ML20126K620
| ML20126K620 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 05/21/1985 |
| From: | Quennoz S TOLEDO EDISON CO. |
| To: | |
| References | |
| EP-1202.01, NUDOCS 8507300355 | |
| Download: ML20126K620 (172) | |
Text
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EP 1202.01-Davis-Besse Nuclear Power Station Unit No. 1 anergency PrMme EP 1202.C1 RPS, SFAS, SFRCS TRIP or SG TUBE IUP1URE u INFORMl0N E.lllSm+.77-m' . "1.8
- n. COPY-Record of Approval and Changes ._ ,
Prepared By M. J. Derivan lo/4/g4 j Date . -
-W Subnitted By w _ . /. / '
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- =- 2 Reccrmended By___ .S _ LJ . to /16 / M S DAN W %ts ~
on Approved N/M . (
Quality An-"-"-- Director Date ___ _,_
A; proved By A4p>::> %^-----V so/26/ 34.-
, Plant ManagFr Date ca s .
_ c-W .sicn SRB QA Plant M1 nager No. En.umadaticn Date Approved Date Ipproval Datb
/ AJ - g DEC 121984gA A_r - 6 h b ,
o2- Ac d MAY 11985 /V A. p _
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B507300355 850521 PDR ADOCK 05000346 p PDR
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L EP 1202.010 '
r, (v ' 7 1. SYMPT 0 tis This procedure will be implemented anytime one of_the six below listed conditions exist alone or in combination with the others and recognizes the fact the Safety Features Actuation System (SFAS) or Steam and Feedwater Rupture Control System (SFRCS) may trip with the plant initially in Mode 3 or less. In c'ase of annunciator alarm failure, the procedure may have to be implemented solely on the plant response.
1.1 Reactor trip (also denotes a trip condition exists whether or not an automatic trip has occurred)
- 1. Ala rm: The following annunciator CRD TRIP CONFIRM (8-1-1)
AND
- 2. Plant Response: NI's indicate a rapid decrease in
, neutron flux level SE 1.2 SFAS trip (except Incident Level 1 on CTMT RAD TRIP (5-6-1) 9
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- 1. Ala rms: Any one or more of the following annunciators SFAS CTMT PRESS > 18.4 PSIA TRIP (5-6-2)
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SEAS RC PRESS < 1650 PSIG TRIP (5-6-3) 2E SFAS RC PRESS < 450 PSIG TRIP (5-6-4)
RR SFAS CTMT PRESS > 38.4 PSIA TRIP (5-6-5)
, . . AND
- 2. Plant Response: Plant response indicates a full trip of SFAS actuation Channel 1 AND/OR 2, on any Incident Level (s) except for CTMT RAD TRIP of Incident Level 1.
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2 EP 1202.01.0 0 1.3 SFRCS trip
- 1. Alarm: The following annunciator SFRCS FULL TRIP (8-6-1)
AND
- 2. Plant Response: Plant response indicates a full trip of SFRCS actuation Channel 1 AND/OR 2.
SE 1.4 SG tube rupture larger than the MU capacity exists.
- 1. Alarm: One or more of the following annunciators:
NOTE: Main Steam Line RAD monitors will NOT respond in analyze mode with reactor shutdown.
VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE 1 RAD HI (12-6-3)
MN STM LINE 2 RAD HI (12-6-4)
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AND O'. 2. Plant Response: Pressurizer level still decreasing wita maximum makeup flow and letdown isclated.
SE 1.5 In the judgment of the operator (s), plant conditions indicate this procedure should be implemented, for example:
- 1. Manual reactor trip is required
- 2. During plant heatup or cooldown with SFAS low reactor coolant pressure trips bypassed, SFAS actuation is required.
.6 Another procedure directs Laplementation of this procedure.
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'm 2. AUTOMATIC ACTIONS 2.1 Reactor trip
- 1. All control rods (except Group 8) drop to the bottom, individual and group in-limit lights come on.
- 2. Main turbine trips and all turbine MSVs, CVs, IVs, and ISVs close.
- 3. Turbine bypass valve setpoint transfers from 870 psig at selected header pressure to 1015 psig at individual steam generator (SG) pressure.
- 4. Rapid Feedwater Reduction (RFR) Control actuates to increase main feed pumps (MFPs) to target speed and target positions the main feedwater c ontrol valves and startup feedwater control valves. After 2 minutes or when SG level decreases to low level limits, the Inte-grated Control System (ICS) Oill control MFP speed and startup feedwater control valve to maintain SGs on low level limits.
- 5. If the main generator was initially synchronized to the switchyard and supplying housepower via station auxili-
,_, ary transformer HX11, one of the following two sequences will occur:
- 1) For a generator trip the generator breakers ACB34560 and ACB34561 and the generator field circuit breaker will immediately trip. 13.8 KV buses A and B will fast dead transfer to the startup transformers HX01 or EX02 per the reserve source selector switch settings.
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- 2) For a turbine trip the generator breakers ACB34560 and ACB34561 and the generator field circuit breaker will teip when the generator anti-motoring timer times out (30 seconds) after the turbine trip. 13.8 KV buses A and B will fast dead transfer to the startup transformers EX01 and EX02 per the reserve source selector switch settings.
2.2 SFAS trip
- 1. Equipment is actuated by Incident Level, dependent on the trip parameter (detailed list on Table 2, Tables Tab).
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n 4 EP 1202.01.0 2.3 SFRCS trip
- 1. Equipment is actuated dependent on the trip parameter
, (detailed list on Table 1, Tables Tab).
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- 3. IMMEDIATE OPERATOR ACTION ACTIONS 3.1 If a SG tube rupture has occurred AND the reactor has NOT tripped, go to SGTR Section 8.
IF THE RX HAS TRIPPED Continue with Step 3.2.
3.2 Manually trip the reactor AND Verify rods respond to the trip IF NOT Shutdown the reactor by any available means. Do NOT proceed in this procedure until the reactor is shutdown.
9 3.3 Manually trip the turbine.
3.4 Isolate letdown.
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- 3. IMMEDIATE OPERATOR ACTION DETAILS 3.2 Use either manual reactor trip pushbutton. If the control rods fail to de-energize in response to the RPS trip and the manual trip, perform the steps below in parallel.
3.2.1 Attempt to maintain primary to secondary heat transfer ,
balanced.
- 1. If NFW has run back below reactor power, manually control MFW to match reactor power.
3.2.2 Attempt to manually de-energize the CRDs in the order listed below:
- 1. Momentarily de-energize 480 volt unit subs E2 and F2 simultaneously.
- 2. Manually trip the three reactor trip breakers in the low voltage switchgear rooms.
- 3. Manually de-energize the CRD System by tripping BE211 on E2 AND BF211 on F2.
3.2.3 Attempt to manually shutdown the reactor
- 1. Manually drive control rods in
- 2. Begin emergency boration by shifting MU pump suction to the BWST, initiate maximum MU and letdown, shift the letdown 3-way valve to the CWRT.
3.3 Use the EHC DERGENCY TRIP SYSTEM trip pushbutton.
3.4 If power is available to E11B, isolate letdown with MU2B, letdown isolation valve ,
9R_ l If power is NOT available to E11B, isolate letdown with MU3, letdown line stop valve.
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- 4. SUPPLEMENTARY ACTIONS ACTIONS O
4.1 ELECTRICAL POWER 4.1.1 Verify A A_ND B buses shift to startup transformers AND voltage is indicated on AC distribution buses and go to 4.2.
IF NOT CAUTION 4.1.2: If a Diesel Generator (DG) fails to auto start, do NOT re-energize a 4160 volt bus with a makeup pump breaker closed and MU-19, Seal Injection Controller, in AUTO as damage to the Reactor Coolant Pump (RCP) seals could occur.
4.1.2 Start OR verify auto start AND load (ing) of DG(s) to unpowered essential bus (es) and go to 4.2.
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- 4. SUPPLEMENTARY ACTIONS DETAILS 4.1 ELECTRICAL POWER 4.1.1 On generator faults the transfer will be inunediate.
On turbine trips the transfer will occur on generator anti-motoring timer action, 30 seconds after the turbine trip.
Normally, A bus will transfer to 01 transformer by the closing of HX01A AND opening of HX11A. B bus will transfer to 02 transformer by the closing of HX02B AND opening of HX11B. The actual final lineup is dependent on startup transformer availability and reserve source selector switch lineup. The generator field circuit breaker will also trip open. Verification of bus voltage and continuation in the procedure prior to the 30 second transfer is allowed, however, reverifications after the transfer will be required.
4.1.2 Auto started, non SA Y -( ' 1. DG starts, output breaker closes to bus.
- 1) DG 1, AC101 closes to C1
- 2) DG 2, AD101 elosed to D1
- 2. Bus Loading
- 1) El and F1 re-energize
- 2) Previously running component cooling water (CCW) pump restarts
- 3) Previously running makeup (MU) pump restarts 4)' Previously non-running CCW pump starts about 40 seconds after DG output breaker closes
- 5) Service Water (SW) Pump (s) start about 40 seconds after DG output breaker (s) closes
- 6) Instrument Air Compressor starts when instrument air header pressure decreases to 95 psig. If the Instrument Air Compressor will not start or has no power, dispatch an operator to start the diesel air compressor.
9 EP 1202.01.0 ACTIONS i
4.1.3 If NEITHER DG can be started AND BOTH C1 and D1 are de-energized, THEN Go to AB 1203.28, Loss of AC Bus Power Sources, until an AC power source is regained to C1 OR D1 l
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DETAILS Failed to auto start, non-SA Start the DG and re-energize the 4160 volt bus with the following sequence for each bus that didn't auto start.
- 1. If closed, TRIP the MU pump breaker OR close MU19.
- 2. Press DG start button.
- 3. Adjust / verify DG frequency is 60 Hz and output voltage 4100 to 4300 volts.
NOTE Substep 3: If DG fails to reach ratee speed and voltage at this point, dispatch an operator to attempt to start and load the DG locally per SP 1107.11.
position.
S. Close AC101 (AD101) and verify C1 (D1) bus voltage <
matches DG voltage.
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CAUTION Substep 5: If DG output breaker will NOT close due to a C1 (D1) bus lockout, overheating damage may occur to the engine if left running without cooling water.
- 6. Turn DG 1 (2) SYNC switch 0FF.
Load or verify auto loading of C1 (D1) as follows:
- 1. El (F1) re-energized
- 2. Start one CCW pump per loop
- 3. Start one SW pump per loop
- 4. Verify Instrument Air Compressor starts when instrument air header pressure decreases to 95 psig. If the Instrument Air Compressor will not start, dispatch an operator to start the diesel air compressor.
4.1.3 AB 1203.28 will direct actions for plant stabilization.
When an AC power source is regained to C1 or D1, return to this procedure at Step 4.1.2.
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-O 4.2 INSTRUMENT AIR 4.2.1 Verify an air compressor is running to supply the instrument air header AND instrument air header pressure > 75 PSIG and go to 4.3.
IF NOT 4.2.2 IF_ instrument air header pressure < 75 PSIG OR pressure loss is imminent because no compressor is immediately available, THEN Manually actuate SFRCS on low SG level AND Have an operator hand jack open CC1460, MU pump header -
isolation and go to 4.3.
4.3 NNI POWER 4.3.1 Verify all four NNI power sources are energized and go to 4.4.
IF NOT 4.3.2 For loss of X AC OR DC, perform 4.3.3.
For loss of Y AC OR DC, perform 4.3.4.
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i DETAILS 4.2 INSTRUMENT AIR l 4.2.1 L
Instrument air header pressure is indicated in the Control Room on PI810. Air compressor status will be known from pretrip plant status and previous actions.
4.2.2 This step assumes if the cause of the reactor trip was the loss of instrument air, the steps to regain a compressor were already underway prior to the trip. If the loss of compressors is a result of loss of offsite power and a failure of a D-G to start, step 4.1 directed start of the diesel air compressor. At this point, if the instrument air header pressure is still > 75 psig, the operator will know if a compressor is immediately available or if the SFRCS
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aust be manually actuated.
CC1460, MU pump header isolation, is in CCW Pump hV Room, on a 1\" line directly above door 332.
4.3 NNI POWER NNI power source indicating lights are "0N" for all four power sources Y side X side AC AND DC AC A_ND DC r
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- 1. Manually actuate SFRCS on low SG 1evel
- 2. Use essential powered indicators
- 3. IF loss of NNI X AC only, transfer pressurizer level AND temperature to Y AND Transfer MU tank level to Y and go to 4.4.
- 4. ADDITIONALLY IF loss of NNI X DC
- 1) Manually control pressurizer heaters to maintain RCS pressure consistent for plant conditions.
- 2) Turn off all pressurizer heaters if uncompensated level is below 50".
- 3) Monitor MU tank level on Y powered indicator AR transfer MU pump suction to the BWST if MU tank level decreases to 10".
- 1. Use essential AND X powered indicators
- 2. Transfer BOTH SG pressure selectors to X power
- 4. Continue with 4.4.
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DETAILS 4.3.3
- 2. Panel indicators marked with black dots and the T-SAT indicators are essential powered.
- 3. With initial switch lineup on X indicators, loss of X AC OR DC will cause loss of the pressurizer low level heater interlock and the MU tank low level transfer interlock. If the power loss is to X AC only, the interlocks can be regained by transferring pressurizer level g temperature selector switches to Y and transferring MU tank level to Y. Pressurizer level and MU tank level recorders will not have power but the interlocks will work, i
- 4. On a power loss to X DC manual control of pressurizer' i heaters will be required. The SCR heaters will not
!- -. function at all. Operation of heaters below an I
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uncompensated level of 50 inches may result in operation with the heaters uncovered. The MU pump suction valve, MU3971, must be manually transferred to the BWST st 10" on the Y powered NU tank level indicator since the low level interlock will be lost.
l 4.3.4
- 1. Panel indicators marked with black dots and the T-SAT indicators are essential powered.
- 2. This will transfer X powered signals into the ICS for TBV/AVV pressure control.
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4.4 ICS POWER 4.4.1 Verify ICS AC AND DC power sources are coergized and go to 4.5.
IF NOT 4.4.2 Manually actuate SFRCS on low SG 1evel 4.5 MAKEUP 4.5.1 If one MU pump is running, go to 4.5.0.
OR 4.5.2 If neither MU pump is running, go to 4.5.4.
4.5.3
- 1. Start the second MU pump.
- 2. Verify MU flow is increasing and go to 4.6.
IF NOT INCREASING Continue with Step 3.
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ij DETAILS 4.4 ICS POWER 4.4.1
- 1. Loss of ICS DC indicated by annunciator alarm ICS 24 VDC BUS TRIP (14-1-2.)
- 2. Loss of ICS AC indicated by annunciator alarm ICS/NNI 118 VAC PWR SUPPLY TRBL (14-2-3.)
WIrnout Loss of NNI AC power from NNI power indicating lights.
I 4.4.2 Manually trip SFRCS on low SG 1evel using BOTH SG LVL TRIP buttons.
4.5 MAKEUP bl t!
4.5.3
- 1. Start MU pump with the following sequence:
- 2) Verify auxiliary gear oil pump auto starts.
- 3) Start the MU pump.
- 2. Increased MU flow is indicated by an increasing demand on MU32, MU control valve, and increased MU flow indication. If necessary, MU32 H/A station can be placed in HAND and flow increased manually.
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- 3. If NNI X AC OR DC is lost AND Instrument air pressure is > 65 PSIG THEN Have an operator locally increase MU flow as necessary
. using MU211, the MU32 bypass valve and go to 4.6.
~4.5.4 IF NNI X AC OR DC is lost S
Instrument air pressure is < 20 PSIG THEN Go to Step 5, otherwise continue.
- 1. Close MU19, seal injection controller.
- 2. Start BOTH MU pumps if possible.
- 3. Slowly re-establish seal injection and return MU19, seal injection controller, to AUTO while continuing.
- 4. Verify MU flow is increasing and go to 4.6.
- 5. Start BOTH MU pumps if possible.
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V DETAILS l 3. MU32 will fail as is on loss of NNI X AC and will fail l half open on loss of NNI X DC. If instrument air header pressure is < 65 PSIG, the Auxiliary Building header will be isolated and MU32 will fail open even
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if NNI X AC or DC has been lost. However, since it )
only takes 21 PSIG air pressure to hold MU32 closed, if increased MU flow cannot be verified, it may be necessary to open MU211, the MU32 bypass valve to increase MU flow to help recover pressurizer level.
4.5.4 1
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- 1. Place MU19 H/A station in HAND and run the demand to zero.
- 2. Perform 4.5.3.1 MU pump start sequence.
- 3. Increase total seal injection flow with MU19, seal injection controller, in 5 gpa increments back to the normal setpoint over a 2 minute period.
- 4. Increased MU flow is indicated by an increasing demand on NU32, MU control valve, and increased MU flow indication. If necessary, MU32 H/A station can be placed in HAND and flow increased manually.
- 5. Perform 4.5.3.1 MU pump start sequence. MU19 will be inoperable on loss of NNI X AC or DC or when instrument air header pressure is < 20 PSIG. The MU pumps will have to be started with MU19 as is. MU19 air supply is from the penetration room air header, which does not have a low pressure cut-off valve.
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- 6. Verify MU flow is increasing IF NOT Have an operator locally increase MU flow as necessary using MU211, the MU32 bypass valve and go to 4.6.
4.6 REACTOR SHUTDOWN 4.6.1 Verify all (except APSRs) rods on bottom A_N_D_
Reactor power decreasing on intermediate range and go to 4.7.
IF NOT 4.6.2 Begin RCS boration to a boron value:
- 1. To assure 1% AK/K shutdcwn margin per SP 1103.15, if one rod failed to insert.
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- 2. 21800 ppmB if more than one rod failed to insert.
4.7 TURBINE TRIP 4.7.1 Verify all main turbine stop valves OR control valves are closed and go to 4.8.
IF NOT 4.7.2 Manually trip SFRCS on low SG level and go to 4.9.
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DETAILS
- 6. If instrument air pressure < 65 PSIG, MU32 will fail open allowing increased MU flow even if NNI X AC or DC is also lost. If instrument air pressure > 65 PSIG, MU32 will fail as is on loss of NNI X AC and will fail half open on loss of NNI X DC. MU211, MU32 bypass valve, can be locally throttled to increase MU flow to help recover pressurizer level.
4.6 REACTOR SHUTDOWN 4.6.1 Individual rod zero percent lites "0N" da CRD PI panel.
4.6.2 RCS can be borated by:
[ 1. Shift MU pump suction to the BWST G,, by closing MU3971, MU pump suction 3-way valve SE
- 2. Boric acid additions to the MU tank per GP 1103.04.
4.7 TURBINE TRIP 4.7.1 Zero percent valve position indicated on EHC Panel 1 for the following valves:
MSV-1 CV-1 MSV-2 CV-2 MSV-3 CV-3 MSV-4 CV-4 4.7.2 Manually trip SFRCS on low SG level using BOTH SG LVL TRIP buttons.
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EP 1202.01.2 21 ACTIONS O
4.8 CONDENSATE AND FEEDWATER RESPONSE 2
4.8.1 Stop all but one of the running Condensate Pu:nps as Condensate System flow allows.
4.8.2 g SFRCS isolation has occurred, go to 4.9, otherwise continue 4.8.3 Verify proper OR manually control MFW system response for RFR OR low level limit control on BOTH SGs and go to 4.9.
IF AUTO OR MANUAL CONTROL IS NOT PROPER n
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EP 1202.01.2 22 t I w/
DETAILS 4.8 CONDENSATE AND FEEDWATER RESPONSE 2 4.8.1 Condensate System flow is reduced to prevent a deaerator high level trip. Maximum flow for one Condensate Pump is approximately 3.5 MPPH.
4.8.2 SFRCS isolation is caused by any SFRCS actuation except loss of all RCPs trip. MFW response to SFRCS isolation is covered later in Step 4.10.
4.8.3 Main Feedwater (MFW) system response is dependent on initial SG level and feedwater H/A control station mode (AUTO or HAND).
- 1) RFR increases MFPs to target speed AND Closes MFW control valves AND Startup feedwater control valves.
- 3) RFR transfers all valves to level / flow error correction after 2.5 minutes OR individual loop valves to level / flow error correction when respective SG goes on low level limit.
- 4) MFP target speed is modified by the larger SG level error signal if one SG is on low level limit.
- 6) If running, the operator shuts down second MFP.
(If applicable, shutdown MFP on the side with SGTR.)
L pressure.
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x /~ 2) The controls in AUTO will respond to ICS flow and level errors.
I EP 1202.01.0 23 ACTIONS O
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O 4.8.4 H FW flow will NOT decrease to a SG AND Same SG 1evel is increasing THEN Trip BOTH MFPTs and go to 4.9
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EP 1202.01 .0 24 r~(%,
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DETAILS
- 3) The operator controls the FW control stations that are in HAND.
- 5) If running, the operator shuts down second MFP.
(If applicable, shutdown MFP on the side with SGTR.)
- 1) RFR increases MFP to target speed.
- 2) MEW valves respond to SG level error.
'T' 1) Place MFP H/A station in HAND and increases MFP speed to maintain MFP discharge pressure > SG pressure.
- 2) The controls in AUTO will respond ".o ICS flow and level errors.
- 3) The operator controls the FW centrol stations that are in HAND. ;
4.8.4 In any initial configuration or SG 1evel, after a reactor trip, proper AUTO OR MANUAL W control should never show W flow NOT decreasing AND SG level increasing at the same time. MFPT trip is required to prevent SG overfill.
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l 4.9 SFAS -
4.9.1 Verify there has NOT been an SFAS actuation on Actuation Channel 1 AND/0R Actuation Channel 2 and go to 4.10.
IF SFAS HAS ACTUATED I x
0 4.9.2 Take the actions below for all trips present as directed.
4.9.3 RCS 1650 PSIC TRIP I. Verify proper SFAS Incident Level 1 and 2 actuation.
- 2. Close RC11, PORV block valve.
- 3. Close RC10, pressurizer spray block valve.
- 4. E subcooled margin is NE adequate.
THEN Trip all RCPs.
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DETAILS 4.9 SFAS 4.9.1 SFAS actuation is verified by at least one of the following annunciator alarms indicating at least one SFAS channel tripped.
SFAS CTMT PRESS > 18.4 PSIA TRIP (5-6-2)
QR SFAS RC PRESS < 1650 PSIG TRIP (5-6-3)
QR SFAS RC PRESS < 450 PSIG TRIP (5-6-4)
QR SFAS CTMT PRESS > 38.4 PSIA TRIP (5-6-5)
/~ AND Plant response indications on the SFAS panels confirm an SFAS actuation.
NOTE: CTMT RAD TRIP (5-6-1) of Incident Level 1, when it is the only trip present, is not within the scope of this procedure.
- 1. SFAS incident level response should be verified in accordance with Table 2, Tables Tab.
- 2. RC11 powered from E16B.
- 3. RC10 powered from EllA.
- 4. Adequate subcooling margin exists when the TSAT meters 1l indicate 2 20*F. If NEITHER TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line.
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27 EP 1202.01.0
,. ACTIONS
- 5. Insure MU3971, MU pump suction valve shifts to the BWST if MU Tank level decreases to 10 inches.
- 6. Verify the HPI system is operating properly per specific rules 1 AND 2.
IF NOT Refer to the SAD to assist in getting the HPI system operating.
- 1. Verify proper SFAS Incident Level 3 actuation.
- 2. IF DG IS HQI carrying its bus, stop both MU pumps.
If DG is carrying its bus, verify the MU pump trips O
when the respective LPI pump starts.
- 3. F the LPI system is not operating properly, THEN Refer to the SAD to assist in getting the LPI system operating.
- 4. IF RCS pressure decreases to the point where LPI flow is observed, THEN Go to Section 10, Large LOCA.
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.Y) DETAILS i
- 5. MU3971, MU pump suction valve will auto shift (CLOSE) to the BWST at a MU tank level of 10 inches. If the valve doesn't auto shift within 45 seconds of reaching 10 inches, the MU pumps will trip. Suction can be manually shifted by closing MU3971. MU3971 powered from E11D.
- 6. Specific rules 1 and 2, in Specific Rules Tab, requires both HPI pumps running with balanced flow and injection on all four lines. HPI SAD may help locate the cause of the HPI system failure if the cause is not known.
- 1. SFAS incident level response should be verified in accordance with Table 2, Tables Tab.
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- 2. This is a large LOCA. MU, seal injection, and seal return are isolated by SFAS. MU pumps are not needed (4) v and should be stopped. If this is concurrent with a loss of electrical power to essential buses such that the DG are carrying the loads, the MU pumps must trip when the LPI pumps start to prevent DG overload.
- 4. IPI flow is an indication of a major LOCA. Section 10 provides instructions for long term core cooling following a major LOCA.
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ACTIONS O
4.9.5 CTMT 18.4 PSIA TRIP
- 1. Verify proper SFAS Incident Level 1, 2, and 3 actuation.
CAUTION: If an SFAS signal to some ESF equipment is BLOCKED (i.e. ,
overridden) that equipment is incapable of responding to either subsequent automatic actuation signal or the system-level manual actuate (TRIP) pushbuttons. Before an operator BLOCKS any SFAS signal, he must assure that the safety function of that equipment is no longer needed. Afterward, the operator is totally responsible for the proper operation of that equipment, including reactuation, if required, until the BLOCK is removed.
