ML071500196
| ML071500196 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 05/09/2007 |
| From: | NRC/RGN-II |
| To: | |
| References | |
| 50-327/07-301, 50-328/07-301 | |
| Download: ML071500196 (148) | |
See also: IR 05000327/2007301
Text
Final Submittal
(Blue Paper)
SEQUOYAH APRIL/MAY 2007 EXAM
EXAM NOS. 05000327/2007301
AND 05000328/2007301
APRIL 9 - 11, 2007 AND
MAY 9, 2007 (written)
As Given Simulator Scenario Operator Actions ES-D-2
I Appendix D
Scenario Outline
Form ES-D-1 I
\\..
(
(
Facility:
Sequoyah
Scenario No.:
1
Op Test No.:
NRC
Examiners:
Ope rators:
Initial Cond itions:
100% Power.
B PZR Spray Valve Isolated
BCCPOOS
Turnover:
Reduce Power to 90% for Turbine Steam Valve testing
Target CTs:
Insert negative reactivity using rods and/or boration prior to compietion of FR-S.1 step 4.
Isolate AF'N flow to the faulted SG prior to transition from E-2
Event No.
Mall. No.
Event Type"
Event Description
1
R-RO
Reduce power from 100%
-
T+O
N-BOP/SRO
2
RX07A
I-RO/SRO
Controlling PZR pressure channei fails high - Tech Spec evaiuation .
T+15
TS-SRO
3
lor
C-BOP/SRO
MFP Master Pressure Controlle r Drifts iow - Requires taking manual
T+25
rxcOpc4620
control of the Master controller to match steam and feed flow,
CLOSE
4
CN09
C-BOP
Degrading Condenser Vacuum - Requirespower reduction
T+35
5
RD07D4
C-RO
Dropped Rod - Tech Spec evaluation.
T+50
TS-SRO
6
RD07F10
M-AII
2'd Dropped Rod during recovery - Reactor Trip required
T+60
7
RP01C
C-RO
RTBs fail to open - ATWS - Insert rods; Initiate borat ion
8
MS03A
C-BOP
.
(N)ormal,
(R)eactivity,
(I)nstrument,
(C)omponent,
(M)ajor
Appendix D
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\\
IAppendix D
Scenario Outline
Scenario 1 Summary
Form ES-D-1 I
(
The crew will assume the shift at 100% power with instructions to reduce power.
Shortly after turnover, the input to the PZR pressure controller fails high, requiring
action to control RCS pressure in accordance with AOP-I.04. The SRO will enter
technical specifications.
When the plant is stable and technical specifications have been addressed, the Feed
Pump Master speed controller will fail low, requiring action to raise feed to match
steam flow in accordance with AOP-S.01.
When feed is restored in manual, a loss of condenser vacuum will occur. The crew
will respond in accordance with AOP-S.02, and reduce load to maintain vacuum.
When vacuum is restored, one rod will drop. The crew will take action to stabilize the
plant in accordance with AOP-C.01. When stabilization steps have been performed,
a second rod will drop, requiring a reactor trip.
The reactor will not trip automatically or manually. The crew will enter FR-S.1. In
FR-S.1, SG safety valves will lift, and 1 SG safety valve will stick open, requiring
action to stop the RCS cooldown after the reactor is subcritical.
The scenario may be terminated after performance of FR-S.1 or upon transition to
EOP flow: E-O - FR-S.1 - E-O - E-2 - ES-1 .1
PSA significant equipment OOS: B CCP
PSA significant transient: ATWS
Appendi x D
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_._---
ESG-I SCN File
0 1/25/07
(
EVENT
IC/l\\IFIRF/OR #
DESCRIPTION/EXPECTED ACTlOl'lSIBO OT H FEEDBACK
Simulator
IC*16
100%, BOL 1-1000 M\\VD/MT UI
' B' Tra in work week
cn '0' Rods @216 steps,all others @ 228 steps;
[B) = 1093ppm; Ba Blender setting: 29% Xe/Sm @ equilihrium
Console Operator actions: Place simulator in run and perfo rm the
followillg:
- Adjust horic acid blender to 27%
I. and tag with HO.
0
Place Loop I Spray valve in manual and tag with Pink Tag.
- Place Train \\Veek n sign
MFs, RFs,
IRF RMR19 f:3
SG BD Rad Monitor OOS: I-IUI-l20A & I2IA. Place Pink Tags on
ORs are
UHF RM90l20 f:1
srcn modules.
active
IMF AN OV 723 f:2
whe n the
IMF RC06B f:O
Loop I PZR Spray Valve Isolated (I-PCV-68-340D)
sex file is
loaded.
IMF CVOIB f:1
\\B-B CCP OOS (Initial conditions)
IMF RPOIC f:1
Reactor Trip Siznal Failure (ATWS)
-
1.
Reduce Power to <93% for Turbine Valve testing. Reset integrators for PW
and BA to zero.
2.
IM F RX07A f:1 k:2
Pzr Press Ch, PT-68-340 fails high.
Support staU'reporl:
When 1Ms or MSS is contacted to trip blstables using AOP-I.04 Appendix A.
inform the crew thai the 1Ms will report to the MCR in - 45 minutes.
3.
lOR RXCOPC4620
MFP Master Controller failure; controller output fails low resulting in
f:.OOI k:3
lowering feed flow to all SGs.
Suvport starrreoort:
o When MSS or IMs are contacted, inf orm the crew that the 1Ms will
report to the MCR in - 45 minutes.
4.
IMF CN09 f:O.1 k:4
NOTE : Modulatelreduce f (i.e.: 0.1 to .05) to slow condenser vacuum loss
to maintain < 2.0 psia. Intent is to require a turbine load reduction to
maintain vacuum.
Supporl staf[report:
- When [Ops Personnel] dispatch ed to investigate, wait - 2 minutes and
D;\\lF CN09 after
report that vacuum breaker flange is leaking.
flan ge is repaired.
- lf7wn [Maintenance Personnel] dispatched to assist. wait - 3 minutes
and report thatflange is tightened/tempororily repaired.
Page- I of 2
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--'---'---
ESG-l SCN File
01/25/07
(
(
EVENT
IC/MF/RF/OR #
DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK
5.
IMF RD07M2 f:l k:5
Dropped Rod: M2 son 'A' rod.
Support uatusma:
- MSS is notified to initiate maintenance, wait "'5 minutes THEN
DELETE MALFUNCTION Notify UO that System Engineerfound
blownf use in stationary gripper coil circuit. Fuse is replaced, and rod
is ready for retrieval.
- Reactor Eng. notified for power peaking.[uelfailure, & xenon
oscillation considerations, inform crew to proceed with rod retrieval
usinv AOP-C.01 considerations (i.e.: <1 hour).
6.
IMF RD07FI0 f:l k:6
Dropped Rod-Rx Trip initiator: FlOcs '0' rod.
2nd dropped control rod- Reactor Trip required per AOP-C.Ol;
7.
IMF RPOIC f:l
Rea ctor Trip Signa] Fail ure (ATWS)
(pre-inserted)
When the reactor protection system (RPS) receives a trip signal, both
Malfunction removal
reactor trip breakers will not open
The turbine will NO T trip from IIny
allows breakers to trip
reactor trip signal but will trip from a Hi-Hi S/G level or S1 signal. Any
infollo wing step.
functions that receive an initiation signalfrom P-4 auxiliary contacts ofthe
reactor trip breakers
will not work properly,
The reactor first out
-
annunciation willfunction properly.
NOTE: Malfunction removal allows breakers to trip.
8.
IRF RPR05A f:1 k:9
Associated Remote Fu nctions- wait 5 minutes following AUO
IRF RPR05B f:l D:15
notification to insert : RPR05A & RPR05B - simulates local opening Rx
k:9
Trip Breakers (RTA & RTB)
Support sta([report:
- A UG reports to crew that the RTBs are open.
9.
IMF MS03A f:l00 e:7
Single main steam safety valve fails open (SC #1) triggered on MT trip.
Support sta([report:
- Report (as outside AUO) to crew that you observe steam comingfrom
too 0{U1 West Valve Vault (for S/Gs #1 or #4).
Termination Criteria
Complete Faulted SG Isolation and verify Heat Sink established/available.
Page 2 of 2
G:\\Prep Week Iiles\\As Submitted Operational Exam\\Scenarios\\Scenario t\\3M19-07 ESC-I.doc
IAppendix D
Required Operator Actions
Form ES-D-2 I
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
Reduce Power
....:...____ Page
3
of
_4;,,:.0--1
Time
I
Position
I
Applicant's Actions or Behavior
(
(
Booth Instructor:
No action required for event 1
Indications available:
None Applicable
Direct a load reduction in accordance with 0-GO-5, Normal
Power Operations, and 0-SO-62-7, Boron Concentration
Control
-
CAUTION
Returning the Boric Acid Blender to service after unplugging, cleaning, or
maintenance on Boric Acid System could introduce debris, sludge, air or
solidified boron into CCP suction resulting in pump damage. Extreme care must
be exercised to properly flush the Boric Acid piping following an outage.
NOTE
If a large amount of boration is required (plant shutdown), pzr heaters should be
energized to cause spray operation for equalizing boron concentration in RCS and
pressurizer.
ENSURE makeup system aligned for AUTO operation
in accordance with Section 5.1.
NOTE
Steps 2 and 3 are N/A for minor power changes OR if immediate boration is required to
Appendix D
3
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IAppendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
Reduce Power
-'-____ Page
4
of
_4"'0---1
Time
I
Position
I
Aoolicant's Actions or Behavior
(
maintain shutdown margin, to maintain rods above the insertion limit, during an
emergency shutdown (AOP-C.03), during recovery of a dropped/misaligned rod (AOP-
C.01), or at Chemistry recommendation in mode 3, 4, 5 or 6.
RECORD the quantity of boric acid required to achieve desired
boron concentration using Appendix D.
gals
PERFORM Appendix I Independent Verification of
-
Calculation for Amount of Boric Acid or Primary Water.
Crew
(N/A if App. D was periormed by SRO to verify data
from Rx Engineering)
DETERMINE availab le boric acid volume in in-service BAT.
gals
PLACE [HS-62-140A], Boric Acid to Blender Flow Control
Switch to the STOP position.
PLACE [HS-62-140B], CVCS Makeup Selector Switch to the
BORATE position.
ADJUST [FC-62-139], Boric Acid Flow Controller to the
desired flow rate.
Appendix D
4
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- ---- --
I Appendix D
Required Operator Actions
Form ES*D*2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
Reduce Power
-'-
Page
5
of
_4:.::;0-i
Time
I
Position
I
Applicant's Actions or Behavior
(
SET [FQ-62-139]. Batch Integrator to the desired quantity.
PLACE [HS-62-140A]. Boric Acid to Blender Flow Control
Switch to the START position.
ENSURE Boric Acid Pump aligned to blender in FAST speed
by right red light LIT on [HS-62-230A] OR [HS-62-232A].
NOTE
Flow oscillatio ns and/or erratic controller response may require manual operation of
Boric Acid Flow Controller [FC-62-139] until stable conditions exist.
VERIFY Boric Acid Flow established.
NOTE
It may take approximately 15 minutes before any changes to reactivity are indicated on
nuclear instrumentation or RCS temperature indication.
IF reactor is critical. THEN MONITOR nuclear instrumentation
Appendix D
5
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I Appendix D
Required Operator Actions
Form ES-D-2 I
(-,
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
Reduce Power
....:..____
Page
6
of
_4~O::--I
Time
I
Position I
Applicant's Actions or Behavior
(
(
and reactor coolant temperature to ensure proper response
from boration.
NOTE
BAT operability limits are prescribed by TRM 3.1.2.6 (Modes 1-3) or 3.1.2.5 (Modes 4-6).
MONITOR Boric Acid Storage Tank level.
-
IF Volume Control Tank level increases to 63 percent,
THEN ENSURE [LCV-62-118], Volume Controi Tank Divert
Valve OPENS to divert excess water to the Holdup Tank.
NOTE
Sample may be obtained at normal RCS sample intervals provided the unit is at power
and the unit response following the boration is as expected.
WHEN boration is complete, THEN
PLACE [HS-62-140A], Boric Acid to Blender Flow
Control Switch to the STOP position.
CHECK no primary water flow on either [FI-62-142A]
OR [FQ-62-142].
ENSURE [FC-62-142], Primary Water to Blender Flow
Controller is in AUTO position and the potentiometer
(dial indicator) is set at 35%.
ADJUST [FC-62-139], Boric Acid Flow Controller to the
desired blend solution in accordance with TI-44 Boron
Tables.
Appendix 0
6
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I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
Reduce Power
....:....
Page
7
of
_4.:.:0'---1
Time
I
Position
I
Applicant's Actions or Behavior
(
(
ENSURE [FCV-62-128j is CLOSED.
PLACE [HS-62-140Bj, CVCS Makeup Selector Switch
to the AUTO position.
PLACE [HS-62-140Aj, Boric Acid to Blender Flow
Control Switch to the START position.
IF RCS boron sample required, THEN NOTIFY Chem
Lab to obtain RCS boron sample.
Appendix D
7
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I Appendix D
Reguired Operator Actions
Form ES*D*2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
Reduce Power
....:....____ Page
8
of _4""0--t
Time
I
Position
I
Applicant's Actions or Behavior
(
(
NOTE
Boration is done in batches until the total boron and/or power change is completed.
REPEAT this section as required to complete total boron
change.
WHEN total boration is complete, THEN:
REALIGN the blende r controls for AUTO makeup to the
CVCS in accordance with Section 5.1.
NOTIFY Chem Lab to obtain RCS boron sample.
-
IF in modes 1, 2, or 3, THEN ENSURE requiremen ts of TRM
US
3.1.2.6 are met.
NOTE
Lowering load on the Main Generator will cause VARs to trend in the positive direction
(towa rd outgoing). This will require lowering generator voltage. Refer to GOI-6 Section E
for MVAR limits for generator stability.
Appendix D
8
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I Appendix 0
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
Reduce Power
....:...
Page
g
of
40
Time
I
Position
I
Aoolicant"s Actions or Behavior
(
PERFORM the following as required:
IF Automatic Voltage Control is in service,
THEN
ADJUST Main Generator VARs USING [HS-57-22] Exciter
Voltage Auto Adjuster as necessary during power escalation.
NOTES
1) Guidance on restoration of EHC Controls after a BOP runback is contained in
Appendix B, Turbine Runback Restoration.
2) For core operating recommendations for situations such as end of core life coast
down or unusual power maneuvers, contact Reactor Engineering for guidance.
3) It is recommended that AFD be controlled within the target band.
