. Verify service water pressure LO indication 40 psig.
- 5. RBSW PUMP A MTR OVLD 0206/0207/ 1. Verify RESW pump amps in ,,60 amps 1
O (Same for all 4 pumps) 0208/0209
- 2. Check systen
- 6. TB SERVICE WATER PP MTR 0296 1. Verify excessive pump amps on MIP OVLD
- 2. Start standby pump as needed.
- 7. TB SERVICE WATER PP AUTO 0299 1. Verify control switch indicating lights on MXP are Green and White.
I-t
- 8. TB SERVICE WTR STR DIFF 0303 1. Send E.O. to check strainer DP P HI and place standby strainer in service as required.
- O 4
-- - - - - - - . , _ . _ . .. . _ - - . -_- .. ._ __i
ANNUNCIATOR ARP VALIDATION
- 9. TB SERVICE WTR HEADER 0325 1. Verify TBSW header pressure 22 psig.
PRESS LO
- 2. Start standby pump and verify header pressure 40 pois.
i 10. RBSW SYSTEM "A" INOP 0424/0425 1. Verify if inoperative switch in TEST.
- 2. See ARP 0426/0427.
- 11. RBSW SYSTEM A DECRADED 0426/0427 1. Loss of position indication on any
; (Same for B) valves that move on an accident.
- 2. Loss of position indication on
. Ultimate Cooling Valves.
- 3. Loss of pump indication on any RESVP.
i
\
i.
I 11 PRECAUTIONS , l
- 1. To prevent damage to the service water pump motors, two consecutive starts shall be allowed with the motor cold and one start shall be allowed with the motor at operating temperature. Subsequent starts with the motor running between starts shall be at least 15 minutes apart. Subsequent starts with the motor stopped between starts shall be at least 45 minutes apart.
Check the NSO log to verify time when RBSWS pumps were started and stopped.
- 2. Supplying service water to the ultimate cooling connection will inject sea water into the reactor vessel if reactor pressure is at or near stmospheric pressure.
The ultimate cooling connection shall only be used as a last resort to supply cooling water to prevent the reactor core from remaining uncovered. Must receive permission from the Watch Engineer for injection.
- 3. Injection of service water into the spent fuel pool shall only be done as a last resort to maintain fuel pool level or temperature.
Must receive permission from the Watch Enginecr.
- 4. Service water shall not be isolated simultaneously to both sets of redundant safety equipment during normal plant operation.
Check NSO log and SECPS to verify isolations, r ~
\
L / 5. When adding or switching loads ensure there are suf ficient pumps operating to prevent motor overloads and ensure sufficient flow path ( 58 amps for the RB Service Water Pumps and 45 amps for TB service water pumps). Check RBSW Amps on MCB-01 Check TBSW Amps on MXP
- 6. Assure that the Salt Water Drain Systems are available.
Check procedure prerequisite checklist for valve lineup and power supplies. 7 Manual operator engagement pins of 1P41*A0V-016A B,C, listed in Appendix 12.2, must be disengaged prior to auto operation. If manual operator engagement pin is engaged at the time of auto operation the woodtrff keys of the " Fisher Controls" operator will sheer and render the valve inoperable. Verify locally in the Emergency Diesel Rooms that the manual operator engagement pins are not inserted when the system is in standby status.
- 8. Do not place heat exchangers IP41*E117A (RBC1.CW Hx) and 1E118E034A (RHR Hx)
, (IP41*E117B and 1E11*E034B) in operation concurrently without heat loads since this mode of operation has not been analyzed.
Check procedure prerequf. site checklist for valve lineup and power supplies.
,n N(YTE: Change made per S&W 1etter LIL-23717. (The S&W 1etter has not been traced (j \
i down to date)
-4 -
- . ~ . . _ _ _ . . . _ ___ _ __ _ _ ._ _ __ _ , __ _ _
III MALFUNCTIONS : o The RBSW system valves and pumps have changed position and are operating during a LOSS OF 0FFSITE POVER as follows: FIG's 1,2,3
- 1) ..dGHxOutletADV16AB&C OPEN
~
- 2) Discharge Header Cross Connect MOV's-32 (A&B) CLOSED
- 3) Hain Chill Water Supply MOV's-36 (A.B&C) CLOSED
- 4) RBCLCW Hx Outlet MOV's 3 .&B)
OPENED All 4 RBSW system pumps are RUNNING with their respective discharge valves OPEN ED. The RBSW system valves and pumps have_ changed position and are operating during a LOCA as follows: FIG's 4.5,66
- 1) EDC Hx outlet A0V-16A.B &C OPEN
- 2) Discharge Header Cros s Connect MOV's 32(A.B) CLOSED
- 3) Hain Chill Water Supply MOV's 30(A.B&C) CLOSED
/Q i
- 4) RBCLCW Hx Outlet MOV's 37(A&B) OPEN F '
$) Dryvell Booster Nx HOV's 129A&B
~
CLOSED All 4, RBSW system pumps are Rt'NNING with their respective discharge valves OPEN c Ultimate Cooling Isolation Valve Leak '
. Alarm RxBuildingSumpLevelHi#044donMCB-01alarmpanel209E.
Call NASO at Radwaste ' Control Room and confirm Ftx Building Salt Water Drain Tank level Hi #4850 annunciated.
-o Loss of Station Air EDG's cooler outlet valves A0*1's 16A.B&C fail OPEN.
' EDC's service water flow a14Ta tr insattters FT-018 A/B/C will cause a service water low flow alarm at the EDC c.ent'o1 pu.el 1R&3*PNL-1/2/3
~
Loss of air to the D/P inattueents will fail the backflush valves on the
. RBSW Pump strainers closed if open' f
, CA11I10N : The inerhabe in flow may be sufficient to cause runout if snly one pump is running .
be
, - 5 ~' ,
IV TECHNICAL SPECIFICATIONS , 3.7.1.1 Two independent plant service water system loops shall be OPERABLE with each loop capable of taking suction f rom the ultimate heat sink and comprised of t
- a. Two OPERABLE plant service water pumps, and
- b. An OPERABLE Reactor Building service water (RBSW) flow path capable of transferring the water to the associated safety related equipment, and
- c. An OPERABLE residual heat removal service water (RHRSW) flow path capable of transferring the water through the associated
. RHR heat exchanger.
APPLICAPILITY: OPERATIONAL CONDITIdNS 1.2 and 3 3.7.1.2 At least one of the following shall be OPERABLE:
- a. Two independent plant service water system loops with each loop capable of taking suction from the ultimate heat sink and comprised of tO)
- u. a 4
- 1. One OPERABLE plant service water pump, and
- 2. An OPERABLE Reactor Building service water (RBSW) flow path capable of transferring the water to the associated cafety related equipment, and
- 3. An OPEMBLE residual heat removal service water (RllRSW) flow path capable of transferring the water through the associated RHR heat exchanger
- b. At least one plant service water system loop capable of taking suction from the ultimate heat sink and comprised of:
- 1. Two OPERABLE plant service water pumps, and
, 2. An OPERABLE Reactor Building service water (RBSW) flow path capable of .
transferring the water to the associated safety related equipment, and
/ 1 L' 3. An OPERABLE residual heat removal service water (R)(R$W) flow path capable of transferring the water through the associated RER heat exchanger.
APPLICABILITY: OPERATIONAL CONDITIONS 4,5, and *. 3.7.1.4 The ultimate heat sink shall be OPERABLE. ' APPLICABILITY: OPERATIONAL CONDITIONS 1,2,3,4,5, and *. I ACTION:
- a. With the ulticate heat sink inoperable because of damage to the jetties or armor which would compromise their ability to withstand a subsequent storm or earthquake, be in at least HOT SHUTDOWN within 12 hours and in COLD SHUTDOWN within the next 24 hours,
- b. With the ultimate heat sink otherwise inoperable, restore the ultimate heat sink to OPERABLE status within 3 days, or, in lieu of any other report required by Specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the following 10 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the ultimate heat sink to OPERABLE status, p -
O v 1 l
. 4 .
7 7 7 7 - 6 2 62 4 6 2 [m S J S 4 5 2 5 4 4
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4 ig 3 -~ 4 3 fg
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%- 2 i 2 2 2 l - 1 -
I - l - O d 04 04 04 llBSW AdPh R95w mPC RSSW-PWPu .PwPs STRCP STROP STRCP DP PC-ISOA _PN50C i PO IS00 PO4500 200 - 75 - 75 - ~ 75 - 75 - 200 - TO A 10- ~ To TO4 - ISO - 60 ': 60 602 40 J' ISO - w w ma w - 100 4 40 : 40 : 40
~
40 : 100 -- ( i w:4 m :4 m:4 m:4 ' w 1 l l% - n; w m n - ! 10 10 104 104 = 1 0 ~ 04 04 04
~-
04 0- l S E RV WTR RB SW WTR 48 C WTR RB,5VC E l RB SW WTR SERV WTR i PMPA-AMP 3 PM AMP 3 PMP0 AMPS PWPB-AMP 5 l Pe P 003A , PCO3C >0030 P 0038 P
.,n '
100- 12- 100 - M 30 - Iso - 100 - 12 100 - d [ 30 - 150 - so 2 io 80 2 2 - 12 0 - e0 2 10 - so 2 2 - 120 2 t m - . 60-- 60 m - 90
- 60-- g 60 -
90 - g_ --
- 15 -
.4 *0
- 16 .4 40- , _- 40 -
10 - 80 - 40- 4 J 10 - 80 - I 20- 4- 20 - S - 30 - 20 - 4- 20 - S - 30 - 1 0--4
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l l ~ ~ ~~ ~ ~- -~ l l NORMAL, ELECTRICAL DIST. STUDENT HANDOUT (From 138KV down to 24VDC) FOR SHIFT (SRO) ADVISOR l TRAINING PROGRAM
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Date: 01/05/84 Prepared hv:
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Handout #: HL 308 Reviewed bv: Oppat ns jiningSpecialist / Date l Revision f: 9 Approved bv: M / T/ ' Trn'ining pervis p / Vafe / ah - l
s I OBJECTIVES ; The student should be able to: A. State the purpose of the Normal Distribution system. B. State the amperage limit for the NSST, RSST and 4KV busses. C. Given control indications or alarms be able to recognize for the Normal Distribution System.