- 2. IF RCS pressure remains above the SFAS 450 PSIG TRIP AND No seismic event has occurred, BLOCK and reopen the following valves:
30 EP 1202.01.0 (V 3 DETAILS 4.9.5 CTMT 18.4 PSIA TRIP
- 1. SFAS incident level response should be verified in accordance with Table 2, Tables Tab.
NOTE: Reactuation, subsequent to a BLOCK, can be accomplished two ways. First, at the equipment level, BLOCKED equipment will respond to the individual control switches for that piece of equipment.
Second, at the system level, operation of the system-level RESET pushbutton will clear any output logic BLOCKS in the system (output logic BLOCKS are the BLOCK switches next to the SAM lights and on the output modules). The equipment will then respond to the system-level manual actuate (TRIP) pushbutton and to automatic actuation signals.
- 2. CCW to the MU pump header should be returned to service to support MU pump operation. MU2A and MU3 are reopened to restore the letdown lineup. Letdown is still isolated with MU2B. If a loss of instrument air has -~
occurred, CTMT isolation valves should NOT be overridden to the non-SA position since there is no assurance they could be later placed in the SA position if needed.
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RCS pressure remains above the SFAS 450 PSIG TRIP AND Instrument air has NOT been lost THEN BLOCK and reopen the following valves.
- 1) MU33, RCS MU isolation
- 2) MU66A thru MU66D, RCP seal injection isolations
- 3) MU38, RCP seal return isolation
- 4) MU59A thru MU59D, RCP seal return isolations 4.9.6 CThT 38.4 PSIA TRIP
- 1. Verify proper SFAS Incident Level 4 actuation 4.10 SFRCS 4.10.1 Verify there has NOT been an SFRCS actuation on Actuation Channel 1 AND/OR Actuation Channel 2 and go to to I4.11.
IF SFRCS HAS ACTUA'17.D 4.10.2
- 1. Verify proper SFRCS actuation for the trip parameters present.
32 EP 1202.01.0 m
I >
v DETAILS l 3. RCS MU should be returned to service and with RCS pressure greater than 1650 psig operated per specific rule 1, Specific Rules Tab.
i Seal injection controller, MU19 should be closed and then l RCP seal injection and seal return should be returned L to service to assure long term seal integrity even if RCPs are off.
If a loss of instrument air has occurred, CTMT isolation valves should NOT be overridden to the non-SA position since there is no assurance they could be later placed in the SA position if needed.
1 l
t 4.9.6 CTMT 38.4 PSIA TRIP l
- 1. SFAS incident level response should be verified in accordance with Table 2, Tables Tab.
l 4.10 SFRCS I 4.10.1 SFRCS actuation is confirmed by annucciator alarm SFRCS FULL
! TRIP (8-6-1)
A_ND Plant response indications confirm an SFRCS actuation.
4.10.2
- 1. SFRCS response should be verified in accordance with Table 1, Tables Tab. Trip parameters are indicated by*
the following annunciator alarms:
SFRCS CH 1 (2) DP HALF / FULL TRIP (12-1-3(4))
SFRCS CH 1 (2) SG LVL HALF / FULL TRIP (12-2-3(4))
SFRCS CH 1 (2) MN STM LO PRESS TRIP (12-5-3(4))
RCP MNTR ALL OFF HALF / FULL TRIP (5-2-9)
33 EP 1202.01.0 ACTIONS 0
- 3. IF the AFW system is not operating properly, THEN Refer to the SAD to assist in getting the AFW system operating.
4.11 SUBC00 LING 4.11.1 Verify adequate subcooling margin exists and go to 4.12.
IF NOT 4.11.2 Go to lack of adequate subcooling margin section 5.
~
4.12 OVERHEATING 4.12.1 Verify adequate primary to secon 4ary heat transfer exists and go to 4.13.
IF NOT 4.12.2 Go to lack of heat transfer section 6.
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34 EP 1202.01.1 O
DETAILS
- 2. See specific rule 3, Specific Rules Tab.
- 3. AW SAD may help locate the cause of the AW system failure if the cause is not known.
4.11 SUBC00 LING Adequate subcooling margin exists when the TSAT meters indicate 2 1l 20*F. If NEITHER TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line.
4.12 OVERHEATING Adequate primary to accondary heat transfer exists when the RCS pressure acd temperature and SG pressure combinaticas, on the P/T display or manual plot show the following trends:
- 1. Plant la stable in or approaching the post trip target box, 0, R_ .
- 2. Plant is stable outside the post trip target box, AND Tc and SG pressure are coupled, indicating heat transfer to SG. Coupled means Tc and TSAT SG are about the same value.
Inadequate primary to secondary heat transfer exists when RCS temperature is increasing AND SG pressure is constant or decreasing.
/
35 EP 1202.01.0 ACTIONS 4.13 OVERC00 LING 4.13.1 Verify primary to secondary heat transfer is NOT excessive and go to 4.14.
IF EXCESSIVE 4.13.2 Go to excessive heat transfer section 7.
b O
4.14 SG TUBE RUPTURE 4.14.1 Verify MS line AND/0R vacuum system discharge radiation monitors are NOT alarming and go to 4.15.
IF ALARMING 4.14.2 Go to SG tube rupture section 8.7.
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36 EP 1202.01.0 m
DETAILS 4.13 OVERC00 LING Primary to secondary heat transfer is NE excessive when the RCS pressure and temperature and SG pressure combinations, on the P/T display or manual plot show the following trends:
- 1. Plant is stable in or approaching the post trip target box, SE
- 2. Plant is stable outside the post trip target box, AND SG pressure is above the steam pressure limit of 960 psig.
Primary to secondary heat transfer is excessive when a secondary ~
side malfunction is causing RCS temperature to decrease due to SG
- f. pressure falling below the steam pressure limit of 960 psig.
Significant HPI cooling can cause RCS temperature to decrease with SG pressure following the temperature decrease until it is belcw the steam pressure limit, but this condition is NOT a symptom of excessive primary to secondary heat transfer.
4.14 SG TUBE RUPTURE SG tube rupture should cause alarm of at least one of the following annunciators:
NOTE: Main steam line RAD monitors will NOT respond in analyze mode with reactor shutdown.
VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE 1 RAD HI (12-6-3)
MN STM LINE 2 RAD HI (12-6-4) h
.l 37 EP 1202.01.0 ACTIONS 9
4.15 The plant is stable in a safe, subcooled condition with proper primary to secondary heat transfer and no major primary or secondary boundry failures. Transfer to another procedure at this point will be under the direction of the Shift Supervisor with the following additional guidance:
- 1. Notify the STA
- 2. Check Emergency Plan Activation EI 1300.01 to determine if emergency action levels have been exceeded and proceed with Emergency Plan activities in parallel with operational activities.
- 3. If the reactor tripped with no additional failures, go to PP 1102.03, Trip Recovery.
- 4. If loss of power to A and/or B bus has occurred, go to AB 1203.28, Loss of AC Bus Power Sources, for -
restoration of normal bits power
- 5. If loss of an NNI power source has occurred, go to AB 1203.41, Loss of NNI Power.
- 7. If a loss of instrument air has occurred, go to AB 1203.36, Loss of Instrument Air, for additional guidance.
- 8. If an SFAS actuation has occurred due to a LOCA and the subcooling margin is being maintained with HPI maintain-ing pressurizer level, go to Section 13, Solid Cooldown or Pressurizer Recovery.
- 10. If an SFRCS actuation has occurred, go to PP 1102.03, Trip Recovery.
- 11. If additional failures occurred and have been corrected by the above procedures, go to PP 1102.03, Trip Recovery.
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3.
d 38 EP 1202.01.0 !
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t 40 EP 1202.01.0 1
- 5. LACK OF ADEQUATE SUBC00 LING MARGIN -
ACTIONS ACTIONS FOR TREATMENT OF LACK OF SUBCOOLING MARGIN 5.1 Trip all RCPs.
5.2 Actuate AND control MU/HPI per specific rules 1 and 2.
5.3 Verify proper SFRCS actuation for the loss of 4 RCP trip.
AND Verify proper SG level control by AIV per Specific Rules 1 and 3.
5.4 Check for overcooling 5.4.1 Verify primary to secondary heat transfer is NOT excessive.
II EXCESSIVE 5.4.2 Go to excessive heat transfer section 7.
5.5 Isolate possible RCS leaks.
5.5.1 Place RC2A, PORV control switch in CLOSE AND check closed RC11, PORV block valve.
5.5.2 Check closed MU2B, letdown isolation valve.
5.5.3 Check closed RC2, pressurizer spray valve AND RCIO, pressuri-zer spray block valve.
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41 EP 1202.01.0 p 5. LACK OF ADEQUATE SUBC00 LING MARGIN DETAILS ACTIONS FOR TREATMENT OF LACK OF SUBC00 LING MARGIN 5.2 Specific rules 1 and 2 are contained in the Specific Rules Tab.
5.3 SFRCS response should be verified in accordance with Table 1, Tables Tab and annunciator alarms SFRCS FULL TRIP (8-6-1) and RCP MNTR ALL OFF HALF / FULL TRIP (5-2-9.) At this point there may have already been an SFRCS trip on other trip parameters.
SG 1evel should be controlled per specific rules 1 and 3.
See Specific Rules Tab.
5.4 Primary to secondary heat transfer is NOT excessive when the RCS pressure and temperature and SG pressure combinations, on the P/T display or manual plot show the following trends:
- 1. Plant is stable in or approaching the post trip target box,
/0 OR
- 2. Plant is stable outside the post trip target box, Ay SG pressure is above the steam pressure limit of 960 psig.
Primary to secondary heat transfer is excessive when a secondary side malfunction is causing RCS temperature to decrease due to SG pressure falling below the steam pressure limit 2f 960 psig.
Significant HPI cooling can cause RCS temperature to decrease with SG pressure following the temperature decrease until it is below the steam pressure limit, but this condition is NOT a symptom of excessive primary to secondary heat transfer.
t%.
42 EP 1202.01.0 ACTIONS I
5.5.4 Close RC239A @ RC239B, pressur?zer sample isolations. i 5.5.5 Check closed RC4608A @ RC4608B, loop 1 high point vents.
5.5.6 Check closed RC4610A AND RC4610B, loop 2 high point vents.
5.6 Check subcooling 5.6.1 E subcooling margin has been established (see Details)
THEN 5.6.2 Go to step 5.12.
l l
5.7 Check for inadequate core cooling. _
5.7.1 g the incore T/C's indicate superheated conditions exist THEN 5.7.2 Go to ICC section 9.
5.8 Check heat transfer conditions are available in BOTH SGs.
5.8.1 g there are conditions for primary to secondary heat transfer available in BOTH SGs, THEN 5.8.2 Go to Section 11, RCS Saturated SG Removing Heat.
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43 EP 1202.01.1
. rD
'U DETAILS 5.6 Adequate subcooling margin exists when the TSAT meters indicate 2 1l 20*F. If NEITHER TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line.
It may be necessary to wait, while monitoring plant response, to make this determination. As long as ICC, loss of heat transfer conditions in one or both SG's or CF tank emptying do not exist, it is permissable to allow time for recovery of subcooling margin.
5.7 The normal temperature inputs to the TSAT meters are the wide range Th's. On rapid pressure decrease, due to the response time of the temperature detectors, they may indicate superheated conditions on
,- the TSAT meters when the RCS is actually saturated. This will be
((
,4 indicated by a negative value being displayed and the NEG MARGIN light will be on. The existance of superheated conditions should be verified, prior to proceeding to Section 9, by selecting INCORE as the TSAT meter temperature input and rotating the INCORE TEM *ERATURE selector switch through all positions while monitoring the TSAT meter. This should be done on BOTH channels if both are available. If BOTH channels are available, inadequate core ccoling will exist if five or more properly working incore detectors show superheated :onditions (negative value displayed). If only one channel is available, inadequate core cooling will exist if three or more properly working incore detectors show superheated conditions (negative value displayed).
5.8 Check heat transfer conditions are available in BOTH SGs 5.8.1 Primary to secondary heat transfer conditions are indicated by Tc and SG pressure being coupled. Coupled means Tc and TSAT SG are about the same value. Significant HPI cooling may be causing reverse heat transfer but the conditions for heat transfer still exist.
Inadequate primary to secondary heat transfer conditions exist when RCS temperature is increasing AND SG pressure is constant or decreasing. Tc and TSAT SG will be uncoupled.
5.8.2 The RCS is saturated. A small RCS break is indicated.
.' Cooldown with SGs can be performed while KPI maintains RCS
, inventory.
44 EP 1202.01.0 ACTIONS 5.9 Loss of heat transfer conditions in ONE SG 5.9.1 IF there are primary to secondary heat transfer conditions in ONLY ONE SG, THEN 5.9.2 Go to lack of heat transfer section 6.
5.10 Check for major LOCA 5.10.1 g the CF tanks have emptied, THEN 5.10.2 Go to Section 10, Large LOCA.
5.11 Go to lack of heat transfer section 6. )
ADEQUATE SUBC00 LING MARGIN HAS BEEN ESTABLISHED 5.12 If possible, restart RCPs.
5.12.1 IF A OR B bus is energized AND NNI X AC AND DC are energized THEN If possible restart a minimum of one RC pump in each loop and go to step 5.13.
M 5.12.2 IF A AND B bus are de-energized NNI X AC OR DC are de-energized TIDLN Begin steps to regain A OR B bus AND/0R NNI X AC AND DC in parallel with proceeding with steps below.
45 EP 1202.01.0 im U
DETAILS I
l 1 5.10.2 The CF Tanks emptying is an indication of a major LOCA.
Section 10 provides instructions for long term core cooling following a major LOCA. DO NOT go to lack of heat transfer section 6. Primary to secondary heat transfer will be lost' and cannot be regained.
l l
() ADEQUATE SUBC00 LING MARGIN HAS BEEN ESTABLISHED 5.12 If possible, restart RCPs.
5.12.1 Restart a minimum of one RC pump in each loop. Normal interlocks apply, if necessary refer to SP 1103.06, RC Pump Operating Procedure. RCP 2-2 is preferred but forced flow in any pump combination is desired at this point. Start as many RCPs as plant conditions allow.
5.12.2 Refer to AB 1203.23, Loss of AC Bus Power Sources, for restoration of in-house bus power.
Refer to AB 1203.41, Loss of NNI Power, and SP 1105.06, NNI Operating Procedure, for restoration of NNI power. Unless absolutely necessary RCPs should not be restarted without seal injection and seal instrumentation and alarms.
46 EP 1202.01.0
. O ACTIONS 5.13 Check for overheating.
5.13.1 Verify adequate primary to secondary heat transfer exists.
IF NOT 5.13.2 Go to lack of heat transfer section 6.
5.14 Check for overcooling. .
5.14.1 Verify primary to secondary heat transfer is NOT excessive.
IF EXCESSIVE 5.14.2 Go to excessive heat transfer section 7.
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47 EP 1202.01.0
[fVI ,
.\j i 1
DETAILS 5.13 Adequate primary to secondary heat transfer exists when the RCS pressure-and temperature and SG pressure combinations, on the P/T display or manual plot show the following trends:
- 1. Plant is stable in or approaching the post trip target box, SE
- 2. . Plant is stable outside the post trip target box, I
AND l f Tc and SG pressure are coupled, indicating heat transfer to SG. Coupled means Tc and TSAT SG are about the same f value.
Inadequate primary to secondary heat transfer exists when RCS
. temperature is increasing AND SG pressure is constant or decreasing.
5.14 Primary to secondary heat transfer is NOT excessive when the RCS f/
- pressure and temperature and SG pressure combinations, on the P/T 1 display or manual plot show the following trends
- 1. Plant is stable in or approaching the post trip target box, SE
- 2. Plant is stable outside the post trip target box, AND SG pressure is above the steam pressure limit of 960 psig.
. Primary to secondary heat transfer is excessive when a secondary side malfunction is causing RCS temperature to decrease due to SG pressure falling below the steam pressure limit of 960 psig.
Significant HPI cooling can cause RCS temperature to decrease with SG pressure following.the temperature decrease until it is below the steam pressure limit, but this condition is NOT a symptom of excessive primary to secondary heat transfer.
4
48 EP 1202.01.0 ACTIONS 0
5.15 Check for SG tube rupture.
5.15.1 Verify MS line AND/0R vacuum system dischacge radiation monitors are NOT alarming.
IF ALARMING 5.15.2 Go to SG tube rupture section 8.7.
5.16 Go to Section 13, Solid Cooldown or Pressurizer Recovery.
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9
49 EP 1202.01.0
. ,,. s .
DETAILS 5.15 SG tube rupture should cause alarm of at least one of the following annunciators:
NOTE: Main Steam line RAD monitors will NQT respond in analyze mode with reactor shutdown.
VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE I RAD HI (l'2-6-3)
MN STM LINE 2 RAD HI (12-6-4) 5.16 The RCS is subcooled. A small break is indicated. It may or may not be isolated. If MU/HPI are still being used to maintain RCS pressure and pressurizer level, it is NOT isolated. There may or may not be a bubble in the pressurizer. Section 13 provides instructions for these conditions.
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1 EP 1202.01.1 '
SECTION 5: LACK OF ADEQUATE SUBCOOUNG MARGIN l
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51 EP 1202.01.0 6.0 LACK OF HEAT TRANSFER ACTIONS O
ACTIONS FOR TREATMENT OF LACK OF PRIMARY TO SECONDARY HEAT TRANSFER IN EITHER SG 6.1 Determine main OR aux feedwater availability 6.1.1 IF main OR auxiliary feedwater is available to EITHER SG, go to Step 6.7 IF NOT 6.1.2 Continue with Step 6.2.
LACK OF FEEDWATER EITHER SUBC00 LED OR SATURATED 6.2 Establish MU/HPI cooling 6.2.1 Actuate AND control MU/HPI per specific rules 1 and 2.
6.2.2 De-energize all pressurizer heaters.
6.2.3 Open RCII, PORV block valve.
6.2.4 Open RC2A, PORV.
6.2.5 Open RC4608A AND RC4608B, loop I high point vent isolations.
6.2.6 Open RC4610A AND RC4610B, loop 2 high point vent isolations.
6.2.7 Open RC239A AND RC200, pressurizer high point vent line isolations.
6.2.8 While continuing in this section, IJF_ subcooling margin is lost, trip all RCPs AND continue in this section. Do NE reroute to Section 5, Lack of Adequate Subcooling Margin, at this time.
6.2.9 While continuing in this section, E SFAS actuation on RCS pressure < 1650 PSIG occurs, verify proper SFAS Incident Level 1 and 2 actuation.
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52 EP 1202.01.0 6.0 LACK OF HEAT TRANSFER g 9,
\h DETAILS ACTIONS FOR TREATMENT OF LACK OF PRIMARY TO SECONDARY HEAT TRANSFER IN EITHER SG 6.1 Attempts to regain main or auxiliary feedwater may continue as long as one SG is NOT dry. With main and aux feedwater NOT available, a SG is considered dry when its startup level is < 8" OR its pressure is < 960 PSIG and decreasing. When BOTH SG's are dry, you must procee:d with Step 6.2. Attempts to regain main or auxiliary feedw. ster may continue in parallel with other actions as time pe rmi ts .
LACK OF FEEDWATER EITHER SUBC00 LED OR SATURATED 6.2 Establish MU/HPI cooling.
6.2.1 Specific rules 1 and 2 are contained in the Specific Rules Tab.
l l
[
) 6.2.4 The PORV can be locked open with its control switch.
1 6.2.8 Actions of Section 5, Lack of Adeq24te Subcooling Margin, are not appropriate for this plant condition at this time.
6.2.9 SFAS incident level response should be verified in accordance with Table 2, Tables Tab.
r
53 EP 1202.01.0 ACTIONS O
6.2.9 Continuously monitor for inadequate core cooling.
6.2.9.1. E the incore T/C's indicate superheated conditions exist THEN 6.2.9.2. Go to ICC section 9.
6.3 Determine SWP availability 6.3.1 E the SWP is available, line up the SWP for operation with suction from the CST.
E D2 bus has to be re-energized to support SWP operation, O
refer to Attachment 2 to re-energize D2 AND Continue with Step 6.4 while performing these lineups.
6.3.2 IF the S WP is NOT available, go to Section 12, MU/HPI Cooling.
6.4 Pick the best SG to feed.
6.4.1 To feed SG 1 go to Step 6.5.
E 6.4.2 To feed SG 2 go to Step 6.6.
6.5 To feed SG 1 6.5.1 BLOCK AND open FW612, SG 1 main feedwater stop valve.
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h 54 EP 1202.01.0 N,
(
%) '
DETAILS 6.2.9. The normal temperature inputs to the TSAT meters are the wide range Th's. On rapid pressure decrease, due to the response time of the temperature detectors, they may indicate superheated conditions on the TSAT meters when the RCS is actually saturated. This will be indicated by a negative value being displayed and the NEG MARGIN light will be on. The existance of superheated conditions should be verified, prior to proceeding to Section 9, by selecting INCORE as the TSAT meter temperature input and rotating the INCORE TEMPERATURE selector switch through all positions while monitoring the TSAT meter. This should be done on BOTH channels if both are available. If BOTH channels are available, inadequate core cooling will exist if five or more properly working incore detectors show superheated conditions (negative value displayed). If only one channel is available, inadequate core cooling will exist if three or more properly working incore detectors show superheated conditions (negative value displayed).
6.3 Determine SUFP availability. _
6.3.1 SUFP availability includes the availability of.TPCW for cooling. The SUFP should be lined up for suction from the y
[v_,
CST per SP 1106.27, Startup Feed Pump. l 6.3.2 Attachment 2 is in Attachments Tab.
6.4 To determine which SG to feed consider SG tube integrity, secondary side integrity, instrumentation and controls availability, and electrical power availability. If E11C is NOT energized, feed SG 2 since FW612 to SG 1 isn't powered. If F11D is NOT energized, feed SG 1 since FW601 to SG 2 isn't powered.
6.5 To feed SG 1 6.5.1 SFRCS trip is BLOCKED using the SFAS BLOCK buttee.
6
55 EP 1202.01.0 ACTIONS 0
6.5.2 IF ICS AC OR DC is lost 0.3 Instrument air pressure is < 65 PSIG THEN Go to Step 6.5.5, otherwise continue.
6.5.3 Place loop 1 SU W valve H/A station in HAND AND run the demand to minimum.
6.5.4 OVERRIDE the SFRCS trip to loop 1 SU W valve and go to Step 6.5.6 6.5.5 Dispatch an operator to take local manual control of loop T SU W valve AND establish continuous communication with the Control Room.
e CAUTION 6.5.6: TPCW must be available to cool the SUFP.
6.5.6 WHEN the SUFP is lined up, start the SUFP.
6.5.7 Feed SG 1 through loop 1 SU W valve at the maximum rate allowed by the following limits. Keep SUFP discharge pressure > 900 PSIG. Keep SUFP running current < 44 amps.
6.5.8 IF this flowpath is successful, go to Step 6.7.
03 I.F this flowpath is NE successful, dispatch an operator to verify the SUFP lineup by performing Attachment 1.
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56 EP 1202.01.0 DETAILS 6.5.2 Loss of ICS DC indicated by annunciator alarm "ICS 24 VDC BUS TRIP" (14-1-2.)
Loss of ICS AC indicated by annunciator alarm "ICS/NNI 118 AC PWR SUPPLY TRBL" (14-2-3.)
WITHOUT Loss of NNI AC power from NNI power indicating lights Loss of instrument air indicated on PI810.
6.5.3 Loop 1 SU FW valve H/A station is ICS-33B.
6.5.4 SERCS trip is OVERRIDDEN using the pushbuttons on the back wall of the cabinet room.
6.5.5 To take local manual control of the SU FW valve, free-wheeI' the handwheel until the hole in the shaft sleeve lines up with the hole in the stem, insert the pin, and open the diaphragm equilizing valve. The valve can then be positioned G, with the handwheel.
6.5.7 Feed is established via manual control from the H/A station or local manual control of the valve. As the SG repressurizes, increased opening of the SU FW valve will be necessary to maintain flow.
6.5.8 Indications of a successful flowpath are the SG repressurizing to the SG safety valve setpoint (1050 PSIG). (This could take about seven minutes starting from zero pressure.) SUFP flow to SG 1 indicated on computer point F866. Tc decreasing.
SG level eventually increasing.
/\ ,
/
I 57 EP 1202.01.0 ACTIONS 6.5.9 IF the SUFP lineup is correct AND this flowpath remains unsuccessful THEN Close W612 AND go to Step 6.6 to feed SG 2 UNLESS An attempt to feed SG 2 has already been made THEN Go to Section 12, MU/HPI Cooling.
6.6 To feed SG 2 6.6.1 BLOCK AND open W601, SG 2 main feedwater stop valve.
6.6.2 IF ICS AC OR DC is lost OR O
Instrument air pressure is < 65 PSIG THEN Go to Step 6.6.5, otherwise continue.
6.6.3 Place loop 2 SU W valve H/A station in HAND AND run the demand to minimum.
6.6.4 OVERRIDE the SFRCS trip to loop 2 SU W valve and go to Step 6.6.6.
6.6.5 Dispatch an operator to take local manual control of loop 2 SU W valve AND establish continuous communication with the Control Room I
, 58 EP 1202.01.0 i
s DETAILS 6.5.9 If feedwater is not available to either SG, there is no heat transfer to either SG. Natural circulation does not exist and cannot be induced due to the total loss of feedwater.
The SG's are dry and the core must be cooled by MU/HPI cooling.