4) The following general approach should be used during power reduction:
(a) borate RCS to reduce RCS TAVG within limits of TREF, (b) reduce turbine load to
match TREF with TAVG (c) periodically take rod control to MANUAL from AUTO and
insert the bank to move AFD near the target value, (d) return rod control to AUTO when
not using the bank to control AFD, and (e) repeat the above as necessary to accomplish
the load change .
5) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements
shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid
or water). All appropriate verifications and peer checks shall be utilized during
performance.
INITIATE a load reduction.
BOP
MONITOR turbine load decreasing.
CAUTION
Do NOT exceed a load change rate of plus or minus 5%/minute or a step change of
10%
Appendix D
9
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I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
. 1
Reduce Power
Event #
....:..____ Page
10
of
....:4::;:0----l
Time
I
Position I
Aoolicant's Actions or Behavior
(
NOTE
TAVG is programmed from 578.2°F at 100% power to 547"F at zero power at a rate of
0.312°F per % power.
MONITOR the following during the load reduction:
TAVG following TREF program.
All RPls, group step counters for rod insertion limits and
Crew
inoperable rods or rod misalignment, Loop z,T, and NIS
for correct power distribution and quadrant power tilts. Core
AFD within - 5% control band around the power
level dependent target value.
NOTE
Valve position limit and governor control meter are displayed on EHC Display
panel 1,2-XX-047-2000 (M-2).
Valve position limit approximately 10% above the current
governor control indication as turbine load is changed.
Lead Examiner may direct initiation of the next event at his discretion
Appendix D
10
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I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
...;2=---____ Page
11
Controlling PZR pressure channel PT 68-340 fails high
of
40
Time
I
Position I
Applicant's Actions or Behavior
(
Booth Instructor:
When directed, initiate event 2
Indications available:
1-AR-M6-A, C5, PRESSURIZER HIGH PRESSURE
1-AR-M5-A, B3, PRESSURIZER PRESS ABOVE REF SETPOINT
Recognizes, announces controlling pressure channel failure,
and takes Prudent Operator Action (POA) to manually close
the PZR Spray Valve.
Crew
Refer to alarm response procedures
-
Determine Instrument Failure has occurred and direct entry to
US
AOP-1.04, Pressurizer Instrument Malfunction, section 2.1
NOTE 1:
Appendixes H is a layout of PZR pressure control provided for operator reference.
NOTE 2:
A failure of channel III (P-68-323) will affect the automatic actuation of PCV 68-334, PZR
PORV, in the normal pressure control circuit. LTOPS operation of this PORV is
unaffected by this failure.
NOTE 3:
A failure of channel IV (P-68-322) will affect the automatic actuation of PCV 68-340A,
PZR PORV, in the normal pressure control circuit. LTOPS operation of this PORV is
unaffected by this failure.
Appendix D
11
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I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
2
Page
12
...;;....---
Controlling PZR pressure channel PT 68-340 fails high
of
40
Time
I
Position
I
Applicant's Actions or Behavior
(
(
Evaluator Note: Operator may take action to close the Pzr Spray Valve prior to entering
the AOP
MONITOR pressurizer pressu re stable or
trending to desired pressure. NO
RESTORE pressurizer pressure USING manual control
of the following:
PIC-68-340A
PZR Spray controllers
PIC-68-340D (Loop 1)
AND/OR
PIC-68-340B (Loop 2)
Pressurizer Heaters
CHECK PI-68-340A indicates NORMAL. NO
PERFORM the following:
ENSURE LOOP TAVG L'.T REC/SEL selector switch
XS-68-2B in LOOP 2, 3, or 4.
ENSURE PRESS CONTROL SELECTOR switch XS-
68-340D in PT-68-334 & 323.
ENSURE PRESS REC CHANNEL SELECTOR XS-68-
340B in PT-68-334, PT-68-323, or PT-68-322.
EVALUATE the following Tech Specs for appli cability:
3.2.5.b. DNB Parameters action. If pressure drops
below 2205 psig (2220 psia), 2-hours to restore to
normal.
US
3.3 .1.1 (3.3.1), Reactor Trip System Instrumentation
(Action 6)
3.3.2.1 (3.3.2), Engineered Safety Feature Actuation
System Instrumentation (Action 17)
3.3.3.5 Remote Shutdown Instrumentation
WHEN malfunction has been identified AND isolated OR
corrected, THEN CHECK PZR PRESS and PZR SPRAY
controllers in AUTO.
Appendix 0
12
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES*D*2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
_2=--
Page
13
Controlling PZR pressure channel PT 68*340 fails high
of
40
Time
I
Position I
Applicant's Actions or Behavior
(
(
PERFORM the following:
ENSURE Master Pzr Pressure Controller PIG-68- 340A
Output Percent Meter is less than 40%.
ENSURE PZR PRESS. controller, PZR SPRAY
controller, and PZR HTRS in AUTO.
NOTE:
If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to
hard trip bistables should be delayed until Eagle system reset is attempted. Actions to
hard trip bistables must be completed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> UNLESS affected loop is restored
to operable status by resetting Eagle rack.
NOTIFY 1M to remove failed pressurizer pressure channel from
service USING appropriate Appendix:
US
Appendix A
When Technical Specifications are identified or at discretion of the Lead
Examiner, proceed to the next event
Appendix D
13
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I Appendix D
Reguired Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
_3~
Page
14
Event Description:
MFP Master Speed Controller Failure
of
40
Time
I
Position
I
Aoolicant"s Actions or Behavior
(
(
Booth Instructor:
When directed, initiate event 3
Indications available:
1*AR-M5-A, B7, STEAM GEN LVL HIGH-LOW DEVIATION
All SG levels decreasing
Crew
Refer to alarm response procedure
-
Direct entry to AOP S.01 , Loss of Normal Feedwater, Section
US
2.2
NOTE:
Appendix C may be used to determine the program feedwater DIP for current power.
MAINTAIN feedwater pressure on program:
PLACE affected MFP speed controller(s) in MANUAL:
PC-46-20, MFPT 1A(2A) 1B(2B) Speed Control.
SIC-46-20A, MFPT 1A(2A) Speed Controller
SIC-46-20B, MFPT 1B(2B) Speed Controller
CONTROL speed on affected MFP(s) to restore feedwater
pressure to program. (MFPC IIp '" 194 psid @ 100%)
Appendix D
14
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES-D-2 I
c
Op Test No.:
NRC
Scenario #
1
Event #
....::,.3
Page
15
Event Description:
MFP Master Speed Controller Failure
of
40
Time
I
Position
I
Applicant's Actions or Behavior
(
(
CAUTION:
Feed flow transients may impact core thermal power.
MAINTAIN steam generator level(s) on program. STEAM GEN
LVL HIGH-LOW DEVIATION annunciator clear.
INITIATE repairs on failed equipment.
US
~
GO TO appropriate plant procedure.
Crew
When SG levels are controlled with Master Speed Controller in manual or at Lead
Examiner's discretion, proceed to the next event
Appendix D
15
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
4
of
40
TIme
I
Position
I
Aoolicant's Actions or Behavior
('
Booth Instructor:
When di rected, initiate Event 4
Indications available:
O-M-12A, C-2, 1-RA-90-119B COND VAC PMP LO RNG AIR EXH MON INSTR
MALFUNC
1-AR-M2-C, CG, CONDENSER VACUUM LOW
Condenser Vacuum deqradlnq, Air in leakaqe increasing.
Evaluator Note: Booth Operator is rnodulatino Condenser Vacuum
Crew
Refer to alarm response procedure
-
VERIFY alarm via [1-PlTR-2-2] recorder.
VERIFY required number of CCW pumps are inservice.
CHECK condenser vacuum exhaust on ICS using either:
a. 1F2700A if 1-FCV-2-255 is closed
b. 1F2263A if 1-FCV-2-255 is open.
IF condenser vacuum exhaust flow> 45 CFM, THEN ENSURE
1-FCV-2-255 OPEN.
Appendix D
16
NUREG 1021 Revision 9
IAppendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
4
Time
I
Position
I
Aoolicant's Actions or Behavior
IF alarm is valid, THEN GO TO AOP-S.02, Loss of Condenser
US
Vacuum.
NOTE:
Use of the highest reading operable condenser pressure instrument is conservative
and recommended by engineering.
-
MONITOR condens er pressure for turbine trip criteria.
CHECK turbine load greater than or equal to 30%.
MT Low Condenser Vacuum Trip @ 3.9 psia increasina
CHECK condenser pressure less than or equal to 2.7 psia.
1-AR-M2-C, C-6, CONDENSER VACUUM LOW @ 2.7 psia
increasina.
ENSURE condenser vacuum pumps RUNNING.
Operator starts 1B Condenser Vacuum Pump
ENSURE condenser vacuum breaker CLOSED.
Appendix D
17
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
4
Time
I
Position I
Applicant's Actions or Behavior
(
CHECK required CCW Pumps RUNNING [M-15].
NOTE:
ICS points F2700A and F2263A will alarm if Condenser Vacuum Exhaust Flow is > 45
ctrn.
DETERMINE volume of condenser inleakage USING the
following plant computer points:
F2700A
F2263A
-
F2260A
VERIFY inleakage value is < 45 elm as indicated by both
F2700A and F2263A. NO
PERFORM the following:
ENSURE FCV-2-255, Condenser Vacuum Exhaust
Bypass, is OPEN.
IF greater than 5% RTP, THEN NOTIFY Chem Lab to
reevaluate Vent Flow Rate Monitor setpoint in
accordance with 0-SI-CEM-030-415.0.
Appendix D
18
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description :
NRC
Scenario #
1
Event #
4
Time
I
Position
I
Aoolicant's Actions or Behavior
(
(
DISPATCH an operator to PERFORM the following:
CHECK loop seal on vacuum breaker [Turbine Bldg,
706' elev].
CHECK the following components:
Main Turbine rupture discs intact
Crew
Condenser shell intact
Main Feedwater Pump rupture discs intact
..
Main Turbine exhaust hoods
VERIFY Main Steam Dump Drain Tank level control
operating properly.
-
ENSURE control rods controlling in AUTO.
CHECK condenser pressure STABLE or DROPPING. (NO)
REDUCE turbine load to maintain condenser vacuum USING
one of the following:
AOP-C.03, Rapid Shutdown or Load Reduction.
(preferred)
Valve Position Limiter.
On Lead Examiner's cue, eroceed to the next event
Appendix D
19
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES*D*2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Descriplion:
Dropped Rod
5
Time
I
Position
I
Aoolicant's Actions or Behavior
Booth Instructor:
When directed, initiate Event 5
Indications available:
1-AR-M4-B, D4, COMPUTER ALARM ROD DEV & SEQ PWR RANGE TILTS
1-AR-M4-B, D7, FULL LENGTH RODS AT BOTTOM
1*AR*M4*B, E3, NIS POWER RANGE CHANNEL DEVIATION
1-AR-M4-B, B3, NIS POWER RANGE UPPER DETECTOR HI FLUX DEVN OR AUTO
DEFEAT (Later)
1-AR-M4-B-C3, NIS POWER RANGE LOWER DETECTOR HI FLUX DEVN OR AUTO
DEFEAT (Later)
1 Rod Bottom-Liqht illuminated on M-4 IRPI Displav
Crew
Acknowledge alarms
Direct entry to AOP-C.01 , Rod Control System Malfunctions,
US
section 2.2
Evaluator Note:
Control rods may have been placed in manual prior to entering
AOP.
PLACE rod control in MANUAL.
RO
VERIFY ONLY ONE rod dropped.
Appendix D
20
NUREG 1021 Revision 9
I Appendix 0
Reguired Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
Dropped Rod
5
Time
I
Position
I
Anollcant's Actions or Behavior
(
NOTE:
If a dropped rod occurs at low power level, retrieval of the dropped rod is NOT the
conservative action to take and could violate Tech Specs (if Mode 2 has been entered).
MONITOR reactor power greater than 5%.
REDUCE load to control T-avg:
-
MONITOR T-avg greater than 541' F. (LCO 3.1 .1.4)
CHECK main turbine loaded.
0
REDUCE turbine load to establish T-avg within
3'F of T-ref. (not required)
MONITOR Quadrant Power Tilt Ratio (QPTR) less than 1.09
USING one of the following:
O-SI-NUC-OOO-133.0, Quadrant Power Tilt Ratio.
NOTIFY MSS to initiate maintenance for affected rod.
US
Appendix 0
21
NUREG 1021 Revision 9
IAppendix 0
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
Dropped Rod
5
Time
I
Position
I
Applicant's Actions or Behavior
(
(
NOTE :
Core thermal power must be reduced to less than 75% within one hour and shutdown
margin must be verified within one hour UNLESS dropped rod can be restored in one
hour. (MOVABLE CONTROL ASSEMBLIES - Group Height, LCO 3.1.3.1 action c)
PERFORM the following to comply with LCO 3.1 .3.1: SRO
determines and enters LCO 3.1.3.1 action C. (Movable
Control Assemblies - Group Height)
INITIATE power reduction to less than 75% USING one of the
following:
_Crew
AOP-C.03, Rapid Shutdown or Load Reduction
0-GO-5, Normal Power Operation.
VERIFY adequate Shutdown Margin within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and
once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> USING SI-NUC-000-038.0.
MONITOR QPTR less than 1.02 USING one of the following:
0-SI-NUC-000-133.0, Quadrant Power Tilt Ratio.
IF QPTR exceeds 1.02 AND core thermal power is greater than
50%, THEN PERFORM the following:
PERFORM 0-SI-NUC-000-133.0 at least once per hour
to comply with Tech Spec LCO 3.2.4.
ENSURE core thermal power reduced as required by
COMPLY with all other applicable actions of LCO 3.2.4.
NOTE
Appendix 0
22
NUREG 1021 Revision 9
I Appendi x D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
1
Event #
Event Description:
Dropped Rod
5
Time
I
Position
I
Applicant's Actions or Behavior
c
Power range high flux trip setpoint must be reduced to less than or equal to 85% within
four hours UNLESS dropped rod is restored. (LCO 3.1.3.1 action c). LCO 3.2.4,
Quadrant Power Tilt Ratio may require more limiting setpoint if QPTR exceeds 1.02.
NOTIFY MIG to prepare to reduce high neutron flux trip
setpoint to less than or equal to applicable value from LCO
US
3.1 .3.1 action C.3 or 3.2.4 action A.1 .a USING 0-SI-IXX-092-
N40.0.
NOTIFY Reactor Engineer and COMPLETE notifications
US
USING SPP-3.5, Regulatory Reporting Requirements.
CHECK the following:
repairs COMPLETE
US
ROD CONTROL URGENT FAILURE alarm NOT LIT.
[M-48 , window A-6j
CAUTION:
Prior to retrieving a dropped rod at power, SRO and Reactor Engineer will
determine length of time the affected rod has been dropped/misaligned. Any
attempt to realign the rod should be coordinated with Reactor Engineer's
recommendations to prevent localized power peaking, possible fuel failure, and to
minimize xenon oscillations.