- 1. the requirement of a fast transfer
- 2. a successful fast transfer
- 3. an unsuccessful fast transfer or bus lockout
- 4. an RSST or NSST transformer fault protection trip
- 5. A Loss of Offsite power
- 6. A Cas Turbine feeder fault backup trip
- 7. a 4KV/480 line, transformer or 480V bus fault
- 8. if a 4KV bus may be re-energized
- 9. a dead 125VDC bus
- 10. a 125VDC battery charger problem
- 11. a 125VDC bus ground
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II PURPOSE I
.The purpose of the Normal Electrical Distribution system is to receive power from ;
the LILCO system and distribute the pover to the plant non-safety related < equipment. III SYSTEM DESIGN A. GENERAL DESCRIPTION FIG. 308-1 Power is supplied to the Normal Dist.ribution system from the LILCO 138KV and 69KV transmission systems. The 138KV transreission system is used to feed 4KV buses 1A and 11 via the Normal Station Transformer (NSST). Each of these 4KV buses is used to supply the loads indicated below: Bus IA Bus 11 o "A" Reactor Recire. MG Set Drive Motor o A TB SW Pump o A Circulating Water Pump o Screen Wash Pumps o A Condensate Booster Pump o Cas Turb Auxiliaries o A Condensate Pump o A TBCLCW Pump o A and B Main Chillers g I o A Air Compressor
.\ o C Circulating Water Pump o All equipment powered from 480V buses 11A, 11B, 11C, 11D The 69KV transmission system is used to feed 4KV buses IB and 12 via the Reserve Station Service Transformer (RSST). Each cf these 4KV buses is used to supply the loads indicated below:
Bus IB Bus 12 o B Reactor Recire. MG Set Drive Motor o Cond Transfer Pump o B Circulating Water Pump o B and C TB SW PP o B Condensate Booster Pump o Fire Pump o B Condensate Punp o B TBCLCW Pump o C Main Chiller o B & C Air Compressor o D Circulating Water Pump o All equipment powered from 480V buses 12A, 12B, 12C, 12D ,, Station loads are split between the NSST and the RSST since neither of these transformers is designed to withstand the transient load associated with a transfer of all plant equipment. w/ i
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.' In general, station loads of less than or equal to 480V are supplied via the same ultimate power source (138KV or 69KV) that supplies the 4KV 1' oads that these lower voltage systems support.
4KV Motor Power Supply 480V Support Component Power Supply A Condensate Pump Bus 11 A Condensate for Discharge MOV McCllA3 B TBCLCW Pump Bus 12 B TBCLCW Pump Discharge MOV McCl2C3 The 11 and 12 4KV busses supply individual components along with one supply breaker to separate step down tran: formers which are connected to 480V Buses. The llA through D buses are supplied from bus 11, 12A through D from bus 12, each buses can be cross tied to its sister buses. (i.e., Bus llA-Bus 12A etc.). The 480V buses supply 480V Motor Control Centers (MCC's), individual components, step down transformers to 120VAC distribution panels, and 125VDC j battery chargers N1 and N2. MCC's are numbered after their normal 480 swgr power source. As an example MCC llA3 is powered from Bus llA. Likewise MCC 12C3 would normally be powered _from bus 12C. Some MCC's are powered from another MCC but they r still retain the generic designation. Referring to Figure 308-2 and 308-3 MCC's 11A3 and 12A3 supply battery
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charters for the 125VDC busses N1 and N2. The 125VDC and battery chargers
- v. supply their respective busses and apply a small trickle current (float chargel to the batt.ery.
i B. COMPONENT DESCRIPTION a) Normal Station Service Transformer The NSST is a stepdown (138KV / 4KV) 3 winding transformer. The primary winding is supplied via the LILCO 138KV transmission 7 system. Two secondary windings are used to minimize the voltage transient on equipment powered from the Normal Distribution system
! when a Rx Recire MG Set Drive Motor is started.
The NSST is a Nitrogen blanketed, oil cooled transformer that can be operated in any one of 3 cooling modes (controlled locally at { transformer control panel). { NSST Cooling Modes
- 1. Natural oil circulation - Natural air circulation (OA), 1650A
- 2. Natural oil circulation - Forced air circulation (FA), 2200A
- 3. Forced oil circulation - Forced air circulation (FOA), 3110A
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The NSST is supplied with redundant protective relaying schemes (primary and backup) that are used to isolate the transformer from all electrical connections in the event of an electrical fault condition.-
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b) Reserve Station Service Transformer
- The RSST is essentially the same as the NSST except it is supplied from the 69KV LILCO CRID. It ins the same current limitations based on the mode of cooling.
C) 4KV SWGR are metal enclosed, air cooled, cubicled compartments for 2000A supply. 1200A feeder breakers, and control devices. The switchgear supplies components in excess of 250 HP. Auto transfer schemes are provided between the RSST and NSST along with fault protection lockouts. Refer to I&C Section. Incoming supp1v line breakers have two protective functions: a) Trip in the event of a fault on the supply side of breakers. Fast transfer initiated, b) Trip in the event of a fault on bus being supplied - Fast i' transfer blocked so that alternate supply breaker doesn't close onto a fault. Fast transfer is locked out if not complete within 10 cycles this prevents breaker closure in which motors are significantly "out of s step" with the bus.
\ Motor feeder breakers have multiple functions:
a) Protect connected motor in event of fault b) Protect motor feeder cables in event of overload or fault conditions c) Open in event loss of bus voltage is sustained beyond the period required for fast transfer. All breakers use 125VDC control power TRIP or CLOSE. The breakers are capable of one close and trip per charge. Manual operation of the breaker can be performed locally at the cubical, however, all automatic protective functions are inoperative if 125V DC is not available. i i D) 480V SWGR - are metal enclosed, air cooled, cubicled compartments I with a step down transformer. Supply and feeder breakers are of the horizontal rack in and out type. Between the 4KV/480V air cooled transformer and the 480V bus there
.is an Inductrol automatic voltage control transformer. ,
j 480V Buses. supply components between 100 and 250 H.P. The Maximum l bus current is 1600A as indicated on the local ammeter.
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There is no auto transfer scheme for the 480V Swgr; breakers. Fault protection trips and lockouts will occur for transformer and/or bus faults. Refer to Ilic Secticas. Feeder breakers will trip on a sustained undervoltage. All breakers use 125VDC for control power which is needed to TRIP or CLOSE a breaker.
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E) Motor Control Centers. (MCC) are metal 2nclosed load centers, i supplied from their respective busses. (i.e. 12B4 is the fourth MCC supplied from 480V Swgr 12B)
- 1. Some MCC's are supplied from other MCC's rather than a SWCR.
(i.e. MCC 12B6 is fed from 12B4)
- 2. MCC cubicles have a breaker (the outside handle) and may have a contactor inside. Control power is from a 480/120V transformer downstream of the breaker.
- 3. MCC's feed smaller loads, up to 100 HP.
- 4. MCC's may be manually cross tied to other MCC's.
F) 125VDC consists of 4 divisions. The only portion that is a part of the Normal Distribution System is the non-safety system, part g consisting of black batteries N1 and N2. , .L , The two black batteries supply equipment required to achieve the l safe shutdown of major plant items when offsite power is lost. i The batteries, busses and chargers are similar to and discussed in the Emergency Distribution Lesson. Take note of the below designations. The black batteries were an add on, so the numbering sequence (N1, N2) and at the bus. N1 - Supplied from 11A3 and feeds 1R42-PNL-A3, A4, A5 and C2 N2 - Supplied from 12A3 and feeds 1R42-Phl-B3, B4, and C3 Refer to FIC 308-2 and 308-3 > [
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IV CONTROLS AND INSTRUMENTS
. A. CONTROLS l
The following controls for the Normal Distribution System are located in the main control room.
- 1. MOABS - 640 (69KV to RSST primary, motor operated air break switch)
- 2. All 4KV supply breakers to 4KV busses
- 3. All 480V supply breakers to 480V busses
- 4. All 480V cross tie breakers to 4BOV sister busses (i.e. IIA to 12A cross tie)
B. The following Normal Electrical Distribution system parameters are monitored in the Main control room.
- 1. NSST/RS$T Load (MW)
- 2. NSST/RSST secondary side amps. (3110A MAX)
- 3. NSS attp load to each 4KV bus. (2000A MAX)
- 4. RSS amp load to each 4KV bus. (2000A MAX)
- 5. NSST/RSST Cooling Mode Status lights
- 6. 4KV bus voltage
- 7. 480V bus voltage
- 8. 125VDC bus voltage (indicator and background recorders)
_ 9. (+) bus volts to ground and (-) bus volts to ground for the 125VDC system The 4KV system voltage is normally controlled at 4160V by the Station Operator. If there is a problem the transformers can be off loaded and the tap changers adjusted. The 480V system voltages will normally be regulated by their respective automatic voltage control transformers. This will determine the 120VAC voltages. The 125VDC system voltage is regulated by the respective battery charger and should be 130-135 VDC for a fully charged battery. The DC system is an ungrounded system. Grounds on the N1 or N2 bus are distinguished by a difference in brilliance of the two white lights on the MCB. A ground on only one side should be located as soon as possible. Damage and/or breaker tripping will occur if both the + and - lead have a ground. C. INTERLOCKS - all assume normal lineup. Review Fig 308-9 so you can identify the normal lineup.