6.6 To feed SG 2 6.6.1 SFRCS trip is BLOCKED using the SFAS BLOCK button.
6.6.2 Loss of ICS DC indicated by annunciator alarm "ICS 24 VDC s BUS TRIP" (14-1-2.) *
- Loss of ICS AC indicated by annunciator alarm "ICS/NNI 118 VAC PWR SUPPLY TRBL" (14-2-3.)
WITHOUT Loss of NNI AC power from NNI power indicating lights.
Loss of instrument air indicated on PI810.
6.6.3 Loop 2 SU FW valve H/A station is ICS-33A.
6.6.4 SFRCS trip is OVERRIDDEN using the pushbuttons on the back wall of the cabinet room.
6.6.5 To take local manual control of the SU FW valve, free-wheel the handwheel until the hole in the shaft sleeve lines up with the hole in the stem, insert the pin, and open the j diaphragm equalizing valve. The valve can then be positioned ,
with the handwheel. l I
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59 EP 1202.01.1 ACTIONS O
CAUTION 6.6.6: TPCW must be available to cool the SUFP.
6.6.6 WHEN the SUFP is lined up, start the SUFP.
6.6.7 Feed SG 2 through loop 2 SU FW valve at the maximum rate allowed by the following limits. Keep SUFP discharge pressure > 900 PSIG. Keep SUFP running current < 44 amps.
l 6.6.8 E this flowpath is successful, go to Step 6.7 O_.R_
1 g this flowpath is yN successful, dispatch an operator to l verify the SUFP lineup by performing Attachment 1.
6.6.9 IJF the SUFP lineup is correct AND this flowpath remains unsuccessful THEN Close FW601 AND go to Step 6.5 to feed SG 1 UNIISS An attempt to feed SG 1 has already been made THEN Go to Section 12, MU/HPI Cooling.
FEEDWATER HAS BEEN RE-ESTABLISHED TO AT LEAST ONE SG BUT THERE IS NO SG HEAT TRANSFER 6.7 Maintain appro}.iate SG level per specific rule 3.
1l 6.8 E subcooling margin is being maintained THEN
\
Go to @ attempt to maintain a one running RCP combination, i
i nreferrably in the loop being fed by the SUFP.
6.9 Check for major LOCA 6.9.1 E the CF tanks have emptied, go to Section 10, Large LOCA.
IF NOT 6.9.2 Continue with Step 6.10.
60 EP 1202.01 0
?
v DETAILS I
6.6.7 Feed is established via manual control from the H/A station or local manual control of the valve. As the SG repressurizes increased opening of the SU W valve will be necessary to l l
maintain flow.
6.6.8 Indications of a successful flowpath are the SG repressurizing to the SG safety valve setpoint (1050 PSIG). (This could take about seven minutes starting from zero pressure.) SUFP
! flow to SG 2 indicated on computer point F868. Tc decreasing.
1 SG level eventually increasing.
i 6.6.9 If feedwaterr is not available to either SG, there is no heat
- transfer to either SG. Natural circulation does not exist and cannot be induced due to the total loss of feedwater. -
The SG's are dry and the core must be cooled by MU/HPI 4 cooling.
. J
, FEEDWATER HAS BEEN RE-ESTABLISHED TO AT I. EAST ONE SG
- BUT THERE IS NO SG HEAT TRANSFER 6.7 Specific rule 3 is contained in the Specific Rules Tab.
6.8 Attempt to maintain one RCP running if subcooling margin exists.
If pump vibration reaches 30 mils start another pump and trip the ,
running pump. If all RCPs have been run and reached 30 mils ;
vibration, RCPs may be stopped.
t 6.9 The CF tanks emptying is an indication of a major LOCA. Section 10 i gives instructions for long term cooling following a major LOCA.
Primary to secondary heat transfer is lost and cannot be regained. ;
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61 EP 1202.01.0 ACTIONS 0
6.10 If necessary, open the PORV.
6.10.1 E a,t any time while attempting to regain heat transfer to the SG, the RC pressure increases to 2400 PSIG THEN 6.10.2 Open RC2A, PORV A_ND RC11, PORV block, if closed A_ND Allow the PORV to remain open until RC pressure decreases to 5 100 PSI above the SG pressure.
6.10.3 Continue with Step 6.11.
6.11 On each SG with the proper water level, lower SG pressure while maintaining SG 1evel, using the turbine bypass valves (TBV) or atmospheric vent valves (AVV) until secondary TSAT is 40 to 60*F ~
lower than incore T/C temperature AND maintain this SG pressure.
E an SFRCS trip has closed the MSIVs, AVV will have to be used as *~
follows:
6.11.1 E ICS AC AND DC are available AND Instrument air pressure is 2 75 PSIG THEN BLOCK the SFRCS signal A_ND manually control SG pressure from the ICS H/A station in HAND E
6.11.2 IF ICS AC OR DC is lost E
Instrument air pressure is < 75 PSIG THEN Dispatch an operator to establish communications with the Control Room and control SG pressure from local control of the atmospheric vent valve handwheels.
O
62 EP 1202.01.0 m
V) DETAILS 6.10 If necessary, open the PORV.
6.10.2 The PORV can be locked open with its control switch.
RC pressure is kept as low as possible to maximize MU/HPI flow while maintaining the primary to secondary AP across the SG tubes in the normal direction.
6.11 This is an attempt to induce heat transfer to the SG by lowering the heat sink temperature (SG) 50*F below the heat source temperature _
(incore T/C temperature).
/\
Nj l 6.11.1 l
- 1. Place both atmospheric vent valves H/A stations in HAND i and run the demand to minimum.
- 2. Press both atmospheric vent valves block buttons, i
HIS-ICS-11D and HIS-ICS-11C.
I
- 3. Press AUTO on HIS-ICS-11B and HIS-ICS-110.
l
! 4. Control SG pressure as desired from the H/A station.
6.11.2 Atmospheric vent valves s W M operate from the Control Room H/A station if ICS An. OR DC is lost OR instrument air pressure is < 75 PSIG. Local control will be required per Attachment 3, Attachments Tab. <
L.)
63 EP 1202.01.0 ACTIONS 0
6.12 Check for re-established SG heat transfer.
6.12.1 E SG heat transfer is re-established go to Step 6.19 ,
IF NOT 6.12.2 Continue with Step 6.13.
6.13 Check ability to bump RCPs.
6.13.1 g RC pumps can be bumped TIEN Go to Step 6.14 6.13.2 E RC pumps could be bumped if A AND/0R B bus was re-energTzed from offsite power THEN Re-energize A AND/0R B bus from offsite power and go to Step 6.14 6.13.3 IF RC pumps can Ny be bumped TIEN Initiate MU/HPI cooling, if not already in progress, by performing Step 6.2 AND TIEN Go to Section 12, MU/HPI Cooling.
6.14 Use RC pump bumps to induce SG heat transfer.
6.14.1 Bump an RC pump, which is capable of being started, in the loop with the highest SG level.
6.14.2 Allow RCS pressure to stabilize (within 125 PSIG) at new pressure before determining if SG heat transfer is re-estab-lished, s 9
64 EP 1202.01.0 p.
U DETAILS 6.12 Check for re-established SG heat transfer.
6.12.1 SG heat transfer is re-established if Tc and TSAT SG re-couple.
6.12.2 Do NOT wait longer than 15 minutes before proceeding with step 6.13.
6.13 Check ability to bump RCPs.
6.13.1 Normal interlocks apply, if necessary refer to SP 1103.06 RC Pump Operating procedure.
6.13.2 Refer to AB 1203.28, Loss of AC Bus Power Sources, for restoration of in-house power.
V 6.13.3 There is no heat transfer to either SG. Natural circulation does not exist and cannot be induced by bumping RC pumps.
The core must be cooled by MU/HPI cooling. The actuation of SFAS Incident Levels 1 and 2 may NOT occur right away so Step 6.2.8 should be performed whenever it occurs.
6.14 Use RC pump bumps to induce SG heat transfer.
6.14.1 Bump an RC pump means to start the pump, observe the starting current drops off, allow it to run for 10 seconds, and then stop it.
6.14.2 Pump bumps will force steam into the SG's where it will condense, causing RCS pressure to drop. This will allow
,/ increased MU/HPI flow into the system causing pressure to (y j increase as the system refills. RCS pressure will have to
,V be somewhat stable then, to determine if the system has completely " felt" the total effect of the bump, and heat transfer has been re-established to the SG.
65 EP 1202.01.0 ACTIONS 0
6.14.3 IF SG heat transfer is established, go to Step 6.19.
IF NOT Continue with Step 6.14.4.
6.14.4 Repeat Steps 6.14.1 through 6.14.3 for available RC pumps that have NOT been bumped. Allow 15 minutes between pump bumps. IF all available RC pumps have been bumped AND SG heat transfer has NOT been re-established THEN Continue with Step 6.15.
6.15 On each SG with the proper water level, further lower SG pressure while maintaining SG level, using the turbine bypass valves or atmospheric vent valves, until secondary TSAT is 90 to 110*F lower than incore T/C temperature AND maintain this SG pressure. ~
6.16 Check for re-established SG beat transfer 6.16.1 IF SG heat transfer is re-established, go to Step 6.19 h IF NOT 6.16.2 Continue with Step 6.17.
6.17 Start an RCP.
6.17.1 IF at least one hour has passed since the reactor trip THEN 6.17.2 Start and run one RC pump in the loop with the highest SG 1evel E
Attempt to maintain at least one RC pump running.
9
66 EP 1202.01.0 6
U <
DETAII.S 6.14.3 SG heat transfer is re-established if Tc and TSAT SG re-couple.
6.15 This is a further attempt to induce heat transfer to the SG by lowering the heat sink temperature (SG) 100*F below the heat source temperature (incore T/C temperature). _
6.16.1 SG heat transfer is re-established if Tc and TSAT SG re-couple.
l 6.17 The RC pump may be running with the RCS saturated in this step. If the pump vibration reaches 30 mils on the Bentley-Nevada (X2 switch required to read this expanded range), stop the pump and start a difftrent pump. It is desirable to run one RC pump on the loop with the highest SG 1evel. Since the reactor has been shutdown for a least one hour, a RC pump may be run with the RCS saturated without regard for the requirements of specific rule 1. Normal starting interlocks apply.
t Q-(J
r 67 EP 1202.01.0 O
ACTIONS 6.18 Check for re-established SG heat transfer.
6.18.1 E SG heat transfer has been re-established, go to Step 6.19 IF NOT 6.18.2 Go to ICC section 9.
SG HEAT TRANSFER HAS BEEN RE-ESTABLISHED 6.19 Recover from MU/HPI cooling, if initiated.
6.19.1 Close RC2A, PORV _
IF_ PORV will NOT close MN Close RC11, PORV block valve.
6.19.2 Close RC4608A AND RC4608B, loop 1 high peint vent valves.
6.19.3 Close RC4610A AND RC4610B, loop 2 high point vent valves.
6.19.4 Close RC239A AND RC200 pressurizer high point vent line isolations.
6.19.5 Control MU/HPI per specific rules 1 A_ND 2.
6.20 Control turbine bypass valves or atmospheric vent valves to maintain RC temperature approximately constant or slightly decreasing.
6.21 Check subcooling.
6.21.1 E there is adequate subcooling margin, continue with Step 6.22 IF NOT 6.21.2 Go to Section 11, RCS Saturated SG Removing Heat.
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68 EP 1202.01.0 1
.s
, DETAILS 6.18 Check for re-established SG heat transfer
~
6.18.2 If there still is no heat transfer- to either SG, attempts to e establish heat transfer by natural circulation and forced 1 flow have failed. The core must be cooled by MU/HPI cooling.
This condition can only exist if the core is very close to
] ICC. For this reason, the initial steps for ICC will be
- taken.
I SG HEAT TRANSFER HAS BLEN RE-ESTABLISHED
. 6.19 Recover froe MU/HPI cooling, if initiated.
! l J
i l
f 1
- 6.19.5 Specific rules 1 and 2 are in Specific Rules Tab. !
1 j 6.20 The intent of this step is to stablize any overcooling as a result i of actions to induce heat transfer and not allow the RCS to heat
! back up.
I 6.21 Check subcooling.,
1 I I l i i
i l
- 6.21.2 The RCS is saturated. A small break is indicated. Cooldown j with the SO's can be performed while MU/HPI maintains RCS l
! iventory.
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69 EP 1202.01.0 ACTIONS e
6.22 Check for SG tube rupture 6.22.1 Verify MS line AND/OR vacuum system discharge radiation monitors are NOT alarming IF ALARMING 6.22.2 Go to SG tube rupture section 8.7.
IF NOT AI. ARMING 6.22.3 Go to Section 13, Solid Cooldown or Pressurizer Recovery.
e e
70 EP 1202.01.0 DETAILS 6.22 SG tube rupture should cause alars of at least one of the following annunciators:
NOTE: Main Steam line RAD monitors will NOT respond in analyze mode with reactor shutdown.
VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE 1 RAD HI (12-6-3)
MN STM LINE 2 RAD HI (12-6-4) 6.22.3 The RCS is subcooled. There may or may not be a bubble in the pressurizer. SG heat transfer is controlled. Section 13 provides instructions either to draw a bubble if necessary, then cooldown normally, or cooldown solid if a bubble cannot -
be drawn.
i i
i I /
i i
tw LACu OF l Mtat TRANSFt h a3 08 CHECK FOm YES uam on aus umson LOCa? GO TO SECTION to FitDwaf tm tCn tMPTIEDs s
a vaLASL1? (
l NO NO K
tifaguSM uu/MPs COouNG
& 10 mCPat$sumE INCREA5Esf0 NO PCRy $t7DOINP (2400 PS3G l
"
- j/.
x ves
-1. .e i
- C C b4 oc to iCC $ECfoN D
<,x tutst' ./ !
y OPEN Pony NO i
i CAN 04f mu, PttDwaff e to t tM TM , Go to StCTON 12
/,*ntis mt N .. <
, y p
amo',1 SG /
NO
\ / Dat$ss ats YI vts /
/
,. vt5 9
wa.NT a:N A** mope.att 51 L E '< t LS Y CLost PORv Y 4 99 er %R*00VNG l LOwf a ga patssant
%0l V ap gin I$
WWeerti MaiNia6NeNG Ae gin T a:NED p ([D Ohl 6fvtwTOsN0uct Mia f TRAN%F f R m;p mgNNiNG 1I
.- w
71 EP 1202.01.1 /"
SECTION 6: LACK OF HEAT TRANSFER e
s 918 MEAT tRANSFan YES Rt EstAeusMEDt y dk NO ses E PuuPSCAN NO ,,y,a gg uy,,,
StSUUP&Li con g YES Y 0010 St0 tion 12 g,, 9 utt PuM* Buwes e ,e toPaDuct 9 MOfTRANSFEA agC0yta amou py,pp, CoouNois NilAtto T
e to 00Nimos ME At TRANSF tm Ve$ "(At TRAN58tm mAfg L
at.tST AsuSMED' WITM f Bve cm awe NO e +s y '
G I' syntate Lowtm ga
- f 5Sumt to iNoycg SUKN G'
No I 30 TO 5e ?.ON * * !
"IAt tAANSFtR ADEQuA ,
l N
vt5 I y
> . ..,/tatta.s,t.y ves f
,I s
( #t tStasuSatD* f'
& / 4222
/ 4 6 22 /
TIS 30 to Sata st:rioN e r
[ sata, NO O
Staat ONE C Puut bl O (, O kj fa
.- to pe0UCI mtat 4223 9
'AANS8tm GQ to St: tion 13 h
i TI UERTUgg
. ,6
'n csyy
, .. . , m.N,,4 m ~e ,, ao ta c0 stCrioN .
atis,.au..to, ,
'N 9507$66S66-o3
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72 EP 1202.01.0
- 7. EXCESSIVE HEAT TRANSFER ACTIONS O
ACTIONS FOR TOO MUCH PRIMARY TO SECONDARY HEAT TRANSFER 7.1 Insure RCS makeup 7.1.1 E pressurizer level is < 100" AND RCS pressure is decreasing THEN 7.1.2 Verify MU flow has been increased to recover pressurizer level AND maintain 100" to 110" in the pressurizer.
7.2 Verify letdown is isolated.
7.3 SFRCS actuation 7.3.1 g a full SFRCS actuation (auto OR manual) has occurred OR occurs while performing Steps 7.4 through 7.8, go to Step 7.14 IF NOT 7.3.2 Continue with Step 7.4.
7.4 Determine which SG is causing overcooling 7.4.1 I_F it is apparent which SG is causing the overcooling continue with Step 7.5 IF NOT 7.4.2 Go to Step 7.13.
7.5 Determine the cause of the overcooling.
7.5.1 E caused by MFW, go to Step 7.6.
7.5.2 g caused by AFW, go to Step 7.7.
7.5.3 g caused by steam pressure control, go to Step 7.8.
7.5.4 g cause can NOT be determined, go to Step 7.13.
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73 EP 1202.01.0
- 7. EXCESSIVE HEAT TRANSFER
, i y-l DETAILS j i
ACTIONS FOR TOO MUCH PRIMARY TO SECONDARY HEAT TRANSFER 7.1 At this point two MU pumps, if available, should already be running supplying maximum MU flow to the RCS. If loss of NNI X AC power has caused loss of the pressurizer level recorder, maintain pressurizer level from 110" to 120" using uncompensated level.
l
[
7.2 Letdown should be isolated with MU2B, letdown isolation valve (motor operated) or MU3, letdown line stop valve (air operated).
7.3 SFRCS Actuation 7.3.1 SFRCS actuation is confirmed by annunciator alarm SFRCS FULL TRIP (8-6-1) and plant response indications confirm an SFRCS actuation.
r O'
7.4 Determine which SG is causing overcooling 7.4.1 The overcooling SG may be apparent after comparing BOTH SG pressures, levels, main and aux feedwater flows, Tc's, and key valve positions (TBV, AVV, and steam release from MSSVs may be heard from the Control Room). Parameters should be compared to each other and to expected values for the plant conditions.
7.5 The cause of the overcooling may be apparent after observing the parameters in the previous step while making the determination of which side is overcooling.
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74 EP 1202.01.0 ACTIONS 0
7.6 MW overcooling 7.6.1 Attempt manual control of MFW to the overcooling SG.
7.6.2 E manual control of MW stops the overcooling, go to Step 7.9 IF NOT .
1 7.6.3 Trip both MFPTs and go to Step 7.13.
7.7 AW overcooling 7.7.1 E MW is available to the overcooling SG, stop AFW flow to the SG, and go to Step 7.9.
7.7.2 If MFW is NOT available to the overcooling SG go to Step 7.13.
7.8 Steam pressure control overcooling 7.8.1 Attempt manual control of any valves causing overcooling.
It may be possible to reseat a MSSV by lowering SG pressure with the TBVs or AVVs.
7.8.2 E manual control stops the overcooling, go to Step 7.9 IF NOT 7.8.3 E known to be a non-isolable steam leak, go to Step 7.28.
O_R IF isolable OR unknown, go to step 7.13.
7.9 Maintain BOTH SG 1evels at low level limit (35") with MW.
7.10 Control turbine bypass valves to maintain RC temperature approxi-mately constant or slightly decreasing.
1 7.11 Check subcooling
} 7.11.1 E there is adequate subcooling margin, continue with Step 7.12 IF NOT 7.11.2 Go to lack of adequate subcooling margin Section 5.
75 EP 1202.01.1
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DETAILS 7.6 Manual control of MFW may be required at various valve or pump H/A stations or valve controls depending on the failure. If controlling overcooling by reducing MFPT speed, care must be taken not to underfeed the good SG.
7.7 If AFW is causing SG overcooling, without an SFRCS actuation, there has been some some inadvertent AFW actuation. If MFW is available, AFW flow should be stopped by any available means. AFW can be stopped by taking manual control of the governor and running the speed to minimum, closing the steam supply valve, closing an AFW discharge valve, or locally tripping the AFPT. Depending on the exact failure, it may also be necessary to remove the power to a MOV to stop the AFW flow.
7.8 Manual control of TBV or AVV H/A stations may stop overcooling. If a MSSV has failed to reseat after lifting, lowering the associated SG pressure with the TBVs may get it to reseat, although it will have to be done slowly to minimize the overcooling effects. Failure of a MSR second stage reheat steam supply valve to close after a turbine trip may also cause overcooling.
7.10 The intent of this step is to not allow the plant to heat back up after the overcooling. The heatup, if allowed, might insurge the pressurizer level enough to cause loss of RC pressure control.
7.11 Adequate subcooling margin exists when the TSAT meters indicate 2 1- l 20*F. If NEITHIR TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on
, the P/T display or manual plot is above and to the left of *be gN, ,
subcooled margin line.
76 EP 1202.01.0 ACTIONS 7.12 Check for SG tube rupture 7.12.1 Verify MS line AND/OR vacuum system discharge radiation alarms are NOT alarming IF AIARMING 7.12.2 Go to SG tube rupture Section 8.7.
IF NOT ALARMING 7.12.3 Go to PP 1102.03, Trip Recovery.
7.13 Manually actuate SFRCS on low SG level.
7.14 Verify proper SFRCS actuation for the trip parameters present.
7.15 Check for overcooling termination by SFRCS 7.15.1 IF SG levels AND pressures are approximately equal and s stabilizing in BOTH SGs, go to Step 7.19 IF NOT 7.15.2 Continue with Step 7.16.
7.16 Check for AFW overcooling 7.16.1 IF SG 1evels are increasing in ONE OR BOTH SG greater than appropriate setpoint THEN Go to Step 7.17 OR A
77 EP 1202.01.0 DETAILS 7.12 SG tube rupture should cause alarm of at least one of the following annunciators:
NOTE: Main Steam Line RAD monitors will NOT respond in analyze mode with reactor shutdown.
VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE 1 RAD HI (12-6-3)
MN STM LINE 2 RAD HI (12-6-4) 7.13 Manually trip SFRCS on low SG level using BOTH SG LVL TRIP buttons.
7.14 SFRCS response should be verified in accordance with Table 1. Tables Tab.
7.15 The intent of this step is to determine if the SFRCS actuation has terminated the overcooling. The operator will have to apply judgment to the many possible plant conditions and possibly even have to monitor planc response for several minutes to make this determination.
If the SFRCS has indeed terminated the direct cause of the overcooling, but the SG levels are still below the appropriate setpoint, the steam generator levels will still be increasing and steam pressure may be low due to direct condensing action by the AFW. In this case, the operator will have to wait until SG levels reach their setpoint. Also once the levels reach setpoint, manual control of AFPT speed, by the operator, may be required to " stabilize" the plant. If the SFRCS has terminated the overcooling and SG levels are being maintained at setpoint, the steam pressure may be increasing as the RCS heats back up. In this case, the SG pressure is not
" stable" but the overcooling symptom would no longer be present. If a small non-isolable steam leak is present, the levels may be stable but the overcooling symptom would still be present. Also AFW flow.
Tc, and SG pressure may be asymmetric.
7.16 Check for AFW overcooling 7.16.1 SG level setpoints are contained in specific rule 3 in the Specific Rules Tab.
t U
78 EP 1202.01.0 ACTIONS 0
7.16.2 E SG levels are NOT increasing past the appropriate setpoint but overcooling is still present THEN Go to Step 7.23.
7.17 Terminate AW overfill 7.17.1 Stop the AW overfill by manual control using the most desirable method available AND 7.17.2 E the overfilling SG is required for RCS heat removal, manual control of the SG level will be required after the -
overfill is stopped OR 7.17.3 E the other SG is maintaining RCS heat removal, periodic AW additions to the previously overfilling SG can be made to maintain a water level, in case it becomes needed, for RCS heat removal.
7.18 With SG levels stabilized in BOTH SGs 7.18.1 E pressures are also stabilized in BOTH SGs THEN Go to Step 7.19 9.E 7.18.2 g pressures have NOT stabilized in BOTH SGs THEN Go to Step 7.23.
7.19 Maintain BOTH SG levels at appropriate setpoint with AW.
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79 EP 1202.01.0 (3.
DETAILS 7.16.2 Indications of a non-isolable steam leak are present.
7.17 Terminate AFW overfill 7.17.1 SG overfill by AFW can be stopped by taking manual control of the AFPT governor and running the speed to minimum, closing the steam supply valve, closing an AFW discharge valve, or locally tripping the AFPT. Depending on the exact failure with an SFRCS trip present, it may also be necessary to remove the power to a MOV to keep the AFW flow stopped.
( f) l
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7.18 The intent of this step is to determine, after SG level control by AFW is eliminated as a cause of overcooling, if a steam leak is causing overcooling. The operator will have to apply judgment to the plant conditions and possibly even have to monitor plant response for several minutes to make this determination. If " stabilizing" the SG levels has terminated the cause of overcooling, the SG pressures may be increasing as the RCS heats back up. In this case, the SG pressure is not " stable" but the overcooling symptom would no longer be present. If a small non-isolable steam leak is present, the levels may be stable but the overcooling symptom would still be present. Also AFW flow, Tc, and SG pressure may be asymmetric.
7.19 SG level setpoints are contained in specific rule 3 in the Specific Rules Tab.
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s_-
80 EP 1202.01.0 ACTIONS 0
7.20 Control atmospheric vent valves to maintain RC temperature approxi-mately constant or slightly decreasing.
7.20.1 IF ICS AC AND DC are available AND Instrument air pressure is 2 75 PSIG THEN BLOCK the SFRCS signal AND manually control SG pressure from the ICS H/A station in HAND SE 7.20.2 IF ICS AC OR DC is lost __
SE Instrument air pressure is < 75 PSIG TesN Dispatch an operator to establish communications with the Control Room and control SG pressure from local control of the atmospheric vent valve handwheels.