CHECK NC-41 U/NC-41 K NIS POWER RANGE HIGH
NEUTRON FLUX RATE alarm DARK rM-6A, 811
Appendix D
23
NUREG 1021 Revision 9
IAppendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
NRC
Scenario #
t
Event #
Event Description:
Dropped Rod
5
of
40
Time
I
Position
I
Aoolicanl's Actions or Behavior
(
RESET affected neutron flux rate module [M-13].
When technical specifications have been identified or at discretion 01 the Lead
Examiner, proceed to the next event
Appendix 0
24
NUREG 1021 Revision 9
1 Appendix D
Required Operator Actions
Form ES*D-2 I
(
Op Test No.:
Event Description;
NRC
Scenario #
1
Event #
_6;;.:...:.7;.,;
. 8=--_ _
Page
25
Dropped Rod, ATWS , Stuck open SG Safety Valve
of
40
Time
I
Position
I
Applicant's Actions or Behavior
(
(
Booth Instructor:
When directed, initiate event 6
Indications available:
Second dropped rod .
No reactor trip indication.
EVALUATOR NOTE:
S/G #1 main steam safety valve fails open on Turbine trip.
- Crew
Recognize a second rod has dropped and determine reactor
trip required
US
Direct reactor trip and turbine trip
Attempt to trip reactor
Verifv turbine trip
US
Direct entry to FR*S.1, Nuclear Power Generation/ATWS
NOTE
Steps 1 and 2 are immediate action steps.
Appendix D
25
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES*D*2 I
('
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
..;6:::.,.:..
7~
, Sc--_
_
Page
26
Dropped Rod, ATWS, Stuck open SG Safety Valve
of
40
Time
I
Position
I
Applicant's Actions or Behavior
(
(
CRITICAL
VERIFY reactor TRIPPED:
TASK
Reactor trip breakers OPEN
Reactor trip bypass breakers OPEN or
DISCONN ECTED
Neutron flux DROPPING
Rod bottom lights LIT
Rod position indicators less than or equal to 12 steps.
TRIP reactor.
IF reactor trip breakers will NOT open,
THEN
MAINTAIN auto or manual rod insertion at max achievable
rate UNTIL rods are at bottom, Insert negative reactivity within
35 seconds of second dropped rod,
-
VERIFY turbine TRIPPED:
ALL turbine stop valves CLOSED
CHECK AFW System operation:
START pumps.
TD AFW pump RUNNING as necessary.
PLACE AFW LCVs in AUTO or OPEN in MANUAL as
necessary.
MD AFW pump recirculation valves FCV*3*400 and
FCV*3*401 CLOSED.
Appendix D
26
NUREG 1021 Revision 9
(
I Appendix D
Op Test No.:
Event Description:
Required Operator Actions
NRC
Scenario #
1
Event #
Dropped Rod, ATWS, Stuck open SG Safety Valve
Form ES-D-2 I
Time
I
Position
I
Aoolicanrs Actions or Behavior
(
CRITICAL
EMERGENCY BORATE RCS by performing the following:
TASK
ENSURE at least one CCP RUNNING. INITIATE Emergency
Boration USING EA-68-4.
PLACE boric acid transfer pumps in fast speed.
ADJUST emergency borate valve [FCV-62-138] to
obtain boric acid flow between 35 gpm and 150 gpm on
[FI-62-137A].
0
MONITOR emergency boration flow:
CHECK emergency boration flow established on [FI-
62-137A].
0
IF boric acid flow less than 35 gpm,
THEN
-
CLOSE recirculation valve for the BAT aligned to the
blender:
0
1-FCV-62-237 for BAT A.
0
0-FCV-62-241 for BAT C.
0
2-FCV-62-237 for BAT B.
VERIFY charging flow path established:
0
FCV-62-90 OPEN
0
FCV-62-91 OPEN
0
FCV-62-86 or FCV-62-85 OPEN.
CHECK pressurizer pressure less than 2335 psig.
VERIFY Containm ent Purge isolated:
Crew
VERIFY containment purge and vent dampers (System 30)
CLOSED . [Panel 6K and 6L]
Appendix D
27
NUREG 1021 Revision 9
IAppendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
_ 6;;.:....;.7.:..;, 8=---_
_
Page
28
Dropped Rod, ATWS, Stuck open SG Safety Valve
of
40
Time
I
Position
I
Aoolicant's Actions or Behavior
(
MONITOR SI NOT actuated :
Crew
S,1. ACTUATED permissive DARK [M-4A, D4].
Evaluator Note: Crew may elect to manually initiate Safety Injection, Main Steam Line
Isolation and/or isolate AFW prior to procedural direction (POAs/Fold out page) if
conditions dictate based on excessive cooldown.
Crew
Reactor TRIPPED.
-
PERFORM the following:
DISPATCH personnel to locally open reactor trip
breakers and MG set output breakers [MG Set Room,
US
Aux Bldg el. 759].
DISPATCH personnel to locally open breakers to MG
sets [480V Unit Boards A and B].
Turbine TRIPPED:
ALL turbine stop valves CLOSED,
MONITOR reactor subcritical:
Power range channels less than 5%.
Intermediate range SUR NEGATIVE.
Appendix D
28
NUREG 1021 Revision 9
IAppendix D
Required Operator Actions
Form ES*D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
....;:.:
6,..:.7.:.;, 8::...-_
_
Page
29
Dropped Rod, ATWS. Stuck open SG Safety Valve
of
40
Time
I
Position
I
Aoolicant's Actions or Behavior
US
GO TO Step 19,
ENSURE status tree monitoring initiated.
US
MONITOR boration termination criteria:
NOTIFY Chem Lab to sample RCS boron
concentration.
CHECK for all of the following:
- RO
0
all control rods FULLY INSERTED
0
RCS temperature greater than 540°F
0
no RCS dilution has occurred.
WHEN emergency boration is no longer needed, THEN STOP
RO/US
emergency boration USING EA-6S-4, Emergency Boration.
RETURN TO procedure and step in effect.
US
Directs transition to E-O, Reactor Trip or Safety Injection
Appendix D
29
NUREG 1021 Revision 9
I Appendix 0
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Sce nario #
1
Event #
_ 6::<,..:.7.....:, 8::....-_
_
Page
30
Dropped Rod, ATWS, Stuck open SG Safety Valve
of
40
Time
I
Position
I
Applican t's Actions or Behavior
(
(-.
VERIFY reactor TRIPPED:
Reactor trip breakers OPEN
Reactor trip bypass breakers DISCONNECTED or
OPEN
Neutron flux DROPPING
Rod bottom lights LIT
Rod position indicators less than or equal to 12 steps.
VERIFY turbine TRIPPED:
-
Turbine stop vaives CLOSED.
VERIFY at least one train of shutdown boards ENERGIZED.
DETERMINE if SI actuated:
ECCS pumps RUNNING.
Any SI alarm LIT [M-4D]
Mav manuallv actuate 51.
Evaluator Note: BOP may isolate TDAFW flow to #1 SG, or all SGs based on POAs-
overfill or excessive cooldown.
PERFORM ES-0.5, Equipment Verifications WHILE continuing
in this procedu re. (At end of scenario)
DETERMINE if secondary heat sink available:
Appendix 0
30
NUREG 1021 Revision 9
IAppend ix D
Required Operator Actions
Form ES*D*2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
...;6:::,*..:..7,:..:8:...-__ Page
31
Dropped Rod, ATWS, Stuck open SG Safety Valve
of
40
Time
I
Position I
Applicant's Actions or Behavior
(
a.
CHECK total AFW flow greater than 440 gpm .
b.
CHECK narrow range level greater than 10% [25 ADV]
in at least one S/G.
c.
CONTROL feed flow to maintain narrow range level
between 10% [25% ADVj and 50% in all S/Gs .
CHECK if main steam lines should be isolated:
a.
CHECK if any of the following conditions have
occurred:
Any S/G pressure less than 600 psig AND
-
STEAMLINE PRESS ISOL SI BLOCK RATE
ISOL ENABLE permissive DARK [M*4A, A4]
Any S/G pressure dropping
UNCONTROLLED.
Phase B actuation
b.
ENSURE MSIVs and MSIV bypass valves CLOSED.
May have already closed MSIVs.
NOTE:
Loss of seal injection flow could adversely affect RCP seals.
Append ix D
31
NUREG 1021 Revision 9
IAppendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scenario #
1
Event #
..;6~,..:.7,.,:,8::....-_
_
Page
32
Dropped Rod, AlWS, Stuck open SG Safety Valve
of
40
Time
I
Position
I
Applicant' s Actions or Behavior
CHECK RCP trip criteria:
a.
CHECK the following:
RCS pressure less than 1250 psig. (NO)
AND
At least one CCP OR SI pump RUNNING
MONITOR RCS temperatures:
IF any RCP running,
THEN
CHECK T-avg stable at or trending between 547 degrees F
_
and 552 degrees F.
IF RCP's stopped,
THEN
CHECK T-cold stable or trending to between 547 degrees
F and 552 decrees F.
CHECK pressurizer PORV's, safeties, and spray valves:
a.
Pressurizer PORV's CLOSED.
b.
Pressurizer safety valves CLOSED .
c.
Normal spray valves CLOSED.
d.
Power to at least one block valve AVAILABLE.
e.
At least one block valve OPEN.
Appendix D
32
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES-D-2 I
(
Op Test No.:
Event Description:
NRC
Scena rio #
1
Event #
...;6"'-,.;,.
7,:..:8'--__ Page
33
Dropped Rod, ATWS , Stuck open SG Safety Valve
of
40
Time
I
Position
I
Aoolicant's Actions or Behavior
CHECK S/G secondary pressure boundaries INTACT:
All S/G pressures CONTROLLED or RISING
(NO)
All S/G pressures qreater than 140 oslo.
US
Direct entry to E*2, Faulted SG Isolation
Caution
Unisolating the Faulted S/G increases the potential for personnel injury, equipment
damage, and an uncontrolled RCS cooldown. This option is NOT be considered
UNLESS needed for RCS cooldown.
RO/BOP
CHECK MSIVs and MSIV bypass valves CLOSED.
CHECK ANY S/G secondary pressure boundary INTACT:
RO/BOP
Anv S/G pressure controlled or rising.
Appendix D
33
NUREG 1021 Revision 9
IAppendix D
Reguired Operator Actions
Form ES-D-2 I
Op Test No.:
NRC
Scenario #
1
Event #
6,7,8
Event Description:
Dropped Rod, ATWS, Stuck open SG Safely Valve
Time
I
Position
I
Applicant's Actions or Behavior
(
IDENTIFY Faulted S/G(s):
CHECK S/G pressures:
Any S/G pressure DROPPING
RO/BOP
in an uncontrolled manner.
Any S/G pressure
less than 140 oslo.
Caution
Secondary heat sink requires at least one S/G available.
Caution
Isolating both steam supplies to the TD AFW pump when it is the only source of feed
flow will result in loss of secondary heat sink.
Evaluato r Note: AFW may have previously been isolated per E-O fold-out page
CRITICAL
ISOLATE Faulted S/G(s):
TASK
ISOLATE MFW,
ISOLATE AFW .
CLOSE TD AFW pump steam
supply from faulted S/G
RO/BOP
0
FCV-1*15 (S/G 1) or
FCV-1-16 (S/G 4).
VERIFY S/G blowdown valves CLOSED,
VERIFY atmospheric relief CLOSED.
RO/BOP
CHECK CST level greater than 5%.
Note:
Chem Lab samples mav reauire resettina Phase A and ooenlnq blowdown isolation
Appendix D
34
NUREG 1021 Revision 9
IAppendix D
Required Operator Actions
Form ES-D-2 I
(
-,
Op Test No.:
Event Description:
NRC
Scena rio #
1
Event #
...;6;:,....:.,7,:..::8:....-__ Page
35
Dropped Rod. ATWS, Stuck open SG Safety Valve
of
40
Tim e
I
Position
I
Applicant's Actions or Behavior
valves as necessary.
VERIFY secondary radiation NORMAL:
NOTIFY Chem Lab to take S/G activity samples.
NOTIFY RADCON to survey main steamlines and S/G
blowdown.
CHECK following rad monitors, including available trends prior
Crew
to isolation:
Main steamline NORMAL
Condenser exhaust NORMAL
-
S/G blowdown recorder RR-90-120 NORMAL
Post-Accident Area Radiation Monitor recorder
RR-90-268B, points 3 (blue), 4 (violet), 5 (black) and 6
(brown) NORMAL. IM-31 (back of M-3011
Appendix D
35
NUREG 1021 Revision 9
I Appendix D
Required Operator Actions
Form ES-D-2 I
(
"
Op Test No.:
Event Description:
NRC
Sce nario #
1
Event #
_ 6:::.,:,..:.7",,:
. 8::......._
_
Page
36
Dropped Rod. ATWS. Stuck open SG Safety Valve
of
40
Time
I
Position
I
Apolicant's Actions or Behavior
(
CHECK SI termination criteria:
RCS subcooling based on core exit TICs greater than 40°F.
Secondary heat sink:
Narrow range level
in at least one Intact S/G
greater than 10% [25% ADVj
Total feed flow to Intact S/Gs
greater than 440 gpm.
Secondary heat sink:
Crew
Narrow range level
-
in at least one Intact S/G
greater than 10% [25% ADVj
Total feed flow to Intact S/Gs
greater than 440 gpm.
RCS pressure stable or rising.
Pressurizer level
greate r than 10% [20% ADV].
GO TO ES-1.1 . SI Termination.
Scenario may be terminated when crew transitions to ES-1.1, SI Termi nation
Appendix D
36
NUREG 1021 Revision 9
(
(
Appendix 0
Required Operator Actions
Form ES-D-2
Op Test No.:
NRC
Scenario #
4
Event #
Page
37
of
40
--
Event Description:
Equipment Verifications
Time
I
Position
I
Applicant's Actions or Behavior
ES-O.5 Actions
CHECK ERCW system operation:
VERIFY at least four ERCW pumps RUNNING.
VERIFY DIG ERCW supply valves OPEN.
VERIFY CCS pumps RUNNING:
.BOP
Pump CoS.
VERIFY EGTS fans RUNNING.
VERIFY generator breakers OPEN.
VERIFY AFW pumps RUNNING:
TO AFW pump.
Appendix D
NUREG 1021 Revision 9
(
Appendix D
Required Operator Actions
Form ES*D-2
Op Test No.:
NRC
Scenario #
4
Event #
Page
38
of
40
Event Description:
Equipment Verifications
Time
I
Position I
Applicant's Actions or Behavior
NOTE
AFW level control valves should NOT be repositioned if manual action has been taken to
control S/G levels, to establish flow due to failure, or to isolate a faulted S/G.