- 1. Terms ,-
- a. Transformer Primary Protection (Pri Prot) - this is a j protection scheme which isolates a transformer by opening an i 4 i upstream and a downstream breaker. There is normally no
- lockouts associated with a Pri Prot. This scheme is normally initiated on a primary to secondary differential overcurrent circuit (Pri to See Diff OC).
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- b. Transformer Backup Protection (B/U Prot) - This is a t(.. protection scheme which normally is called to operate if the Pri Prot failed. It will usually isolate the upstream power source or a larger portion of a distibution system.
- c. Fast Transfer Scheme (Fast Xfr) - occurs normally with a Pri Proc. The source of power for a bus is transfered with no loss of equipment, supplied by the bus.
- d. Slow Transfer Scheme (Slov Xfr) - occurs normally with a B/U Prot. The source of power for a bus is transferred but equipment is tripped because a dead bus transfer was accomplished. Equipment may restart dependent on its control circuit.
- 2. RSST Primary Protective Trips Figure 308-4
- a. This trip will isolate the RSST from all sources of power due to the following. (86T4P)
Signal Identification Pri to See Diff OC RSS PRI PROT TRIP (0220) ANN 69KV Bus Diff OC D hs_, 4KV RSS SUPPLY BRK AUTO TRIP (( (0082) ANN
- b. System Response - The Transformer input and output breakers will trip open, the cooling fans will trip.
- 3. NSST Primary Protection Trips Figure 308-5
- a. This trip will isolate the NSST from all sources of power and protect the equipment tripped. (86T3P)
Signal Identification Pri to See Diff OC NSST PRI PROT (0218) ANN i j 4KV NSS BRK !.UTO TRIP (0081) ANN 1
- b. System Response - All input and output circuit breakers will
, trip open, the cooling fans will trip. The main generator and 1 turbine will trip most probably causing a scram. ' (k -,) ,~_
- 4. RSST Backup Protective Trips Figure 308-6 I
- a. This trip will isolate the RSST from all sources of power due to the following. (86T4B)
Signal Identification Numerous Electrical RSS BU PROT TRIP (0221) Ah3 Sudden Pressure, 69KV Breaker Failure l Cas Turb Breaker Failure l 4KV RSS SUPPLY BRK AUTO TRIP (0082) AhT 4KV BUS UNDERVOLT (0085) Ah3
- b. System Response - The Transformer input and output breakers will trip open, the cooling fans will trip.
On a backup protection trip Bus IB and 12 vill lock out, most probably causing a scran, because the NSST breakers will not close.
- 5. NSST Backup Protection Trips Figure 308-7
- a. This trip will isolate the NSST from all sources of power.
(86T3B) Signal Identification Numerous Electrical NSST BU PROT (0219) ANN Sudden Pressure 1310/1330 Brkr Failure 4KV NSS BRK AUTO TRIP (0081) Ah5 4KV BUS UNDERVOLT (0385) ANN 1310/1330 Fail Scheme Operated (0281/0061) ANN
- b. System Response - All input and output circuit breakers vill trip open, the cooling fans vill trip. The main generator and turbine vill trip most probably causing a scram.
l On a hackup protection trip Bus IA and 11 vill lockout, most l probably causing a scram, because the RSST breakers will not ! close.
- 6. 4KV Bus Auto Isolation Lockout Figure 308-6 or 7
- a. The 4KV normal busses will trip and not transfer due to th'e following signals.
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Signal I.dentification l NSST Backup Prot 4KV NSS or RSS BRK RSST Backup Prot AUTO TRIP (0081/ Sys Backup Prot 0082) ANN 1310/1'.30 BRK Failure Scheme ANN for respective 4KV Bus Fault signal Bus 11 or 12 4KV/480 Feeder Backup Prot Bus 11 Cas Turb Area Feeder Backup Prot 4KV Bus UV(0085) Fast Transfer failed ( 10 cycles) ANN Bus 11 and 12 on same Xfar + Accident Signal
- b. System response - Supply breaker that was closed is OPEN with bright white light, alternate breaker is OPEN.
Individual 4KV loads trip on undervoltage. NOTE: The only way to tell if you can re-energire a dead bus is by checking all signal trip devices in Relay Room or on Swgr. There is no trip device you can check for fast transfdr failure, or Bus 11 and 12 on the same transformer with an accident signal.
- 7. 4KVBusAutoTransferInitia*ionFigure30h4or30h
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(/ a. The 4KV norcal busses vill fast transfer to its alternate supply due to the following signals. Signal Identification The breaker supplying the bus OPENS Green light on NSST due to 1. Operator Action or RSST supply
- 2. NSST Pri Prot Trip breakers
- 3. Gen Line Prot Trip
- 4. RSST Pri Prot Trip 4KV NSS or RSS BRK AUTO TRIP (008;/
0082) ANN
- b. System response - The supply breaker that was closed vill have a bright white light, the alternate supply breaker will close, giving red light, if there is a voltage on its transformer.
- 8. 480V Bus Isol Figure 308-8 A and B
- s. All of the 480V SWGR supply breakers will trip open on the signals below, there is no auto transfer.
l Signal Identification .. Respective Brk 9 OC 480V NSS SPLY BUS i n Respective BRK Cnd OC UNDER VOLT ANN (0279) k" Respective 4KV Feeder OC + Any 4KV/480 Transformer Gnd OC Brk or Transformer OC ANS
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- b. System Response - individual breakers on phase overcurrent which trip opens the breaker and gives a bright white light.
A transformer ground is indicated below for 11B. The 11A, C, D and 12A-D would be similar except for which X-TIE breaker is locked out. 4KV/480 Feeder Open NOTE: A 4RV feeder 11A 480 Supply Brk Open L/0 would be the 11B 480 Supply Brk Open same except the Bus 11C 480 Supply Brk Open Tie Brk would not be 11D 480 Supply Brk Open locked out. 11B-12B X-TIE. Locked Out. NOTE: 1. Backup protection on the'4KV 480 Feeder breaker vill Fig. trip the 4KV Normal and/or Reserve supply breaker for 308-8B the respective 4KV bu's.
- 2. There are no protection trips on the X-TIE breaker other than individual OC.
D. ANNUNCIATORS - Refer to Fig 308-9 The following Ann are located in the Main CR. ANN ARP # CR Verification (Excluding Computer) g
- NSS XFMR PRI PROT TRIP $218 E0 finds 86T3F tripped on RR PNL RSI
- NSS XFMR BU PROT TRIP f.919 EO finds 8673B tripped on RR PNL RS1
- NSS OR RSS XFMR PROT LOSS 9222 EO finds 1 of 4 Amber light off on RR OF CONTROL PNL's RS1/RS2
- NSS XFMR TROUBLE 9226 E0 sent to transformer - Various
- REMOTE TRIP - SWD RELAY OPER 9461 E0 sent to 138KV Yard House
- RSS XFMR PRI PROT TRIP 9220' EO finds 86T4F tripped on RR PNL RS2
- RSS XFMR BU PROT TRIP $221, IO finds 86T4B tripped on RR PNL RS2 l - RSS XFMR TROUBLE 9227; E0 sent to transformer - Various l <-
- 4 KV NSS SPLY BRXR AUTO TRIP. ~ (081 .4KV NSS Brk white and green light on l ,
i.lA, 1B, 11, and 12 l
- 4 KV RSS SFLY BRKR AUTO TRIP. 9082 4KV RSS Brk white and green light on 1A, IB. 11,'and 12
- 4 KV NSS FDR BRKR AUTO TRIP. 9084 Either 4KV/460 supply brk white and green light OR EO finds Gas Turb For Open v
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ANN ARP # CR Verification (Excisding Computer)
\ - 4 KV NSS BUS UNDERVOLT 9985 BUS 1A, 1B, 11, and 12 voltage indicates low Bus Load trip, RBSVs starts if on 11 and 12 ( 2900)
- 4 KV BRKRS NSS & RSS PARALLELED 9243 Both brks on Bus 1A, 1B, 11, or 12 closed at the same time.
- 4 KV NSS SPLY UV CKT LOS CONT. 9244 EO finds Local Amber light on SWGR OFF
- 4R$ V NSS SPLY BRKR OC TRIP. 9161 EO finds local white tab tripped
- 489 V NSS SPLY BRKR XFMR CND. 9162 EO finds 86 device tripped
- 480 V NSS TIE BRKR OC TRIP. 9163 EO finds local white tab tripped on brk
- 489 V NSS SPLY UV CKT LOSS CONT. 9278 EO finds local Amber light on SWGR OFF
- 489 V NSS SPLY BUS UNDERVOLT. 9279 Any 480V Bus indicates low, loads trip
- BUS 11A-12A SPLY - TIE BREAKERS 9330 Supply and X-TIE Brks Red light PARALLELED.
- 3US 11B-12B SPLY - TIE BREAKERS 9331 Supply and X-TIE Brks Red light PARALLELED.
- BUS.31C-12C SPLY - TIE BREAKERS 9364 Supply and X-TIE Brks Red light PARALLELED 4
- BUE IID-12D SPLY - TIE BREAKERS 9380 Supply and X-TIE Brks Red light PARALLELED.
