ML17212B291
| ML17212B291 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 10/12/1981 |
| From: | FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17212B290 | List: |
| References | |
| 2-0700040, 2-700040, NUDOCS 8201130426 | |
| Download: ML17212B291 (22) | |
Text
Emergency Procedure CQ 2-0700040 Rev 0 LOF FLORIDA POWER 6 LIGHT COMP ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NESTLER 0700040 REVISION 0 OCTOBER 12, 19 1 LOSS GF FE OR S/G LEVEL REV FRG Approval Plt Mgr TOTAL NO. OF PAGES 14
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4r L ST. LUCIE PLANT UNIT 2 EMERGENCY EROCED URE NUMBER 2-0700040 REVISION 0
- l. 0 SCOPZ This procedure is provided to assist the control roan operators in evaluating and controlling a loss of feedwater or S/G level condition.
NOTE: Any or all of the following symptoms may be present.
- 2. 0 SYMPT(MS 2.1 Low-low S/G level 2.1 Indications LIC-9013-A,B,C,D,(RTGB202)
LIC-9023-A,B,C,D,(RTGB202)
LR-9011,9021 (RTGB202).
LIA-9012,9022 (RTGB202)
LR-9012,9022 (RTGB202)
LR-9013D,9023D (RTGB206)
RPS-CH7
- 2. 1 Alarms G-I,G-9,L-11 2.2 Low feed pump suction 2. 2 Indica tions or discharge pressure PI-1 2-1 9 PIS-09-5 Abnormal Readings On:
AM615/620 AM60S /606 AM62S/626
- 2. 2 Alarms G-18,G-19,G-1 7 2.3 Incorrect feedwater regulator 2 3 Indications position Fl-09-1A, 1B (open with high level FIC-9011, 9021 closed with low level) FR&9-1A, 1B FCV-9011,9021 2.3 Alarms G-26,G-2 7
EMERGENCY PROCEDURE NUMBER 2-0700040 RE VIS ION 0
2.0 SYMPTCNS
(Cont. )
2.4 Low condensate pump discharge 2. 4 Indications pressure P l-l2-1 9 Alarms G-18,G-19 2.5 S/G Feed pump trip 2.5 Indications Green Lite AM-615 AM-620
- 2. 5 Alarms G-l, G-2, G-3 2.6 Condensate pump trip 2.6 Indications Green Lite AM-605 AM-606 2-6 Alarms 2; 7 Heater drain pump trip 2.7 Indications Green Lite AM-625 AM-62 6
- 2. 7 Alarms F-35, F-3 6 2.8 Increasing T ave* 2.8 Indications TR-1 12QE, TR-1 111, TR-1 121
- Initial increase, then decrease 2.8 Alarms K-17
EMERGENCY PROC ED URE N UMB ER 2-0 700040 REVIS ION 0
- 2. 0 SYMPTOMS: (Cont. )
2-9 Increasing RCS Pressure 2.9 Indications (initially) PI 1102A, B, C, D PR-1 100 P IC -110X, Y RPSWH5
- 2. 9 Alarms L-20, L-28 NOTE: If a feedwater break occurs inside containment, be especially alert for erroneous indications.