7.21 Check subcooling 7.21.1 IF there is adequate subcooling margin, continue with Step 7.22.
4 IF NOT 7.21.2 Go to lack of adequate subcooling margin Section 5.
7.22 Check for SG tube rupture 7.22.1 Verify MS line AND/OR vacuum system discharge radiation alarms are NOT alarming IF ALARMING 7.22.2 Go to SG tube rupture Section 8.7.
IF NOT ALARMING 7.22.3 Go to PP 1102.03, Trip Recovery.
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81 EP 1202.01.1 A'
[(,,/\
DETAILS 7.20 The intent of this step is to not allow the plant to heat back up after the overcooling. The heatup, if allowed, might insurge the pressurizer level enough to cause loss of RC pressure control.
7.20.1
- 1. Place both atmospheric vent valves H/A stations in HAND and run the demand to minimum.
- 2. Press both atmospheric vent valves block buttons,.HIS-ICS-11D and HIS-ICS-11C.
- 3. Press AUTO on HIS-ICS-11B and HIS-ICS-11C.
- 4. Control SG pressure as desired from the H/A station.
7.20.2 /.tmospheric vent valves will not operate from the Control Room H/A station if ICS AC OR DC is lost OR instrument air pressure is < 75 PSIG. Local control will be required per m Attachment 3, Attachments Tab.
( '
7.21 Adequate subcooling margin exists when the TSAT meters indicate 2 1 20*F. If NEITHER TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line.
7.22 SG tube rupture shculd cause alarm of at least one of the following annunciators:
NOTE: Main Steam Line RAD monitors will NOT respond in analyze mode with reactor shutdown.
VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE 1 RAD HI (12-6-3)
MN STM LINE 2 RAD HI (12-6-4)
()'
82 EP 1202.0100 ACTIONS 7.23 Non-isolable steam leak.
7.23.1 E SG level and pressure are stabilizing in one SG AND the other SG is boiling dry, go to Step 7.30 IF NOT 7.23.2 Continue with Step 7.24.
7.24 Non-isolable steam leak NOT actuating SFRCS low MS line pressure trip .
7.24.1 IF it is apparent which SG is causing the overcooling, go to Step 7.28 IF NOT 7.24.2 Continue with Step 7.25 7.25 Take manual control of BOTH AFPT governors and run the speed to minimum to stop AW flow to BOTH SGs.
..h 7.26 Identify the SG with the steam leak by monitoring for the SG with
'the fastest level AND pressure decrease.
7.27 Immediately restore AW to the good steam generator.
7.28 Manually actuate SFRCS on low steam line pressure on the side with the steam leak.
7.29 Verify proper SFRCS actuation for the low main steam line pressure trip 1
If the governors had previously been placed in manual, return BOTH AFPs to service on the good SG.
7.30 Maintain proper SG 1evel in the good SG with AW.
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1 83 EP 1202.01.0 l m
DETAILS 7.23 At this point if SG level and pressure are stable in one SG and the other is boiling dry, the SFRCS would have to have isolated all feedwater to the SG with the steam leak, on a low main steam line pressure at 612 PSIG.
7.24 The overcooling SG may be apparent after companing BOTH SG pressures, levels, aux feedwater flows, and Tc's. Parameters should be compared to each other and to expected values for the plant conditions. The steam leak may also be identified from reports from cutside the Control Room.
4 7.25 With a water level present in BOTH SGs, there is a heat sink for the
._ RCS which allows AFW to be temporarily stopped.
7.27 AFW flow is restored by increasing the speed of the AFPT on the good SG with manual control of the governor. The controls can be returned to AUTO if desired.
7.28 To manually actuate SFRCS on low main steam line pressure, press the TRIP switch for the side with the leak in BOTH actuation channels
- and insure the switches stay in the tripped position.
7.29 SFRCS response should be verified in accordance with Table 1, Tables Tab. The SFRCS trip will realign the AFP steam and feed valves to the good SG. The operator will have to return the steam leak side AFP to service with manual control of the governor.
7.30 SG 1evel setpoints are contained in specific rule 3 in the Specific Rules Tab.
O 3
.-_-..__..-..-_,_.-_.,,._,,,,,_,,-.m. , - . . , _ . . _ _ . - . _ . . , .-,7_.,__y, . . _ . - _ , , , , , . _ , , . , . - , - . - . _ , , , _m._.
i 84 EP 1202.01.0 ACTIONS 0
7.31 When the steam leak side SG boils dry terminating the overcooling, control the atmospheric vent valve on the goed SG to maintain RC temperature constant or slightly decreasing.
7.31.1 IF ICS AC AND DC are available 2
Instrument air pressure is 2 75 PSIG TIDLN BLOCK the SFRCS signal AND manually control SG pressure from the ICS H/A station in HAND SE 7.31.2 IF ICS AC OR DC is lost SE Instrument air pressure is < 75 PSIG THEN Dispatch an operator to establish communications with the Control Room and control SG pressure from local control of the atmospheric vent valve handwheel.
7.32 Check subcooling 7.32.1 IF there is adequate subcooling margin, continue with Step 7.33.
IF NOT 7.32.2 Go to lack of adequate subcooling margin Section 5.
7.33 Check for SG tube rupture 7.33.1 Verify MS line AND/0R vacuum system discharge radiation alarms are NOT alarming IF ALARMING 7.33.2 Go to SG tube rupture Section 8.7.
IF NOT ALARMING 7.33.3 Go to PP 1102.03, Trip Recovery. O
4 .
85 EP 1202.01.1
\s_-
DETAILS 7.31 The intent of this step is to not allow the plant to heat back up after the overcooling. The heatup, if allowed, might insurge the pressurizer level enough to cause loss of RC pressure control.
7.31.1
- 1. Place the atmospheric vent valve H/A station in HAND and run the demand to minimum.
e
- 2. Press the atmospheric vent valve block button HIS-ICS-11D or HIS-ICS-11C.
- 3. Press AUTO on HIS-ICS-11B or HIS-ICS-11C.
- 4. Control SG pressure as desired from the H/A station.
7.31.2 Atmospheric vent valves will not operate from the Control Room H/A station if ICS AC OR DC is lost OR instrument air
- pressure is < 75 PSIG. Local control will be required per
-s Attachment 3, Attachments Tab.
') ,)
7.32 Adequate subcooling margin exists when the TSAT meters indicate 2 1l 20*F. If NEITHER TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line.
7.33 SG tube rupture should cause alarm of at least one of the following annunciators.
NOTE: Main Steam Line RAD monitors will NOT respond in analyze
, mode with reactor shutdown t-VACM SYS DISCH RAD HI (9-5-1)
MN STM LINE 1 RAD HI (12-6-3) 3 -( MN STM LINE 2 RAD HI (12-6-4) f
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87 EP 1202.01.1
- 8. STEAM GENERATOR TUBE RUPTURE ACTIONS ACTIONS FOR SG TUBE RUPTURE 8.1 Reactor trip 8.1.1 IF the reactor trips OR must be manually tripped at 100" pressurizer level, return to Step 3.2.
IF NOT 8.1.2 Continue with Step 8.2.
8.2 Manual reactor shutdown 8.2.1 Place the Bailey Reactor Demand H/A Station in HAND 8.2.2 Place the Diamond Rod Control in MANUAL AND insert control rods as continuously as possible without causing a reactor trip on imbalance.
1l 8.3 As unit load decreases, perform the following steps:
CAUTION: The reactor must be manually tripped if pressurizer level decreases to 100". -
8.3.1 Start Apendix B, C and D of AB 1203.40, SG Tube Leak 8.3.2 Determine which SG has the tube leak.
8.3.3 Fire the Auxiliary Boiler and transfer the auxiliary steam and gland steam headers to the Auxiliary Boiler.
8.3.4 Lineup and start HPI/LPI piggyback operation.
1 1
O l
l l
l 1
88 EP 1202.01.0 l
em 8. STEAM GENERATOR TUBE RUPTURE (J )
DETAILS ACTIONS FOR SG TUBE RUPTURE 8.1 If this section has been entered prior.to reactor trip and then the reactor trips or must be tripped by the operator, stabilizing the plant after the trip has priority over dealing with the SGTR.
8.2 The Bailey Reactor Demand is placed in HAND to force it to "minitrack".
Continuous insertion of rods will result in a power decrease of about 20%/ minute. The ICS will be in TRACK with Tave controlled by feedwater.
8.3 As unit load decreases, perform the following steps:
8.3.2 Compare RE609 (line 1) and RE600 (line 2) readings. Backup determination can be made by a local survey of the main 4 steam lines.
- 8. 3.' 3 The Auxiliary Boiler should be ready to assume the auxiliary steam load as soon as possible in order to maintain condenser vacuum after reactor shutdown.
8.3.4 Piggyback operation will allow HPI at RCS pressures below approximately 1850 PSIG.
- 1. Start HPI Pumps 1-1 AND 1-2.
- 2. Fully open injection valves Pump 1-1 open HP2C A_ND HP2D _
Pump 1-2 open HP2A AND HP2B
- 3. Start LPI Pumps 1-1 AND 1-2.
). 5. Start the CCW pump on the non-running side to supply
'-' the essential header.
e s---,,,--- _
r , - - - _ . , _ , - , , . - _ _ _ _ , _ _ - , - _ _ . _ , . , _ _ , - , , . . , , _ _ _ , , , , _ . _ , _ , . _ . _ . . . _ . , , _ . . _
89 EP 1202.01.0 ACTIONS 0
l 8.3.5 At approximately 590 We, verify MSR 2nd stage reheat pressures are decreasing under low load valve control.
8.3.6 At approximately 450 We, remove the MFPT from service on the side with the SGTR.
8.3.7 At approximately 360 We, stop all but one condensate pump.
8.3.8 At approximately 270 We, transfer the station electrical loads from the auxiliary transformer to the SU transformers.
m O
8.4 At approximately 25% power, stop inserting rods AND hold power at approximately 25%.
8.5 Transfer the reactor power steam generation from the turbine to the TBVs until generator load is <50 We.
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90 EP 1202.01.0 7-
)
v DETAILS 8.3.5 At approximately 590 MWe (128 PSIG cross-around pressure)
MS195A and MS195B (RSELV) close AND 2nd stage reheat pressure will decrease with turbine load under control of MS338 and MS353 (RSLLV).
8.3.6 If the MFPT on the side with the SGTR is the only one available, it will have to remain in service, but the SUFP should then be put in service as soon as load permits.
8.3.7 One condensate pump will handle the load when condensate flow is <3.5 MPPH.
8.3.8 NOTE: If the auxiliary transformer and the SU transformers are paralleled through the switchyard the synch check relays (25A and 25B) need not be checked at A or B bus, cubicle 5, prior to the transfer.
- 1. Place Bus A (Bus B) Synch Check Switch to the "X01"
("X02") position.
- 2. Close HX01A or HX02A (HXO2B or EX01B).
- 3. Place Bus A (Bus B) Synch Check Switch to the "0FF" position.
- 4. Place Bus A (Bus B) Reserve Source Selector Switch to the position corresponding to the opposite S/U trans-former to the one supplying the bus.
8.4 With NI calibration inaccuracies due to the power reduction the exact point for this step will have to be determined by the operator.
Additional indications for this point are Tave just starting to ramp down, SGs going on low level limits, and a unit AT of about 12*F.
8.5 This step is attempting to get all the reactor power steam generation transferred to the fully open TBVs so there will not be a secondary pressure spike on the reactor-turbine generator trip causing the MSSVs to lift.
- 1. Place BOTH loop TBV H/A stations in HAND.
- 2. Place the turbine in MANUAL.
- 3. Coordinate opening the TBVs with decreasing the turbine load in manual until generator load is <50 MWe.
1
- 4. If the TBVs are fully open and the generator load is
[']
N- - NOT <50 MWe, bump reactor power down while reducing turbine load until <50 MWe.
91 EP 1202.01.0 ACTIONS 0
8.6 Manual reactor trip.
,8.6.1 Manually trip the reactor AND the turbine AND Control TBVs to increase individual SG pressure to 1015 PSIG AND return TBV H/A stations to AUTO THEN 8.6.2 Return to Step 3.2.
8.7 HPI/LPI piggyback 8.7.1 IF HPI and LPI are already piggybacked, go to Step 8.8
-~
IF NOT AND T
8.7.2 Piggyback operation will help control RCS inventory, lineup and start HPI/LPI piggyback operation.
8.8 Determine RCP availability 8.8.1 IF all RCPs are running, go to Step 8.16.
8.8.2 IF all RCPs are NOT running AND A OR B bus is energized AND NNI X AC AND DC are energized Go to Step 8.9.
9
_ _ m _ _ _. - . . _ _ . ~ . . . - . . _ _ _ __. __ _ _. .. ___
i 1 92 EP 1202.01 0 i
i I DETAILS
! 8.6 When the reactor is tripped at approximately 25% power the turbine will also trip. TBVs will have to be slowly throttled back
- to increase individual SG pressures to 1015 PSIG. If the TBVs were transferred to AUTO immediately on the reactor trip, the 145 PSI
- post trip bias would rapidly close them and possibly cause lifting i of MSSVs before the TBVs could respond. 4 1
s 1 i
- 8.6.2 The plant will be stabilized after the reactor trip prior to performing the remainder of this section.
l 8.7 The need for HPI/LPI piggyback operation at this point is dependent i on plant conditions, i.e, RCS pressure and pressurizer level.
l - Piggyback operation will allow HPI at RCS pressures below approximately 1850 PSIG. To piggyback: _
j 1. Start HPI Pumps 1-1 AND 1-2.
I{
! [V' 1 ; 2. Full open injection valves.
Pump 1-1 open HP2C AND HP2D Pump 1-2 open HP2A AND HP2B lt
- 3. Start LPI Pump 1-1 AND 1-2.
i
} 5. Start the CCW pump on the non-running side to supply l
the essential header.
j- 8.8 Determine RCP availability.
1 8.8.2 If the conditions of this step are met, at least one RCP in
! each loop is available for immediate restart.
i 1
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' s 4
93 EP 1202.01.0 ACTIONS 0
8.8.3 IF A AND B bus are NOT energized AND/0R ,
NNI X AC @ DC are NOT energized THEN Begin steps to regain A OR B bus AND/0R NNI X AC AND DC in parallel with proceeding with Step 8.11.
8.9 RCP restart 8.9.1 IF POSSIBLE, restart all four RCPs.
S 8.9.2 E the above pump combination is NOT available, . start the next most desirable available pump combinatior.. -
8.9.3 E no RCP can be restarted at this time, go to Step 8.11.
O 8.10 Determine pressurizer spray availability.
8.10.1 E pressurizer spray is available, go to Step 8.16 IF NOT 8.10.2 Go to Step 8.11.
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94 EP 1202.01.0 m
U DETAILS 8.8.3 If the conditions of this step are met, RCPs are not available for immediate restart but steps are begun to make them available. Refer to AB 1203.28, Loss of AC Bus Power Sources, for restoration of in-house bus power. Refer to AB 1203.41, Loss of NNI Power, and SP 1105.06, NNI Operating Procedure, for restoration of NNI power.
8.9 Forced RC flow is preferred over natural circulation in order to provide pressurizer spray. Pump combinations are listed below in order of preference to provide maximum pressurizer spray. Fourth RC pump temperature limit and NPSH limits should be observed.
RC pump starting interlocks apply.
% Of Full Flow -~
Pump Combination Spray Flow
- 1. 2/2 100 2.
/'*]- 3.
1/2 0/2-92 84
(__// 60
- 4. 2/2-2
- 5. either Loop 1/2-2 53
- 6. 2/2-1 50
- 7. 0/2-2 41
- 8. either Loop 1/2-1 38
- 9. 0/2-1 26
- 10. 2/0 20
- 11. 1/0 0 8.10 Pressurizer spray should be available in any RCP combination other than 1/0 unless some known condition exists which would prevent pressurizer spray operation.
d
95 EP 1202.01.0 l
ACTIONS O ll' BEGIN COOLDOWN AND DEPRESSURIZATION WITHOUT RCPs (WITHOUT PRESSURIZER SPRAY) 8.11 g RCPs (pressurizer spray) are regained while performing this section, go to Step 8.16.
8.12 Verify SG levels are controlled at OR increasing to the proper level per specific rule 3.
8.13 Depressurize the RCS to approximately 1700 PSIG to allow HPI and MU to recover pressurizer level.
8.13.1 Turn off all pressurizer heaters.
S.13.2 Start the QT circ pump.
8.13.3 Open RC239A, pressurizer steam space sample valve AND RC20U, pressurizer vent to QT isolation, to drop RC3 pressure to approximately 1700 PSIG. Manually cycle RC230 g control pressurizer heaters to maintain RCS pressure from approximately 1700 to approximately 1800 PSIG 9.R E the pressurizer vent line is NOT available OR depressurizes too slow, open RC2A (PORV) AND RC11 PORV block valve, if closed, to drop RCS pressure to approximately 1700 PSIG.
Manually cycle the PORV AND control pressurizer heaters to maintain RCS pressure from approximately 1700 to approximately 1800 PSIG.
8.13.4 Allow HPI and MU to recover pressurizer level M maintain pressurizer level from 90" to 110" by controlling HPI and MU. Do NOT continue until pressurizer level is restored.
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96 EP 1202.01.0
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DETAILS BEGIN C00LDOWN AND DEPRESSURIZATION WITHOUT RCPs (WITHOUT PRESSURIZER SPRAY) 8.12 Specific rule 3 is contained in the Specific Rules Tab.
8.13 RCS pressure is dropped to allow HPI in the piggyback mode to aid in pressurizer level recovery. HPI shutoff head in this mode is approximately 1850 PSIG. The QT cire pump is started to cool the QT although it may not be sufficient to prevent QT pressure buildup.
The preferred method for RCS depressurization is via the pressurizer vent line. If this method is not available, or too slow, the PORV should be used. The use of the PORV may lead to lifting of the QT relief (90 PSIG) or failure of the QT rupture disk (100 PSIG). Use of the PORV is left to the judgment of the operator after considering plant conditions at the time. The use of the pressurizer vent linE or PORV may affect pressurizer level indication.
Ur 8.13.4 Pressurizer level is recovered prior to starting RCS cooldown.
At this point, the leak rate can also be estimated by totaling HPI and MU flow with pressurizer level constant.
i
97 EP 1202.01.0 ACTIONS 0
8.14 Begin an immediate cooldown and depressurization at 50*F/hr., using BOTH SGs, if both can be steamed, to Th of 520*F @ 1000 PSIG While proceeding, take the below steps as necessary. Plant conditions may require deviating from the order given.
8.14.1 Establish a 50'F/hr cooldown rate. Use TBVs on BOTH SGs if pos sib,le . IF CONDENSER IS NOT AVAILABLE, use AVVs on BOTH SGs if possible.
CAUTION 8.14.2: With the SFAS low RCS pressure trip BLOCKED, the operator is responsible for initiating SFAS should the condition of the leak-worsen such that pressurizer level OR RCS pressure can NOT be controlled.
8.14.2 E SFAS has NOT actuated on low RCS pressure of 1650 PSIG AND the RCS pressure decrease is being manually controlled MIEN BLOCK the SFAS low RCS pressure trip when the block permit ,
comes in.
98 EP 1202.01.0 DETAILS <
8.14 Begin an immediate cooldown and depressurization at 50 F/hr using BOTH SGs, if both are available for steaming, to Th of 520*F AND 1000 PSIG. For guidance, refer to PP 1102.10, Plant Shutdown and Cooldown, as much as possible.
8.14.1 It is desirable to cooldown using BOTH SGs if possible.
Place BOTH loop TBV H/A stations in HAND and position them to establish a cooldown at a rate as close to 50*F/hr as can be reasonably controlled. IF the condenser is NOT available, use the AWs. IF the SFRCS or SFAS has tripped the AWs, BLOCK the trip and taka control as follows:
1
- 1. Place the atmospheric vent valve H/A station in '
HAND and run the demand to minimum.
- 2. Press the atmospheric vent valve block button l HIS-ICS-11D or HIS-ICS-11C.
X 3. Press AUTO on HIS ICS-11B or HIS-ICS-11C.
I 4. Control SG pressure as desired from the H/A station.
Atmospheric vent valves will not operate from the Control Room H/A station if ICS AC OR DC is lost OR instrument air pressure is < 75 PSIG. Local contrel will be required per Attachment 3, Attachments Tab.
N0TE 8.14.2: SFAS initiation on high containment pressure, high containment radiation and from the manual actuation switches will function normally with the SFAS low RCS pressure trip BLOCKED. To manually actuate the SFAS in response to low RCS pressure, the operator can actuate all the necessary equipment for the required incident i level, component by component, tros each conponent control switch OR manual actuation _
at the SFAS system level from the manual actuation switches.
8.14.2 When RCS pressure is <1800 PSIG and annunciator alarm SFAS RC PRESS <1800 BLK PFNr (5-3-3) comes in, BLOCK all four SFAS channels and insure the SFAS RC press < 1650 TRIP BLOCKED (5-4-3) light comes on. E manual actuation of SFAS becomes necessary, f refer to Table 2 in Tables Tab for component status information.
%v
99 EP 1202.01.1 ACTIONS 8.14.3 Depressurize the RCS down to AND maintain the minimum adequate subcooling margin limit during RCS cooldown until RCS pressure reaches approximately 1000 PSIG, THEN Maintain RCS pressure between 975 to 1025 PSIG.
8.14.4 BLOCK SFRCS low main steam line pressure AND SG High level trips when the block permit comes in.
8.14.5 IFF the tube ruptured SG Operate Range level is approaching
- 1) the SFRCS high level trip setpoint (94%)
THEN Increase the steaming rate on the tube ruptured SG to attempt to keep the level below the CFRCS trip setpoint. -)
8.14.6 IF the tube ruptured SG Operate Range level can NOT be 1l maintained <94% on the Operate Range THEN Stop steaming the tube ruptured SG AND close its MS1V AND continue the cooldown on the good SG.
O
100 EP 1202.01.1 DETAILS 8.14.3 Adequate subcooling margin exists when the TSAT meters 1l indicate 1 20'F. If NEITHER TSAT meter is available, adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line. This pressure is below the fuel-in-compression curve, but it is necessary to reduce the driving force on the tube leak.
This is also shown on Figure 1 in the Figures Tab.
8.14.4 Vaen SG pressure is <650 PSIG and annunciator alarms SFRCS CH I (2) MN STM LO PRESS /HI LVL BLK PRMT (12-3-3(4)) come in, BLOCK all four SFRCS channels and insure both SFRCS CH 1 (2)
MN STM LO PRESS /HI LVL TRIP BLKD (12-4-3(4)) annunciator alarms come in.
8.14.5 If cooldown is established using the TBVs and condenser, an SFRCS high level trip would cause SG isolation forcing use of AVVs. If the cooldown is established using the AVVs, an SFRCS high level trip would necessitate closing the AVV to protect it from possible water damage. An increased steaming rate on one SG will require a decreased steaming rate on the
[_'
other SG to maintain the cooldown rate constant.
I 8.14.6 IF the SFRCS high SG level trip has NOT been BLOCKED, a water level of 94% on the Operate Range will cause a high SG level SERCS trip. The steam generator cannot be steamed above this level as possible water damage to the MSIV, MS line, TBVs, or AVV might occur, preventing later isolation of the SG. If the water level can't be controlled, the cooldown will have to be shifted to the good SG, and the tube ruptured SG isolated before water enters the MS line.
l
[
/
101 EP 1202.01.0 ACTIONS 8.14.7 When RCS conditions of 520*F Th AND 1000 PSIG are reached, l if the non tube ruptured SG can be steamed l THEN Stop the RCS cooldown.
Close the MSIV on the tube ruptured SG.
Maintain DH removal by steaming the good SG with the TBVs (AVV if condenser is not available), AND go to Step 8.15.
0,,R, IF the non tube ruptured SG can NOT be steamed THEN Go to Step 8.20.
8.15 Proceed with plant operation as directed by PP 1102.10, Plant Shutdown and Cooldown and refer to the appendices of AB 1203.40, SG Tube Leak, for additional guidance on actions and control measures.
BEGIN C00LDOWN AND DEPRESSURIZATION WITH RCPs RUNNING 8.16 Verify SG levels are controlled at OR increasing to the proper level per specific rule 3.
I 1
0
102 EP 1202.01.0 0 DETAILS 8.14.7 When RCS conditions of 520*F Th and 1000 PSIG are reached, stop the RCS cooldown by closing back on the TBVs (AVVs).
Ensure no steam loads are being supplied by the tube ruptured SG MS line and isolate the tube ruptured SG by closing its MSIV. The SG will continue to fill thru the tube rupture.
Increase the steaming rate dsing the TBVs (AVV) on the good SG enough for DH removal as indicated by constant or slightly decreasing Tc.
4 BEGIN C00LDOWN AND DEPRESSURIZATION WITH RCPs RUNNING 8.16 Specific rule 3 is contained in the Specific Rules Tab.
- 1. IF MFW is available AND RCPs have been continuously available, SG level should be maintained at low level limit (35") with MFW.
- 2. IF MFW is available AND RCPs have been restarted, SG level should be maintained at low level limit (35")
with MFW and the AFW System shutdown per below steps:
- 1) Place both AFP mode selectors in MANUAL and reduce turbine speed to 1500 RPM.