- BLACK BATTERY TROUBLE 9476 Dispatch E0 to field
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1 V SYSTEM PROCEDURES ; A. SYSTEM PRECAUTIONS, CArfl0NS, AND/OR LIMITATIONS
- 1. The motor-operated and manually operated air break disconnect evitches are "Off Load" switches not designed with load interrupting capability. No attempt should be made to operate them when they are carrying load,
- s. Purpose - To prevent personnel injury and/or damage of the ABS due to excessive arcing.
- b. Recognition - Disconnect switches should only be opened via a switching order received from the System Operator (50).
- 2. Tap changers must not be operated while the transformer is energized. Serious personal injury and/or damage to the transformer may result if this is attempted. The tap changers are designed for "off-load" operation only,
- s. Purpose - above
- b. Recognition - Tap changing is done by substation maintenance section in conjunction with a switching order.
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- 3. Damage to the transformer may result if both tap changers are not selected to the same setting,
- s. Purpose - to have the same voltage on the secondary winding output.
- b. Recognition - Difference of voltages of 4KV busses when supplied from different secondary windings.
- 4. Current transformer secondary windings must not be open circuited under any circumstances when the transformer is energized or demaged will result and dangerous voltages may be developed.
- a. Purpose - above
- b. Recognition - local shorting bar not in place l 5. The radiator inlet and outlet valves should not both be left closed on any radiator, or damage due to therma ~ expansion may result. No relief valves'are fitted.
- a. Purpose - above
- b. Recognition - local valves closed with ITMR energized
,bh 6. Before resetting any protection relay, ensure that the condition k/ which caused the trip has been determined and corrected.
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- a. Purpose - not to re-energize a faulted bus .
- b. Recognition - 86 device tripped or flag up on a protective device. Should only be reset after obtaining permission from the Watch Engineer.
- 7. When opening or closing a manually operated air-break disconnect switch, a positive visual check should be made to verify all three phases are in the desired position.
- a. Purpose - to prevent single phase energizing of transfomer
- b. Recognition - motor trips due to locked rotor protected on motor start.
- 8. Should an arc-over occur during a closing operation of the air-break disconnect switch or if any blade should fail to close properly, do not attempt to open the air-break disconnect switches.
- a. Purpose - to prevent damage to the ABS due to arcing
- b. Recognition - local
- 9. The Fire Protection Water Deluge System tends to expell all air from the vicinity of the transformer when it is initiated.
Personnel working in the vicinity should be aware of this and
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vacate the area if the deluge system is initiated,
- a. Purpose -
- b. Recognition - Fire Panel alam
- 10. Both incoming supply breakers on any 4160 V normal station bus shall not be closed simultaneously except when transferring from one supply to the other, and then only for a short period of time.
- a. Purpose - to prevent damage due to circulating currents between secondary windings of NSST and RSST.
- b. Recognition - RSST and NSST breakers for 1 bus closed at the same time and/or Paralleled Ann.
- 11. Breaker operations are normally carried out from the main control board. Local operation is possible but should only be used when normal control is lost and never to transfer between the normal and reserve supplies.
- a. Purpose - prevent damage to bus during periods of minimal
- indication. -
- b. Recognition - NSST and RSST Breakers closed without CR operation.
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- 12. If all loads are being supplied from one transformer, closely i monitor the asperage on the transformer to insure that it is not overload.
- a. Purpose - above
- b. Recognition - secondary winding amperage approaching 3110A.
- 13. Do not close incoming breakers manually if control power is lost.
- a. Purpose - to protect the bus since the breaker will not trip without control power. Also provides personnel safety.
- b. Recognition - No indication of breaker or LCTL Ann and bus re-energized.
- 14. For all 486 V switchgear: Before racking in a breaker, the control switch for that breaker must be in the " PULL-TO-LOCK" position, where applicable,
- a. Purpose - prevent inadvertant breaker closure
- b. Recognition - control switch position not in P-T-L
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- 15. Before tying buses together, ensure that both buses 11 and 12 are
[ being fed frca che same transformer. If not, the affected 489 VOLT BUS must be de-energized before closing the Tie Breaker. (480V caution 8.12) t
- a. Purpose - to protect against large currents due to circulating i current.
- b. Recognition - Bus 11 and 12 supply breakers closed form i different transformers.
- 16. Prior to energizing switchgear from a bus tie, ensure total load is I less than the transformer limit. (480V caution 8.1.2)
- a. Purpose - protect transformer from overcurrent
- b. Recognition - local ampmeter for the 11 and 12 sister' buses indicate greater than 1600 amps.
B. NORMAL OPERATION Fig. 308 The normal distribution systems are in operation when they are energizing their respective loads through the previously discussed power trains. The Prerequisite checklist requires a check of'the flexi test. switches which disconnect Unit, Sys, Gen line, etc. protection. These circuits are verified energized by their respective amber indicating light on PP panel ts RU-1, 2 and 3.
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~/ The requirements for a megger reading on equipment is by the NE or maintenance department. The acceptability of the findings is stated on the maintenance surveillance form.
A prerequisite for the battery is that the checks are completed. There may be found in SP 23.315.01 section 8.1.2 in addition to any maintenance section checks. Before starting any equipment on a 4KV or 480V switchgear, the operator should determine that the rated amperage for the equipment, when added to the amperage that the bus is carrying does not exceed the bus or transformer maximum amperage. This may occur when the switchgears are cross tied. NOTE: A 4KV bus load is also a transformer load, so check both. C. ABNORMAL OPERATI,0K - refer to Emergency Distribution for T.S. limitations , 1. Loss of the NSST or RSST -
- If due to a fault the 4KV bus will fast transfer to its alternate source. If due to a loss of voltage on the LILCO grid, operator action is required to strip the bus, open the lost supply breaker and close in the alternate supply breaker.
g- g - NOTE: If an accident occurred at this time both 11 and 12 buses g l' j would trip and only one could be re-energized after 30 seconds. If bus 11 or 12 is locked out transfer the respective 480V Bus to its alternate source via the tie breakers. The 120VAC panels N1 and N2 vill transfer to their alternate source. The major loads on N1 and N2 is the Display Memory Module Fan and control room recorders. The 120VDC buses will stay energized on the batteries until power is restored to the respective switchgear.
- 2. Loss of Offsite Power All normal distribution systems'are de-energized except for the 125VDC and.24VDC systems which are on their respective batteries.
Indication would be by: 4KV NSS BUS UNDERVOLT ANN 4KV EMERG BUS UNDERVOLT ANN l
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- 3. Battery Charger Problems (k
A battery charger failure would be indicated by: BLACK BATT TROUBLE ANN The black batteries may show a lov voltage indication on the MCB or back panel recorder. A ground on one line is indicated by a difference in brilliance of the MCB white lights. The response in either case would be to dispatch an EO to check the charger.
- 4. Loss of a Distribution Bus or Panel
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If an abnormal condition can not be identified to a logical failure (i.e., trip of a pump etc.) then a loss of power would be suspected. The identification of a loss of a bus or panel could be one of the following: g _
- 1. Auto trip alarm on numerous components
) -
- 2. Several equipment problems in one area of the plant
- 3. Loss of indicating lights on equipment (leads you to a loss of MCC)
- 4. Downscale (below zero) failure of indicators or recorders
- 5. A0V's change state to their failure positions A loss of a 120VAC panel can be picked up by 4 and 5 above.
The first response of the operator is to handle any trip, scrams or isolations that may have occurred. Additionally he would scan his indications checking for overloaded equipment i.e.: one service water pump running when 3 are required, a transformer at or near its rated capacity. When a loss of power is determined by the operator a selection of one load can-be traced, via prints, computer sorts or readouts, or SP checklist to find the specific load source. Then the operator would have to go up and downstream from there to find the initial
- cause. -
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2 O A list of loads for a bus or panel can be found in:the control room Power Distribution book, Load List by Power Source book, and/or by the S&W FE - 1A I one line diagram. The alternate source for an MCC can most easily be seen on the FE one line prints. If a transformer capacity is reduced because of lack of cooling ! fans use the Load List book to determine what equipment can be l removed from service. D. EMERGENCY OPERATIONS High drywell pressure or to Lo Lo reactor level will not have a major effect on the normal distribution system. VI SYSTEM INTERRELATIONS The LILCO 69KV and/or 138KV grids must be energized to supply the primary motive force for all electrical loads. The 125VDC buses N1 and N2 are needed for control power for the 4KV and 480V Swgr. O VII TECHNICAL SPECIFICATIONS 1 There are nct Technical specifications related to the normal distribution buses. Offsite power will be covered in Emergency Distribution. NOTE: A loss of power causes a component to be INOP therefore you may be in Tech. Specs. (i.e., SRM drives). VIII SIGNIFICANT INDUSTRIAL EVENTS A. Offsite Fire Causes Station Blackout Incident: While in cold shutdown, a brush fire started near the main switchyard. Local firefighting agencies who were called in to fight the fire requested that two transmission lines into the site be de-energized to aid in firefighting. During the next 14 hours all other transmission lines were successively lost resulting in a total loss of offsite power. The transmission circuits automatica11y' tripped because of out of phase comparisions in the transmission protection logic. Smoke from the fire had provided sufficient conductive path between the three phases to cause a,, differential trip. All diesel generators worked and supplied power to the site for four and one half hours until offsite power was
,_s restored.
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l In the past 10 years there have been six documented cases of a loss of all offsite power to nuclear power plants caused caused be offsite forest / grass fires. The main cause of the transmission 1.ogic trips has been smoke which induces out of phase differential trips. All of Shoreham's transmission lines stretch through woodland which are susceptible to fires, especially during the
, summer months.