CHECK AFW valve alignment:
a.
b.
c.
VERIFY MD AFW pump recirculation valves FCV-3-400
and FCV-3-401 CLOSED.
VERIFY MFW Isolation:
MFW pumps TRIPPED
MFW regulating valves CLOSED
MFW regulating bypass valve controller outputs ZERO
MFW isolation valves CLOSED
MFW flow ZERO.
MONITOR ECCS operation:
VERIFY ECCS pumps RUNNING:
RHR pumps
SI pumps
Appendix D
NUREG 1021 Revision 9
(
Appendix 0
Required Operator Actions
Form ES-D-2
Op Test No.:
NRC
Scenario #
4
Event #
Page
39
of
40
--
Event Description:
Equipment Verifications
Time
I
Position
I
Applicant's Actionsor Behavior
VERIFY CCP flow through CCPIT.
CHECK RCS pressure less than 1500 psig.
VERIFY SI pump flow.
CHECK RCS pressure less than 300 psig.
VERIFY RHR pump flow.
VERIFY ESF systems ALIGNED:
Phase A ACTUATED:
0
CONTAINMENT ISOLATION PHASE A TRAIN
-
A alarm LIT [M-6C, B5].
0
CONTAINMENT ISOLATION PHASE A TRAIN
B alarm LIT [M-6C, B6].
Containment Ventilation Isolation ACTUATED:
0
CONTAINMENT VENTILATION ISOLATION
TRAIN A alarm LIT [M-6C, C5].
0
CONTAINMENT VENTILATION ISOLATION
TRAIN B alarm LIT [M-6C, C6].
Status monitor panels:
0
6C DARK
0
60 DARK
0
6E LIT OUTSIDE outlined area
0
6H DARK
0
6J LIT.
Train A status panel 6K:
0
CNTMT VENT GREEN
0
PHASE A GREEN
Train B status panel 6L:
0
CNTMT VENT GREEN
0
PHASE A GREEN
Appendix 0
NUREG 1021 Revision 9
(
(
Appendix 0
Required Operator Actions
Form ES-O-2
Op Test No.:
NRC
Scenario #
4
Event #
Page
40
of
40
Event Description:
Equipment Verifications
Time
I
Position I
Applicant's Actions or Behavior
MONITOR containment spray NOT required:
Phase B NOT ACTUATED
AND
Containment pressure less than 2.81 psig
Ensure Containment Spray is actuated
VERIFY pocket sump pumps STOPPED: [M-15. upper left
corner]
HS-77-410 . Rx Bldg Aux Floor and Equipment Drain
Sump pump A
-
HS-77-411, Rx Bldg Aux Floor and Equipment Drain
Sump pump B.
DISPATCH personnel to perform EA-0-1. Equipment Checks
Following ESF Actuation.
Appendix D
NUREG 1021 Revision 9
Operations Chemistry Information
(
- -
Bor,o~ Results
' -
.
.' .
Sample Point
Date I Tim e
Goal
Limit
U1 RCS
ppm
1093
Today / Now
Variable
Variable
U2 RCS
ppm
816
Today / Now
Variable
Variable
U1 RWST
ppm
2601
Today / Now
2550 - 2650
2500 - 2700
U2 RWST
ppm
2569
Today / Now
2550 - 2650
2500 - 2700
BAT A
ppm
6850
Today / Now
Variable
Variable
BATB
ppm
6850
Today / Now
Variable
variable
BATC
ppm
6850
Today / Now
Variable
Variable
U1 CLA #1
ppm
2556
Today / Now
2470-2630
2400-2700
U1 CLA #2
ppm
2575
Today / Now
2470-2630
2400-2700
U1 CLA #3
ppm
2591
Today / Now
2470-2630
2400-2700
U1 CLA #4
ppm
2589
Today / Now
2470-2630
2400-2700
U2 CLA #1
ppm
2531
Today / Now
2470-2630
2400*2700
U2 CLA #2
ppm
2650
Today / Now
2470-2630
2400-2700
U2 CLA #3
ppm
2522
Today / Now
2470-2630
2400-2700
U2 CLA #4
ppm
2526
Today / Now
2470-2630
2400-2700
Spent Fuel Pool
ppm
2547
Today / Now
~2050
~2000
. Midpoint, .
>
, r* ..: . ", .(.l. o,'..~_. ~::~ .. .. ....
>1
2.18-2.48
2.33
" . ~ , '.~ ';~"
- .*~ : Pr i~~y. .to ~e.c9ndary. L~akrat~: 'I)forrri~tion >(Tot~ 1 C~M R~*90*~9!119r : '.
.
.
- ;!. ...
.;tl**)'l~ ...
""
...
"'...
~
,..\\~
.
. ....
.v
"
o\\ ~
<_ . : .*""',.
",
.,
.
- .1. .:i,~ ,""
.
~ .
..* *
'J"
,
_,_
~ ..,. .
,x. ~
~
-.
t . ... $;-~
Indicator
Units
U1
Date ITime
U2
DatelTime
SI 50 S/G Leakage?
Yes/No
No
Today / Now
No
Today / Now
S1137.5 CVE Leakrate
gpd
< 0.1
Today / Now
< 0.1
Today / Now
5 gpd leak equivalent
cpm
380
Today / Now
68
Today / Now
30 gpd leak equivalent
cpm
1980
Today / Now
83
Today / Now
50 gpd leak equivalent
cpm
3250
Today / Now
206
Today / Now
75 gpd leak equivalent
cpm
4850
Today / Now
455
Today / Now
150 gpd leak equivalent
cpm
9750
Today / Now
870
Today / Now
CVE Air Inleakage
cfm
10
Today / Now
12.5
Today / Now
Bkgd on 99/119
cfm
50
Today / Now
40
Today / Now
G:\\Prep Week lilt:s\\As Submitted Operational Exam'Scenarios'Scenario 1\\3-19-07 ESG- I TO Sheets.doc
02/13/07
(
SHIFT TURNOVER CHECKLIST
APPENDIX C
Page 1 of 3
Today
t L
u ICondltlons
Train B Week
1-PCV-68-340D Valve Controller setpoint drift; (WO 06-080000-000). Pink tag on 1-M-4.
Abnormal E
0
0
US/MCR
Unit
1
0
UO
Unit
1
Off-going - Name
0
Station
SON
0
AUG Camp Actions
On-coming - Name
Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift:
. .
MAIN CONTROL ROOM(7690) (593-5409)
TURBINE BUILDING (7771) (593-5416)
(
1-RM-90-120&121 SG BD Rad Monitor 005; In vestigate the pump/instrument failure (WD 06-
080880-000). Pink tag on 1-M-12.
All equipment normal
AUXILIARY BUILDING
(7775) (593-54 14)
CCP 1B-B Out of Service: Tagged for maintenance to repair leak on pump discharge. (WO 06-
080025-000) (Out for previous 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />). ETR 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
Re s Leakage (SI-137.0)
I
Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.Q1 gpm. (Today 0600)
Gi' Prep Week files'As SubmittedOperational Exam'Scenarios'S cenar io 1'03-19-0'7 ESG-l TO Sheets.doc
SHIFT TURNOVER CHECKLIST
Page 2 of 3
Today
(
SlfTest in Progress/Planned: (Including Need for New Brief)
SI-401 release package (wi Chern Supvr) for SGBD releases to the river.
Major Activities/Procedures in Progress/Planned:
Reduce to <93% turbine power for Turbine Valve Testing. Initiate boration per Rx Engineering
Spreadsheet. Spreadsheet has been verified by the STA.
Radiological Changes in Plant During Shift:
None
V ~ '~"¥0~~ ;,:
" , ',~ ;::8'",.£:, '"7 ,!,' LCO/ODCMfTRM ACTIONS
' :
'
,('
' ~ :;;$";; -;.;-,,:" ,~¥'\\L
"
~ -",I
.
S', ~
. ~
TS 3.5.2.a, TRM 3.1.2.2. for 1B-B CCP DOS.
ODCM 1.1.1 action 31 for 1-RM-90-1201121 ODS
Part 2 ' Performed by on-coming shift
0
Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's)
0
Review of Rounds Sheets/Abnormal Readings (AUO's only)
Review the Following Programs tor Changes Since Last Shift Turnover:
0
Standing Orders
0
LCO(s) in Actions (N/A for AUOs)
0
Immediate Required Reading
0
TACF (N/A tor AUG's)
Part 3 - Performed by both off-going and on-com ing shift
0
Walkdown of MCR Controi Boards (NIA for AUG's)
Relief Time:
Relief Date:
today
TVA40741 [03-2001]
OPDP-l-t [03-14,2001
G:\\Prep Week files\\As Submitted Operational Exam'Scenarios'Scenario 1\\3-19-07 ESG*l TO Sheets.doc
02113/07
SHIFT TURNOVER CHECKLIST
Page 3 of 3
Today
(
PANEL
WINDOW
Disabled Annunciato rs
Equipment Off*Normal (Pink Tags)
WO I PER Number
UNID And No un Name
Panel
Problem Description
w o I PERNumber
(
(
-
10 And Noun Name
Panel
Probl em Description
WOlPER Number
I
G:\\Prep Week filcs\\As Submitted Operational Exam\\Scenarios\\Scenario l\\J*1Q.o1 ESG* l TO ShCCIS.doc
02113/07
(
UNIT ONE REACTIVITY BRIEF
Date: Today Time: Now
~. ' .:.. ,Gerierallnformation '.'
Res Boron: 1093 ppm
Today
I
BA Controller Setpoint: 27% *
I RCS B-10 Depletion: 2 ppm
Operable BAT: A
I BAT A Boron: 6850 ppm
I BAT C Boron : 6850 ppm
I RWST Boron: 2601 ppm
Nominal Gallons per rod step from 219 :
7 gallons of acid, 36 gallons of water
- Venfy bonc acid flow controller IS set at Adjusted SA Controller Setting law 0-SO-62-7 section 5.1
- 1
Rod Steps: 4
Gallons of water: 138
Gallons of acid: 26
f'?" : "
, ;' '::,: .
'.-~ :;<
. ... *.~
'. '*:f ..' :;Estim. ated valu' e's' 'f*o*-r a . ~1 c * .-Chang*e in Tave **
~
_
.
__~.
.
~.
,
I:
~
~ \\
.
"
~
.
.
_
____
_
_
_
__-'-
1
Power reduction amount
Estimated Final Rod Position
Estimated boron addition
10%
198
Steps on bank 0
101
gallons
30%
174
Steps on bank 0
295
gallons
50%
-
152
Steps on bank 0
485
gallons
- These values are approximations and not intended nor expected to be exact. The values may be superceded by
Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power
operation only. Engineering data last updated one week ago, Data Valid until one week from now.
Number of dilutions: 0***
Number of borations: 0
Rod steps in: 0
Gallons per dilution: 0
Gallons per boration: 0
Rod steps out: 0
Total amount diluted: 0
Total amount borated: 0
Net change: 0
IN/Out
..::~ '
"~,
~ p urr~nt Shift EStimated Reactivity:Mimipulations
.. . *1
Number of dilutions : 0
Number of borations: 0
Rod steps in: 0
Gallons per dilution: 0
Gallons per boration: 0
Rod steps out: 0
Total expected dilution: 0
Total expected boration: 0
Net change: 0
In/Out
Remarks:
Rx Power - 100%
MWD/MTU - 1000
Xenon & Samarium at Equilibrium
Next Unit 1 Flux .Map is scheduled - three weeks from now
Unit Supervisor:
(
NamelDate
G:\\Pn:p Week tilc:s\\As Submitted Operational Exam'Sccnarios'Sccnario 1\\3-19 -07 ESG-I TO Sheets.doc
02/13/07
Operations Chemistry Information
(
. .Bo'ron Results :. ~.. .
'l:
,
1
~
..
-
. ~
.
. - -
~...~~.
~
.-
...:.:...-
Sample Point
Date /Time
Goal
Limit
U1 RCS
ppm
1093
Today / Now
Variable
Variable
U2 RCS
ppm
816
Today / Now
Variable
Variable
U1 RWST
ppm
2601
Today / Now
2550 - 2650
2500 - 2700
U2 RWST
ppm
2569
Today / Now
2550 - 2650
2500 - 2700
BAT A
ppm
6850
Today / Now
Variable
Variable
BAT B
ppm
6850
Today / Now
Variable
Variable
BAT C
ppm
6850
Today / Now
Variable
Variable
U1 CLA #1
ppm
2556
Today / Now
2470-2630
2400-2700
U1 CLA #2
ppm
2575
Today / Now
2470-2630
2400-2700
U1 CLA #3
ppm
2591
Today / Now
2470-2630
2400-2700
U1 CLA #4
ppm
2589
Today / Now
2470-2630
2400-2700
U2 CLA #1
ppm
2531
Today / Now
2470-2630
2400-2700
U2 CLA #2
ppm
2650
Today / Now
2470-2630
2400-2700
U2 CLA #3
ppm
2522
Today / Now
2470-2630
2400-2700
U2 CLA #4
ppm
2526
Today / Now
2470-2630
2400-2700
Spent Fuel Pool
ppm
2547
Today / Now
.? 2050
z 2000
U1 RCS
U2 RCS
2.18-2.48
2.33
i~' :n:~'~: "'.;;
F?ri.rj1ae:~~~1~:qri~ ar;Y ':Le.~krate,J!lf9rma~Lq~~- (T9tc.l:I.~~PM. , RM~90':991119 )
, ~~_ ~~ :...::..::
Ind icator
Units
U1
Date / Time
U2
DatelTime
SI 50 S/G Leakage?
Yes/No
No
Today / Now
No
Today / Now
SI 137.5 CVE Leakrate
gpd
< 0.1
Today / Now
< 0.1
Today / Now
5 gpd leak equivalent
cpm
380
Today / Now
68
Today / Now
30 gpd leak equivalent
cpm
1980
Today / Now
83
Today / Now
50 gpd leak equivalent
cpm
3250
Today / Now
206
Today / Now
75 gpd leak equivalent
cpm
4850
Today / Now
455
Today / Now
150 gpd leak equivalent
cpm
9750
Today / Now
870
Today / Now
CVE Air Inleakage
cfm
10
Today / Now
12.5
Today / Now
Bkgd on 99/119
cfm
50
Today / Now
40
Today / Now
G:\\Prep Week files'As Submitted Operational Exam\\Scenarios\\Sccnario 1\\3-19,07 ESG-I TO Sheets.doc
02/13107
(
SHIFT TURNOVER CHECKLIST
APPENDIX C
Page 1 of 3
Today
d t
tL
Ab
0
0
US/MCR
Unit
1
0
UO
Unit
1
Off-going - Name
0
Station
SON
D
AUO Comp Actions
On-coming - Name
Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift:
. .