- 2) Close the steam supply valve MS106(A) and MS107(A).
- 3) Close the AFP to SG stop valves AF3870 and AF3872 (AF3869 and AF3871).
- 4) Run the AFPT speed changer to low speed stop, then to high speed limit by holding in raise for 25 f seconds.
Os 5) Return both AFP mode selectors to Auto-Essential.
103 EP 1202.01.0 ACTIONS 0
8.17 Depressurize the RCS to approximately 1700 PSIG to allow HPI and MU to recover pressurizer level.
8.17.1 Turn off all pressurizer heaters.
8.17.2 Open RC2, pressurizer spray valve AND RC10, pressurizer spray block valve, if closed, to drop RCS pressure to approximately 1700 PSIG. Manually cycle RC2 M control pressurizer heaters to maintain RCS pressure from approxi-mately 1700 to approximately 1800 PSIG.
8.17.3 Allow HPI and MU to recover pressurizer level M maintain pressurizer level from 90" to 110" by controlling HPI and MU. Do NE continue until pressurizer level is restored.
8.18 Begin an immediate cooldown and depressurization at 100*F/hr, using BOTH SGs, if both can be steamed, to Te of 500*F AND 1000 PSIG AND While proceeding, take the below steps as necessary. Plant conditions may require deviating from the order given.
8.18.1 E possible, go to or remain in a 2/2 RCP combination while above 500*F.
s O
104 EP 1202.01.0 O
DETAILS
8.17 RCS pressure is dropped to allow HPI in the piggyback mode to aid in pressurizer level recovery. HPI shutoff head in this mode is approximately 1850 PSIG.
8.18 Begin an immediate cooldown and depressurization at 100*F/hr, using BOTH SGs, if both are available for steaming, to Tc of 500*F AND 1000 PSIG. For guidance refer to PP 1102.10, Plant Shutdown and j Cooldown, as much as possible.
8.18.1 Forced RC flow is preferred over natural circulation in order to provide pressurizer spray. Pump combinations are listed below in order of preference to provide maximum pressurizer spray. Fourth RC pump temperature limit and NPSH limits should be observed.
% Of Full Flow Pump Combination Spray Flow
- 1. 2/2 100
- 2. 1/2 92
- 3. 0/2 84
- 4. 2/2-2 60
- 5. either Loop 1/2-2 53
- 6. 2/2-1 50
- 7. 0/2-2 41
- 8. either Loop 1/2-1 38
- 9. 0/2-1 26 :
- 10. 2/0 20
~11. 1/0 0 6 :
l
105 EP 1202.01.0 ACTIONS 0
8.18.2 Establish a 100*F/hr cooldown rate. Use TBVs on BOTH SGs if possible. IF CONDENSER IS NOT AVAILABLE, use AVVs on BOTH SGs if possible.
O CAUTION 8.18.3: With the SFAS low RCS pressure trip BLOCKED, the operator is responsible for initiating SFAS should the condition of the leak worsen such that pressurizer level OR RCS pressure can NOT be controlled.
8.18.3 IF SFAS has NOT actuated on low RCS pressure of 1650 PSIG AND the RCS pressure decrease is being manually controlled THEN BLOCK the SFAS low RCS pressure trip when the block permit Comes in.
8.18.4 Depressurize the RCS down to AND maintain the minimum adequate subcooling margin limit during RCS cooldown until RCS pressure reaches approximately 1000 PSIG.
THEN Maintain RCS pressure between 975 to 1025 PSIG.
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106 EP 1202.01.1
,f I )
(/ DETAILS 8.18.2 It is desirable to cooldown using BOTH SGs if possible.
Place BOTH loop TBV H/A stations in HAND and position them to establish a cooldown at a rate as close to 100*F/hr as can be reasonably controlled. IF the condenser is NOT available, use the AVVs. IF the SFRCS or SEAS has tripped the AVVs, BLOCK the trip and take control as follows:
- 1. Place both atmospheric vent valves H/A stations in HAND and run the demand to minimum.
- 2. Press both atmospheric vent valves block buttons, HIS-ICS-11D and HIS-ICS-11C.
- 3. Press AUTO on HIS-ICS-11B and HIS-ICS-11C.
- 4. Control SG pressure as desired from the H/A station.
Atmospheric vent valves will not operate from the Control Room H/A station if ICS AC OR DC is lost OR instrument air pressure is <75 PSIG. Local control will be required per p; Attachment 3, Attachments Tab.
I GM NOTE 8.18.3: SFAS initiation on high containment pressure, high containment radiation and from manual actuation switches will function normally with the SFAS low RCS pressure trip BLOCKED. To manually actuate the SEAS in responses to low RCS pressure, the operator can actuate all the necessary equipment for the required incident level, component by component, from each component control switch OR manual actuation at the SFAS system level from the manual actuation switches.
8.18.3 When RCS pressure is <1800 PSIG and annunciator alarm SFAS RC PRESS <1800 BLK PRMT (5-3-3) comes in, BLOCK all four SFAS channels and insure the SFAS RC press <1650 TRIP BLOCKED (5-4-3) light comes on. IF manual actuation of SFAS becomes necessary, refer to Table 2 in Tables Tab for component status information.
8.18.4 Adequate subcooling margin exists when the TSAT meters 1 indicate 2 20*F. If NEITHER TSAT meter is available,
. adequate subcooling margin exists when the RCS pressure and temperature combination on the P/T display or manual plot is above and to the left of the subcooled margin line. This g pressure is below the fuel-in-compression curve, but it is rx necessary to reduce the driving force on the tube leak.
(_),/ This is also shown on Figure 1 in the Figures Tab.
107 EP 1202.01.1 ACTIONS 8.18.5 BLOCK SFRCS low main steam line pressure AND SG high level trips when the block permit comes in.
8.18.6 g the tube ruptured SG Operate Range level is approaching 1l the SFRCS high level trip setpoint (94%)
THEN Increase the steaming rate on the tube ruptured SG to attempt to keep the level below the SFRCS trip setpoint.
8.18.7 E the tube ruptured SG Operate Range level can NOT be 1l maintained <94% on the Operate Range THEN Stop steaming the tube ruptured SG AND close its MSIV )
AND continue the cooldown on the good SG.
~
8.18.8 When RCS conditions of 500*F Tc AND 1000 PSIG are reached, if the non tube ruptured SG can be steamed THEN Stop the RCS cooldown.
Close the MSIV on the tube ruptured SG.
Maintain DH removal by steaming the good SG with the TBVs (AVV if condenser is not available), AND go to Step 8.19.
0R E the non tube ruptured SG can NOT be steamed THEN Go to Step 8.20.
8.19 Proceed with plant operations as directed by PP 1102.10, Plant Shutdown and Cooldown and refer to the appendices of AB 1203.40, SG )
Tube Leak, for additional guidance on actions and control measures.
108 EP 1202.01.1 p
DETAILS 8.18.5 When SG pressure is <650 PSIG and annunciator alarms SFRCS CH 1 (2) MN STM LO PRESS /HI LVL BLK PRMT (12-3-3(4)) come in, BLOCK all four SFRCS channels and insure both SFRCS CH 1 (2)
MN STM LO PRESS /HI LVL TRIP BLKD (12-4-3(4)) annunciator alarms come in.
8.18.6 If cooldown is established using the TBVs and condenser, an SFRCS high level trip would cause SG isolation forcing use of AVVs. If the cooldown is established using the AVVs, an SFRCS high level trip would necessitate closing the AVV to protect it from possible water damage. An increased steaming rate on one SG will require a decreased steaming rate on the other SG to maintain the cooldown rate constant.
8.18.7 If the SFRCS high SG level trip has NOT been BLOCKED, a 1l water level of 94% on the Operate Range will cause a high SG level SFRCS trip. The steam generator cannot be steamed above this level as possible water damage to the MSIV, MS line, TBVs, or AVV might occur, preventing later isolation of the SG. If the water level can't be controlled, the cooldown will have to be shifted to the good SG and the tube ruptured SG isolated before water enters the MS line.
8.18.8 When RCS conditions of 500*F Tc and 1000 PSIG are reached, stop the RCS cooldown by closing back on the TBVs (AVVs).
Ensure no steam loads are being supplied by the tube ruptured SG MS line and isolate the tube ruptured SG by closing its MSIV. The SG will continue to fill thru the tube rupture.
Increase the steaming rate using the TBVs (AVV) on the good SG enough for DH Removal as indicated by constant or slightly decreasing Tc.
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109 EP 1202.01.0 ACTIONS 8.20 Transition from SG cooling to MU/HPI cooling.
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8.20.1 Stop the RCS cooldown but continue to steam the tube ruptured SG enough to maintain RCS temperature constant or slightly decreasing until it has been at least 1/2 hour since reactor shutdown (or trip).
DO NOT continue until the reactor has been shutdown at least l 1/2 hour.
l 8.20.2 Increase MU/HPI flow to start increasing pressurizer level l at a rate as fast as RC pressure can be controlled AND At the same time maintain RCS pressure above the minimum %
adequate subcooling margin limit but below 1000 psig by:
Jf Manually operating RC2, spray valve (RCPs on)
QR Manually operating RC239A and RC200, pressurizer vent line OR RC2A, PORV (RCPs off)
B.20.3 IF the increased MU/HPI flow, in combination with the j steaming on the tube ruptured SG, re-establishes enough cooldown rate to slow pressurizer fill, THEN Reduce the SG steaming rate.
O
110 EP 1202.01.0 DETAILS 8.20 . Transition from SG cooling to MU/HPI cooling.
These steps will establish MU/HPI cooling with the RCS solid, the
. PORV open and, if necessary,140 gym letdown in service, while I maintaining adequate subcooling margin AND maintaining RCS pressure less than the SG MSSV setpoints. This will permit isolation of the tube ruptured SG AND maintain core cooling without SG heat removal.
8.20.1 The reactor must be shutdown for at least 1/2 hour to allow the decay heat level to be low enough to be matched by i MU/HPI cooling. The tube ruptured SG will have to be steamed until this time limit is reached. The cooldown is stopped by closing back on the TBVs (AVVs) when RCS tempera-ture of 500* Tc (520' Th, RCPs off) is reached, but maintaining enough steaming to prevent RCS heatup.
i 8.20.2 This step is trying to collapse the steam bubble as quickly
- as possible while still maintaining RCS pressure control.
This step will have to be coordinated with Step 8.20.3 below.
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j-8.20.3 This step will have to be coordinated with Step 8.20.2 above. The increased MU/HPI cooling will have to be i
balanced with the SG heat removal or the RCS contraction will slow pressurizer fill.
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l 111 EP 1202.01.0 ACTIONS O
8.20.4 When the pressurizer goes solid, as indicated by a sudden rapid increasing of RCS pressure, Immediately Open the PORV.
Throttle MU/HPI flow to maintain RCS pressure greater than the minimium adequate subcooling margin limit but less than 1000 PSIG. .
8.20.5 Stop steaming the tube ruptured SG and monitor RCS temperature.
E the RCS begins to heat back up THEN Go to an RCP combination that has a maximum of two RCPs -
running Re-establish letdown flow for additional core cooling, up O
to 140 GPM may be required.
8.20.6 Close the MSIV on BOTH SGs AND Isolate the tube ruptured SG per AB 1203.40, Appendix A.
8.20.7 As the RCS cools down, throttle MU/HPI back to maintain RCS pressure close to but greater than the minimum adequate subcooling margin limit.
8.20.8 g RCPs are NOT running, open the loop high point vents, Loop 1, RC4608A AND RC4608B Loop 2, RC4610A AND RC4610B AND Maintain adequate subcooling margin based on incore T/C temperature AND Continue attempts to regain forced RCS flow.
112 EP 1202.01.0
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DETAILS 8.20.4 When the pressurizer goes solid, RCS pressure will begin rapidly increasing. At this time, LOCK OPEN the PORV with its control switch and throttle NU/HPI to maintain RCS pressure greater than the minimum adequate subcooling margin limit but less than 1000 PSIG.
8.20.5 Stop steaming the tube ruptured SG by closing the TBVs (AVVs). At this time, the core is being cooled by NU/HPI injection to the RCS with flow out of the RCS through the PORV. If additional RCS cooling is needed and three or four RCPs are running, going to a 2 running RCP combination will reduce heat input to the RCS. Re-establishing letdown flow will provide additional cooling by removing hot water from the RCS and increasing NU/HPI flow. --
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8.20.6 When the NSIVs are closed, NFW will be lost, however, it is not needed in this mode of cooling. The tube ruptured SG secondary water level will continue to increase through the leak.
8.20.7 RCS pressure should be maintained as low as possible to minimize the leak rate through the ruptured tube but this will have to be, balanced against the core cooling required to maintain decay heat removal. As RCS pressure is lowered, the flow through the PORV will decrease.
' 8.20.8 With RCPs NOT running and no SG heat removal, there will be no natural circulation flow in the loops. The stagnant hot water in the loops may eventually flash to steam as RCS :
pressure is lowered. Opening the loop high point vents will l provide a small amount of flow in the loops, although it will probably be insufficient to prevent loss of minimum subcooling margin in the loops. Forced RCS flow, even with only one RCP running, should prevent loss of minimum subcooling margin in the loops, i
113 EP 1202.01.0 ACTIONS 0
8.20.9 Transfer MU pump suction between the MU tank and the BWST by shifting MU3971, as necessary, to keep MU tank level between the high and low level alarm points AND -
Insure the MU pumps are injecting greater than the letdown flow to the RCS so MU tank level can be lowered.
8.20.10 Continue cooldown and depressurization in this manner until plant conditions permit establishing DHR system cooling at 250 PSIG and 280*F. Use PP 1102.10, Plant Shutdown and Cooldown, as a guide as much as possible.
AND Monitor BWST level. If BWST level decreases to 8 feet before DHR system cooling can be established, piggyback HPI to LPI taking suction on the containment emergency sump per SP 1104.04, Section 11.
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114 EP 1202.01.0 CT DETAILS 8.20.9 With letdown in service, it will be necessary to periodically pump the NU tank level down. It is NOT desirable to divert the letdown to the CWRTs as it will cause more inventory loss from the BWST. When the decay heat level is low enough that core cooling can be maintained by the flow through the PORV alone, letdown can be isolated. The actual time when this will occur will have to be determined by periodic attempts.
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I 116 EP 1202.01.0 !
- 9. INADEQUATE CORE COOLING ACTIONS No assumptions have been made on how the inadequate core cooling condition was reached. Obviously the condition could only be the result of a series of equipment failures and/or operational errors. Nevertheless, the condition is assumed to have occurred and this procedure provides guidance on what steps should be taken to correct the problem. Note that some of the equipment called upon is the same equipment which would probably have to have failed in order to reach this condition. Therefore, completion of all of the steps may not be possible, but those steps that can be completed should be. Some directions given in this section are not in agreement with directions in other procedures or other sections of this procedure.
If an inadequate core cooling situation exists, the directions of this section supersede all others.
ACTIONS FOR INADEQUATE CORE COOLING 9.1 Actuate AND control MU/HPI per specific rules 1 and 2.
9.2 Verify operable SG(s) Startup Ra'nge level is at OR manually increase to 124".
9.3 Lower SG pressure to induce heat transfer.
9.3.1 Depressurize SGs, while maintaining secondary side water level, to achieve secondary TSAT 90* to 110'F lower than TSAT for the existing RCS pressure.
9.3.2 When heat transfer is restored, continue to depressurize SGs as necessary to achieve a 100*F/hr RCS cooldown rate.
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117 EP 1202.01.0
- 9. . INADEQUATE CORE COOLING N./
DETAILS ACTIONS FOR INADEQUATE CORE COOLING 9.1 Specific rules 1 and 2 are contained in the Specific Rules Tab.
9.2 Verify operable SG(s) Startup Range level is at OR manually increase to 124". -
- 1. If STRCS AND SA2 are actuated, SG levels will be auto controlled at 124".
- 2. If SFRCS is actuated but SA2 has NOT actuated, levels will be auto controlled at 46". Change thT SG level setpoint to HIGH on the SFAS valve panel.
- 3. If MW is the only W source available, manually increase SG 1evels to 124". This may require resetting or overriding STRCS trip signals to provide a flowpath dependent on the exact failure.
- 4. If the SUFP is the only W source available, place it in service on ONLY ONE SG. Refer to Steps 6.4 and 6.5 or 6.6. When the SG level is increased to 124", return to Step 9.2. For remainder of this section, steps directing actions on both SG's will only apply to the SG being fed by the SUFP.
9.3 This step is making the SG a better heat sink by lowering the SG TSAT below the RCS TSAT. Both TSATs must be determined from the corresponding system pressure. If the condenser is available, place TBV H/A stations in HAND and open them slowly to lower SG pressure.
If the condenser is NOT available, use AWs to lower SG pressure.
If the STRCS or SFAS has tripped the AWs, BLOCK the trip and take control as follows:
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118 EP 1202.01.0 ACTIONS 0
9.4 Ensure core flood tank isolation valves are open CFIA AND CF1B.
9.5 Verify LPI systems are actuated with SFAS Incident Level 3 at 450 PSIG RCS pressure with maximum LPI flow supplied to the core.
9.6 IF RCS pressure is > 1500 PSIG OR subsequently increases to > 1500 PSIG _
THEN Open RC2A (PORV) A_N_D RC11, PORV block, if closed AND Cycle the PORV, as necessary, to maintain RCS pressure 90 to 100 PSIG greater than the highest SG pressure.
9.7 Monitor the incore T/C temperatures AND RCS pressure.
9 . 7 . 7. Refer to Figure 2 AND take action according to the following table.
REGION ACTION 1 Go to Section 11 2 Continue Step 9.1 thru 9.7 3 Go to Step 9.8 4 Go to Step 9.12 9.8 If possible, start one RCP per loop. Do NE override normal pump starting interlocks. Containment isolation for seal injection and component cooling water may be BLOCKED and opened as necessary.
9.9 Attempt to induce heat transfer from the RCS to the SGs.
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119 EP 1202.01.0 0 DETAILS
- 1. Place the atmospheric vent valve H/A station in HAND and run the demand to minimum.
- 2. Press the atmospheric vent valve block button HIS-ICS-11D or HIS-ICS-11C.
- 3. Press AUTO on HIS-ICS-11B or HIS-ICS-11C.
- 4. Control SG pressure as desired from the H/A station.
9.5 SFAS incident level response should be verified in accordance with Table 2, Tables Tab.
9.6 This step is attempting to keep RCS pressure as low as possible to allow maximum injection flow, while maintaining the normal AP direction on the SG tubes. __ .
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9.7 Monitor the incore T/C temperatures A_ND RCS pressure.
9.7.1 Figure 2 is in Figures Tab. Core outlet temperature is determined from the incore T/C temperatures per Attachment 4, Attachments Tab. RCS pressure is determined from wide range pressure indication (SFAS Channel 1 or 2 can be used as they also input to the TSAT meters).
9.8 If necessary, refer to SP 1103.06, RC Pump Operation, for starting and operating limits.
9.9 Attempt to induce heat transfer from the. RCS to the SGs.
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120 EP 1202.01.0 ACTIONS 9.9.1 Manually increase AND maintain BOTH SG levels to 85% on the Operate Range.
9.9.2 Rapidly lower BOTH SG. pressures to achieve a 100*F step decrease in secondary TSAT. Use the following table for guidance on how far to drop secondary pressure.
INITIAL PRESSURE FINAL PRESSURE (PSIG) 1000 400 800 300 600 210 400 125 9.10 Further depressurize the RCS by cycling the PORV, as necessary, to keep RCS pressure 40 to 60 PSIG greater than the highest SG pressure ~
AND Open or verify open the loop AED pressurizer high point vents.
Loop 1 RC4608A AND RC4608B Loop 2 RC4610A AND RC4610B Pressurizer RC239A AND RC200 9.11 Check for re-established SG heat transfer.
9.11.1 IF heat transfer from the RCS to at least one SG IS NOT established THEN Lock open RC2A (PORV) control switch to depressurize the RCS until MU/HPI/CF/LPI return incore T/C temperature to saturation AND THEN Go to Section 12, MU/HPI Cooling SE 9.11.2 IF heat transfer from the RCS to at least one SG IS established when incore T/C temperatures return to saturation 1
Go to Section 11, RCS Saturated 3G Removing Heat.
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121 EP 1202.01.1
( ,) DETAILS 9.9.1 Using the available feed source, MFW, AFW, or SUFP, increase SG 1evels to and then maintain 85% on the Operate Range.
This SG 1evel may promote boiler condenser cooling while allowing some margin below the SFRCS high SG level trip 1l setpoint at 94% on the Operate Range. If RCP restart was not possible per Step 9.8, increasing SG 1evel in this step may cause the SG depressurization that will be performed in Step 9.9.2.
9.9.2 This step is attempting to induce heat transfer by lowering the heat sink temperature. At this point, the temperature drop is limited to 100*F to maintain the SG tube to shell AT within the 100*F limit.
9.10 This step is attempting to further increase injection flow by lowering RCS pressure while still maintaining the normal AP direction on the SG tubes.
O 9.11 Check for re-established SG heat transfer.
9.11.1 If heat transfer to at least one SG cannot be re-established, core cooling is via the available ECCS injecting water through the core, out the PORV and system high point vents, and into the containment vessel.
9.11.2 If heat transfer to at least one SG is re-established, core 7 cooling is via a combination of ECCS injection water and SG heat removal.
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122 EP 1202.01.1 ACTIONS 9.12 If possible, start all four RCPs.
9.12.1 If necessary, jumper RCP start interlocks per Attachment 5 AND Record the start time for each RCP, 1-1 1-2 2-1 2-2 Set the "ST timer" for 30 minute from the time cach pump is started.
1l 9.12.2 If CCW is NOT available to the RCP motor within 30 minutes from the starting time THEN Trip the RCP.
9.13 Attempt to induce heat transfer from the RCS to the SGs. D 9.13.1 Manually increase AND maintain BOTH SG 1evels to 85% on the Operate Range.
9.13.2 Rapidly depressurize BOTH SG pressures to 60 to 100 PSIG.
9.14 Depressurize the RCS by opening the PORV and RC11, the PORV block valve, if closed AND Open or verify open the loop AND pressurizer high point vents.
Loop 1 RC4608A AND RC4608B Loop 2 RC4610A AND RC4610B Pressurizer RC239A AND RC200
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123 EP 1202.01.1 h
DETAILS 1-r 9.12 If possible, start all four RCPs.
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! 9.12.1 RCP. starting interlocks are jumpered per Attachment 5, l Attachments Tab. If the interlocks must be jumpered, complete the work on one pump and then proceed to the next one, starting each pump as soon as its interlocks are
, jumpered. The motor overload trip circuit will remain in 1 service. It should be recognized that' starting the RCP
, without cooling and/or injection water will probably fail ,
l the pump seals and may cause the pump shaft to break.
i 9.12.2 To minimize the possibility of a fire in containment, in conjunction with hydrogen in the containment atmosphere, the RCPs must be tripped after 30 minutes of run time without CCW available to the motor, i /
9.13 Attempt to induce heat transfer from the RCS to the SGs. I 9.13.1 Using the available feed source, NFW, AFW, or SUFP, increase j SG levels to and then maintain 85% on the Operate Range.
j This SG 1evel may promote boiler condenser cooling while j allowing some margin below the SFRCS high SG 1evel trip 1l setpoint at 94% on the Operate Range. If RCP restart was
- not possible per Step 9.12, increasing SG 1evel in this step '
j may cause the SG depressurization that will be performed in j Step 9.13.2.
9.13.2 This step is a further attempt to induce heat transfer by j lowering the heat sink temperature. SG pressure must be 1 maintained at a minimum of 50 PSIA to drive the AFPT unless i its steam is being supplied by the Auxiliary Boiler or the j startup feed pump is feeding the SGs.
1 9.14 This step is a further attempt to increase injection flow by lowering j RCS pressure. RCS pressure should eventually drop enough to allow j LPI to start injecting water at approximately 150 PSIG.
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124 EP 1202.01.0 ACTIONS 0
9.15 When incore T/C's return to the saturation temperature for the existing RCS pressure AND LPI flo's is established THEN
- 1. Decrease running RCPs to one per loop.
- 2. If the core flood tanks have emptied, close the core flood tank isolation va'ves, CFIA and CFIB.
9.16 Check for re-establiahed SG heat transfer.
9.16.1 IF heat transfer from the RCS to at least one SG IS estab-lished, go to Section 11, RCS Saturated SG Removing L st.
IF NOT 9.16.2 IF heat transfer from the RCS to at least one SG IS NOT s Etablished go to Section 12, MU/HPI Cooling. N 4s e
125 EP 1202.01.0 i '
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EP 1202.01.2 127 r ] 10. A LARGE LOCA HAS OCCURRED AND THE CORE FLOOD TANKS ARE EMPTYING
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The objective of this section is to provide high level guidance to allow continued plant cooldown using existing procedures for the details of system and equipment operation. This high level guidance is necessary since the end conditions reached in the various sections of this procedure will not necessarily coincide with the assumed entry conditions in the existing plant and system procedures. The time span over which these actions are performed is sufficient to allow consulting other procedures, drawings, and references for the details of operation.
10.1 As time permits, perform the following actions:
- 1. Notify the STA.
- 2. Check EI 1300.01, Emergency Plan Activation, to determine j
if Emergency Action Levels have been exceeded and implement any appropriate procedures.