B. 4160 Volt Breaker Problem Plant: Shoreham Incident: Trip flags on 4160 volt breaker protective relays have been observed to spuriously fall (indicate a breaker relay trip) in respons,e to minor mechanical jarring such as that experienced when a switchgear door is closed. Failure to assume that all relay flags are properly reset could mislead or* confuse trouble shooters / operators- in the event of a breaker fault trip. C. 480 Volt Breaker Problem Incident:
~
A 480 volt bus tie breaker failed to operate on demand. 1 Investigation revealed that the breaker charging spring motor had D been inadvertantly de-energized. A toggle switch, which is located on the breaker face was inadvertantly switched to the off position and, thereby, prevented the recharging of the breaker close spring. Shoreham's 480 volt breakers are similar to those installed at Fort St. Vrain in that there is a charging spring motor on/off toggle switch located in the breaker face. Hispositioning of the toggle switch could defeat the function of those systems supplied by 480V breakers including safety related or power process related equipment. D. Overloading of MOV Close Circuits Incident: If a MOV with seal-in circuit design is held in the closed position sf ter the valve is full closed, the valve operator power supply ran overload and trip. This trip would require a local reset and would res~lt u in a loss of the remote operability of the MOV. MOV's which are equipped with a seal-in feature should normally be allowed to stroke without use of the " emergency" features which.is initiated by continually holding the control switch. . l i l'...._....._.___._..__...__ _ -- -
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- I TwERGENCY ELECTRICAL DISTRIBUTION STUDEN* HANDOUT O\ -
kx Date: March 13, 1984 Prepared by: m d 2/ [4/ Tra ing Instructor / Date' Mendout II: 309/311/314/315 Approved by: d/,6" g / h/ / 3,df/fy' Operations Tra'ining Spee ist /'Date Revision #: 3 1 U
( i b1.0 LESSON PLAN: Emergency Electrical Distribution . 2.0 LECTURE DUF.ATION: 4 Hours 3.0 MATERI,ALS REQUIRED FOR STUDENTS: 3.1 Emergency Electrical Distribution Lessen Plan 4.0 NATERIALS REQUIRED FOR INSTRUCTOR: 4.1 Ec3ated Graphics 5.0 REFERENCE MATELIA1: 5.1 4169V AC, 489V AC,125V DC, System Descriptions 5.2 FSAR, Chapter B 5.3 Technical Specifications, Section 6 6.0 SCOPE OF LECTURE: To give the student the arrangement, instrucentation ar.d operation of the emergency electrical distribution system. 7.0
- STUDENT OBJECT:VM At the completion of this lesson the student should be able to:
7.1 State the purpose of the Emergency Electrical Distribution System. 7.2- Given an Emergency Electrical Distribution bus, state the normal and alternate power supplies to that bus. 7.3 Giver an Feergency Electrical Distribution 4FV bus, statt the loads, er that bun. 7.4 In the Control Room either point out or correctly operate all controls for the Emergency Electrical Distribution System that are identified in the following procedures: SP 23.309, 23.311.01, 23,314.01, 23.315.01, 24.309.01, 24.315.01, 29.015.01 or 29.015.02. 7.5 Validate any given control room annunciator related to the Energency Electrical Distribution syster. 7.6 Given a diagram of various control room annunciatoYs and/or indications, identify the folleving Emergency Electrical Distribution Conditions:
- a. Normal Bus Configuration
- b. A successful fait transfer
- c. An unsuccessful fast transfet
- d. A bus fault (o\--) e. An NSST or RSST fault protectin trip f - - - - - _ _ ._ _ _ _ _ _ _ _ _
- f. A loss of offaite power .
'~
- g. A 4KV/4 ROV transformer or bus fault
- h. If a bus can be reenergized
- i. If a slow transfer signal in present
- j. A successful slow transfer
- k. An unsuccessful slow transfer 7.7 Given any of the Precautions or Cautions contained in SP 23.309.01, 23.311.01, 23.314.01, 23.315.01, 24.309.01, 24.315.01, 29.015.01 or 29.015.0?:
a) State the purpose b) State how the operator can identify free control room indications that a limit of that Precaution or Caution is being approached or exceeded. 7.8 State the load limit for the 4KV Emergency Busses. 7.9 State the 4KV emergency loads that do not trip on an undervoltage conditior. 7.10 State how proper LPCI MG set operation car be verified from the main control room. O L) I ~7.11 State under what conditiers a 4KV breeker can be operated locally. 7.12 Given a diagran of the Emergency Dist. control panel, identify if an LCO applies for Energency Electrical Distribution and state any actions required that must be completed in less than I hr. 7.13 State the non-safety related loads supplied by the Emergency Distribution systen that can be reenergized with a LOCA. nignal present. 7.14 Given a valid LOCA signal on DIV I and DIV II identifv all 4KV & 4POV equipment that auto operates. 7.15 Given a valid LOCA signal for either DIV I or DIV II oniv (I&C surveillnece teet mishap) identi*y all 4KV & 480V equipnent thet vill auto operate.
! )
v E.-______.___ ._. ___.__ _ _ . _ _ _ . . _ _ _ 1 8.0 LESSON OUTLINE: , 8.1 Theorv 8.1.1 Purpose
.1 The purpose of the erergenev electrical distribution sveten is to supply the electrical power requirer.ents of all nucleer safety related equipment.
7 Safety related equipment is the equipment that is required to safely shutdown the P during nr eccident (LOCA1 conditfra. R.1.2 Design Basis Fig. 1
.1 The; emergency distribution system consists of 3 independent electric divisions. (Therefore single fault can't dis.'ble 2 divisiens).
.2 All plant se.fety related equipment is ultimately powered ' rem the 4KV emergency buses.
.3 Each 4KV energency bus is capable of being supplied b' the FSST. RSST cr its associated EDG.
1 M 4 Entire energency distribution svnten in meismic, Cat. 1. are all loceted in one switchgear roen. (Total of 3 rooms).
.5 The 3 evitchgear roons are physically isolated from each other so that a single fault can't disable 2 divisions.
.6 Each 4KV bus can be supplied by one of 3 power sources, a) Normni Station Service Trensformer (NSST) b) Reserve Station Service Transformer (RSST) c) Its associated Emergency Diesel Generater (EDG) 7 The nornal power suppiv to each 4KV bus and therefore all equipment in that division in the NSST.
.8 Auto transfer schemes are provided to the RSST & then the EDG if NSS power is lost to the 4KV emergency bus.
.9 Each 489V bus can only be supplied by its associated 4KV emergency bus. (No crosstie breakers are provided). ,
.10 Each 489V bus supplies all of the various 489V MCC's m amsoefeted with that division.
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/ .11 The 489V MCC's supply various small motor loads (i.e. pumps &
valves) that either support the operation of the associated 4KV equipment or perform a safety function of their own. In addition, they also supply the 125V DC Battery charger & 129V AC instrument panels associated with each division.
.12 The 129V AC instrument panels supply the AC instrumentation power to the systems associated with that division.
.13 The 125V DC Battery Charger supplies the 125V DC bue during normal operation & also supplies e small float charge on the associated 125V DC batterv.
.14 The 125V DC bus supplies 125V DC distribution panels. Buses A
& B also supply 125V DC MCC's.
.15 The 125V DC MCC's supp1v power to MOV's & auxiliarier. for the HPCI & RCIC systens.
.16 The 125V DC distribution panels supply power to the associated division ECCS logic circuits, associated division EDG start auxiliaries, associated division 4KV bus & 489V bus control power as well as associated division instrumentation.
8.3 Major Equipment
Description:
I 8.3.1 4KV Emergenev Buses a) All circuit breakers on the bus are equipped with 125V DC control power. (1 circuit breaker supplies control power to all bus breakers on one bus). b) Circuit breaker operation is as follows: Fig. 3
- 1) 125V DC supplies power to a charging motor that is located inside each circuit breaker mechsnism.
- 2) Charging motor is used to compress (charge) ACB cloring springs.
- 3) Closing springs remain compressed until either the closing coil is energized (from control room control switch or local control switch on cubicle) or local close pushbutton is pressed.
- 4) When close signal is received the closing springs discharge as they close the circuit breaker contacts.
- 5) During the close cycle the ACB opening springs are -
compressed to provide motive force for opening the breaker contacts during an open sequence. (v)
- 6) The compressed opening springs are held in a latched position.
- 7) The opening springs can be unlatched by energizing the ACB trip coil (from control room control switch or local control switch on cubicle) or pushing the local trip pushbutton.
- 8) ACB Operational Characteristics:
a) ACB requires contrcl power for remote operation (closing or opening). b) Therefore if con:rol power is lost the breaker will remain in the position it was prior to the loss of power. c) Loss of control power disables ACB fault protection so thet on a fault condition the circuit breaker renains closed, a) Control Power Indications
- 1) all 4KV circuit breakere are equipped with the following control roor indicatirg lights.
[0) OREEN - WHITE - RET
- 2) CREEN light significance:
a) indicates that ACB ic OPEN and control power is available.
- 3) RED , light significance:
a) indicates that ACB is closed and control power is availabl_e. b) also indicates that there is continuity through the trip coil. Therefore auto trip functions will operate.
- 4) WHITE light a) Indicates breaker disagreement.
Contrc~ switch is auto after start and ACB is open. l
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b) Lightisoutduringhormaloperation (' ' but on an ACB trip it will light either die or bright.
- 1. dim light
, indicates ACB has tripped due to a system problem (i.e. high level low pressure etc.). Trip can be reset by taking control l switch to STOP.
- 7. b,righ t light
. indicates breaker has tripped to an electrical fault & has been
. locked out. Lockout must be reset locally at ACB cubicle.