MAIN CONTROL ROOM(7690) (593-5409)
Train B Week
1-PCV-68-340D Valve Controller setpoint drift; (WO 06-080000-000). Pink tag on 1-M-4.
TURBINE BUILDING (7771) (593-5416)
(
1-RM-90-120&121 SG BD Rad Monitor DOS; Investigate the pumplinstrument failure (WO 06-
080880-000). Pink tag on 1-M-12.
All equipment normal
AUXILIARY BUILDING
(7775) (593-5414)
CCP 1B-B Out of Service: Tagged for maintenance to repair leak on pump discharge. (WO 06-
080025-000) (Out for previous 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />). ETR 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
Res Leakage (SI-137.0)
Total 0.03 gpm !Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600)
(
G:\\Prep Week files'As Submitted Operat ional Exarn'Sce narios'Scenario
1 \\3 ~ 1 9 w0 7 ESG-l TO Sheets.doc
02/ 13/07
"
SHIFT TURNOVER CHECKLIST
Page 2 of 3
Today
(
(
31fTest in Progress/Planned: (Including Need for New Brief)
0
SI-401 release package (wI Chern Supvr) for SGBD releases to the river.
Major Activities/Procedures in Progress/Planned:
0
Reduce to <93% turbine power for Turbine Valve Testing. Initiate boration per Rx Engineering
Spreadsheet. Spreadsheet has been verified by the STA.
Radiological Changes in Plant During Shift:
None
I Z';; if~':fl :~17 :;t;"t~\\ Y
iA; ' .J~ ' i4",j ' f." ~?),LCOIODCM!TRM ACTIONS ~~\\~'.
,~;k:"
M~*..ft~ ' '....:.t.:j$f;;~;*
- ','v
'-." " . .'i- -: ~ .... Jl.I:~'
~ 0 TS 3.5.2.a, TRM 3.1.2.2. for lB-B CCP DOS. 0 ODCM 1.1.1 action 31 for 1-RM-90-1201121 ODS Part 2 - Performed by on-coming shift 0 Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) 0 Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shift Turnover: 0 Standing Orders 0 LCO(s) in Actions (N/A for AUOs) 0 Immediate Required Reading 0 TACF (N/A for AUO's) Part 3 - Performed by both off-going and on-coming shift 0 Walkdown of MCR Control Boards (N/A for AUO's) Relief Time: Reiief Date: today TVA 4074 1 [03-2001) OPOP-l -1 103-14-2001 Gt'P rep Week files\\As Submitted Operational Exam'Scenarios'Scenario 1\\3* 19*07 ESG*l TO Sheets.doc 02113/07
SHIFT TURNOVER CHECKLIST Page 3 of 3 Today ( PANEL WINDOW Disabled Annunciators ANNUNCIATOR Equipment Off*Normal (Pi nk Tags) WO I PER Number UNIO And Noun Name 10 And Noun Name Panel Panel Problem Description MCRWO LIst Problem Description WO I PER Number WOlPER Numb er G:\\Prep Week f iles'As Submitted Operational Exam'Scenarios'Scenario 1\\3*19-0? ESG-! TO Sheets.doc 0211 3/07
( UNIT ONE REACTIVITY BRIEF Date: Today Time: Now Res Boron: 1093 ppm Today I BA Controller Setpoint: 27% * IRCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850 ppm I BAT C Boron: 6850 ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 36 gallons of water
- Verity boric acid flow controller IS set at Adjusted SA Controller Setting law 0-SO-62-7 section 5.1
Gallons of acid: 26 Gallons of water: 138 Rod Steps: 4 ( Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 198 Steps on bank D 101 gallons 30% 174 Steps on bank D 295 gallons 50% - 152 Steps on bank D 485 gallons
- These values are approximations and not intended nor expected to be exact. The values may be superceded by
Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago . Data Valid until one week from now. Number of dilutions: 0*** Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 0 Total amount borated: 0 Net change: 0 IN/Out Number of dilutions: 0 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total expected dilution: 0 Total expected boration: 0 Net change: 0 In/Out Remarks: Rx Power - 100% MWD/MTU - 1000 Xenon & Samarium at Equilibrium
- The boron letdown curve is flat for the next 25 EFPD.
Next Unit 1 Flux Map is scheduled - three weeks from now Unit Supervisor: Name/Date G:\\Prep Week filcs\\As Submitted Operational ExarrrScenarios'Scenario 1\\3- 19-07 ESG-l TO Sheets.doc 02J1 3i07
2.18-2.48 2.33 Operations Chemistry Information ( ~ Sample Point Limit U1 RCS ppm 1093 Variable U2 RCS ppm 816 Variable U1 RWST ppm 2601 2550 - 2650 2500 - 2700 U2 RWST ppm 2569 2550 - 2650 2500 - 2700 BAT A ppm 6850 Variable Variable BAT B ppm 6850 Variable Variable BATC ppm 6850 Variable Variable U1 CLA #1 ppm 2556 2470-2630 2400-2700 U1 CLA #2 ppm 2575 2470-2630 2400-2700 U1 CLA #3 ppm 2591 2470-2630 2400-2700 U1 CLA #4 ppm 2589 2470-2630 2400-2700 U2 CLA #1 ppm 2531 2470-2630 2400-2700 U2 CLA #2 ppm 2650 2470-2630 2400-2700 U2 CLA #3 ppm 2522 2470-2630 2400-2700 U2 CLA #4 ppm 2526 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 ~2050 ~2000 ~~~ ~y :.~. t >*:*:.1Pfimaiy; t~Si"c~ti~a rY *leakrate Inforn1aflon{'f.p'tal 'CPM RM-90';991119) - ~~~~~~ .;'%. ~,
0'-
- * ",,
> ~ . . --"" _ ~ , . '. . ~ To ' . " ", "" '. Indicator Units U1 Date I Time U2 DatefTime SI 50 S /G Leakage? Yes/No No Today 1Now No Today 1Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today 1Now 5 gpd leak equivalent cpm 380 Today 1Now 68 Today 1Now 30 gpd leak equivalent cpm 1980 Today / Now 83 Today 1Now 50 gpd leak equivalent cpm 3250 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 4850 Today 1Now 455 Today / Now 150 gpd leak equivalent cpm 9750 Today / Now 870 Today / Now CVE Air Inleakage cfm 10 Today 1Now 12.5 Today 1Now Bkgd on 99/119 cfm 50 Today 1Now 40 Today / Now ( G:\\Prep Week files\\As SubmittedOperational Exam\\Scenarios\\Seenario 1\\3-19-07 ESG-I TO Sheets.doc 02113/07
( 3HIFT TURNOVER CHECKLIST o SM o US/MeR o UO o AUO o STA (STA Function) Unit Unit Station APPENDIX C Page 1 of 3 1 1 SON AUO Comp Actions Off-going - Name On-coming - Name Today Part 1 * Completed by Off-going Shift/Reviewed by On-coming Shift: Abnormal E ui ment Lineu IConditions: MAIN CONTROL ROOM(7690) (593-5409) Train B Week
1-PCV-68-340D Valve Controller setpoint drift; (WO 06-080000-000). Pink tag on 1-M-4. TURBINE BUILDING (7771) (593-5416)
1-RM-90-120&121 SG BD Rad Monitor ODS; Investigate the pump/instrument failure (WO 06- 080880-000). Pink tag on 1-M-12.
All equipment normal [I AUXILIARY BUILDING (7775) (593-5414)
CCP 1B-B Out of Service: Tagged for maintenance to repair leak on pump discharge. (WO 06- 080025-000) (Out for previous 16 hours). ETR 12 hours. ( .Re8 Leakage (81-137.0) Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600) G:\\Prep Week files'As SubmittedOperational Exam'Scenarios'Scenario 1\\3-19-07 ESG-I TO Sheets.doc 02/13/07 I
SHIFT TURNOVER CHECKLIST Page 2 of 3 Today ( "I{fest in Progress/Planned: (Including Need for New BrieO 0 SI-401 release package (wi Chern Supvr) for SGBD releases to the river. Major Activities/Procedures in Progress/Planned: 0 Reduce to <93% turbine power for Turbine Valve Testing. Initiate boration per Rx Engineering Spreadsheet. Spreadsheet has been verified by the STA. Radiological Changes in Plant During Shift: None I'{\\ !fr:*1'*'iif'1# ~iii.<*,j t,: i,f " . LC()/ODCMITRM ACnONSf"i ~¥; ;; -:""*.' .;:;;1 ' '" " l ;Y "o ;~ :J (' *1 ",',;:Fi'>, " , .,'" . . 0 TS 3.5.2.a, TRM 3. 1.2.2. for 1B-B CCP OOS. 0 ODCM 1.1.1 action 31 for 1-RM-9Q-1201121 OOS Part 2 . Performed by on-coming shift D Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) D Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shift Turnover: D Standing Orders D LCO(s) in Actions (N/A for AUOs) D Immediate Required Reading D TACF (N/A for AUO's) Part 3 - Performed by both off-going and on-coming shift D Walkdown of MCR Control Boards (NIA for AUO's) Relief Time: Relief Date: today (, TVA 40741 [03-2001] OPOP-1-1 [03-14-2001 G:\\Prep Week files\\As Submitted Operational Exam' Scenarios'Scenario 1\\3-19-07 ESG* I TO Sheets.doc 02/13/07
SHIFT TURNOVER CHECKLIST Page 3 of 3 Today ( PANEL WINDOW Disabled Annunciators ANNUNCIATOR Equipment Off*Normal (Pink Tags) WO I PER Number UNID And Noun Name Panel Problem Description MCRWO List WO I PER Number ( ( 10 And Noun Name Panel Problem Description WOlPER Number I G:\\Prep Week tiles\\As Submitted Operational Exam' Scenarios'Scenario 1\\3-19-07 ESG-I TO Sheets.doc 02/13107
( UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 1093 ppm Today I BA Controller Setpoint: 27% * I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850 ppm I BAT C Boron: 6850 ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 36 gallons of water
- Venfy boric acid flow controller IS set at Adjusted SA Controller Setting law 0-SO-62-7 section 5.1
Rod Steps: 4 Gallons of water: 138 Gallons of acid: 26 '--- 1_' ~ _ ,, '~"r;f,':¥ ' :' : <; '<>>t>\\ ., ,Estimatea ro~slDbror( for:~merge.ncy steRP'~wer 'reduCtion *~..*r:z " . >
- ~J,
, , . ~ . ; . (Assuming Xenone.quilibJiLmandno'r:eac.\\ivity effects di.jeto')~enon. 2l3 total'reactivityfrom reds, 1JQfrom boronj .: t i
- '
Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 198 Steps on bank D 101 gallons 30% 174 Steps on bank D 295 gallons 50% - 152 Steps on bank D 485 gallons "* Th ese values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now. Number of dilutions: 0*** Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 0 Total amount borated: 0 Net change: 0 IN/Out ,* 1 Number of dilutions: 0 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total expected dilution: 0 Total expected boration: 0 Net change: 0 In/Out Remarks: Rx Power - 100% MWD/MTU - 1000 Xenon & Samarium at Equilibrium
- The boron letdown curve is flat for the next 25 EFPD.
Next Unit 1 Flux Map is scheduled - three weeks from now Unit Supervisor: _ ( Name/Date G:\\Prep Week fi l t:S\\A.~ Submitted Operational Exam'Scenarios'Scenario 1\\3-19-07 ESG-I TO Sheets.doc 02113/07
r-.
r<;
Unit 1
DELTA
REACTOR
POWER
ASSUMED
I NSERTED
EXPECTED DELTA RHO
BORON
DELTA RECOMMENDRECOMMEND IODINE
TIME
POWER
DEFECT
ROD HT
WORTH
XENON
BORON
CONC
PPM
DI LUTION BORATION
CONC
(hrs)
( %)
(pcm)
(s t e ps )
(pcm)
(p cm)
(pcm)
(ppm)
(ppm)
(g a l)
(g a l )
( % eq )
0 . 0
10 0 .0
17 32 . 0
216 . 0
-24 . 5
-2 72 8 . 0
10 93. 0
100 .0
1.0
93 .0
1608 .0
204.0
- 83 . 7
- 2 742 . 5
- 5 0 . 4
1100 .8
7 . 8
0
87
99 . 7
2 . 0
93 .0
1 604 .5
204 .0
- 83 . 7
- 27 64 . 3
18.4
1 09 8 .0
- 2 . 9
168
0
99.0
3 . 0
100. 0
1729 . 6
216 .0
-2 4. 5
- 27 62 . 9
64 .4
1087 .9
-10 .0
594
0
98.8
4.0
100 . 0
1734 .4
21 6 . 0
- 24. 5
- 2747 . 7
- 1 0 .4
1089 .6
1. 6
0
18
98 . 9
5 . 0
100 .0
17 33 . 7
21 6 . 0
- 2 4 . 5
- 2736.8
J11 . 7
1091. 4
1. 8
0
20
99 . 0
6 .0
100 .0
1732 . 8
21 6 . 0
- 2 4 .5
- 2729 . 0
-8 .6
1 092 .7
1. 3
0
15
99 . 1
7. 0
1 00 . 0
1732.2
21 6 . 0
-24 . 5
-2723 .7
- 6. 0
1093 . 7
0 .9
0
10
99 . 2
8 . 0
100 . 0
1731. 7
216.0
-2 4 . 5
-272 0 . 1
- 4.1
1094 . 3
0.6
0
7
99 .3
9 .0
100 .0
17 31. 4
21 6 . 0
- 24 . 5
-2 717 . 8
-2 .6
109 4 . 7
0 .4
0
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f
SQN
0-80-62-7
1,2
BORON CONCENTRATION CONTROL
Rev. 45
Page 157 of 195
APPENDIX 0
Page 1 of 1
CALCULATION FOR AMOUNT OF BOR IC ACID OR PRIMARY WATER (TI44)
NOTE 1
NOTE 2
One calculation is required for each major change.
Boric acid amountsto achieve required RCS boron concentration may be
significantly higher than calculated amounts if CVCS demin resins are
removing boron. Amount of boron removal by mixed bed resins will
depend on RCS boron, resin age, whether demin bed was previously
borated, and letdown temperature. Chemistry should be consulted if
required to evaluate resin bed removal.
[1]
IF REACTF not used,
THEN
CALCULATE amount of primary water or boric acid required using TI-44 .