10.2 Reverify proper SFAS response to all trip parameters present i
per Table 2, Tables Tab.
- 1. SFAS equipment may NOT be overridden except as addressed in specific rule 4, Specific Rules Tab.
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l / 2. Additional equipment overridden per specific rule 4.2.8,
with the Plant Manager's (or designee's) approval, l l should not be done without a review of the potential release of radioactive gas or liquid from containment.
10.3 IF RCS pressure stabilizes above the maximum injectian pressure for LPI (about 200 PSIG) l THEN
- 2. IF there is NO heat transfer to either SG, go to Section 12, MU/HPI Cooling.
10.4 Refer to PP 1102.10, Plant Shutdown and Cooldown, for the balance of plant operation as much as possible.
10.5 Verify LPI system operation per SP 1104.04 Section 9, DH and LPI Operating Procedure.
- 1. The referenced procedure includes instructions for cross connecting one LPI pump for injection on both LPI lines in the event one of the LPI pumps is disabled.
10.6 Control HPI flow per specific rules 1 and 2 contained in the
, ^3,.i,, Specific Rules Tab.
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128 EP 1202.01.0 10.7 q SFAS Incident Level 4 has actuated, verify CS system operation per SP 1104.05, CS System. -
10.8 Stop both MU pumps.
i 10.9 Prior to the BWST level decreasing to 8', determine if HPI can be stopped per specific rule 2.3 contained in the Specific Rules Tab.
- 2. E HPI can NOT be stopped, piggyback LPI to the HPI pump suction per SP 1104.04 Section 11, DH and LPI Operating Procedure.
10.10 When the BWST level decreases to 8', transfer the LPI (and CS if running) pump suction to recirculation from the containment emergency sump per SP 1104.04 Section 10, DH and LPI Operating Erocedure.
- 1. E CS pumps are still operating, verify CS discharge valves CS1530 and CS1531 go to the THR0 TILE position.
10.11 Continue LPI cooling until further instructions are given.
10.12 When a SG depressurizes to 25 PSIG, shutdown the AW to that SG per SP 1106.06 Section 5, Auxiliary Feedwater System.
- 1. Core cooling via SG heat removal will not exist and is not required in a large LOCA. The AFPTs are left running until SG pressure decreases to 25 PSIG for heat removal from the SGs only. If a SG tube leak is known to exist, the AW to that SG should be shutdown.
10.13 After approval per specific rule 4.2.8 AND if NOT supplying power to the essential electrica buses, return both DGs to the standby ' condition per SP 1107.11, EDG Operating Procedure.
10.14 Monitor AND control containment conditions per Table 3 in Tables Tab.
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129 EP 1202.01.0 10.15 IF MCCE11B OR MCCF11A is NOT powered, in order to allow valve O* s operation in the next step, an emergency tie of MCCE11B and MCCF11A can be accomplished as follows: I
- 1. Insert the draw out units to breaker modules BE1153 (E11B) AND BF1135 (Fila).
NOTE: These draw out units to be installed into the l breaker cubicles are located in the Maintenance Shop storage bin and yellow tagged. Breaker cubicle BE1153 (E11B) is located on Elevation 585' outside the #3 Mechanical Penetration Room.
Breaker cubicle BF1135 (Fila) is located on Elevation 603' on the north end of the #2 Electri-cal Penetration Room.
- 3. Manually trip all load breakers of the non-energized MCC except the Auxiliary Spray and Decay Heat Cooldown l Isolation Valve Breakers BF1125 AED BF1130 if Fila is NOT energized OR BE1155 AND BE1183 if E11B is NOT energized.
- 4. Close cross tie breakers BE1153 AND BF1135 which completes I
the tie between E11B and Fila.
3 10.16 Within seven dayr, initiate a long term boron dilution flowpath by performing one of the following steps:
- 1. Open DH11 AND DH12 and verify a minimum total flow of 40 gym on FI4908 and FI4909. If flow can NOT be verified, close DH11 AND DH12.
- 2. Close RC10. Open DR2736 AND DH2735 and verify a minimum flow of 40 gpa on FI4999 (located on Elevation 565' in hallway across from MU Pump Room).
EP 1202.01.2 130
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) SATURATED WITH SGs REMOVING HEAT The objective of this section is to provide high level guidance to allow continued plant cooldown using existing procedures for the details of system and equipment operation. This high level guidance is necessary since the end conditions reached in the various sections of this procedure will not necessarily coincide with the assumed entry conditions in the existing plant and system procedures. The time span over which these actions are performed is sufficient to allow consulting other procedures, drawings, and references for the details of operation.
11.1 As time permits, perform the following actions:
- 1. Notify the STA.
- 2. Check EI 1300.01, Emergency Plan Activation, to determine if Emergency Action Levels have been exceeded and implement any appropriate procedures.
11.2 Reverify proper SFAS response to all trip parameters present per Table 2, Tables Tab.
- 1. SFAS equipment may NOT be overridden except as addressed s, in specific rule 4, Specific Rules Tab.
c 2. Additional equipment overridden per specific rule 4.2.8,
'2 l with the Plant Manager's (or designee's) approval, should not be done without a review of the potential release of radioactive gas or liquid from containment.
11.3 Verify that heat transfer is being controlled.
- 1. Verify maximum MU/HPI flow per specific rule 1, Specific Rules Tab.
- 2. Verify SG levels are at or increasing to the appropriate setpoint on the Startup Range per specific rule 1 at full continuous flow per specific rule 3.4, Specific Rules Tab.
11.4 IF RCS pressure decreases to the point where LPI flow starts, THEN Go to Section 10, Large LOCA.
IF NOT Continue in this section.
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131 EP 1202.01.0 11.5 Ensure the CF tank isolation valves remain open, CFIA and CFlB.
11.6 Begin a cooldown of the RCS referring to PP 1102.10, Plant Shutdown and Cooldown, as much as possible. [F the RCS cooldown rate due to the HP flow is 2100*/hr, steaming per step 11.6.1 below will not be necessary until cooldown rate is
<100*/hr.
- 1. Increase SG steaming by MANUAL control of TBVs if the condenser is available OR AVVs if the condenser is NOT available.
Incore T/C temperatures decrease as SG pressure is lowered AND SG pressure remains coupled to Tc.
- 3. BLOCK SFRCS low main steam line pressure trip when the BLOCK PRMT alarm comes in.
- 4. IF the RCS does NOT cooldown as the SGs are depressurized resulting in primary to secondary heat transfer being ,,
lost, THEN IF an RCP is running, go to Section 12, MU/HPI Cooling, SE IF an RCP is NOT already running, go to Section 6, Lack of Heat Transfer, Step 6.13.
- 5. IF heat transfer to the SGs is maintained or restored THEN Continue saturated cooldown by decreasing SG pressure.
11.7 IF BWST level decreases to 8' THEN IF running, stop the MU pumps AND Piggyback LPI to the HPI pump suction per SP 1104.04 Section 11, DH and LPI Operating Procedure.
. i 132 EP 1202.01.0 11.8 After approval per specific rule 4.2.8 AND if NOT supplying A power to the essential electrical buses, return both DGs to the standby condition per SP 1107.11, EDG Operating Procedure.
11.9 Monitor A_ND control containment conditions per Table 3 in Tables Tab.
11.10 g the RCS becomes superheated, based on the guidance in Step 5.7, THEN Go to ICC Section 9.
11.11 E the RCS remains saturated during the cooldown, go to Step 11.13 g minimum adequate subcooled margin is regained on the incore T/Cs and the hot legs during the cooldown proceed as directed below:
- 1. Q an RCP is running, go to Section 13, Solid Cooldown Tir Pressurizer Recovery.
- 2. E an RCP can NOT be started, go to Section 13, Solid
-Q Cooldown or Pressurizer Recovery.
NOTE: SUBSTEP 3:
When restarting RCPs on natural circualtion or with possible steam voids in the RCS, anticipate a drop in RCS pressure and pressurizer level.
- 3. E an RCP can be started, start an RCP per SP 1103.06, RC Pump Operating Procedure, preferably in Loop 2 to provide pressurizer spray, AND E adequate subcooling margin still exists two minutes after the RCP. start, go to Section 13, Solid Cooldown or Pressurizer Recovery.
E E adequate subcooling margin is lost after the RCP start, allow the pump to continue to run and proceed with Step 11.12. The RC pump may be running with the RCS saturated. If the pump vibration reaches 30 mils stop the pump and start a different pump. It is desirable to maintain one RC pump running if possible.
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133 EP 1202.01,0 11.12 When the CF tank levels decrease to O', close the CF tank isolation valves CFIA and CFIB. Refer to SP 1104.01, Core Flooding System Operating Procedure, for guidance on correcting indicated CF tank level for containment ambient conditions.
11.13 Continue RCS cooldown and depressurization by decreasing SG pressure. WHEN RCS pressure decreases to 250 PSIG (this l
corresponds to 406' saturation temperature) ;
THEN
- 1. Decrease the cooldown rate by throttling back on the TBVs (AVVs).
- 3. At this point as the core decay heat level decreases and the core is cooled by HPI and some secondary side cooling, I adequate subcooled margin will be regained. When adequate i subcooled margin is regained at this time, remain in this I section and continue with Step 11.14. '
11.14 While maintaining RCS pressure at 250 PSIG with HPI, continue the cooldown by decreasing SG pressure until the operating '
conditions of the DHR system are met (<250 PSIG and <280 F).
When these conditions are met, proceed with Step 11.15.
11.15 Determine the operability of the DH pumps. If both Dit pumps are available, go to Step 11.17. If only one DH pump is available, continue with Step 11.16.
11.16 Continued cooldown with only one DH pump initially available.
- 1. Piggyback the operable DH pump to the suction of the HPI pump (s) per SP 1104.04 Section 11, DH/LPI Operating Procedure.
- 3. IF/WHEN the BWST level decreases to 8', transfer the LPI pump suction to the emergency m p per SP 1104.04 Section 10.
- 4. Maintain these plant conditions until the second DH pump becomes available.
- 5. IF the second DH pump is NOT available within seven days, establish a long term boron dilution flowpath per Section 10, Steps 10.15 and 10.16 AND then return to this section, Step 11.16.6.
- 6. WHEN the second DH pump becomes available, start it in the DH removal mode through DHil and DH12 using the applicable steps of SP 1104.04 Section 4.
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134 EP 1202.01.0 t
N 7. With decay heat flow greater than 1000 gpm, any running RCPs may be stopped. '
- 8. As RCS temperature decreases, throttle HPI flow to reduce RCS pressure while maintaining adequate subcooling margin.
- 9. WHEN RCS pressure is low enough that at least 1000 gpm LPI flow is established on the DH pump in the LPI mode, stop HPI pumps and close the piggyback valves DH63 and DH64.
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- 10. With one DH pump in the DH removal mode and one DH pump in the LPI mode with suction from the emergency sump, maintain this mode of cooling until further instructions are given by Station Management.
11.17 Continued cooldown with both DH pumps available
- 1. IF/WHEN the BWST level decreases to 8', transfer the LPI pump suction to the emergency sump per SP 1104.04 Section 10, DH/LPI Operating Procedure.
- 2. Start one DH pump in the DH removal mode through DH11 and DH12 using the applicable steps of SP 1104.04 Section 4.
3.
0;j With the decay heat flow greater than 1000 gps, any running RCPs may be stopped.
- 4. As RCS temperature decreases, throttle HPI flow to reduce RCS pressure while maintaining adequate subcooling i mergin. ,
- 5. WHEN KCS pressure is low enough that at least 1000 gpa LPI flow is established on the DH pump in the LPI mode, stop HPI pumps and close the piggyback valves DH63 and DH64.
- 6. With one DH pump in the DH removal mode and one DH pump in the LPI mode with suction from the emergency sump, maintain this mode of cooling until further instructions
, are given by Station Management.
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EP 1202.01.2 135 T 12. TRANSIENT TERMINATION FOLLOWING AN OCCURRENCE THAT LEAVES THE RCS (j BEING COOLED BY MU/HPI COOLING The objective of this section is to provide high level guidance to allow continued plant cooldown using existing procedures for the details of system and equipment operation. This high level guidance is necessary since the end conditions reached in the various sections of this procedure will not necessarily coincide with the assumed entry conditions in the existing plant and system procedures. The time span over which these actions are performed is sufficient to allow consulting other procedures, drawings, and references for the details of operation.
12.1 As time permits, perform the following actions:
- 1. Notify the STA.
- 2. Check EI 1300.01, Emergency Plan Activation, to determine if Emergency Action Levels have been exceeded.and implement any appropriate procedures.
12.2 Reverify proper SFAS response to all trip parameters present per Table 2, Tables Tab.
- 1. SFAS equipment may NOT be overridden except as addressed
,_. in specific rule 4, Specific Rules Tab.
- 2. Additional equipment overridden per specific rule 4.2.8, SJl with the Plant Manager's (or designee's) approval, should not be done without a review of the potential release of radioactive gas or liquid from containment.
12.3 Refer to PP 1102.10, Plant Shutdown and Cooldown, for the balance of plant operation as much as possible.
12.4 IF the RCS becomes superheated, based on the guidance in Step 5.7 THEN Go to ICC Section 9.
12.5 Monitor AND control containment conditions per Table 3 in Tables Tab.
12.6 Prior to the BWST level decreasing to 8' , piggyback LPI to the HPI pump suction per SP 1104.04 Section 11, DH/LPI Operating Procedure.
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136 EP 1202.01 0 12.7 When the BWST level decreases to 8', transfer the LPI (and CS if running) pump suction to recirculation .' rom the containment emergency sump per SP 1104.04 Section 10
- 1. E CS pumps are operating, verify OS discharge valves CS1530 and CS1531 go to the THROT"LE position.
12.8 Open or verify open the following valve :
- 2. RC4608A AND RC4608B, Loop 1 high point vents.
- 3. RC4610A AND RC4610B, Loop 2 high point vents.
- 4. RC239A AND RC200, pressurizer high point vent.
12.9 While the core is being cooled by MU/HPI cooling flow into the RCS and out the open vent valves, control MU/HPI per specific rules 1 and 2, in the Specific Rules Tab.
AND Continue efforts, in parallel, to regain heat transfer to a SG
- 1. E the SUFP is regained after entering Section 12 without it, return to Section 6, Step 6.4.
- 2. E main or auxiliary feedwater is regained after entering 3 Section 12 without it, return to Section 6, Step 6.7.
. 3. E the ability to bump or run an RCP is regained after '
entering Section 12 without it, return to Section 6, Step 6.14.
- 5. E heat transfer to at least one SG is regained AND the RCS has adequate subcooled margin, go to Section 13.
12.10 E the RCS is saturated, ensure CFIA and CFIB, CF tank isolation valves, remain open until the CF tank level decreases to O',
THEN Isolate the CF Tanks. Refer to SP 1104.01, Core Flooding System Operating Procedure, for guidance on correcting indicated CF tank level for containment ambient conditions.
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137 EP 1202.01.0 12.11 RCS adequate subcooled margin will eventually be regained allowing MU/HPI throttling for RCS pressure control. As the RCS cools down, throttle HPI flow to decrease RCS pressure.
WHEN RCS temperature is <280*F AND RCS presaure is <250 PSIG THEN Go to Section 11, Step 11.15.
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EP 1202.01.2 138 l
<x 13. TRANSIENT TERMINATION FOLLOWING AN OCCURRENCE THAT MAY REQUIRE PRESSURIZER RECOVERY OR SOLID PLANT C00LDOWN WITH SG(s) REMOVING
- HEAT AND RCS SUBC00 LED l
l The objective of this section is to provide high level guidance to l allow continued plant cooldown using existing procedures for the details of system and equipment operation. This high level guidance j is necessary since the end conditions reached in the various sections of this procedure will not necessarily coincide with the assumed entry conditions in the existing plant and system procedures. The time span over which these actions are performed is sufficient to allow consulting other procedures, drawings, and references for the details of' operation.
13.1 As time permits, perform the following actions:
- 1. Notify the STA.
- 2. Check EI 1300.01, Emergency Plan Activation, to determine if Emergency Action Levels have been exceeded and implement
! any appropriate procedures.
13.2 Reverify proper SFAS response to all trip parameters present i
per Table 2, Tables Tab.
- 1. SFAS equipment may NE be overridden except as addressed
/,.s in specific rule 4, Specific Rules Tab.
l - 2. Additional equipment overridden per specific rule 4.2.8, 2l with the Plant Manager's (or designee's) approval, should not be done without a review of the potential release of radioactive gas or liquid from containment.
13.3 g the RCS is being vented through the PORV line or high point vents THEN Isolate all vent flowpaths
- 2. Close RC4608A AND RC4608B, Loop I high point vents
- 3. Close RC4610A AND RC4610B, Loop 2 high point vents
- 4. Close RC239A AND RC200, pressurizer high point vents 13.4 g the SFAS has actuated, if possible reset the SFAS and restore components per PP 1102.03, Trip Recovery.
13.5 Monitor AND control containment conditions per Table 3 in Tables Tab.
13.6 E-there is a bubble in the pressurizer, refer to PP 1102.10, Plant Shutdown and Cooldown as much as possible.
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139 EP 1202.01.1
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NOTE: 13.7: When restarting RCPs on natural circualtion or with possible h y
, steam voids in the RCS, anticipate a drop in RCS pressure and pressurizer level.
13.7 Go to a 0/2 RCP combination, if possible, for plant cooldown.
If on natural circulation and RCPs can NOT be started continue with Step 13.8. Start RCPs per SP 1103.06, RCP Operation.
1 RCP restart may be performed after step 13.10 at the Shift Supervisors discretion.
13.8 Control MU/HPI flow
- 1. Throttle MU/HPI flow to maintain RCS pressure as low as possible without exceeding any limits per Figure 1 Figures Tab. It may be possible to terminate HPI per specific rule 2.3, Specific Rules Tab.
- 2. Re-establish letdown flow as an aid in RCS pressure control.
13.9 Il[ the decision is made NOT to establish a bubble in the pressurizer, proceed with a solid plant cooldown at Step 13.13, 13.10 Establish a bubble in the pressurizer N
(.. 1. Turn on all available pressurizer heaters.
y
- 2. Monitor.the increase in pressurizer water temperature.
When the temperature reaches saturation for the existing RCS pressure, a bubble will begin forming.
- 3. Increase letdown flow to lower pressurizer level to approximately 200".
13.11 After a bubble is formed, control RCS pressure within the limits of Figure 1, with heaters and spray (RCPs on) or pressurizer vent (RCPs off).
13.12 Refer to PP 1102.10, Plant Shutdown and Cooldown as much as possible.
13.13 If a bubble is NOT formed in the prassurizer, proceed with plant cooldown following PP 1102.10 as much as possible. As eL. cooldown rate is established using the TBVs (AVVs if condenser is NOT available), RCS pressure will have to be centrolled by increasing RCS makeup (or HPI) or decreasing letdown flow to compensate for RCS contraction.
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140 EP 1202.01.0 SPECIFIC RULE 1 ACTIONS FOR LOSS OF ADEQUATE SUBC00 LING MARGIN 1.0 ACTIONS FOR LOSS OF ADEQUATE SUBC00 LING MARGIN 1.1 If RCS pressure is > 1650 PSIG SFAS trip setpoint, two MU pumps must be run at full MU system capacity taking suction from the BWST as long as BWST level > 8'.
- 1. Start the second MU pu.np.
- 2. Fully open MU32, MU coatrol valve.
p r'
- 3. Shift MU pump suction to the BWST by closing MU3971, MU pump suction 3-way valve.
1.2 HPI must be initiated per specific rule 2.1.
1.3 RCPs must be immediately tripped.
1.4 Operable SG 1evels must be raised to 124" (128") on the Startup Range using AFW.
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141 EP 1202.01.0 SPECIFIC RULE 2 -
MU/HPI FLOW INITIATION THROTTLING, AND TERMINATION 2.4 HPI Piggyback Operation 4
2.4.1 HPI piggyback operation may,be initiated at the operators discretion, as an aid to maintaining pressurizer level, at times not specifically called for by the procedure for any plant condition except the following. A large break LOCA has occurred such that there is LPI flow into the RCS and LPI pump suction is from the BWST.
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2.0 MU/HPI FLOW INITIATION, THROTTLING, AND TERMINATION 2.1 HPI Initiation i
2.1.1 If RCS pressure is 5 1650 PSIG SFAS trip setpoint, two HPI pumps must be run at full HPI system capacity.
- 1. Verify both HPI pumps start.
- 2. Verify valves HP2A, HP2B, HP2C, and HP2D are fully open.
- 3. Balance HPI flow between the two lines on each pump such that the higher flow < 1.5 times the lower flow. Throttle only the high flow line and do NOT throttle it below the value on Figure 3.
If MU pumps are injecting through line 2-1 (valve HP2A line) flow on FIHP3A may be indicating low.
2.2 MU/HPI Throttling 2.2.1 MU/HPI must be throttled to prevent exceeding the appropriate maximum RCS Pressure / Temperature for cooldown Limit Line on Figure 1.
2.2.2 HPI must be throttled, during piggyback operation, to limit HPI pump flow to < 950 gpm per pump.
2.2.3 HPI must NOT be throttled to < 35 gpm per pump when the pump recire valve is closed.
1 2.2.4 HPI may be throttled and normal MU flow established when adequate subcooling margin has been restored and pressurizer level is > 100" and increasing.
2.2.5 MU must be throttled to maintain pump discharge pressure
> 1500psig and motor current < 57 amps.
2.3 MU/HP1 Termination 1
2.3.1 HPI may be stopped if the LPI system has been started and flow has been 2 1000 gpm/line for 2 20 minutes.
2.3.2 If core cooling is NOT being provided by MU/HPI cooling (at least one SG is available as a heat sink),
HPI may be stopped and normal MU flow established when adequate subcooling margin has been restored and pressurizer level is > 100" and increasing.
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142 EP 1202.01.0 /
L.
. SPECIFIC RULE 3 r
i SG LEVEL SETPOINTS 3.0 SG LEVEL SETPOINTS i*
- 3.1 If SFRCS has actuated and SA2 has NOT actuated, maintain operable SGs at 46" (50") on the Startup Range us:ing AFW.
, 3.2 If SFRCS has actuated and SA2 has actuated, maintain operable SGs as 124" (128") on the Startup Range using AFW.
3.3 If SFRCS has NOT actuated, maintain 35" (low level limit) on the Startup Range using MFW.
3.4 If using AFW, when SG level is below setpoint, maintain full continuous AFW flow until the appropriate SG level is-reached.
3.5 If using AFW, due to the level error band of AFW level control, it may be necessary to place AFPT controls in MANUAL to control SG level in a narrower band to reduce RCS pressure swings.
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, . . . ,_.,,_-,.....an, -,,,-,...,.-,,,,,.,,,.,,m .,,..,-,...,nv.. ,, -
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4 4.0 MISCELLANEOUS POST ACCIDENT ACTIONS 4.1 Compensation For Elevated Containment Temperature If containment temperature is > 150 F as determined by the average of the running containment air cooler suction tempera-ture, manually maintain appropriate level as indicated below.
- 1. Maintain compensated or uncompensated pressurizer level
> 80" or manually de-energize pressurizer heaters.
4.2 Do NOT Override Any SEAS Actuated Equipment Except As Listed Below
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- 1. If RCS pressure is > SFAS 450 PSIG TRIP, the following valves may be overridden to the open position:
MU33, RCS Makeup Isolation MU66A, MU66B, MU66C, and MU66D, RCP Seal Injection Isola-tions 1 MU59A, MU59B, MU59C, MU59D, and MU38, RCP Seal Return I Isolations
- 2. If RCS pressure is > SFAS 450 DSIG TRIP, and no seismic event has occurred, the following valves may be overridden to the open position:
MU2A and MU3, Letdown Isolations, when needed for RCS inventory contr61 CC1460, CCW to MU pump header
- 3. When there is a need to sample, the following valves may be overridden to the open position.
CV5010A, CV5010B, CV5010C, CV5010D, CV5010E, CV5011A, CV5011B, CV5011C, CV5011D, and CV5011E, Containment Atmosphere Supply and Return Isolations RC240A, RC240B, and RC232, Pressurizer /RCS Sample Supply and Return l
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143 EP 1202.01 0 #
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SPECIFIC RULE 4 MISCELLANEOUS POST ACCIDENT ACTIONS -
- 4. When needed_to control secondary pressure, the following j valves'may be overridden to the open or throttled position:
ICS11A and ICS11B, Atmospheric Vent Valves
- 5. In the event of a failure of one LPI pump which requires the remaining pump feed through both LPI lines, the following valves may be overridden to the throttled position:
DH14A and DH14B, DH Cooler Outlet Valves
- 6. HPI pump and valve controls may be overridden as necessary to operate the system per specific rule 2.
- 7. If plant conditions are stable at normal operating or hot standby conditions after a transient with no evidence of an RCS leak, other systems may be bypassed with the Shif t Supervisor's permission.
- 8. If there are any questionable conditions or any sign of an RCS leak, no other safety systems should be bypassed without approval of Plant Manager or his designee.
4.3 SFAS equipment that has been BLOCKED and overridden after an SFAS trip can be reactivated two ways:
- 1. At the equipment level, BLOCKED equipment will respond to the individual control switches for that piece of equipment.
- 2. At the system level, operation of the' system level RESET pushbutton will clear any output logic blocks in the system (output logic blocks are the BLOCK switches next to the SAM lights and on the output modules). The equip-ment will then respond to the system level manual actuation TRIP pushbutton and to automatic actuation signals.