(Lockout should not be reset until fault has been repaired). 8.3.2 480V Energenev Svitchgear Buses a) Supplied by 4KV/4PPV transformer from associated 4KV emergency
- j. bus.
b) breaker operation is the same as that discussed for the 4KV ., s breakers. c) 1 --125V DC breaker on an associated 125V PC distribution panel supplies control power to all 489V bus breakers on each ' of the 480V buses. 8.3.3 4POV MCC's e) Fed from associated 486V buses j i.e. Bus 111 supplies MCC's 1110 - 1119 etc. b) First three numbers of MCC designate its electrical DIVISION. t c) As plant electrical requirements b ue grown, the number of MCC's associated with each division has also grown. Therefore, alpha-numeric designations have been incorporated. ! 'd) The following convention has been incorporated:
~
- 1) Letters at beginning of alphabet designate a non-safety related MCC that is supplied with emergency power.
e.g. MCC 111A; Mic 1125. .
- i
- 2) These non-safety related MCC's are disconected fron their emergency power sources due to either a LOCA signal or EDC supplving the associated emergency bus with a LOCA signal present (load shed).
- 3) Panels in the emergency switchgear rooms allow non-safety related loads to be reenergized by manually overriding their load shed signals:
NOTE: loads are reenergized by taking their override switch to the override positten. (White light illuminates to indicate the load shed signal has been overridden). MCC breaker must then be reset, e) Letterm at the end of the alphabet desigt see safety related MCC's. e.g. MCC 111X, 112Y. etc. f) MCC Operational Characteristics li Each renotely controlled AC MCC load uses 120V AC contrni power. O ~ 21 This 120V AC control power is tapped off via a stepdevn
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transformer from the 480V power to the load. (Each cubicle contains a conerni power transformer).
- 3) Each cubicle is equipped with a circuit breaker that is closed during normal operation (provides isolation for maintenance purposes).
- 4) Remotelv operated loads are equipped with magnetic motor contactors that are used to open & close the circuit during normal operations. Thernal overloads, that open the circuit, due to overcurrent conditions are also supplied.
- 5) Loss of control power (120V AC) to an operating MCC load will cause the load to be deenergized due to the opening of the magnetic contractor.
g) MCC Control Power Indications
- 1) Remotely controlled MCC loads are equippsd with 2 general indicating lieht schemes:
a) GREEN - RED . CREEN - indicates that a valve is closed or a motor contactor (pumps, fan, heaters, etc) is open. RED - indicates that a valve is open or a noter contactor (pumps, fans, heaters, etc) is closed. GREEN AND RED BOTH LIT - indicates that a valve is in a mid-position. b) CREEN-blue-RED GREEN - same as for green-red scheme RED - same as for green-red scheme BLUE
- monitors the condition of the thermal overload en certain MOV's
- the blue light is normally lit indicating that the thermal overload is reset.
- blue light "not lit" in conjunction with either
[) (~~/ _a green or red light indicatec that the ,thereal overload is trippc_d_.
- green, blue & re,d lights all "not li,t" indicetes that a 1,oss of control power has occurred.
(Pessible fuse failure).
- all valves that are automatically positioned by LOCA signals have their therec1 overloads bypassed during a LOCA condition.
- in addition, the thernal overloads can be bypassed by the operater holding the control switch or pushbutton to the position of desired travel.
8.3.4 125V DC Euses Fig. 2 a)- Power can be supplied to the bus free 2 sources:
- 1) associated 125v DC battery (hardwired to bus)
- 2) associated 125V DC battery charger ,
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~ - ~ ~ ~ ~ - -
O _ _. - . . _ _ . __ _ _ _ _ _ . b) During normal operation the battery charger stipplies all 1 cads
- and maintains a float charge on the batter .
c) Each of the 125V DC systems is ungrounded, except for ground detection circuit, so that a single ground won't disable the system. d) If a ground occurs it must be isolated & repaired to assure that a second ground won't cause systein damage. e) Major loads supplied by the 125V DC buses include:
- 1) ECCS system logic circuits (energize to operate)
- 2) HPCI 3)' RCIC
- 4) Series MOV's associated with NS 4 primary containment isolations.
- 5) Control power for 4KV emergency buses (allows breaker operation to restore power to emergency buses on a Ices of off-site power).
- 6) EDC auxiliaries needed for starting.
8.3.5 125V DC Battery Chargers Fig. 2 a) Supply DC loads during normal operation. b) Power to charger is supplied via an associated emergency division MCC. c) The battery cherger is equipped with an output current limiter so that on a high load condition both the charEer & the battery will supply the DC loads. 8.3.6 125V DC Distribution Panelm Fig. 2 a) Supply power to ECCS system logics (energize to operate) b) DIV I & DIV 11 power is used for this purpose. c) Supply required EDG start auxiliaries & power to power restoration schemes for associated emergency division. o
{ _ _ _ _ _ . __. . .. 1 8.3.7 120V AC Instrument Panels - a) Supplied by step down transformers from associated division MCC's, b) Supply power for remote indication & controller operation for associated safety related systems. e.g. 1R35*PNLR1 (R2) (R3) supp1v instrument power for "A" Core Spray, "A" Rx Bldg. Service Water, "A" RBSYS, "A" % Recombiners, etc. 1R35*PNL B1 (B2) (B3) supply instrument power for "B" Core Spray, "B" RHR "B" RBSYS, "B" Fuel Poc1 Cooling, etc. 8.4 System Operation 8.4.1 Normal Operation . Figure 9 During normal operation the NSS supply breakers are closed or all 3 4KV emergency buses supplying power to all safety related plant equipment. 8.4.2 Abnormal Operation ('~b ~ a) Fast Transfer (NO LOCA) Figure 10
- 1) Initiated.by the NSS supply breaker to an emergenev bus opening for any reason except backup protective relaving schemes associated with the NSST.
- 2) When NSS supply breaker opens the RSS suppiv breaker receives an auto close signal.
- 3) If fast transfer is successful all motors losds that were being supplied by the bus will remain running.
- 4) If fast transfer is not completed in 10 cycles the RSS supply breaker will be blocked from closing & slow transfer will try to restore bus power.
NOTE: There is njl provision for fast transfer fror the RSS to the NSS on the energency buses; therefore the NSST is the preferable supply to the emergency bus.
/* \
l b) Slow Transfer (NO LOCA) . Fig. 11
- 1) Initiated by sustained undervoltage on the emergency buses. Initiation signals are:
e) 80% voltage for 2 seconds b) 90% voltage for 8 seconds
- 2) If either of the above conditions is sensed the folloving occurs:
a) NSS supply breaker receives trip signal, b) All motor loads supplied by the bus are tripped,
. except CRD pump.
NOTE: 4KV feeder breaker to the associated 48@V bus also stays closed, c) RSS supply breaker receives an auto CLOSE signal (NSS supply breaker must be open or the RSS supply breaker will not auto close).
<-~s d) Associated EDG receives a start sfFnal.
I
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e) If slow transfer is successful the RSS supply breaker will be feeding the emergency bus and the EDC will be running with its output breaker open. f) The only auto other auto action associated with the slow transfer scheme is the auto start 6f the Rx Bldg. service water pump associated with the EDG, The Rx Bldg. service water pump starts a few seconds af ter the EDC is close to rated RPM in order to provide cooling for the diesel engine. c) Unsuccessful Slow Transfer (NO LOCA) Fig. 12
- 1) If bus voltage is not restored within 5 seconds of slow transfer being initiated.
Th e. following occurs: a) NSS & RSS supply breakers are locked out. (Lockout relay on MCB-91 for each bus). b) EDG supply breaker auto closes onto the emergency bus (will not auto close if NSS or RSS supply breaker fails to open). O N -
)
C - . _ . ._ _ . _ . _ _ _ . _ _ j l l l d) LOCA signal present .
- 1) The existence of a LOCA signal will initiate the Bus Loading Program arsociated with each emergency bus 6 cause the running CRD pump to auto trip. (ChD pump ccn be manually started via operator action after a 60 second time delay).
.)
' All 4KV safety related loads then receive aute start signels v,1,a the bus Loading Pregrams.
- 3) The Eus loading programs are as follows:
- 1) at time = 9 a LOCA signal is received.
- 2) 2 seconds - RHR pump starts (cIl 3 buses)
- 3) 7 seconds - Core Spray pur.p starts (or second Rl!E pump on DlV Ill bus)
- 4) 12 seconds - Rx Bldg. Service Water Purps start [
RBSVS & Crac chillers receive start signal. NOTE: The Rx Bldg. Service Water Purps discharge valves rust be closed as a start permissive.
,, -~3 -
}
}
The Bus Loading programs are not initiated until bus
"' 4) voltage has been restered, therefore on a concurrent Icts of eff-site power there will be a time delay while the EDG's restore bus voltage before the bus loading programs will start.
- 5) LOCA & concurrent loss of NSST will cause bus 1cading to begin after either fast or slow transfer to the RSST is successful.
e) Loss of offsite power occurring after a LO.CA signal hes been received (NSS supplying buses).
- 1) Fast transfer will be initiated if NSS supply breaker opens.
- 2) If fest transfer is successful safety related loadt keep running.
- 3) If fast transfer is not successful:
a) Slow transfer will be initiated on sustained , undervoltage. 7m k ) n-b) Safetv related loads trip c) RSS supply breaker receives close signal. d) If bus voltage is restored the safety related loads will sequence back on via the hus loading programs.