2.1.0 Increasing containment 2.10 Indications pr essur e Break inside containment PIS-07-2A, 2B, 2C, 2D (RTGB206)
PI-07-4A,SA (RTGB206)
PR-07-4B,SB (RTGB20 6) 2.10 Alarms L-5,L-1 3, Q-3, P-3, P-1 3, P-2 3
- 2. 11 Increasing containment 2 ~ 11 TI-07-3A, 5A (RTGB206) temperatur e TR-0 7-3B, 5B (RTGB 206) 2.11 Alarms 2.12 Increasing reactor cavity 2. 12 Indica tions sump level LIS W 7-6 (RTGB 205)
FR-07-3 (RTGB 205) 2.12 Alarms N-29,N-21,N-4 6 2.13 Feed flow/steam flow 2.13 Indications mi sma tch FR-8011,9011 FR-8021,9021 FR-09-1A, 1B
- 2. 13 Alarms
LOF EMERGENCY PROC ED URE NUMB ER 2-0 700040 REVIS ION 0
- 2. 0 SYMPTOMS: (Cont. )
- 2. 14 Reactor Trip 2.14 Indications CEA's Inserted (ADS)
RPS-CH.7 tripped RPS-RTCB's Open 2.14 Alarms L-3,L-1 1, K-l,K-2, K-3 K-4, K-5, K-9, K-1 0 A
2.15 Turbine Trip 2. 15 Indications WM881-0 Magawatts Meter for generator output 9 zero W-REC-871
- 2. 15 Alarms D-8,C-3 2.16 After Trip, following key paraneters:
2.16. 1 Reactor Power-Decrease
- 2. 16. 2 Przr Pr essur e-Initial increase, then decrease, then stabilize
- 2. 16. 3 Tempe ratur e-initial increase, then decrease 2.16.4 Pressurizer level slight increase, then decrease 2.16.5 S/G Pressure slight increase, then decrease 2.16.6 S/G Level-decrease NOTE: Break Diagnostic Chart Fig. 1 may assist in evaluating the situation.
LOF EMERGENCY PROCEDURE NUMBER 2-0700040 RE VIS ION 0
Cl EMERGENCY PROCED URE NUMB ER 2-0 700040 RE VIS ION 0 3 0 AUTCNATIC ACTIONS 3.1 Reactor Trip 3 1.1 Reactor trip breakers open (Low S/G level) 3.1.2 CEA's insert
- 3. 1.3 Reactor Power decreasing 3.1.4 AFV Start (t 34K Level 3.2 Turbine Trip 3 ~ 2.1 Turbine valves close (Reactor trip turbine) 3~ 2~ 2 Generator breakers open 3~ 2~ 3 Auxiliary power transfers to Startup transformers
- 3. 2-4 Main Pdwtr Valves close, bypasses open to 5X flow position
- 3. 3 Turbine Runback 3 3.1 Load reduction > 40 of (los s of one feedwa ter rated power pump) 30 30 2 Operation of steam bypass control system and/or atmospheric dumps
- 4. 0 IMMEDIATE OPERATOR ACTIONS
- 4. 1 Ensure imaediate operator actions for a reactor trip have been accanplished.
4.1.1 Any autoaetic functions that were required have operated properly.
- 4. 2 A feedwa ter b reak is 4. 2 Continuously decreasing S/G indicated level and pressure with increased fdwtr flow-THEN Isolate the break with Isolate the break manually controls available in with local controls.
the control room 4-3 Continue feeding the 4.3 Either main fdwtr or aux non-faulted S/G with the fdwtr available source.
4.4 If possible maintain one 4-4 To provide secondary system condensate pump running system cooling.
4.5 Verify proper operation of 4 5 Maintain primary system przr. pressure and level control.
control systems
Cl LOF EMERGENCY PROCED URE NUMB ER 2-0700040 REVIS ION 0 4.0 IMMEDIATE OPERATION ACTIONS: (Cont. )
If a non-isolable break has occurred, immediately refer to Main Steam Line Break procedure, EP 1-0810040.
4-6 If the following symptoms NOTE: Loss of feedwater to both are indicated, refer to steam generators during power ICC procedure 2-0120043 operation has the potential of producing conditions which could a S/G level at or lead to inadequate core near zero cooling'.
S/G pressure rises to NOTES:
dump valve setpoint, Following an SIAS caused by low unless a break occurs RCS pressure and after it has been in which case pressure verified that CEA's have been fully would be continually inserted for 5 seconds, stop all decreasing operating RCP s
- c. Coincident pressure Following any SIAS, operate the SIS in the S/G and the until RCS hot and cold leg and the primary system temperatures are at least 50oF below saturation temperature subcooled for RCS pressure and a pressurizer initidly and decrease, level is indicated, unless the then increase sharply cause of the SIAS has been verified to be an inadvertent actuation.
- e. After reaching approx If 50oF subcooling cannot be constant temperature, maintained after the system has the primary coolant stopped, the HPSI system must be temperature increases restarted.
well above secondary saturation temp Reactor Coolant Pumps may be restarted if it has been confirmed that a LOCA has not occurred, pump services can be restored, and RCS pressure-temperature conditions permit restart.