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144
[ ( EP 1202.01.0
() ATTACHMENT 1 Page 1 of 2 STARTUP FEEDWATER PUMP FLOWPATH VERIFICATION If the Control Room operator indicates that he is not receiving any flow, check the position of the following valves:
VALVE POSITION SUFP Min Recirc Iso Valve, FW 96 657' south end of Heater Bay Area in front of blue guard rail OPEN SUFP Min Recirc Iso Valve, FW 97 657' south end of Heater Bay Area in front of blue guard rail OPEN SG 1-2 FW SU Ce? trol Valve Iso Valve, FW 162 603' north end of Heater Bay next to west wall OPEN SG 1-2 FW SU Control Valve Iso Valve, FW 154 603' north end of Heater Bay next. to west wall OPEN SUFP to 11ain Feed Line Iso Valve, FW 106 Q. 603' southwest corner of Heater Bay above blue guard rail (behind FW 45) OPEN SG 1-1 FW SU Control Valve Iso Valve, FW 142 603' south end of Heater Bay in front of blue guard rail (behind FWHs) OPEN SG 1-1 FW SU Control Valve Iso Valve, FW 161 603' southwest corner of FW Heater Bay at corner of blue guard rail OPEN SUFP to HP Cond Valve, FW 102 585' north end of FWH 1-1-6 next to west wall CLOSED Demerator Storage Tank 1-1 to 1-2 Out Manual Crossover Valve, FW 84 585' on Christmas Tree' OPEN Demerator Storage Tanks to AFP Suction Valve, FW 85 585' on Christmas Tree CLOSED l
SUFP Suction From Deaerator Storage Tanks Valve, FW 32 585' on Christmas Tree CLOSED r SUFP Suction from Cond Storage Tanks, Valve FW 91 north end of AFP Room 1-2, east side of SUFP OPEN
145 EP 1202.01.0 ATTACHMENT I Page 2 of 2 VALVE POSITION O
SUFP Discharge Valve, FW 100 north end of AFP Room 1-2, west side of SUFP (next to wall) OPEN SUFP Min Recire Valve, FW 93 north end of AFP Room 1-2, west side of SUFP (next to wall) OPEN l
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(~-) , EP 1202.01.0 ATTACHMENT 2 Page 1 of 3 RE-ENERGIZATION OF D2 BUS FOR STARTUP FEED PUMP (SUFP)
This attachment provides guidance for re-energizing D2 bus by providing the necessary major steps without addressing any specific complications.
If complications exist, the appropriate procedures will have to be con-sulted. Also, some steps may be omitted if unnecessary at the time; for example, A or B bus may already be energized from offsite power.
Determine most desirable source for D2 bus and proceed per the below table. Sources are listed in descending order of desirability. When D2 bus is re-energized, return to Step 6.4.
Source Section Remarks B Bus 1.0 Assumes 01 or 02 is energized A Bus 2.0 Assumes 01 or 02 is energized and DG2-on D1 bus 7 qn D1 Bus /DG2 3.0 Assumes offsite power not available, l ; ) DG2 on D1 bus f ss_/
C1 Bus /DG1 4.0 Assumes offsite power and DG2 not available, DG1 on C1 bus l
1.0 Re-energization of D2 bus from B bus 1.1 Re-energize B bus from offsite power
- 1. Trip / verify tripped all the load breakers on B bus.
- 2. Turn the sync selector switch on and close the desired supply breaker for B bus, HX01B OR HX02B.
- 3. Turn the sync selector switch off.
l 1.2 Re-energize D2 bus from B bus via BD transformer 1
- 1. Trip / verify tripped all the load breakers on D2 bus EXCEPT AD211, lighting feeder breaker
- 2. Close HBBD
- 3. Close ABDD2 1.3 Loads on B and D2 buses may be re-energized at the Shift Super-visor's discretion. A turbine plant cooling water (TPCW) pump
("')N
(_, must be in service to support SUFP operation.
147 EP 1202.01.0 ATTACHMENT 2 2.0 Re-energization of D2 bus from A bus 2.1 Re-energize A bus from offsite power
- 1. Trip / verify tripped all the load breakers on A bus
- 2. Turn the sync selector switch on and close the desired supply breaker for B bus, HX01A OR HX02A
- 3. Turn the sync selector switch off 2.2 Re-energize D1 via AC transformer
- 1. Verify AACC2 and AACD1 are tripped
- 2. Close HAAC
- 3. Parallel DG2 with AC transformer across AACDI, close AACD1 and trip AD101 2.3 Re-energize D2 from D1
- 1. Trip / verify tripped all the load breakers on D2 bus EXCEPT--
AD211, lighting feeder breaker
- 2. Trip / verify tripped ABDD2
- 3. Close AD11D 2.4 Loads on A and D2 buses may be re-energized at the Shift Super-visor's di:.cretion. A TPCW pump must be in service to support SUFP operations.
3.0 Re-energization of D2 bus from D1 bus (assuming DG 2 on D1 bus) 3.1 Re-energize D2 from D1
- 1. Trip / verify tripped all the load breakers on D2 bus EXCEPT AD211, lighting feeder breaker
- 2. Trip / verify tripped ABDD2
- 3. Turn sync selector to AD110 and close AD110, turn sync selector off 3.2 Loads on D2 bus may be re-energized at the Shift Supervisor's discretion. A TPCW pump must be in service to support SUFP operation. DG2 load will have to be limited within DG ratings.
Half the plant normal lighting is returned to service but may have to be de-energized to limit DG load.
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148 EP .1202.01.0 ATTACHMENT 2
. Page 3 of 3 4.0 Re-energization of D2 bus from C1 bus (assumes DG 1 on C1 bus) 4.1 Re-energize D2 from C1
- 1. Trip / verify tripped all the load breakers on D2 bus EXCEPT AD211, lighting feeder breaker
- 2. Trip / verify tripped AD110.
- 3. Trip / verify tripped HBBD
- 4. Trip / verify tripped ABDD2
- 5. If C1 is supplying C2, trip AC110.
- 6. Turn sync selector to ABDC1 and close ABDC1, turn sync selector off
- 7. Close ABDD2 4.2 Loads on D2 bus may be re-energized at the Shift Supervisor's discretion. A TPCW pump must be in service to support SUFP operation. DG1 load will have to be limited within DG ratings.
Half the plant normal lighting is returned to service but may have to be de-energized to limit DG load.
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EP 1202.01.0 ATTACHMENT 3 Page 1 of 4 OPERATION OF ATMOSPHERIC VENT VALVES I. NORMAL OPERATION (ICS)
- 1. Instrument air is supplied through IA supply valve through both SA1 and SA2. This air positions VI and V2 open (air ported from boosters to actuator) and V3 closed. V2 and V3 are two-way valve (open/ closed). VI is a three-way valve which ports from booster to actuator o_r actuator to vent.
- 2. Modulation is achieved by the transducer which receives the ICS signal. The transducer (I/P) supplies a control air signal to the positioner which in turn supplies a control signal (increased or decreased modulation) to the two boosters.
II. SAFETY FEATURES ACTUATION / STEAM FEEDWATER RUPTURE CONTROL SYSTEM
- 1. An SFAS or SFRCS signal de-energizes SA1 and SA2 - V1 repositions to vent the actuator while V2 closes. V3 opens and 100# air
.. positions the actuator down through V3.
- 2. The transducer, positioner, and boosters have no control since V2 is closed and V1 is positioned to vent.
- 3. To re-establish ICS control, the SFAS/SFRCS actuation must be cleared or blocked. Ensure the H/A station is at 0%. Then ,
press HIS ICS liA/B AUTO. This energizes SA1 and SA2 and allows either ICS auto control or H/A station manual control.
III. EMERGENCY OPERATION USING THE REl'OTE VALVE OPERATORS A. Operation with sal and SA2 energized. This would be the condition with SFAS AND SFRCS NOT tripped.
0,R SFAS OR SFRCS tripped AND trip blocked AND valve control returned to auto.
In this condition, V3 is closed, and it is NOT possible to vent the air off the valve actuator using only valves A and B.
- 1. IF access to Control Room switches HIS ICS IIA and B is Wallable, THEN, press CLOSE on the switches and proceed per Section B.
150 EP 1202.01.0 ATTACHMENT 3 Page 2 of 4 i
- 2. IF access to the Control Koom is NOT available, h THEN close the instrument air supply to Main Steam Atmsopheric l Vent Valve IA450, located on Turbine Building 585' level next to the emergency isntrument air compressor receiver and i proceed as follows:
NOTE: Closing IA450 isolates instrument air to the following valves:
ICS11A ICS11B MS375 MS394 MS100A MS101A
- a. Valve A (see urawing) must rerain open.
- b. Open Valve B (vent valve) to vent supply piping, allowing V3 to open so actuator will also vent.
- c. Check the handwheel counter at zero. Then open the handwheel (CCW) to the desired position.
O turns = closed --
253 turns = open NOTE: Valve does no,r start to open until approximately 13 s turns.
- d. If partial closing is desired, simply rotate the manual handwheel in the clockwise direction since the valve is spring assisted in the close direction.
- e. If positive shutoff is desired, close the manual handwheel until it reaches the full closed position (zero counts on counter).
- f. Close B valve.
CAUTION: Do NOT open IA450 unless BOTH valve's remote manual operator counters are at zero counts as damgae can occur to the lifting fork on the valve stem.
- g. Open IA450 to restore closing air to BOTH actuators.
(
O
151 EP 1202.01.0 l ATTACHMENT 3 Page 3 of 4 r-~s
(,,,I B. Operation with SA1 and SA2 de-energized. This would be the condition with SEAS or SFRCS tripped, AND The trip signal has NOT been blocked, AND The valve has NOT been returned to auto.
t
- 1. Manual control of the atmospheric vent valves is necessary I to maintain hot standby conditions.
1
- 2. In the radwast ventilation area outside the Control Room j (elevation 623') is located a manual handwheel and two valves for each atmospheric vent valve. Instructions are posted near each handwheel as follows:
)
- a. Close Valve A (see drawing) which isolates air from Valve V3.
- b. Open Valve B (vent valve) which vents actuator air --
through V3.
4 c. Check the handwheel counter at zero. Then open the
!c'ge-}- handwheel (CCW) to the desired position.
0 turns = closed 253 turns = open NOTE: Valve does not start to open until approximately 13 turns.
- d. If partial closing is desired, simply rotate the manual handwheel in the clockwise direction since the valve is spring assisted in the close direction.
- e. If positive shutoff is desired, close the manual handwheel until it reaches the full closed positoin (zero counts on counter). !
- f. Close B valve.
CAUTION: Do NOT open A valve unless remote manual operator l counter is at zero counts as damage can occur to the lifting fork on the valve stem.
- g. Open A valve to restore closing air to the actuator.
l
/%.
\
Valve Stem J ,
control Vent 7
(Silencer) 30 PSIG -tr- V2 7 Regulator Signal / Close / !. h, y3 Booster 3 ;
Fr'om II/A 30 PSIC Station / T } } 2, i i.
100 PSIG J 6 Closing F. y Signal ! I [!j n ,
SA2 (V)
[ h osition 100 PSIC Supply
/ Bypass g,ine Transducer l j
' For 8 $
Opi ning Emergenc / g Si nal y) Close Directi t)a Operatio i o g
(Spring Assit t) N N
m Open.
[]
100 PSIG Actuator 3, IA \ nooster g g Supply j _
VI 52h5
-O-O P Mn rol Vent NO # -
wo VI - Vents to atmospliere on SPAS or SFRCS (Silencer) Clieck (']
V2 - Closes on SFAS or SFRCS (normally open)
V3 - Opens on SFAS or SFRCS (normally closed) Valve 1 l
r (V)
m,.
)
m l
DETEPJ!I!;ATIO:; 0F CORE OUTLET TEMPERATURE Core outlet tenperature will be determined using the incore T,'C's which are the inputs to the TSAT neters. Connunications should be established between a person at the Post Accident Monitoring Panel and the Post Accident Monitoring Cabinet. The person recording the readin;:s at each cabinet Test Display Module dicital display should note the "as found" position of the Test Display Module thumbwheel switch and then set it to
- 43. When the readings have been completed the thusbwheel switch should be returned to the "as found" position. The person at the Post Accident Monitoring Panel should rotate the Incore Temperature Selector Switch clockwise through all 8 positions starting at the switch tcp center position. If both TSAT channels are available, core cutlet temperature will be the average of the 5 highest temperatures. If enly one TSAT channel is available, core outlet temperature will be the average of the 3 highest temperatures on that channel. !f neither TSAT channel is avail-able, have I & C take the 16 T/C temperatures, by point number, per IC2001.07 Manual Measurement of Incore Thermoccuples and report then to the control roon. Core outlet temperature will be the average of the 5 highest readings.
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153 h tsc h nt 4 EP 120"' 01*1 (Page 1 of 2) ,/
Ch nnel 1 i Channel 1 i Char.nel 1
{ Core Point Temp Core Point Temp Core Pcint Teno Location ,. . . Location ,. Location ..,-,
umoe r -a,e 6a,B . u: er C-a.,6aB
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MS 4627 HS 4627 ES 4627 E9 I T539 l E9 i T539 I E9 i T539 I .
C10 i T544 i CIO I T3-4 I C10 i T544 i .
Kll 1 T551 l K11 1 T551 1 Kil 1 T551 i L13 I T560 l L13 i T560 ! L13 i T560 i M7 I T532 1 M7 I T532 1 i M7 i T532 1 0o 1 !527 1 _ Oo t T527 1 06 i T527 G5 ! T520 i G5 i T520 i G5 I T520 !
F3 I T514 I F3 I T511. I 1i F3 i T514 Channel 2 Channel 2 l l Channel 2 Core Ccre Ccre Location Point
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Location Point .cco A
Location Point
_.e p au: C -3,, 3 3 ^, .ucher C - 3 / ;. .' ""'U*# C - 2 ' 2 2 ~-
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Channel 1 Channel 1 1 i Cora Core
~~-
re Point Temp Point Temp Point Temp t Location Location
'ocation Number C-5763B Number C-5763B HS 4627 Nu=ber C-5763B US4627 HS 4627
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T539 E9 T539 E9 T539 T544 C10 T544 C10 T544 1 !
'K11 T551 K11 T551 K11 T551 ! !
7 L13 T560 L13 T560 L13 T560 -
T532 I
- M7 T532 M7 T532 M7 06 T527 06 T527 06 T527 l T520 G5 T520 I i b G5 l T520 G5 1 T514 F3 T514 1 1 !
T514 F3 i 1
] F3 l Channel 2 Channel 2 Channel 2 i
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, Core Core l
- E *E Location **E b
- ocation Location Nu ber C-5755A i Nuc er C-5755A Number C-5755A HS 4623 l h 462S HS 4623 E7 i T330 1 E7 i T530 i E7 I .T530 i t F13 I T557 i F13 i T557 1 F13 i T557 I [
Gil i T550 l l Gli i T550 i G11 1 T550 I i f 010 i T547 1 010 1 T547 l 010 1 T547 I i M9 I T542 i M9 I T542 M9 i T542 I . s L3 i T515 i L3 i T515 L3 i T515 I .
I y5 T322 i K5 i T522 i KS I T522 1 -
C6 ! T519 i C6 i T519 i C6 i T519 i !
.erate l Time i Date Averace i Time i Date Averace i Tire i Date l l 1 I i i I I j
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-v Core Core
.~~'e Point Temp Pcint Terp Point Tenp
_acation Location .. Location ,. .
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u: er C-2,633 un er MS 4627 HS 4627 HS 4627 E9 I T539 I E9 i T539 I E9 i T539 I i C10 1 T544 i C10 i T544 i C10 1 T544 I :
K11 i T551 i K11 1 T551 1 K11 i T551 I .
L13 i T560 I l L13 ! T560 i L13 I T560 t i M7 i T532 1 M7 I T532 i M7 I T332 1 1 06 i T527 I 06 i T527 1 06 i T527 I G5' I T520 i G5 1 T520 1 G5 1 T520 1 F3 I T514 i F3 i T514 I l F3 I T514 1 i Channel 2 i Channel 2 i Channel 2 i Cere Core Core i Peint Te=p Pcint Terp y Point Tenp '
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au ter C-2< M^,
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i :- I c6 i T519 i C6 l T519 I i 1 e 1 re i Da e i Averace ! Time i Date Averace l Tire i Date !
11 I j i i ;
E um es oca .wo . u- - - - - -
- - (Pagn 2 of 2) ~/
Channel 1 Chennel 1 i Channel 1 I Core Cere Cora Point Te=p Pcint Te=p Point Te=p l Location 1;u=.cer Location.
C-57633 Location 1u=ber C-57633 C-5763R HS 463
!;u=ber HS 4627 ;
MS 4627 E9 I T339 I E9 i T539 I E9 i T539 l .
1 C10 1 T544 I C10 i T3:4 i C10 t T5'a I .
Kil 1 T551 Kll i T551 l Kil i T551 1 L13 i T560 L13 I T560 i L13 i T560 I i M7 i T532 i M7 i T532 l M7 I T532 I i 06 I T527 I i 06 i T527 1 06 i T527 I i G5 1 T520 I i G5 l !520 1 G5 ! T520 t ,
i F3 I T514 I F3 1 T514 i F3 i T514 i
! Channel 2 Channel 2 Channel 2 Cere Core Core Pcint Te=p Point Temp Point Tc=p 1 Locatien Location Location 2,.u=cer .
C-5755A =e C-5735A 'uzber C-5755A -
ge ;g;3 ES 4623 ES 4623 E7 i T530 i l E7 1 T330 1 E7 i T530 i F13 i T557 I I I F12 1 T557 i F13 i T557 1 1
Gil l T350 1 I Gil i T350 i Gil ! T550 1 010 1 T547 l l 010 i T547 1 010 1 T547 i l M9 I T542 I l M9 I T512 1 M9 i T542 I I L3 i T515 i L3 i T515 i L3 i T515 1 l K5 1 T522 I K5 i T522 i K5 i T522 1 C6 i T519 I C6 i T519 i C6 i T519 i 1l1 Averace i Ti=e i Dare lAverace l Ti=e i Date Averace l Ti=e i Date l 1 I I I i l l Channel I Channel 1 l Cnannel 1 lI Ccre Cora Core Temp Pcint Te=p ,
~
Point Te=p Point Location Location Location .
C-37633 ou=ber C-37633 er C-M633 HS 4627 h.u: er HS 4627 HS 4627 T539 E9 i T539 l E9 i T539 I i E9 i I C10 T564 C10 I r5;4 I .
C10 t T544 I I I K11 i T551 i K11 i T551 I :
K11 ! T551 i L13 T550 o L13 i T560 l J L13 i T560 i l M7 T532 M7 i T532 I I M7 I T532 i I 06 i T527 1 06 i T527 I .
l 05 i T527 1 G5 T520 i G5 i T520 1 :
I G5 1 T520 i 1 F3 I T514 i F3 I T514 I .;
F3 i T514 I l
1 Channel 2 ! Channel 2 Channel 2 .l Core Core .
il Cora -
Point Te p Point _ temp ,oca amen Point ienp i.
Lccat,. n .""
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Location .. ,.
"" "# -# ##^, ~ # # # #". i
..ucher HS 4623 ES 162S MS '. 6 5 E7 T530 J i E7 i T530 l E7 i T533 i t l
' F13 i T557 I i F13 I T557 I i F13 i T557 I i)
Gil i T550 i Gil i T550 l t Gil i T550 i 010 i T547 I i 010 i T547 i j 010 i T547 1 M9 i T5a2 i _M9 I T542 l .
M9 I T542 l T51; L3 i T515 i L3 i T515 l !
L3 i K5 !522 i K5 i T522 K5 i T522 i C6 !519 i C6 i T519 i T519 tl C6 Tire I
i Date Aversta
~
=e i Late Averace i Ti=e i Date ;
Averace i ;
1 j i l I i n._ . _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ - _ .
155 EP 1202.01.0 ATTACHMENT 5 Page 1 of 1 TO JUMPER RC PUMP START INTERLOCKS Performing the following will defeat the RCP starting interlocks. All overload protection will be available.
RCP 1-1-1 (HA03)
At RC3717, install jumper on scheme 27X/FS-MU30C, TB20L, Terminal 12 to scheme TSX/RC4B, TB13L, Terminal 11.
RCP 1-1-2 (HB03)
At RC3718, install jumper on scheme 27X/FS-MU30D, TP20R, Terminal 12 to scheme TSX/RC4B, TB13R, Terminal 11.
RCP 1-2-1 (HB01)
At RC3718, install jumper on scheme 27X/FS-MU30A, TB9R, Terminal 12 to scheme TSX/RC4, TB3R, Terminal 11.
RCP 1-2-2 (HA01)
At RC3717, install jumper on scheme 27X/FS-MU30B, TB9L, Terminal 12 to scheme TSX/RC4A, TB3L, Terminal 11.
e
136 EP1202.01.2 /
FIGURE 1 RC PRESSURE / TEMPERATURE LIMITS CURVES 1 THROUCH 6 USE PRSRC2Al AND TIRC4A2 CR TIRC432; CURVES ARE AD.!USTED FOR INSTRtHEhT ERROR.
CURVE 7 USES PR$RC2Al AND INCORE T/C TEMPERATURE CURVE IS ADJUSTED TOR FRESSURE TMSTRtHENT ERROR.
CURVE 8 IS A SATURATION CURVE; No ADJUSTMENTS.
- 1. MAIIMUM RCS PRESSURE /TDEPERATURE FOR C00LIK%18
- 2. MINIMUM PRESSURE /TDtPERATURE TO MAINTAIN ADEQUATE SURC00 LING MARGIN
- 3. MINIMUM PRESSURE /TDtFERAME TO MAINTAIN FUEL IN COMPRESSION 4,
MINIMUM PRES $URE/TDtPERATURE TD MAINTAIN FUE: IN COMPRESSION DURING CDOLDOW ON NATURAL CIRCULATION
- 6. MIN!JCM PRESSURE /TDtPERATURE TO FROVIDE NPFP WITH Tk'O RCPs IN A LC4P 7.
MAXIMLH RCS PRESSURE /TDtFERATURE FCR C00LDOW WITH NO FORCED OR NATL 1tAL CIRCI1.ATION IN RCS (RPI/W C00LINC)
- 8. SATURATION CURVE.
- 9. ABNORMAL TRANSIENT ENVELOPE.
2600 2 .- 5 c.
2400 -
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100 200 300 400 500 600 700 REACTOR COOLANT TEMPERATURE, *F
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157 _.EP 1202.01.0 - - . . .
7 INCORE T/C TEMPERATURE vs. RC PRESSURE FOR INADEQUATE CORE COOLING 2600
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300 400 500 600 700 800 900 1000 1100 1200 1300 Incore Thermocouple Temperature (F) u.__ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ . . _ _ . _ . _ _ . . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ . _ _ . _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ . _ _ . _ . _ _ . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . . . _ _ _
158 EP 1202.01.0 FIGURE 3 HPI THROTTLING LLMIT (FOR HIGH FLOW HPI LINE)
- y. .._
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_ _r._. . . , . _
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EP 1202.01.2 159 Table 1: SFRCS EQUIPMENT ACTUATION (SHEET 1 0F 2)
ACTUATION CHANNEL 1 FULL
- RIPS STEAM LINE 1 SG *.D'JiHICH LEVEL IDW PRESSURE REVERSE F4 10 SG dP IDSS CF ForR (CVER-RIDING AC* ION) STEAM *.INE 2 LOW PRESS RCPs CN'Y CHECK CLOSED: CHECK CI.0 SED: CHECK CLOSED:
ICS-11E AVV #1 ICS-113 AVV ul AF-3S69 AFP v1 OISCH TO SG 82 MS-101-1 MSIV EYPASS #1 MS-101-1 MSIV EYPASS #1 *MS-106A *2 Pl TO AF?! v1 MS-394 MS DRAIN el PS-394 MS DRAIN ul CHECT. OPEN:
MS-611 SG Lrain el SP-?B SU W C2NT VLV #1 SP-7B SU F4 CONT VLV al AF-608 ATJ di CISCH TO SO #1 72-612 MW STOP VLV #1 FW-612 MW SICP VLV #1 MS-106 Al MS !3 AFF" di 2 *MS-106A v2 MS TO AFP* #1 MS-106 #1 MS TO AFPI #1 AF-3870 ATP *1 OISCH TO So al MS-101 MSIV al MS-101 MSIV el ,/, ,,,i= - <
925-100 MSIV #2 MS-100 MSIV cI HAL7 TPIP AF-3870 AFP el DISG TO SG #1 AF-3869 AFP #1 DISG 10 SG #2 STEAM LINE LOW PRESSLTJ.
l- W-780 M W ELE VLV #1 FM-780 MFJ ELE VLV #1 SG LCW/H SM LEVEL l REVERSE FJ To SG dP S?-6A MW CONT VLV #2 SP-6A MW C0!TI VLV 82 CHECE CLOSEO:
AF-608 A W #1 DISCH TO SG #1 ICS-11B AVV 41 MS-101-1 MSIV BYPASS #1 CHECK OPEN: CHECK OPEN: MS-3 % MS LRAIN #1 MS-611 SG LRAIN #1 MS-106A #2 MS TO AFFT #1 MS-106 el MS TO AFFT #1 t
2' AF-3869 AFP #1 DISCH TO SG #2 *If open at the time of the trip, i valve must be manually closed.