- 4) If slow transfer is not successful:
ni NSS & RSS supply breakers will be locked out & the EDG's will close onto the buses. b) When EDG's close onto the buses the screty related loads vi'.) sequence back on via the Bus Londing Programs. NOTE: If the EDG is supp1ving the bus when a sustained undervoltage is sensed Iced shedding vill not occur. 8.5 System interlocks 8.5.1 The NSS & RSS supply breakers tn the emergency buses are each equipped with 2 sets of trip coils, m ( - 8.5.? One trip coil is energired by faults on the NSST (RSS) side cf the (s) NSS (RSS) suppiv breakers, a) Operation of this trip cofi vill cause the NSS (RSS) supply breaker to the emergency bus to open and appropriate power restoration scheme vill be implemented. b) These trip circuits are powered from non-safety related 125V DC power and continuity through the trip coil is monitored via red indicating lights on the MXP panel. 8.5.3 The second trip coil for each of the NSS & RSS supply breakers ir. energized by faults on the emergency bus, a) If a bus fault occurs all 3 power supplies to the emergency bus NSS, RSS & EDC will be toeked out and the entire emergenev division vill be disabled. b) These trip coils are monitored via the red indicating light associated with the breaker control switch on MCB-@l. NOTE: In addition to indicating that a circuit breaker is closed, the red indicating light also monitors trip coil continuity. (The trip coils are energized to operate). Therefore if a red light is out it may indicate that the trip coil is opened. All aute ( ,) trips would be disabled and the breaker would have t c / to be considered inoperable, (even if it va= closed and supplying load). l l l 1 8.5.4 4160/480V Transformer Protection , Fig. 4 a) The step down transformers that supply the 480V emergency buses are equipped with 2 protective relaying schemes.
- 1) Primarv Protection
- causes auto trip of the 4KV suppiv breaker & 4 ROV supply breaker to the 480V energencv bus.
NOTE: If this protection operatec the 4KV can be running but all lower voltage eexiliaries will be inoperable (except 125V DC that will be supplied by the batteries). 2), Backup Protection
- causes auto trip & lock out of all 4KV supp1v breakers (NSS, RSS & EDG) to the associated 4KV emergency bus.
8.6 System Interrelations 8.6.1 The emergency distribution system requires the operation of each of its composite systems in order to support the operation of the
,e's _
entire distribution network. < )
'~# In additier 4KY power via the NSST, RSST or EDC is required.
R.6.2 8.7 Tech Specs 8.7.1 The following LCO's appiv to the emergency distribution syster. The following AC electrical power sources shall be OPERABLE: a) NSST supply to emergency buses b) RSST supply to emergency buses c) 3 separate and independent EDG's each with:
- 1) separate day tank containing 275 gallons of fuel 21 separate fuel storage system containing a minimum of 40,600 gallons of fuel
- 3) separate fuel transfer pump Applicable in Conditions 1, 2 & 3.
Action Within one hour, if any of above sources are inoperable, must demonstrate operability of remaining A.C. sources by . performing appifcable surveillances. g' N Other one hour actions required for more limiting casen than
! above - connuit Tech Specs.
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[ . - . . - . . . . .a -.- . - . . - - NOTE: 1 EDG & 1 offsite power source can be inop in condition 4 or 5. . In Conditions 4 and 5 If A.C. electrical power scurces are less conservative than specified must suspend Core Alterations, handling of irradiated fuel in secondary containment operations with e potential fer draining vessel and crene operatters over speu fuel pool. E.7.2 The following ,AC distribution syst,ey electrical divisions shall be OPERABLE,anc energized: a) DIVISION 1 consisting of: 1). Bus 191
- 2) Bus 111
- 3) MCC's 1119 through 1119, 111W 111Y and 1112
- 4) MCC 111X (normally aligned with DIV I but autecatically transferable to DIV III).
,s
, 3) 120V AC distribution panels 11 R2 & R3
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# b) DIVISION 11 consisting of:
- 1) But 111
- 2) Bus 112
- 3) McC's 1120 through 1129, 112W & 112%
- 4) 129V Al distributter panels D1, B2 & B3 c) DIVISION 111 consisting of:
- 1) Bus lp3
- 2) Brs113
- 3) MCC's 1131,1133 & 1134
- 4) 120V AC distribution panels fl & 92 applicable conditions applicable canditione 1, 2 & 3 In conditione. 4 h $ 2 cut of 3 divisions are required. ,
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_ _ . _ -_ _ . . _ . - _ \ l i
.3 The following DC distribution, system electrical divisions shall be g
OPERABLE and energized: , a) DIVISION 1 consisting of:
- 1) 125V battery Al
- 2) 125V charger Al
- 3) 125V Bus Al b) DIY1SION II consicting of:
- 1) 125V battery El
- 2) 125V charger B1 3)* 125V bus B1 c) DIVISION III consisting ef:
- 1) 125V battery C1
- 7) 125V charger C1
-~s 3) 125V Eus C1
[ ) Applicable Conditions 1. 2 & 3
- i. ' ' -
in conditier 4. 5 2 out of 3 of the DC divisions Furt be OPERABLE. With two of the above required AC or DC divisions not energized, suspend core alterations, handling of irradiated fuel in the secondary containment and operations with e potential of draining the reactor vessel. 4 Tvc independent LPCI/ recirculation valve swing bus power surPly assemblies shall be_0P,ERABLE. Each assemb,1y shall be ecer, rise,d of: a) 2 OPERABLE HC Sets b) An OPERABLE power monitor and automatic tr-n3fer instrumentation { c) An OPERABLE valve bus. Applicable Conditions 1. 2 & 3 In Condition 4 or 5 only 1 MG set need be OPERABLE.
/,
Ik .5 All primary containment penetration protective overcurrent devices shall be OPERABLE.
.6 The thermal overload protection of MSIV-LCS valves shall be bypassed continuously hv an OPERABLE bypass device.
.7 Two RPS power monitoring assemblien for each inservice RPS FG set or alternate power supply shn11 be OPERABLE.
R.7 Summary The emergener distribution system supplies power to all plant safety reinted ecuipment. It consists of 3 independert electrier.1 divisionc. DIV I (Red) DIY II (Blue). DIV III (Orange) The only plant loads that can he supplied with power from 2 divisions are MCC's 1117. & 112Y (LPCI injectior valves) but separation criteria Fig. 5 is maintained by using MG sets to supp1v these MCC's. The LPCI MC Set 480V distribution system is illustrated schematically in Figure 5. Normal Control room configuration is illustrated in Figure Sa.
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_,) The 4KV loads supplied by these divisions are: DIV I DIV II _D_IV III Fig. 6,7,P A Core Spray B Core Spray C RHR Pump A RHR B RRR D RHR Pump A Rx Bldg. Service Water P Rx Bldg. Service Water C Rx Bldg. Service Water Pump A CRD B CRD D Rx BldR. Service Water Pump 3A RBSVS & Crac Chiller 3B RBSUS & Crac Chiller 4A & 4B RBSVS & Crac Chiller 480V Bus 111 480 Bus 112 480V Bus 113 The following safety related systems are powered by the 480V systems: DIV I DIV II "A" RBCLCW "B" RBCLCW
/~'s "A" RBSVS "B" RBSYS'
! I "A" Fuel Fool Cooling "B" Fuel Pool Cooling "A" MSIV Leakage "B" MSIV Leakage Control Control
~ _ _ _ _ __. _ _ _ . .
s MALFUNCTIONS ' f I Normal Operation I o All control switch semaphors and breaker indicating lights should be in l agreement. e MSST should be supplying power o NSST amps to 4r7 bus should be less than 1200 o 4KV Feeder amps should be less than 180. o DC Bus Ammeter should show a slight positive anp reading caused by battery charger supplying 125V DC loads and small battery float charge, o Both 125V DC Bat.terv Ground Detector lights should be dimly lit. (Probably have to cup hard around lens to deternine that the lirht is on). o 4KV & 480V Bus power available lights ere both on indicating that the buses are energized. FAST TRANSFER Fig. #2 o All control switch semaphors and breaker indicating lights should be in s agreement EXCEPT for NSS supply breaker k__ o NS2T no longer supp3ving power o Should show RSST amps to 4KV bus o EDG does not start on a successful fast transfer o All motor loads supplied by 4KV bus remain as they were prior to the
. transfer f .e. If running they renain running. If not running thev rennin off.
SLOW TRANSFER (successful) Fie. *3 o The control switch senaphors and breaker indicating lights for the NSS and RSS supply breakers will not be in agreement. o The EDG has auto started but the EDG output breaker has not closed because the RSS supply breaker is in the close position, o NSST no_ longer supply.ing power o Should show RSST amps to the 4KV bus o All motor loads on 4KV bus auts crip (ekeept CRD pump)
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(--<) 9 -n . - , , - .
~ f _ . _ . _ _ .. m___ _ _. __ o Slow transfer nav result in Rx scram and Rx isolation due to RPS power supply frequency / voltage transient. o DC loads may increase due to transfer of UPS to battery power & DC powered isolation valves. SLOW TRANSFER (unsuccessful) ILoss of offsite power if all 3 Emergency Bus are affected1 Fic. 4/Fic. 6 o The control switch senaphors and breaker indicating lights for the NSS and EDG supply breakers will not be in agreement. NOTE: If the NSST had been out of aervice for repairs then it could be the RSS & EDG supply breakers that nr: not in agreenent. o Lockout relay tzipped due to voltage nnt being restored to the 4KV bus after the slow trensfer scheme was initiated. o Load supplied by EDG will vary depending upon whether or not a LOCA signal is present: NO LOCA SIGNAL LOCA SIGNAL RBSk' pumo starts CRD Pump Trips (Bus 101 or 102 onlyi l CRP pump continues to rue Bus loading program sends (Bus 101 or 102 only) start pernissives to remainder of 4KV bus loads. 480V loads continue to be supplied 4KV Bus Fault or 4KV/480V XFRMR Backup Protection Fig. 5
' Cor' *ol rone f rd'entions for either o' the above malfuncticas vould kn similar. Distinguishing actuel f ault will require field checking the lockcut relavs in the Emergency Switchgeer Room.
o EDG has auto started due to sustained undervoltage or the 4KV bus. o EDG output breaker has a trip signal present but no " double brilliant" white light since control switch is in auto after trip, o 4KV feeder breaker & 480V supply breaker to the 480V Bus renain closed however both the 4KV Bus & the 480V bus are deenergized. (All voltmeters & ammeters indicators are at zero). o Indication of EDG SW outlet valve position is lost since this is en AC powered solenoid, o 125V DC Battery is supplying DC loads.