1 LOF EMERGENCY PROC ED URE NUMB ER 2-0 70004 0 REVIS ION 0 5.0 SUBSE UENT ACTIONS CHECK 5.1 Refer to Reactor Trip/Turbine Trip, 2-0030130 and ensure that all subsequent actions (Section 5) have been or are being performed.
5.2 If partial loss of feedwater results in a turbine runback:
- 5. 2.1 Verify the load reduction is > 40X of rated pwr.
5.2.2 Attempt to restore main feedwater using manual control.
5.2.3 Maintain S/G levels with the remaining feedwater source.
5.2.4 Match turbine power with reactor power (T avg Tref), within the capacity of the remaining f eedwa ter source.
5.3 If both feed pumps are lost:
5.3. 1 Initiate aux feed 5.3.2 ~Sto (2) Heater Drain Pumps 5.3.3 ~Sto (1) Condensate Pump 5.3-4 ~Sto (1) RCP in each loop 5.4 Close S/G blowdown isolation valves 5-4.1 Close FCV-23-3, 5, 4, 6 5.4.2 Close FCV-23-7, '9 CAUTION:
Overfeeding the S/G s can cause excessive cooldown
(> 75oF/hr)
Cl LOF EMERGENCY PROCED URE N UMB ER 2-0 700040 REVIS ION 0 5-0 SUBSE UENT ACTIONS: (Cont. )
CHECK 5.5 If the motor driven aux fdwtr pp capability is lost, perform the following:
5.5. I Open MV-08-13 (2A) OR MV-08-1 4 (2B)
Stean Supply Valve to aux fdwtr pp.
5.5.2 Control turbine speed with MV-08-3 for the desired rate.
5.5.3 Control feed flow to S/G's with MV-09-11 (2A S/G)
MV-09-12 (2B S/G) 5-6 For manual operation of AFW.
- 5. 6. 1 Es tab lish canmun ications between the control room and AFW station.
5.6.2 If local manual control is needed, OPEN breakers 2-50308 and 2-60320 8 2AB-125VDC bus.
5.6.3 Throttle MV-08-3 to raise 2C aux fd pp discharge pressure to approx 1200 psig.
5.7 If S/G level is < 38% do not exceed 785 GEf.
(Maximum flow rate of 2 elect AFW Pumps)
(Maximum flow rate. of Steam AFW Pumps) 5.8 Check auxiliary feedwater flow utilizing all available indications (flow indicators, flow recorders, S/G levels)
CAUTION:
Do not feed a dry S/G unless both S/G become dry. Then admit fdwtr to only one S/G.
5.9 Observe CST level frequently (1/30 min) 5.10 If condenser vacuum is lost or MSIV s close, take manual control of the atmospheric dumps for S/G pressure control.
LVi EMERGENCY PROC ED URE N UMB ER 2>>0 700040 RE VIS ION 0 5.0 SUBSE UENT ACTIONS: (Cont.)
CHECK 5.11 Ensure that the pressurizer pressure control system is automatically restoring RCS pressure.
5.12 Ensure that the CVCS is restoring pressurizer level, (MAX charging, MIN letdown) ~
NOTE: Any system that is placed in manual, requires more operator attention 5.13 Coordinate operations with Unit 81 to assure sufficient condensate via, 5.13.1 Water treatment plant and/or 5.13.2 City Wtr Str Tk and/or 5.13.3 Unit Fl CST 5.14 Folio~ appropriate procedures for cooldown or return to power. Do not exceed 75oF/hr cooldown rate.
EMERGENCY PROC ED URE N UMB ER 2-0 70004 0 REVIS ION 0 6~0 PURPOSE/DISCUSSION 6.1 This procedure provides instructions to be followed in the event of loss of feedwater flow and/or loss of steam generator level. It is to be used when specific symptoms indicate this condition and the immediate actions of the Reactor Trip/Turbine Trip procedures have been ccmpleted.
N 6.2 Loss of stean generator level results in a reduction in capability of the secondary system to remove the heat generated in the reactor core. Loss of stean generator level results from the inability to supply feedwater in an amount equal to the existing steam demand.