AF-3870 AFP el DISCH TO SG #1 f
AF-608 AFW #1 DISCH TO SG #1 CHECK TRIPPED: CHECK TRIPPED:
MAIN TURBINE MAIN TURBIhI REACTOR (via ARIS) REACTOR (via ARIS)
l EP 1202.01.2 .
160 / t
'l Table 1: SFRCS EQUIPMENT ACTUATION (SHEET 2 0F 2)
ACTUATION CHANNEL 2 FULL TRIPS SH AM LINE 2 SG LOW /HIGH LEVEL LOW PRESSURE REVERSE W TO SG dP LOSS OF FOUR fCVER-RIDING AC" ION) STEAM LINE 1 LCW FRESS RCPg 0*1Y CHECK CLOSED: CHECK CLOSED: CHECK CLOSED:
ICS-11A AVV #2 ICS-11A AVV d2 AF-3871 AFP d2 DIS 3 TO SG #1
- l MS-100-1 MSIV BYPASS d2 MS-100-1 MSIV BYPASS #2 *MS-lG7A #1 MS TO AFF #2 MS-375 MS DRAIN d2 MS-375 MS DRAIN #2 CFECK OPEN
MS-603 SG DRAIN d2 SP-7A S" FJ CCfC '.1 V v2 SP-7A St W "A!C VLV #2 AF-599 ATP **; DIS 3 !C SG *2 FW-601 MFW SICP VL" d2 FW-601 M W STOP VLV #2 MS-107 m2 MS !O AFP* #2 2
- MS-107A #1 MS TO AFP~ *2 1 MS-107 *2 MS TO AFFI #2 AF-3572 ATP =2 DISCH TO SO e2 MS-101 MSIV #1 MS-101 MSIV #L ,,, .i, c, ,,i.
MS-100 MS!V v2 MS-100 MSIV #2 HALF
- RIP AF-3872 AFP 02 DISCH TO SG #2 AF-3871 AFP #2 DISCH TO SG *1 STEAM LINE LOW PRESSURE PJ-779 PFJ 3LK VLV #2 W-779 MFJ ELK VLV #2 SG LOWiH CH LEVEL REVERSE PJ TO SG dP SP-6B MFJ CONT VLV #1 SP-6B MFJ CCtC VLV #1 CHECK CLOSED:
AF-509 AFJ #2 DIS 3 TO SG #2 ICS-11A AVV #2 MS-100-1 MSIV SYPASS #2 CHECK OPEN: CHECK OPEN: MS-375 MS CRAIN er MS-603 SG CPAIN #2 MS-107A #1 MS 10 AFPI #2 MS-107 #2 MS TO AFPT e2
- AF-3871 AFP #2 DISCH #1 AF-3872 AFP #2 DISCH TO SG #2 *If open at the tritre of the trip, j valve must be manually closed.
AF-599 A W #2 DISCH TO SG #2 CHECK TRIPPED: CHECK TRIPPED:
MAIN TURBINE MAIN TURBINE REACTOR (via ARIS) REACTOR (via ARTS)
- a
i 161 EP 1202.01.0 )
Table 2: SFAS EQUIPMENT ACTUATIO (Sheet 1 of 2)
ACTUATION CHANNEL 1 SFAS INCIDENT LEVEL 1 SFAS INCIDE'.T LEVEL 2 VLV # EOUIPMEPC DESCRIPTION POSITION VLV # ECUIPMENT DESCRIPTION POS! tit Emer Vent Fan 1 Start HP Inj Pep 1 S: art HV5437 ECCS Room 105 HV&AC Iso V1v Closed HP2C HP Inj 1-1 V1v Cpen HV5440 ECCS Room 105 HV&AC Iso Viv Closed HP2D HP Inj 1-2 V1v Cpen HV5024 Emer Vent Fan i Viv From Aux Bldg Closed CDC Clr Fan 1 Slow HV5716 ECCS Room 115 Iso Depr Closed CT!C Clr Fan 3 Slow CV5008 CDC Purge Out Iso Viv Closed CC Pump 1 Start CV5011A CT!C Air Sample Iso Viv Closed CC Pump 3 S: art CV5011B CT!C Air Sample Iso Viv Closed CV5070 CDC Vacm R1f Iso Viv Closed CV5011C CTMI Air Sacple Iso Viv Closed CV5071 CDC Vacm Rif Iso V1v 7 ned CV5011D CIE Air Sample Iso Viv Closed CV5072 CDC Vacm Rif Iso Viv Closed CV5006 CTMI Purge In Iso Viv Closed CV5073 CDC Vacm Rif Iso Viv Closed CV5009 Mech Pent Room 4 Purge Viv Closed CV5074 CDC Vace Rif Iso Viv Closed CV5016 Mech Pent Room 4 PurFe V1v Closed SW Pump 1 5: art CV5011E CDC Air Sep1 Ret Iso Viv Closed SW Pump 3 Start CDC Ret Fan & HV/AC Unit 1 Stop SW1424 SW From CC HX 1 Iso Viv Open Sk'1429 SW From CC EX 3 Iso Viv C >en CS1530 CS 1 Iso V1v Coen SFAS INCIDENT LEVEL 3 Emer DG 1 5: art MU2A RC latdown Delay Coil Out Viv Closed VLV # EOUIPMENT DESCRIPTION POSITION DR2012A CDC Norm Sump Iso V1v Closed RC240A RC Przr Sample Viv Closed DH Pump 1 Start SW1399 SW Iso Viv to Cing W:r Closed CCli67 CC From DH Clr 1 Out Viv Cpen RC1773A RC DT Hdr Iso Viv Closed DH2733 DH Pump 1 Suct Viv From BWST Open RC1719A CDC Vent Edr Iso V1v Closed DH14B DH Clr 1 out V1v Open SS607 SG 1 Sample Iso Viv Closed DH13B DH Clr 1 bypass Viv Closed ICS11E SG 1 Atm Sem Vent V1v Closed CC1495 CC Aux Equip In V1v Closed SS235A Przr Qnch Tk Sample Iso Viv Closed MU33 RC MC Iso Viv Closed CF1544 CF A 1 W:r & Nitrogen Fill Iso V1v Closed:
MU66B RCP 2-2 Seal In Iso V1v Closed DH9B CDC Emer Sump Viv Closed ML'66C RCP 1-1 Seal In Iso Viv Closed DH75 BEST Out Viv Coen i M"39A RCP 2-1 Seal Ret Viv Closed NN236 Ni:rogen CDC Isc Viv Closed:
MU59B RCP 2-2 Seal Ret Viv Closed RC229A Przr Qnch A Out Iso V1v Closed!
MU59C RCP 1-1 Seal Ret Viv Closed MS3% Mr. 5:m Line 1 WU Drn Iso Viv Closed:
MU59D RCP 1-2 Seal Ret V1v Closed CV5065 CDC HydroFen Dilution In Iso V1v Closed DW6*31A ECF STDP Demin W:t Iso Viv Closed CV5035 CT'C Hydrogen Dilution Crat Iso Viv Closed SFAS INCIDENT LEVEL 4 VLV # EOUIP'IENT DESCRIPTION POSITION CS Pump 1 Start CC1411A CC In Iso Viv to CDC Closed CC1407A CC Out Iso Viv From CD C Closed CC1567A CC In Iso V1v to CRD Closed CC1328 CC CRD booster Pump 1 Suct Viv Closed MS101 Mn Stm Line 1 Iso Viv Closed FW112 hn FW 1 Stor V1v Closed tis 100-1 ha Lee Line 1 WU Iso Viv Closed
E w
4 6 ,
162 EP 1202.01.0
[.
Table 2: SFAS EQUIPMENT ACTUATION
!- (SHEET 2 of 2) l
'~
ACTUATION CHANNEL 2 I
I I
SFAS INCIDEhT LEVEL 1 SFAS INCIDENT LEVEL 2 VLV e EOUIPMENT DESCRIPTION POSITION VLV # EOUIP"ENT DESCRIPTION POS! TIC; Emer Vent Fan 2 Start HP Inj Pmp 2 Start HV5441 ECCS Room 115 HV&AC Iso Viv Closed HP2A HP Inj 1-2 Viv Cben HV5442 ECCS Room 115 HV&AC Iso Viv Closed EF2B HP Inj 2-2 Viv Open HV5025 Emer Vent Fan 2 Viv from Aux. Bldg. Closed CDC Clr Fan 2 Slow HV5715 ECCS Room 105 Iso Depr Closed CT!C Clr Fan 3 Slow CV5010D CDC Air Sample Iso Viv Closed CC Pump 2 Start CV5004 Mech Pent Room 3 Purge Viv Closed CC Pump 3 Start CV5021 Mech Pent Room 3 Purge Viv Closed CV5075 CDC Vaca R1f Iso Viv Closed:
CV5005 CDC Purge In Iso Viv Closed CV5076 CDC Vace Rif Iso Viv Closed.
CV5007 CDC Purge Out Iso Viv Closed CV5077 CDC Vacm R1f Iso Viv Closed' CV5010A ~ CDC Air Sample Iso Viv Closed CV5078 CDC Vace Rif Iso Viv Closed CV5010B CDC Air Sample 1so Viv Closed CV5079 CDC Vace R1f Iso Viv C'osed CV5010C CDC Air Sample Iso Viv Closed SW Pump 2 Start CV5010E CDC Air Sample Ret Iso Viv Closed SW Pump 3 Start CIRM Ret Fan & HV/AC Unit 2 Stop SW1434 SW From CC HX 2 Iso Viv 6en SW1429 SW From CC HX 3 Iso V1v 6en CS1531 CS 2 Iso Viv Open SFAS INCIDENT LEVEL 3 Emer DC 2 Start MU3 RC Letdown Hi Icep Viv Closed VLV # EOUIPVEh2 DESCRIPTION POSITION LR2012B CDC Norm Sump Iso V1v Closed RC2405 RC Przr Vapor Sacple Viv Closed DH Pump 2 Start CT1542 CF R Vent Iso V1v Closed
'CC1469 CC From DH Clr 2 Out Viv Open SW1395 SW 1so Viv to Cing Wtr Closed DH2734 DH Pump 2 Suet V1v From BWST Open EC1773B RC DT Hdr Iso Viv Closed Dd14A DH Clr 2 Out Viv Open RC1719B CDC Vent Hdr Iso \1v Closed DH13A DH Clr 2 Bypass Viv Closed S5598 SG 2 Sample Iso Viv Closed CC1460 CC Viv to Erser Inst Air Ceps Closed
- ICS11A SG 2 Atm Stm Vent Viv Closed-PC38 RCP Seal Ret Iso V1v Closed SS235B Przr C'nch n Sample Iso Viv Ctosed VU66A RCP 2-1 Seal In Iso Viv Closed CT1541 CF Ik 2 Wtr & Nitroger. Till Iso Viv Closed.
MU66D RCP 1-2 Seal In Iso Viv Closed RC232 Przr Qnch Tk In Ise Viv Closed RC229B irzr Qnch n Out Iso Viv Closed CC1545 CF A Sample Viv Closed SFAS INCIDENT LEVEL 4 DH9A CDC Emer Sump Viv Closed DH7A L.'SI Out Viv C"x n POSITION IA2011 CDC Instr Air 1so Viv Closed, VLV a EOUIPMENT DESCRIPTION SA2010 CDC Serv Air Iso V1v Closedi CS Pump 2 Start !:5375 .% Sem Line 2 WU Drr Iso Viv Closed?
CC1411B CC In Iso V1v to CDC Closed CV5090 CI!C hydrogen Dilution in Iso Viv Caosed; CC1407B CC Out Iso Viv From CDC Closed L'a6831B RCP STDP Demin Wtr Iso Viv Closedi CC1567B CC In Iso Viv to CRD Closed CV5037 CDC Hydrogen Dilutier Out Iso Viv Closed l CC1338 CC CRD Looster Pump 2 Suct V1v Closed MS100 in Stz Line 2 Iso V1v Closed W601 ha FW 2 Secp Viv Closed MS100-1 Mn Srm Line 2 WU Iso V1v Closed m . a
h%s '
\
W3TES
. Freque ey si ru. dings thould b2 estEblished by Shif t Sup;rvisar bisxd c.n plrnt condittins.
- 2. Hydrogen analyzers must be returned to service af ter SFAS actuation.
1 Containment rectre 'ans should be in operation to keep containment atmosphere thorougbly mixed.
.. Accuracy of contai.eent wide range level andscation is 1 6.6 feet.
If containment water level must be lowered, follow guidance below.
_ "? PPI?S Acti'n Level 1
- 1. kerify STAS INC LEVEL 1 through 3 per Table 2.
Action Level :
A3ti+n Level 3
- 1. kerif y SFAS INC LEVEL 1 through 4 per Table 2.
~
aJ Aetten Level 1
- 1. kertry STAS INO LEVEL 1 per Table 2.
A:ta=n Leve;
- 1. Stop bydrogen purge per SP 110. 55.
- 2. Request of f stte support evaluatton prior to using Hydrogen Purge System.
'*** FYro0CEN Artt"n Level 1
- 1. Inform offstte support groups; TSC and E00' Art 1*n Level 2
- 1. Initiate one bydrogen control system tc tne order listed below:
11 Operate hydrogen re:ometner 2: Operate hydroren Lilation Blowers per SP 110 55
- 3) Operate hyoroge: Purge System per SP 1104.55 I'"- '.T!!El k? LE Ti setton Level I 1 Oneca f;r fluid tvstems leaming into containment, SW, CCk, MFW, AFW, Lk, or Pk, and isolate.
- 2. Refer tc M 509 tot equipment elevations instoe containment for potential fatlures.
l tec Level :
- 1. Lh valve pt v1.. tegt: to flood taru vent pipe. Open CHl. and EH10 f or long term coron dilution f.owpath prior tc valve f at.ure er use alternate flowpath - See Section 10 Step 10.le.
settet Lave 3
- 1. hyorosen purge penetration wall begin to flood. Soutdown hycrogen Furge System per SP 1104.!!.
-*** S'?MP PnPON Artter leve! 1
- 1. Insure long term coro dilution flowpatt is estaeltsned.
L. Oceca f or stdt:atter. cf occ-corated flute leasage intc. ecntatcment (tnereasing leve'.
- 3. !! no proclems are f ound, request offstte support group evaluation on nees for Dorot addition.
- gross rurte ltatt tas peer. evaluated fer tne EW:7 tc tne event the EWST must be used for terocrary storage :f ra:toactive water Tnts mist cecur. for example. af ter a LOCA wcen f cr crerational reasons .. is aestred tc pump some
. ter from esttainment tacr. L: tne PWS! Ine limit and assumptions are as foiiows:
Itse After Average Gamma EWST snutoest Eneres Curye Limit (i nr ..Q Mev 2500 C.
25 nr 0.9 Mev 3300 C1
.:I:e curte Atmats have been evaluated to result to a cose rate of 2.0 mrem /tr at the exterior cf tne Personne'.
Froessstog Faellity (PPF;. If tne gallon amount allowed as toc restrtetive f or toe oestred plant evolution, consult
.~.n2a caJ EP Managemect for a more detailed calculatloc or to allow a cnange in the dose rate basis.
- o csiculate the allowable transfer amount in sa;1ons using tne f ollowing formula, tne operator will need to Know the 13e stace reactor shutoown and toe gross activity of tne containment sump water.
10 6 uct Gallons a fC1 limit *' ' et
(;*.C Sample g.:y W E Es cc gat per aeove based on time since reactor snutdown.
Ints would give the maxtmum amount witbtn the assumptions. Any lesse r amaunts wo.id, theref ore, be conservative. The ectu;l amount transferred would have to then be baseo on the BWST level change during tne transfer.
k EP 1202.01.2 I
163 Table 3: CTMT MONITORING AND CONTROL CTMT CTMT RAD CTMT CTMT VES CTMT PRESS H2 WR LEVEL BORON PSIA MR/HR R/HR % FEET PPM 8599, EE8B $ $ %2 g g FROM c=c= c==c e e == c c C&HP -
, 2OOU c.
C2EU S $ CC 3: I: SA'IPLE l e e c: e c: c: = x << ,
ACTION 2 SFAS TRIP INCREASING LEVEL 1 218.4 SETPOINTS N/A , 20.5 ON RECIRC , 51500 '
ACTION 2100 at 55 hr LE\TL 2 233 N/A 250 at $10 hr 23 2 33.7 N/A !
ACTION ' ' t
! LESTL 3 238.4 N/A N/A N/A 2 36.1 !' N/A !
t TIME '
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L_.__________.__._
. i DBAS
, DISTRIBUTION Criginal. Res.ono6t>4e Section Head Action j
_ f- 9/c 3 _ Pil. Co... M Fil.
' COPlES TO BE MODIFIED FOR IMMEDIATE IMPLEMENTATION DAVIS BESSE NUCl. EAR POWER STATION - UNIT 1 1 Shift Supervivor 1 Ops Eng. Book TEMPORARY MOOlFICATION REQUEST 4 C.R. File 1 C.R. Book ED eens i " . _ig gm7, __
SECTION 1 PROCEDURE TITLE AND NUMSER Auxillary Feedwater System SP 1106.06.22 REASON FOR CHANGE Aux feed pump 1-2 governor valve must be in the high speed stop position to ensure response time requirement. AF3872' Changed from open to Closed position to keep speed Changer motor at high speed stop position. See FCR 94 -l'i.C CHANGE
(,]s See attached pages of rev.22, page numbers 5,12,13,and 'd.
IS PROCEDURE REVISION REQUIRED PREPAREDSY DATE APPROVED SY DATE APPROVED SV DATE DATE SUBMITTED\O SY (Section HoodlY" s ( W k c1 $1jUlf 0[ '
RECOMMENDED SY (SRiicheerinent [7/ T DATE
' APR 171985 A -
6 /
QA APPROVED BY (Menegar of Quality As.urence) DATE
- APPROVED 8Y (Station Superlatendent)
A# DATE APR 171985
- o _
~
12 SP 1106.06.22
_1 22l _
- 2. Turn the trip throttle valve handwheel clockwise I until the sliding nut rises and engages the latch up
! lever to the trip hook.
NOTE: It may be necessary to pull on the trip throttle valve linkage to fully engage the latch up lever to the trip hook. <
- 3. Verify the latch up lever and the trip hook are fully engaged.
- 4. Turn the trip throttle valve handwheel counterclockwise until the trip throttle valve is fully open.
- 5. Turn the trip throttle valve handwheel 1/4 turn clockwise.
- 6. Seal the trip throttle valve handwheel.
Independently Verified
^
- 7. Verify computer point 2001 (Z002) AFPT 1 (2) Stop Valve reads "0 PEN".
- 8. Verify the red IL ICS 38E (38J) AFPT 1 (2) Governor Valve fully open light is on.
.,' 4.2.9 For AFPT 1-2 only, perform the following: ,
- 1. Verify the speed droop control knob is set at later.
- 2. Verify the load limit control knob is set at 10.
4.2.10 Place the AFPT speed changers HIS 520A HIS 521A in the raise position. Hold in this position for 25 seconds ( 90 TEcoWod 4.2.11 Place the AFP mode selector switches HIS-520B .aa4-(HIS-521B)inthe" Auto-Essen" mode.
4.2.12 In the Control Room, ensure that the following valves have a closed indication.
NOTE: If the closed light is not present, verify by other means power to the valve and closed valve position.
AF 3869 MS 106 AF 3870 MS 106A AF 3871 MS 107 22l SW 1382 MS 107A SW 1383 _ yspf 3 7 y AP
', SP 1106.06
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Davis-Besse Nmlam Power Staticn Unit No. 1 System Procedure SP 1106.06 AUXITJARY FEEDHm:R SYSTEM M i . 4 Record of Approval and Changes
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Prepared By T. Imbman, T. Poranski, R. Clark 1/14/76 Date Sidnitted By Tarry D. h 4/6/76 Secticn Head Date
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Reca mended By Jack Evans:
SRB cha 4 man 4/20/76 Date QA Appd N/A Quality Assurance Director Date Approved By Jack h c: 4/20/76 Plant Manager Date Pavisicn SRB QA Plant .% nager Ib. h is-dation Date Approved Date Approval Inte 22 A4 - g s ' 'M NA AJ- g /2/2 ejse
DBAS . ,, ur,c, criein:J, Responsibu Sectbn Head Action fd _ Fii. Copy, Mester Pii.
CDPIES TO BE MODIFIED FOR IMMEDIATE IMPLEMENTATION
%, DAVIS BESSE NUCLEAR POWER STATION . UNIT 1 (-5s J. +s , t - w.A y eA
.... TEMPCRARY MODIFICATION REQUEST , c. t a m u, A ED 6W26 C' *
- G Os SECTION 1 PROCEDURE TITL,E AND NUMBER r' l% 4mlsh fm.e e e6 5P \ \ O L, . o & . 2 L RE ASON FOR Ce* ANGf lh 0 ^* Wg da A PM *A t 3 h F3% ~\
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IS PROCEDURE REVISION REQUIRED 3% m u,-
APPROVED 5Y .
DATE p APPROVED BY
% Wkw* % DATE 3 / 3 t /JS SUBMITTED SY (5 DA k RECOMMENDED BY (SRB Chairmans DATE PJ x _
APR 3 igg 5 QA APPROVED BY (Menseer of Quellty A'soutence) / DATE
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APPROVED BY (steden seeeringendent) j- ~
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DATE gPR 3 1985 _
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18 SP 1106.06.22
, For AFPT 1-2 receiving steam from:
SG 1 Close "Mn Sta Line 1-2 to AFPT 1-2 Inlet Isolation Valve" MS-107 using HIS-107A.
SG 1 Close "Mn Sta Line 1-1 to AFPT 1-2 Inlet Isolation Valve".MS-107A using HIS-107E Aux Steam System - Close "AFPT 1-1 Sta Inlet Hde "X" Connect Isolation Valve" MS-728 (manually operated valve).
NOTE: If the auxiliary steam system is no longer needed for steam to either AFPT(s), close AS-273, " Secondary Isolation Valve from 235#
Aux Steam Header to AFPT's and MS 733 22 Iconnect isolation. .
As steam pressure decreases, the governor control valve opens to maintain AFPT speed.
When the control valve is fully open, the
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red governor control valve fully open light
, above t.he speed changer switch (s) (HIS-520A -
- ,. and/or HIS-521A) will light. AFPT speed will then decrease. Due to the loss of hydraulic control oil pressure to the governor control valve as the AFPT speed decreases, the governor control valve will remain open.
7.2.4 Determine which AFP was supplying feedwater and to which SG; then close the desired AFP to SG stop valve as listed below:
AFP 1-1 to SG 1-1 Stop Valve AF-3870 using HIS-3870 AFP 1-1 to SG 1-2 Stop Valve AF-3869 using HIS-3869 22 AFP 1-2 to SG 1-1 Stop Valve AF-3871 using HIS-3871 Mf' l-L !* 26 1.Q tror VAW .V 1M2 erve s Mit 3 f i l.
7.2.5 Using the AFFT speed changer JHIS-520A am#se-(HIS-521A),exercisespeedchangertothelowspeed stop using the " lower" position, then position the AFPT governor the " Raise" to the position high for 25 speed( limit seconds by holding in)
To sgre,yaf .
7.2.6 Crack open MS 748 (MS 749) and MS 750 (MS 751), MS 745A (MS 744A) and MS 746A (MS 747A). Allow condensate to drain off, then close each valve.
13 SP 1106.06.22
.. 22 4.2.13 -t--*'*" Bres7FC Section 4.2 completed by Date
- 5. REMOVING THE AFWS FROM SERVICE FOR PIANT SHUTDOWN 5.1 Prerequisites 5.1.1 Plant is in Operational Modes 4, 5, or 6.
5.2 Procedure 5.2.1 Place both AEWS mode selector switches EIS-520B and HIS-5213 in the " MANUAL" mode.
5.2.2 Close both AFPT trip throttle valves.
5.2.3 Ensure AFPT turbine drains are cracked open.
22 5.2.4 -etuur1tF-3872. DEAD;Na .
5.2.5 At the following MCC's, open the below listed breakers:
INITIAL MCC BREAKER NO. NAME VLV NO.
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In Diesel Generator Room #1:
{Q,' E-12-8 BE-1271 SG 1-2 to AFPT 1-1 In Sta Viv MS-106A In Diesel Generator Roos #2:
F-12-B BF-1262 AFP 1-2 Disch to SG 1-2 AF-3872 In the Low Voltage Switchgear Room #1:
D1PA D-107 AFP 1-1 Disch to SG 1-1 AF-3870 DINA D-135 AFPT 1-1 Mn Sta In Iso Viv MS-106 E-12-A BE-1218 SW 1382 SW to AFP 1-1 SW-1382 In the Low Voltage Switchgear Room #2:
F-12-A BF-1201 AFP 1-2 Disch to SG 1-1 AF-3871 In the #2 Electrical Penetration Room:
F-11-A BF-1124 AFP 1-2 Mn Sta In Iso Viv NS-107 In the Fuel Handling Storage Rocs 405, East of the Equipment Hatch:
F-11-B BF-1188 SG 1-1 to AFPT 1-2 In Stm Viv MS-107A In the #1 Electrical Penetration Room:
E-11-E BE-1146 AFP 1-1 Disch to SG 1-2 Viv AF-3869 To the Right of the Door Inside the #2 Mechanical Penetration Room:
F-11-C BF-1177 SW 1383 SW to AFP 1-2 SW-1383 32 Section 5 ccepleted by Date
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