. . . - . . . . ~ . . - ~ - -- - - - - . . .
4KV/480V XFRMR PRIMARY PROTECTION , Fin. 7 o The control switch semaphors and breaker indicating lights for the 4KV feeder breaker & the 480V supply breaker to the 480V Bus will be in disagreement. o 4KV notor loads will continue to run if they were running prior to the nalfunction. However, all AC powered auxiliaries that support these 4KV loads will be deenergized. i.e. MOV's control room instrunentation. o DC loads are supplied by the 125V DC batteries since the batterv charger in deenergized. 125V DC SUPPLY BREAKER TRIP Fig. 8 o The trip of a 1,25V DC Supply Breaker could result in any of the folloving: a) RCIC INOP (DIV I) b) HPCI INOP (DIV II) c) ECCS INITIATION LOGIC INOP d) EDG START AUXILIAPIES INOP el BUS LoadivR Progran INOP [~ C, ' NOTE: The malfunction depicted by Figure P involves the trip of a circuit breaker that supplies the 125V DC distributier. nsncis. o Indicating lights for all 4KV 6 480V Bus loads are extinguished. o Lack of 125V DC prevents auto operation & remote operation of the 4KV 6 480V Bus loads. NOTE: 4KV Breakers will not trio on electrical fault nrotection. 480V Bus breakers will auto trip due to overcurrent fault protection, o AC distribution systen remains energized and the AC loads that were running will continue to run, i 125V DC DISTRIBPTION PANEL CB TRIP . Fig. 9 NOTE: Malfunction depicts'a trip of the current breaker (CB) that supplies j control power to all of the 4KV bus breakers. o Same discussion applies for the 125V DC Supply Breaker trip with the exception that oniv the 4KV circuit breakers are affected. j
l 125V DC DISTRIBUTION PANEL CB TRIP . Fig. 10 NOTE: Malfunction depicts a trip of the circuit breaker (CB) that supplies control power to the 480V bus breakers. o Same discussion epplies as for the 125V DC Supply Breaker trip with the exception that only the 480V Bus circuit breakers are affected. 1?5V DC SYSTEM GROUND Fig. 11 NOTE: 125 VDC Systems are ungrounded so that a single fault will not disable any of the 125V DC equipment. However, the cristence of grounds on both the (+) Icg end the (-) leg could cause extensive damage to the syster. To prevent this, grounds should he isoleted and repaired as soon as thev are detected. e The bright light.on the ground detector would be on the ungrounded lec. o If the ground is of the internittent type both lights nav return tc a diniv lit status without operator action. o Grounded leg can be verified and severity of ground can be determined bv checking ground detectors at back of 125V DC Bus in the Fmergenca Switchgear Room, gxi - YJ' l ! ! \ i 1
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L - .. .- . . - ..- - .- a . [ MALFUNCTIONS Norwal Operation t. I o All control switch semaphors and breaker indicating lights should be in agreement.
- o. NSST should be supplying power 4 NSST amps to 4KV bus should be less than 1200 o 4KV Teeder amps should be less than 180.
o DC Bus Ameter should show a slight positive anp reading caused by battery charger supplying 1257 DC loads and small batter, float charge. o Both 125V DC Battery Cround Detector lights should be dimly lit. (Probably have to cup hard around lens to determine that the light is on). o 4KV & 480V Bus power available lights are both on indicating that the buses are energized. FAST TRANSTER Fig. #2 o All control switch semaphors and breaker indicatinF liRhts should be in agreement E7. CEPT for NSS supply breaker t
\ o NSST ne longer supplying power o Should show RSST amps to 4KV bus o E G does not start on a successful fast transfer -
o All motor loads supplied by 4KV bus remain as they were prior to the transfer f.e. If running they remain running. If not ranning they renain off. SLOW TRANSTER (successful) Fig. #3 o The control switch semaphors and breaker indicating lights for the NSS and RSS supply breakers vill not be in agreement. o The D G has auto started but the EDG output breaker has not closed because the RSS supply breaker is in the close position, o NSST no longer supplying power 1 o Should show RSST amps to the 4KV bus o All motor loads on 4KV bus auto trip (except CRD pump)
o Slow transfer may result in Rx serem and Rx isolation due to RPS Power supply frequency / voltage transient.
- t o DC loads may increase due to transfer of UPS to battery power & DC powered foolation valves.
SLOW TRANSFER (unsuccessful) (Loss of.offsite power if all 3 Emergency Bus are
. affected) Fig. 4/Fie. 6 o The' control switch semaphors and breaker indicating lights for the NSS and EDG supply breakers will not be in agreement.
NOTE: If the NSST had been out of service for repairs then it could be the RSS & EDG supply breakers that are not in agreement, o Lockout relay tripped due to voltage not being restored to the 4KV bus after the slow transfer scheme was initiated. o Load supplied by EDG will vary depending upon whether er not a LOCA signal is present: NO LOCA SIGNAL LOCA SIGNAL RBSV pump starts CRD Pump Trips (Bus 101 or 102 only)
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CRD pump continues to run Bus loading program sends (Bus 101 or 102 only) start permissives to remainder of 4KV bus loads. 480V loads continue to be supplied 4KV Bus Fault or 4KV/4BOV XFRMR Backup Frotaction Fig. 5 o Control room indications for either of the above malfunctions would be similar. Distinguishing actual fault will require field checking the lockout relays in the Emergency Switchgear Room. o EDG has auto started due to sustained undervoltage on the 4KV bus, o EDG output breaker has a trip signal present but no " double brilliant" white light since control switch is in auto after trip. l o 4KV feeder breaker & 480V supply breaker to the 480V Bus remain closed however both the 4KV Bus & the 480V bus are deenergized. (All voltmeters & ammeters indicators are at sero). o Indication of EDG SW outlet valve position is lost since.this is un AC
- powered solenoid.
t
, o 125V DC Battery is supplying DC loads.
(s_-) 4KV/480V IFRMR PRIMARY _ PROTECTION , Fia. 7 o The control switch senaphors and breaker indicating lightr,for the 4KV feeder breaker & the '30V supply breaker to the 480V Bus will be in disagreement. o 4KV motor loads will continue to run if they were running prior to the malfunction. However, all AC powered auxiliaries that support these 4KV loads will be deenergized. i.e. MOV's control room instrumentation. o DC loads are supplied by the 125V DC batteries since the battery charger in deenergized. 125V DC SUPPLY BREAKER TRIP Fig. R o The trip of a 125V DC Supply Breaker could result in any of the follevinF: a) RCIC IMOP (DIV I) b) RPCI INOP (DIV II) c) ECCS INITIATION LOGIC INOP d) EDG START AUXILIARIES INOP e)' BUS Loading Program IMOP NOTE: The malfunction depicted by Figure 8 involves the trip of a circuit breaker that supplies the 125V DC distribution panels. o Indicating lights for all 4KV & 480V Bus loads are extinguished. o Lack of 125V DC prevents auto operation & remote operation of the 4KV & 480V Bus loads. NOTE: 4KV Breakers will not trip on electrical fault protection. 4807 Bus breakers will auto trip due to overcurrent fault protection. o AC distribution system remains energized and the AC loads that were running will continue to run. i 125V DC DISTRIBPTION PANEL CB TRIP Fig. 9 DOTE: Malfunction depicts a trip of the current breaker (CB) that supplies control power to all of the 4KV bus breakers. e Same discussion applies for the 1257 DC Supply Breaker trip with the exception that only the 4KV circuit breakers are affected. 1
o 125V DC DISTRIBUTION FANE1. CB TRTP Fie. 10 30TE: Malfunction depicts a trip of the circuit breaker (CB) that supplies control power to the 4807 bus breakers. 't o Same discussion applies as for the 125V DC Supply Breaker trip with the ! exception that only the 480V Bus circuit breakers are affected. 1257 DC SYSTEM CROUND Fig. 11 MbTE: 125 VDC Systems are ungrounded so that a single faule will not disable any of the 125V DC equipment. However, the existence of grounds on both the (+) leg end the (-) leg could cause extensive damage to the systen. To prevent this, grounds should be isoleted and repaired as soon as they are detected. o The bright light on the ground detector would be on the ungrounded leg. o If the ground is of the intermittent type both lights may return to a dimly lit status without operator action. o Grounded leg can be verified and severity of ground can be deterr.ined bv checking ground detectors at back of 125V DC Bus in the Emergenev
~
Switchgear Room.
.O (N _
i EMERGENCY ELECTRICAL MALFUNCTIONS l i
- 1. Normal Operation
- 2. Fast Transfer
'3 . Slow Transfer (Sucessful)
- 4. Slow Transfer (Unsucessful)
- 5. 4 KV Eus Fault, 4 KV /480 V Transformer Backup Frotection
- 6. Loss of Offsite Power
- 7. 4KV/480VTransfor$erPrimaryProtection
- 8. 125 VDC Supply Breaker Trip
- 9. 125 VDC Dist Pnl. Bkr CB Trip
- 10. 125 VDC Ground and CB Trip
(] 11._125 VDC GrourA 3 k N.
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