Excessive steam demand, i.e., above feedwater system capability is considered in Emergency O.P. 2-0810040, Main SE ncn Line Break.
6.3 The loss of all feedwater to the steam generator and the subsequent heatup of the Reactor Coolant System will result in saturation conditions at high temperature and pressure in the Reactor Coolant System. This would cause a loss of reactor coolant mass through the PORV's and code safeties and void formations throughout the system. A maximum effort should be directed toward the initiation of feedwater flow to the steam generators- Without feedwater, the steam generators could boil dry within approximately 13 minutes.
6.4 The inability to supply feedwater in the required quantity could result from one or a combination of the following:
6.4-1 Pipe break in the condensate/feedwater system ~
6.4.2 Flowpath blockage due to valve closure or strainer stoppage.
6.4.3 Loss of pumping capacity due to pump trip, loss of AC power, or pump cavitation.
6.4-4 Loss of 2C Auxiliary Feedwater pump remote operating capability-6.5 The following protective functions are provided to prevent loss of heat sink.
a) Reactor trip:
Stean generator low-low level at 39/.
EMERGENCY PROCEDURE NUMBER 2-0700040 REVIS ION 0 6.0 PURPOSE/DISCUSSION: (Cont.)
- 6. 5 (Cont. )
b) Turbine Runback; due to:
- 1. Loss of both heater drain pumps if turbine power is > 92X.
IIORlf
- 2. Loss of feedwater pump
> 60X.
if turbine power is c) AFH Pump Auto-start at 34X steam generator level.
6.6 The action taken for loss of steam generator level is basically the same regardless of cause. That is, to trip the reactor, thereby removing the heat source, and restoring steam generator level with the auxiliary feedwater pumps. This approach is due to the self-sufficient nature of the auxiliary feed system. It, in no way, depends on the normal feedwater systems The auxiliary feed system has the capability to bring the unit to hot shutdown and remain there for a period in excess of 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />, regardless of any single failure in the normal feed system. Three auxiliary feed pumps are available. Wo motor driven pumps, either of which can supply either steam generator and one steam driven pump which can supply either stean generator.
The auxiliary feedwater system ties into each steam generator feed line downstream of the steam generator feed inlet check valve.
Capability exists to feed either steam generator by any auxiliary feed pump. A break in the feed line between the feed line check valve and the steaa generator would result in the loss of that steam generator as a heat sink- Corrective action would be to isolate feed flow to that steam generator and continue maintaining level in the unaffected steam generator. Residual heat can be adequately dissipated in this manner.
The leak must be isolated in any incident involving a break even though the break does not immediately affect the auxiliary feedwater system. The isolation of a leak is necessary to conserve the water available in the condensate storage tank. The leak is isolated by stopping the steam generator feed pumps and condensate pumps. A leak downstream of a steam generator feed line check valve would also require stopping auxiliary feed flow to that steam generator.
LOF EMERGENCY PROCED URE NUMB ER 2-0 700040 REVIS ION 0
- 6. 0 PURPOSE/DISCUSSION: (Cont ~ )
6.7 The Aux feed pumps will auto start approximately 3 minutes following either S/G level dropping below 34X (2/4 logic) ~ Flow is automatically initiated to both steam generators and cannot be terminated for 30 seconds. Bypass switches are provided on RTGB 102 which will prevent pump starts and valve stroke and would be utilized if normal feedwater flow remains or becomes available and is desired.
- 7. 0 REFERENCES 7.1 FSAR, Section 15.2.8 and Section 10.5.3 7.2 Combustion Engineering Emergency Procedure F-EP-9
- 7. 3 C.E- LOF guidelines, CEN>>l 28 7.4 '78%L EP 0700040 Rev. 8 (Unit 1)
('as of Feedwater or Steam Generator Level) 7.5 Draft of NUREG 0799 8 0 RECORDS R UIRED Log Book Entries Applicable chart recorders
- 9. 0 AP PRO VAL Reviewed by the Facility Review Group 19 Approved by Plant Manager 19 Rev ~ Reviewed by FacQ.ity Review Group 19 Approved by Plant Manager 19 "LAST'PAGE" Emergency Procedure 2-0700040 Rev. 0 TOTAL NO. PAGES 14