RCS BORON
1t):1
ppm
Current PPM CHANGE
TOTAL GAL(s) NOTE REACTF datasheets are to be signed by the preparer and reviewer. [2] IF REACTF used attach printout to procedure. ~ NOTE IV is not required if appendix is performed by an SRO to verify data provided by Rx. Eng. ( [3] ENSURE independently verified by an SRO in accordance with Appendix I. END OF TEXT
( SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 45 Page 29 of 195 TrJJ,,!' Date---,,--,,,,"-'"i!-_ _ I Borate Unit_ _ -l- _ 6.4 CAUTION Returning the Boric Ac id Blender to service after unplugging, cleaning, or maintenance on Boric Acid System could introduce debris, sludge, air or solidified boron into CCP suction resulting in pump damage. Extreme care must be exercised to properly flu sh the Boric Acid piping following an outage. [C.2] NOTE If a large amount of boration is required (plant shutdown), pzr heaters should be energized to cause spray operation for equalizing boron concentration in RCS and pressurizer. [1] ENSURE makeup system aligned for AUTO operation in accordance with Section 5.1 . ( NOTE Steps 2 and 3 are N/A for minor power changes OR if immediate boration is required to maintain shutdown margin, to maintain rods above the insertion limit, during an emergency shutdown (AOP-C.03), during recovery of a dropped/misaligned rod (AOP-C.01), or at Chemistry recommendation in mode 3, 4, 5 or 6. [2] RECORD the quantity of boric acid required to achieve desired boron concentration using Appendix D. [3] PERFORM Appendix I Independent Verification of Calculation for Amount of Boric Acid or Primary Water. (N/A if App. D was performed by SRO to verify data from Rx Engineering) tit SRO [4] DETERMINE available boric acid volume in in-service BAT. _____ qals [5] PLACE [HS-62.140A], Boric Acid to Blender Flow Control Switch to the STOP position. I - 1-"- rsr:
( SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 45 Page 30 of 195 Borate (Continued) Unit. _ 6.4 Oate _ ( [6] PLACE [HS-62-1 40Bl, CVCS Makeup Selector Switch to the BORATE position. [7] ADJUST [FC-62-1391, Boric Acid Flow Contro ller to the desired flow rate. [8] SET [FQ-62-139], Batch Integrator to the desired quantity. [9] PLACE [HS-62-140Al, Boric Acid to Blender Flow Control Switch to the START position. [10] ENSURE Boric Acid Pump aligned to blender in FAST speed by right red light LIT on [HS-62-230A] OR [HS-62-232AJ. / - 1*-rsr: --'-- lSI CV I -1-* -
c::;-
NOTE Flow oscillations and/or erratic controller response may require manual operation of Boric Acid Flow Controller [FC-62-1391 until stable conditions exist. [11] VERIFY Boric Acid Flow established. NOTE It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrumentation or RCS temperatu re indication. [12] IF reactor is critical, THEN MONI TOR nuclear instrumentation and reactor coolant temperature to ensure proper response from boration. D NOTE BAT operability limits are prescribed by TRM 3.1.2.6 (Modes 1-3) or 3.1.2.5 (Modes 4-6). ( [13] MONITOR Boric Acid Stora ge Tank level. D
( SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 45 Page 31 of 195 Borate (Continued) Unit'--- _ 6.4 Date _ [14] IF Volume Control Tank level increases to 63 percent, THEN ENSURE [LCV-62-118], Volume Control Tank Divert Valve OPENS to divert excess water to the Holdup Tank. NOTE Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the boration is as expected . [15] WHEN boration is complete , THEN [aL PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the STOP position. t -1 s;- cv ( [b] CHECK no primary water flow on either [FI-62-142A] OR [FQ-62-1421 [c] ENSURE [FC-62-142], Primary Water to Blender Flow Controller is in AUTO position and the potentiometer (dial indicator) is set at 35%. [d] ADJUST [FC-62-139], Boric Acid Flow Controller to the desired blend solution in accordance with TI-44 Boron Tables. t - 1"- cv [e] ENSURE [FCV-62-128] is CLOSED. [f] PLACE [HS-62-140B], CVCS Makeup Selector Switch to the AUTO position. [9] PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the START position. t -1-"- cv [h] IF RCS boron sample required , THEN " NOTIFY Chem Lab to obtain RCS boron sample. "
( SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 45 Page 32 of 195 Borate (Continued) Unit. _ 6.4 NOTE Date _ Boration is done in batches until the total boron and/or power change is completed. ( ( [16] REPEAT this section as required to complete total boron change. [17] WHEN total boration is complete, THEN [a] REALIGN the blender controls for AUTO makeup to the CVCS in accordance with Section 5.1 . [b] NOTIFY Chem Lab to obtain RCS boron sample. [18] IF in modes 1,2, or 3, THEN ENSURE requirements of TRM 3.1 .2.6 are met. [19] IF in modes 4,5, or 6, THEN ENSURE requirements ofTRM 3.1.2.5 are met. [20] ENSURE boration is logged in Unit Narrative Log. End of Section 6.4 o
(
(
c.
Sequoyah Nuclear Plant
Unit 1 & 2
General Operating Instructions
O-GO-5
NORMAL POWER OPERATION
Revision 0047
Quality Related
Level of Use: Continuous Use
Effective Date:
10-10-2006
Responsible Organization:
OPS, Operations
Prepared By:
Jimmy Morris
Approved By:
D. A Porter
Current Revision Description
Revised step in section 5.4 concerning control rods, ref. NB 060297. Added references to
existing precautions to applicable sections concerning voltage control as a minor editorial
change, ref. 060531. Added step to section 5.1 concerning MFPT master controller output,
ref. PER 100196-03.
PERFORMANCE OF THIS PROCEDURE COULD IMPACT REACTIVITY.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 2 of 93 Table of Contents 1.0 1.1 1.2 2.0 2.1 2.2 3.0 3.1 3.2 4.0 5.0 5.1 ( 5.2 5.3 5.4 5.5 6.0 INTRODUCTION 3 Purpose
3 Scope 3 REFERENCES 4 Performance References 4 Developmental References 5 PRECAUTIONS AND LIMITATIONS 6 Precautions , , 6 Limitations 11 PREREQUiSiTES 14 INSTRUCl:IONS 16 Power Ascension From 30% to 100% 17 At Power Conditions 58 Power Reduction From 100% to 30% 64 Power Coastdown at End of Life " 77 LOAD FOLLOW OPERATIONS __ 82 RECORDS 86 Appendix A: DELETED 87 Appendix B: TURBINE RUNBACK RESTORATION 88 Ap pendix C: ISOLATION OF MSR STARTUP VENTS 90 Appendix D: RECOMMENDED POWER VALUES BASED ON CONDENSATED PRESSURE 91 Source Notes 92 ATTAC HMENTS Attachment 1: NORMAL POWER OPERATION
(, SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 3 of 93 1.0 INTRODUCTION 1.1 Purpose This General Operating (GO) Instruction provides guidance for power ascension from approximately 30 to 100% power, at power conditions, power reduction from 100 to 30% power, Power Coastdown at End of Life operations, and Load Follow operations. This instruction provides additional guidance for turbine control restoration following a turbine runback. 1.2 Scope This GO contains the following sections: 5.1 Power Ascension From 30% Power to 100% 5.2 At Power Conditions 5.3 Power Reduction From 100% to 30% 5.4 Power Coastdown at End of Life 5.5 Load Follow Operations
( ( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pace 4 of93 2.0 REFERENCES 2.1 Performance References A. 1,2-S0 -5-1, Feedwater Heaters and Moisture Separator Reheaters B. 1,2-S0-5-2, NO.3 Heater Drain Tank and Pumps C. 1,2-S0 -5-3, No. 7 Heater Drain Tank and Pumps D, 1,2-S0 -2/3-1, Condensate and Feedwater System E. 1,2-S0-2-9, Condenser Vacuum and Turbine Steam Seal Systems Operation F, 0-SO-12-1, Auxiliary Boiler System G. 0-SO-35-4, Monitoring Generator Parameters H. 0-SO-58-1. Main Generator Bus Duct Cooling System I. 0-SI-NUC-000-038.0, Shutdown Margin J. 0-SO-62-7, Boron Concentration Control K. 1,2-S0-62-9, CVCS Purification System L. 0-SO-68-3, Pressurizer Spray and Heater Pressure Control System M. 0-SO-85-1, Control Rod Drive System N. 0-PI-OPS-000-666.0, River Temperature Limits Specified by NPDES permit O. 0-SI-OPS-092-078.0, Power Range Neutron Flux Channel Calibration By Heat Balance Comparison P. 0-SI-CEM-000-050.0, 72-Hour Chemistry Requirements Q. 0-SI-CEM-030-407.2, Radioactive Gaseous Waste Effluent Particulate and Iodine Dose Rates from Shield and Auxiliary Building Exhausts (Weekly/Special) and Condenser Vacuum Exhausts (Special) R. 0-SI-CEM-030-415.0, Gaseous Effluent Requirements (Gross Alpha, Noble Gas and Tritium S. 0-SI-OPS-000-001.0, Initial Startup System Parameter Log T. TI-40, Determination of Preconditioned Reactor Power
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 5 of 93 2.2 Developmental References A. Memorandum from System Engineering concerning MSR operation - RIMS S57 880322 999 B. Memo from Reactor Engineering - RIMS S57 941219 934 C. S57-880322-999 and S57-880808-851 D. W Letter GP89-076 (RIMS No. S53 890427 984) E. W Letter GP 89-155 (RIMS S57 891026 972) F. W Letter GP 86-02(B44 861112 002) G. SSP-2.3, Administration of Site Procedures H. TVA-NQA-PLN89-A I. GOI.J 0, Reactivity Control at End of Cycle Life (Trojan Nuclear Plant) J. FSAR, Section 13.5 K. Memo from Reactor Engineering - August 6, 1996 (G Bair)
( ( SQN NORMAL POWER OPERATION O-GO-S Unit 1 & 2 Rev. 0047 Paae 6 of 93 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Precautions A. To ensure that NIS Reactor Power level indications remain within 2% of true power during power level changes, a check should be performed about every 20% power level change, when greater than 15% power, by comparing calorimetric power to each NIS Power Range drawer. The 20% power level check does not preclude the operating crews from making necessary changes in response to changing plant conditions . B. TRM 3.3.3.15 requires LEFM core thermal power (U2118) to be used to perform 0-SI-OPS-092-078.0 above 15% reactor power. LEFM indication is available if the following conditions are met:
LEFM status NORMAL on ICS Calorimetric Data screen.
LEFM core thermal power (ICS point U2118) shows good (green) data.
LEFM MFW header temp (ICS point T8502MA) greater than or equal to 250°F. If LEFM indication is NOT available above 15% reactor power, then TR 3.3.3.15 action must be entered. C. The following should be used to determine the most accurate reactor power indication for comparison with NIS:
When reactor power is greater than 15%, use LEFM calorimetric power indication (U2118).
If LEFM is NOT available , then use average loop ~T (U0485 or M-5 indicators) up to 40%. Above 40%, use computer point U1118. D. The turbine should be operated in "IMP OUT" control during normal unit operation. "IMP IN" operation results in system swings and should only be used during the performance of valve tests. (W Ltr GP 89-155; RIMS S57 891026 972) E. Pressurizer heaters and sprays may be operated as required to maintain pressurizer and RCS boron concentration within 50 ppm. If loop boron concentration is changed by 20 ppm or greater, use the pressurizer backup heaters to initiate automatic spray.
( SON NORMAL POWER OPERATION O-GO-S Unit 1 & 2 Rev. 0047 Paae 7 of 93 3.1 Precautions (continued) F. Condensate DI polishing operations during power ascension are controlled by staying within system parameters and by recomme ndations from the Chemistry Section. G. The valve position limiter should be periodically positioned approximately 10% above the current governor control indications (keeps governor valves off of the limiter) as turbine load is changed. This prevents inadvertent load increases by limiting governor valve opening and allows a faster response of the runback feature which ensures main feedwater system will supply the required amount of flow. H. Any off-frequency turbine operation is to be reported to Engineering for record keeping. The report will include duration and magnitude of off-frequency operation. I. Opera tion at off-frequencies is to be avoided in order to prevent the probable occurrence of turbine blade resonance. Prolonged periods of operation at certain off-design frequencies could cause excessive vibratory stresses which could eventually generate fatigue cracking in the blades . Off-frequency operation is permitted to the degree and time limit specified on the chart "Off-Frequency Turbine Operation", Figure A.26 of TI-28. J. The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated. K. Initial Startup After Refueling - After refueling operations, the NIS indications may be inaccurate until calibration at higher power levels. The NIS calibration procedures will adjust the PRM trip setpoints to ensure that the excore detectors do not contribute to an overpower condition at the following RTP hold points. Reactor Engineering and/or Systems Engineering will determine procedure performance. [C.3] 1. At < 50% RTP a flux map and single point alignment, a hot channel factor determination, an axial imbalance comparison, and a PR NIS calibration will be performed. The PR high range trip setpoint will then be increased to its normal value of 109%. 2. At < 75% RTP, calorimetric calculations and ReS flow verification may be performed, EAGLE-21 updated prior to increasing power, a flux map, a hot channel factor determination, an axial imbalance comparison may be required if not performed at < 50%, a detector calibration (if!'!. AFD ::: 3%), and a PR NIS calibration may be performed.
( " ( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 8 of 93 3.1 Precautions (continued) 3, If not performed at 75% hold point. an axial imbalance comparison and a detector calibration (if 1\\ AFD ~ 3%) should be performed at - 100% RTP. Engineering will determine if PR NIS calibration must be perfonmed. Calorimetric calculations, RCS flow verification, a hot channel factor determination, and a reactivity balance will be performed and EAGLE-21 updated . Reactor Engineering will notify Operations that normal full power operations may proceed. 4. Preconditioned Power Levels and Maximum Allowable Rates of Power Increase are specified in TI-40, Determination of Preconditioned Reactor Power. 5. During initial startups , based on Westinghouse recommendations, a lower power ramp rate limit has been implemented for power levels above the intermediate power threshold. The Intermediate Power Threshold is uniUcycle dependent and is determined by the Vendor. Refer to TI-40. 6. l CS will automatically monitor pre-conditioned power level as follows: a. Point U1127 is reactor power in percent of RTP based on either secondary calorimetric or RCS 1\\T depending on power level. b. Point U01 03 is a 20 minute rolling average of reactor power rate-of-change fitted over a 20 minute period. U0103 is a leading indicator of %/hour power ramp rate and can be used in deciding to speed up or slow down the ramp rate. c. Point U0104 is a 1 hour rolling average of reactor power rate-of-change fitted over a 1 hour period. U0104 is used in demonstrating compliance with fuel pre-conditioning power ramp rate limits. d. Point K0058 is the currently qualified (or pre-conditioned) power level. e. These points can all be monitored with the ICS group display "TI40". Append ix A may be used if the ICS is unavailable. L. TI-40 power increase limits that are exceeded, in anyone hour, are evaluated in accordance with SPP-3.1 .
( ( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 9 of 93 3.1 Precautions (continued) M. Power Coastdown At End Of Life: 1. Reactor power changes should be limited to less than or equal to 1% per hour to avoid causing xenon peaking which could force a plant shutdown . 2. Do not perform unnecessary unit power maneuvers or testing (e.g., turbine valve testing). Such testing could result in an uncontrollable Xenon oscillation. 3. Nonessential work on systems which could cause a plant upset should be deferred . 4. Secondary Plant runbacks such as Main Feed Pump Turbine trip or
- 3 Heater Drain Tank runback will require a unit shutdown if Reactor power
is not promptly returned to pre-transient level due to the resulting severe Xenon transient. If a system power alert is in effect, and electrical generation is critical, unit load should be reduced as necessary keeping TAVG on program. Contact Reactor Engineering for an evaluation and guidance concerning unit shutdown or reduction of load. 5. Management should be consulted to evaluate the feasibility of a unit restart if a reactor trip occurs with RCS equilibrium boron concentration less than 50 ppm. If the reactor is to be restarted, the power level shall be limited to nominal pre-trip power level. N. Axial Flux Difference Management: When the reactor is operating at a steady power or during normal load changes, maintain "'I within the operating limits of the Core Operating Limits Report (COLR). It is recommended that the core axial flux difference (AFD) be maintained within +/- 5% of the target band at all times, excluding the performance of 0-PI-NUC-092-036 .0, "Incore - Excore Calibration," and End of life power coast downs. Operating time outside the band, which is given in TI-28 Attachments 1 and 2, should be minimized. Reactor Engineering should be contacted if time out of the +/- 5% target band exceeds approximately 30 minutes. O. The position of control bank D should normally be ~ 215 steps when power level is steady state at or above 85% RTP. At steady state power levels below 85%, control bank D should normally be ~ 165 steps. If rod position is more than 2 steps below this guidance for long term, then impact may occur to safety analysis assumptions. P. During heatup and cooldown transients, RCS density changes will cause changes in NIS indicated power. At constant reactor power, a 1°F change in TAVG may cause as much as a 1% (or more) change in indicated NIS power.
( ( ( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 10 of 93 3.1 Precautions (continued) Q . Opera tion of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator. Also, refer to Section E of GOI 6 for MVAR limits. R. Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Duty Specialist (ODS) within twenty four (24) hours. S. Main Generator operation outside of the Voltage Schedule in GOI-6 requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1) hour. T. The following limitations are applicable to Unit Two ONLY. 1. tn winter months #7 HDTP capacity is not adequate to pump #6 Heater drains when all Condensate Demineralizer pumps are in service. Current practice is to run two Cond DI Pumps and I or throttle the condensate system to reduce backpressure. The preferred method is to throttle condensate pressure instead of running only two Conden sate Demineralizer booster pumps at full power due to pump runout concerns. 2. Siemens-Westinghouse analysis has determined that the maximum unit power with one MFP operation is 65% under worst case conditions. The plant could operate higher if plant conditions permit. 3. MFP flow from the lead MFP should not exceed 53.7% of the total flow. Flow rates above this would result in HP steam flow tot he lead MFPT. Computer points 1(2)U0 504 and U0505 can be used to monitor.
( ( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 11 of 93 3.2 Limitations A. When the axial flux difference monitor alarm is inoperable , the AFD must be logged every hour by performing 0-SI-NUC-000-044.0. (SR 4.2.1.1.a.2 & 4.2.1.1.b) B. When both the plant computer and NIS QPTR alarm systems are inoperable, the QPTR must be calculated every 12 hours by performing 0-SI-NUC-000-133.0. (SR 4.2.4.1.b) C. Do not exceed a load change rate of plus or minus 5% per minute or a step change of 10%. D. River water temperatures shall be maintained within the limitations of the NPDES permit as specified in 0-PI-OPS-000-666.0. NOTE Westinghouse should be contacted if the turbine is operated outside of its operating limits as stated below. E. To prevent high vibratory stresses and fatigue damage to the last stage turbine blading , do not operate the turbine outside of limits listed below: [W Ltr GP 86-02 (B44 861112 002)] 1. At loads less than or equal to 30% (350 MW), the maximum permissible backpressure is 1.72 psia. (3.5" Hg) 2. At loads greater than 30%, the maximum permissible backpressure is 2.7 psia (5.5" Hg) with a 5 minute limitation before tripping the turbine. F. Do not allow the generator to become underexcited . G. In the event of a change in the rated thermal power level exceeding 15% in one hour, notify Chemistry to initiate the conditional portions of 0-SI-CEM-000-050.0, 0-SI-CEM-030-407.2 and 0-SI-CEM-000-415.0 due to the thermal power change.
( l ... SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pace 12 of 93 3.2 Limitations (continued) H. The following Main Turbine vibration limitations and actions should be adhered to: 1. Vibration levels which exceed 7 mils (alarm setpoint) should be verified by Predictive Maintenance Group . 2. Vibration levels greater than 7 mils and less than 14 mils should be continuously monitored by Predictive Maintenance Group. 3. IF vibration level is greater than or equal to 14 mils, THEN TRIP the turbine. I. Westinghouse recommends that if any throttle valve is held closed for more than 10 minutes, then it should be re-tested immediately upon reopen ing in accordance with 1,2-PI-OPS-047-002.0. J. The generator may be operated without a bus duct cooler up to appro ximately 729-MW turbine load. K. To ensure sufficient voltage for a safe shutdown after loss of both units, voltage and reactive power should be maintained within the limits of GOI-6. L. With LEFM calorimetric power indication available, full power operation is defined as approximately 3455 MWT not to exceed 3455.0 MWT averaged over a 8-hour period. [C.1] If LEFM is available, power shall be monitored using plant computer point U2118 Instantaneous Value. DO NOT allow average thermal power to exceed 3455 MW thermal for two consecutive hours. M. The following restrictions apply if LEFM calorimetric power indication (U2118) is unavailable: 1. Applicable action of TRM 3.3.3.15 must be entered. 2. AFD limits in COLR and T1-28 must be made more restrictive by 1%. 3. Rod insertion limits in COLR must be raised by 3 steps . 4. If reactor power is greater than 40%, power should be monitored using U1118. If U1118 is also unavailable, use the highest reading NIS channel. 5. If reactor power is less than 40%, use the RCS average !'>T as the preferred method for determining power level. N. IF equilibrium conditions are achieved, after exceeding by 10% or more of rated thermal power the thermal power at which the heat flux hot channel factor was last determined, THEN cond itional performance of 0-SI-NUC-000-126.0, Hot Channel Factor Determination is required.
( ( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 13 of 93 3.2 Limitations (continued) O. At low power levels , the LP Heaters may be unbalanced in extraction steam supply use and heat pickup across the condensate side of the heater string. This condition should correct itself as the unit approaches 45-50% Turbine Power. (Ref: PER 99-003789-000) P. With one LP heater string out of service (isolated), power is limited to 86% (Unit 1) or 90% (Unit 2). This is based on LP turbine blading limitations. (Ref: DeN E21203A).
( SQN NORMAL POWER OPERATION O-GO-S Unit 1 & 2 Rev. 0047 Page 14 of 93 4.0 STARTUP No. _ PREREQUISITES Unit l Date nil., NOTES 1) Throughout this Instruction where an IFITHEN statement exists, the step should be N/A'd if the condition does not exist. 2) Prerequisites may be completed in any order. [1] ENSURE Instruction to be used is a copy of effective version. [2] TAVG is being maintained within 1.5°F of TREF. [3] SG level controls are being maintained in AUTO (N/A if auto control NOT available). [4] Control rods are being maintained within the operating band of C6fe Operating Limits Report (COLR) (N/A if shutting down due to dropped or misaligned rod). [5] Steam dump control system is in the TAVG mode (N/A if Tavg Mode NOT available). [6] The EHC system should be in OPER AUTO (pushbutton lit). [7] Generator pressurized with hydrogen according to capability curve. (TI-28, Fig. A.14) NOTE During start up after a cold shutdown the Condensate 01 normally will be aligned for full flow polishing until the MSRs are in service. ( [8] ENSURE Condensate DI polishing operation in accordance with RCL recommendations.
(, SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 15 of 93 4.0 STARTUP Noo _ PREREQUISITES (continued) Unit I Date~ [9] ENSURE each performer documents their name and initials: ( ( Print Name Initials
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 16 of 93 5.0 INSTRUCTIONS CAUTION Steps of this procedure must be performed sequentially, unless specifically stated otherwise. NOTES 1) RADCON should be notified during normal plant operations if power level increases or decreases are either stopped or started. 2) Guidance on restoration of EHC Controls after a BOP runback is contained in Appendix B, Turbine Runback Res/ora/ion. [CAl
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 17 of 93 STARTUP No. _ 5.1 Power Ascension From 30% to 100% Unit __ Date _ NOTES 1) Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Duty Specialist (ODS) within twenty four (24) hours. 2) Main Generator operation outside of the Voltage Schedule in GOI-6 requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1 ) hour. 3) Operation of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator. Also, refer to Section E of GOI 6 for MVAR limits. 4) Confirmation from Chemistry Section SHALL be obtained prior to exceeding 30% reactor power. [1] [2] ENSURE Section 4.0, Prerequisites complete. VERIFY from Chemistry Section that SG and feedwater secondary chemistry is within acceptable limits. o Chemistry personnel contacted [3] IF this is a startup following refueling, THEN ENSURE applicable portions of 0-RT-NUC-000-001.0 are COMPLETE for operation above 35% power. Rx Engr.
( SON NORMAL POWER OPERATION O-GO*S Unit 1 & 2 Rev. 0047 Paae 18 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) NOTES Date _ 1) This step may be performed out of sequence as necessary to meet power level. 2) O-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [4] PERFORM the following at approximately 35% reactor power: [4.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = % 34.55 D [4.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Average value of RCS 6.T (U0485)= - - _ % [4.3] VERIFY all NIS Power Range channel drawers are within +/- 2% of the calculated reactor power: N-41 N-42 N-43 N-44 (XI-92-5005B) (XI-92-5006B) (XI-92*5007B) (XI-92-5008B) YES D YES D YES D YES D NO D NO D NO D NO D [4.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 19 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) Date _ NOTES 1) With reactor enginee ring concurrence, power increase per steps 5.1 [6] through 5.1[9] may be performed in parallel with this step. 2) if startup is following refueling operations and secondary side chemistry is acceptable for power increase, then N/A Step 5.1[5]. (Startup Reactivity Calibrations and Tests will be performed at" 45% Reactor Power if not performed at " 30% Power). [5] IF startup is following refueling activities and secondary chemistry hold is precluding power ascension , THEN ENSURE the following have been performed prior to exceeding 50% rated thermal power: (May be performed in any order) ( [5.1] 0-SI-NUC-000-126.0, Hot Channel Factor Determination. ( Rx Eng [5.2] 0-SI-NUC-092-079.0, Incore-Excore Axial imbalance Comparison. Rx Eng [5.3] 0-PI-NUC-0 92-002.0, Detector Single Point Alignment. Rx Eng Date Date Date
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pane 20 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) [5.4J 0-PI-IXX-092-N45.0, PR NIS Calibration. [5.5] PR High Flux Trip reset to 109%. [C.3]. [5.6] Applicable portions of 0-RT-NUC-000-0010 COMPLETE for operation above 50% power. MIG MIG Date _ Date Date Rx Eng Date [6J DETERMINE the following from TI-40 AND RECORD in narrative log AND below: [6.1J [6.2J Reactor preconditioned power level. _ Ramp rate restrictions. _ o o NOTE N/A Substep 5.1[6.3] and 5.1[6.4] if not initial startup after refueling outage. [6.3] [6.4] Intermediate power threshold _ Ramp Rate above the intermediate power threshold. o o [7J MONITOR TI-40 limits (using ICS trend features if available). o
( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pane 21 of 93 STARTUP No. _ Unit __ Date _ ( ( 5.1 Power Ascension From 30% to 100% (continued) NOTE Raising load on the Main Generator will cause VARs to trend in the negative direction (toward incoming). This will require raising generator voltage. Refer to GOI-6 Section E for MVAR limits for generator stability. Refer to precautions Q , R, and S. [8] PERFORM the following as required: [8.1] IF Automatic Voltage Control is in service, THEN ADJUST Main Generator VARs USING [HS-57-221 Exciter Voltage Auto Adjuster as necessary during power escalation. [8.21 - IF Automatic Voltage Control is NOT in service, THEN ADJUST Main Generator VARs USING [HS*57 -231 Exciter Voltage Base Adjuster as necessary during power escalation. NOTES 1) Steps 5.1[9] through 5.1 [15] may be performed concurrently or out of sequence. 2) Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). 3) Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). 4) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance. [9] INITIATE power increase to between 45 and 49% and MAINTAIN valve position limit approximately 10% above current governor control indication as turbine load is changed. 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 22 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band. [10] IF diluting the RCS to increase TAVG. THEN CONTINUE dilution and increase turbine load to maintain TREF with TAVG.(0-SO-62-7) 0 [11] PERFORM the following during power increase: NOTE TAVGwill be programmed from 547°F at no load to 578.2°F at 100% load at a rate of 0.312°F per % power. [11.1] MONITOR TAVG following TREF on program. [11.2] MONITOR pressurizer level on program (25 to 60% as a function of TAVG). o o NOTE If LEFM is available, computer point U2118 should be used as true reactor power. If LEFM is NOT available , use U1118 when greater than or equal to 40% and the average value of RCS to.T when less than 40%. [11.3] MONITOR all RPls, group step counters for rod insertion limits and inoperable rods or rod misalignment, Loop to.T, and NIS for correct power distribution and quadrant power tilts. 0 NOTE Generator MVARs may be reduced if the Generator Stator Ground Fault Relay indication approaches the alarm value of 50%. Automatic trip function is disabled by TACF 1-03-029-057 for Unit 1 and TACF 2-05-012-057 for Unit 2. Refer to GOI-6 Section E for MVAR limits for generator stability. ( [11.4] MONITOR generator conditions in accordance with 0-50-35-4, Monitoring Generator Parameters. [C.6] o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pace 23 of 93 STARTUP No, _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE The turbine load increase should be stopped until the main feedwater reg valves are operating in the acceptable band, [11 .5] ENSURE main feedwater reg valves are operating properly in auto (within +/- 5% from zero deviation is acceptable). [1 1.6] IF main feedwater reg. valves are NOT maintaining within the 5% band, THEN NOTIFY Instrument Maintenance. CAUTION The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated. o o NOTE Instrument Maintenance support may be required if controller adjustments are needed. [11.7] ENSURE Feedwater Heaters 5 and 6, MSR Drain Tank, and #7 Heater Drain Tank level controllers are adjusted to maintain levels within normal ranges. 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 24 of 93 STARTUP No, _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) [12] WHEN reactor power is approximately 35%, THEN VERIFY annunciator XA-55-4A, window C-5: P-B LOW POWER LOW FLOW TRIP BLOCK is DARK. o [13] IF unit is returning to service after a power reduction and the MSRs were removed from service, THEN PLACE MSR HP steam warming valves to OPEN position: MSR - HANDSWITCH WARMING VALVE INITIALS A1 HS-1-142 FCV-1-142 1st CV 81 HS-1-144 FCV-1-144 1st CV C1 HS-1-146 FCV-1-146 1st CV A2 HS-1 -136 FCV-1-136 1st CV 82 HS-1-138 FCV-1-1 38 1st CV C2 HS-1-140 FCV-1-140 tst CV [14] ENSURE #3 and #7 heater drain tanks on recirc in accordance with 1,2-S0-5-2 and 1,2-S0 -5-3. 0 ( [1 5] ENSURE the remaining available pumps are aligned and ready for service in accordance with 1,2-S0 -2/3-1: [1 5.1] Condensate booster pumps. [15.2] Hotwell pump. o o
( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 25 of 93 STARTUP No.. _ Unit __ Date _ ( ( 5.1 Power Ascension From 30% to 100% (continued) NOTES 1) Whe n placing additional condensate pumps inservice, or HDT pumps in service, ensure that the main reg valves respond correctly and then stabilize in the acceptable band. 2) The following step may be performed out of sequence and may be marked N/A if it was previously performed in 0-GO-4. [16) WHEN the condensate booster pump reaches approximately 140 amps, THEN START the following pumps in accordance with 1,2-S0-2/3-1: [1 6.1r Third HW pump (if available). [16.2) Second car.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 26 of 93 5.1 STARTUP No. Unit __ Powe r Ascension From 30% to 100% (con tinued) Date _ ( CAUTION Valves 106A and 1068 shall be verified to be controlling properly after each #3 HOT pump start. NOTES 1) When placing additional condensate pumps or HOT pumps in service, ensure that the main reg valves respond correctly and then stabilize in the acceptable band. 2) With verbal approval from the Operations Superintendent, pumping forward of the #3 and #7 Heater Drain System may be deferred until turbine load is approximately 60%, if system conditions warrant. 3) Steps 5.1[171 through 5.1 [22] may be performed out of sequence. [17] DETERMINE if#3 and #7 heater drain tank pumps can be aligned to pump forward: [17.1] WHEN confirmation obtained from Chemistry Section that #3 heater drain tank chemistry is within limits, THEN START pumping forward using two (2) #3 heater drain tank pumps using 1,2-S0-5-2. [17.2] WHEN confirmation obtained from Chemistry Section that #7 heater drain tank chemistry is in limits, THEN START pumping forward using the #7 heater drain tank pumps using 1,2-S0-5-3. [18] IF turbine load increase continues without the #3 heater drain tank pumps pumping forward, THEN [1 8.1] MAINTAIN Condensate Booster Pump suction pressure greater than or equal to 75 psig (PI-2-77). 0 ( [18.2] MAINTAIN Main Feedwater Pump suction pressure greater than 330 psig (PI-2-129). o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 27 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) CAUTIONS Date _ ( 1) MSR heatup limits are restricted to 100°F per hour or 25°F in a 15-minute period (automatic mode) or 50°F in a 30*minute period (manual mode). (SECO limits, contract 85P62-836839) 2) On the LP turbine in let, do NOT exceed an instantaneous change of 50°F or a rate of change of 125°F/Hr for turbine expansion considerations. 3) For a cold start, the HP bundle warming valves should be opened at least 15 minutes before bringing the MSR in service. NOTE Placing MSRs in service before 35% turbine load can cause turbine rotor long condition. [19] WHEN ~ 35% turbine load, THEN [19.1] IF cold start (LP turbine inlet metal temperature less than 300°F), THEN ( DEPRESS the RESET pushbutton on the moisture separator reheater control panel. [19.2] CLOSE the following steam inlet leakoff isolation valves: MSR VALVE POSITIO N INITIALS 1-679 CLOSED A-1 1-714 CLOSED 1-680 CLOSED B-1 1-715 CLOSED 1-681 CLOSED C-1 1-716 CLOSED 1-682 CLOSED A-2 1-717 CLOSED 1-683 CLOSED B-2 1-718 CLOSED 1-684 CLOSED C-2 1-719 CLOSED o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 28 of 93 STARTUP No. _ Unit __ Date _ ( ( 5.1 Power Ascension From 30% to 100% (continued) NOTE Due to required interlocks on MSR valves the following valves listed in the table should be performed in sequential order. For example: Open FCV-1-241 and when full open, then open FCV-1-141. [19.3] ENSURE MSR HP steam supplies ALIGNED as follows: MSR EQUIPMENT HANDSWITCH POSITION -.j MSR BYPASS ISOL HS-1-241A OPEN 0 A1 MSR MAIN ISOL HS-1-141A OPEN 0 MSR BYPASS ISOL HS-1-243A OPEN 0 B1 - MSR MAIN ISOL HS-1 -143A OPEN 0 MSR BYPASS ISOL HS-1-245A OPEN 0 C1 MSR MAIN ISOL HS-1-145A OPEN 0 MSR BYPASS ISOL HS-1-235A OPEN 0 A2 MSR MAIN ISOL HS-1-135A OPEN 0 MSR BYPASS ISOL HS-1-237A OPEN 0 B2 MSR MAIN ISOL HS-1-137A OPEN 0 MSR BYPASS ISOL HS-1-239A OPEN 0 C2 MSR MAIN ISOL HS-1-139A OPEN 0 NOTES 1) Control valves ramp open for 120 minutes for turbine cold start. 2) MSR Control valves ramp open from the 400°F position to full open in one hour when Hot Start button was previously depressed during performance of 0-GO-4 or 0-GO-11. [19.4] DEPRESS the RAMP pushbutton on the moisture separator reheater control panel to initiate steam flow to the reheater. 0 (step continued on next page)
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 29 of 93 ( 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) [19.5] IF MSR controls will NOT function in RAMP mode,
- THEN
PERFORM the following: A. DEPRESS MANUAL pushbutton on MSR control panel. 8. ADJUST manual potentiometer to gradually open MSR TCVs over approx. 120 minutes WHILE continuing in this procedure. [19.6] OPEN all MSR OPERATING vents (6-3 thru 6-93) on panel XS-6-3. [19.7L CLOSE all MSR STARTUP vents (6-1 thru 6-91) on panel XS-6-1. [1 9.8] PERFORM Appendix C to locally isolate MSR startup vents. Date _ ( [19.9] ENSURE MSR HP steam warming valves are CLOSED: MSR EQUIPMENT HANDSWITCH POSITION " A1 MSR WARMING LINE HS-1-142 CLOSED 0 81 MSR WARMING LINE HS-1 -144 CLOSED 0 C1 MSR WARMING LINE HS-1 -146 CLOSED 0 A2 MSR WARMING LINE HS-1-136 CLOSED 0 82 MSR WARMING LINE HS-1-138 CLOSED 0 C2 MSR WARMING LINE HS-1-140 CLOSED 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 30 of 93 STARTUP No. _ Unit __ Oate _ 5.1 Power Ascension From 30% to 100% (continued) [19.10) IF this power ascension is during the months of October ."1 through March 31, THEN REFER to 0-PI-OPS-000-006.0 and consult System Engineer for position of MSR doghouses' vent dampers. [19.11] IF this power ascension is during the months of April 1 through September 30, THEN OPEN MSR doghouses' vent dampers . [20) IF pumping forward with #3 HOT, THEN ENSURE 1,2-LCV-6-106A and B are maintaining #3 heater drain tank level. NOTE Benchboard instruments PI-5-87A for #7 heater and PI-5-84A for
- 6 heater may be used to determine heater shell side pressure.
[21] IF #7 heater drain tank (HDT) pressure is indicating an overpressure condition, THEN PERFORM 1,2-S0-5-3, Section 8.0, Infrequent Operation to prevent #7 HDT overpressurization. o
( SON NORMAL POWER OPERATION 0*GO*5 Unit 1 & 2 Rev. 0047 Page 31 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) [22] WHEN approximately 40% turbine load: [22.1] VERIFY annunciator XA-55-4A, window E-?: C*20 AMSAC ARMED is LIT. [22.2] CLOSE the drains on the operating main feedwater pump turbine (N/A other pump). Date _ o ( MFPT DESCRIPTION HANDSWITCH POSITION INITIALS A DRAIN VALVES HS-46-14 CLOSED B DRAIN VALVES HS-46-41 CLOSED
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 32 of 93 STARTUP No, _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE With verbal approval from the Operations Superintendent, placing the second main feed pump in service may be deferred until power is approximately 55% (Unit 1) or 65% (Unit 2). Logic prevents opening the standby MFPT condenser isolation valves if the pump is NOT reset prior to exceeding 9 million Ibs/hr flow on the running pump. [23] WHEN approximately 40 to 45% turbine load, THEN PLACE second MFPT in service by performing the following: [23.1] IF the Operations Superintendent has approved one MFP operation during the power ascension, THEN - A. 1.RECORD which MFPT is in service. ___ MFPT B. MONITOR loading of the MFP in service as load is increased. 0 [23.2] WHEN second MFPT is to be placed in service, THEN ( PLACE second MFPT in service in accordance with 1,2-S0 -2/3-1, o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 33 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) NOTE Date _ (, This step and individual substeps may be performed out of sequence. [24) PERFORM the following as system parameters permit: [24.1) VERIFY three (3) Hotwell pumps running (if available). D [24.2) VERIFY two (2) Condensate booster pumps running. D [24.3) VERIFY MFW pump(s) in service (only 1 required if approved by Operations Superintendent). D [24.4]- VERIFY two (2) #3 heater drain tank pumps running. D [24.5) VERIFY one (1 ) #7 Heater Drain Tank pump in service. D [24.6] ENSURE one gland steam exhauster running and one stopped in AUTO position: EXHAUSTER HANDSWITCH ("") ("") A HS-47-209A AUTO 0 START 0 B HS-47-209B AUTO 0 START 0 [24.7) IF gland seal water is being supplied from opposite unit, THEN RESTORE normal gland seal water alignment (supplied from this unit) in accordance with 1,2-S0 -37-1, Gland Seal Water System. 0
( SQN NORMAL POWER OPERAliON 0-GO-5 Unit 1 & 2 Rev. 0047 Page 34 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) Date _ NOTE Steps 5.1[25] through 5.1[30] may be performed out of sequence. [25] IF the second #7 heater drain tank pump has not been started, THEN START the second #7 heater drain tank pump in accordance with 1,2-S0-5-3. NOTE Hydrogen pressure should be maintained greater than or equal to 66 psig. [26J ENSURE generator hydrogen pressure is sufficient for anticipated load in accordance with TI-28, Figure A.14, Generator Capability Curve. [27] VERIFY river water temperature within the limitations of the NPDES permit as specified in 0-PI-OPS-000-666.0. CAUTION o After refueling operations, the NIS indications may be inaccurate until calibration at higher power levels. DO NOT increase power greater than 50% until Reactor Engineering has ensured that applicable portions of O-RT-NUC-000-001.0 are complete. [28] IF applicable portions of 0-RT-NUC-000-001 .0 are complete for power increase above 50% of rated thermal power, THEN N/A the following Step 5.1 [29]. (Reactor Engineering)
( saN NORMAL POWER OPERATION 0*GO-5 Unit 1 & 2 Rev. 0047 Page 35 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) [29] IF startup is following refueling activities, THEN ENSURE the following have been performed prior to exceeding 50% rated thermal power: (may be performed in any order) A. 0-SI-NUC-000-1 26.0, Hot Channel Factor Determination. Rx Eng Date B. 0-SI-NUC-092-07 9.0, Incore-Excore Axial Imbalance Comparison. Rx Eng Date C. 0-PI-NUC-092-002.0, Detector Single Point Alignment. Rx Eng Date D. 0-PI-IXX-092-N45.0, PR NIS Calibration.. MIG Date E. PR High Flux Trip reset to 109%. [C.3]. MIG Date F. Applicable portions of 0-RT-NUC-000-001.0 COMPLETE for operation above 50% power. Rx Eng Date [30] WHEN reactor power is approximately 49%, THEN PERFORM the following: (in any order). r [30.1] ENSURE indicated Axial Flux Difference is within the '- limits specified in the COLR (TS 3.2.1.1).
( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 36 of 93 STARTUP No. _ Unit __ Date _ 5.1 Powe r Ascension From 30% to 100% (continued) [30.2] PERFORM a conditional 0-SI-NUC-000-044.0, Axial .. Flux Difference. NOTE QPTR alarms pertain to the plant computer and annunciator panel AR-M4-B, windows B-3, C-3, and 0 -4. Alarms may sporadically occur at 1.5% when the setpoint is 2%. [30.3J PERFORM a conditional 0-SI-NUC-000-133.0, Quadrant Power Tilt Ratio. [30.4] IF QPTR exceeds 1.015, THEN CONTACT Reactor Engineering for evaluation. NOTE Ramp load rate increases shall be within the limits stated in TI-40. ( [31 ] RECORD the following fromTI-40: [31 .1 ] Power ascension ramp rate from T1-40. _ NOTE NIA substep 5.1 [31.21and 5.1[31.3] if NOT initial startup after refueling outage. [31.2] Intermediate power threshold setpoint. _ [31 .3] Ramp Rate above the intermediate power threshold. o o o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 37 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) [32] CONTINUE reactor power ascension to 74%. NOTE Date _ o Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band. [33] IF diluting the RCS to increase T AVG. THEN CONTINUE dilution and increase turbine load to maintain TREF with T AVG. (0-SO-62-7) 0 NOTE Valve position Iirnit and governor control meter are displayed on EHC Display paneI 1,2-XX-047-2000 (M-2). [34] MONITOR the turbine load increasing and MAINTAIN valve position limit approximately 10% above current governor control indication as turbine load is changed. 0 NOTE Steps 5.1 [35] through 5.1 [37] may be performed out of sequence. [35] WHEN greater than or equal to 50% reactor power, THEN [35.1] VERIFY annunciator XA-55-4A, window E-4: ( P-9 LOW POWER TURB TRIP-REAC TRIP BLOCK is DARK. o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 38 of 93 is DARK. is DARK. 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) [35.2) . VERIFY annunciator XA-55-4B, window B-3: NIS POWER RANGE UPPER DETECTOR HI FLUX DEVN OR AUTO DEFEAT [35.3] VERIFY annunciator XA-55-4B, window C-3: NIS POWER RANGE LOWER DETECTOR HI FLUX DEVN OR AUTO DEFEAT [35.4] VERIFY annunciator XA-55-4B, window D-4: Date _ o o COMPUTER ALARM ROD DEV & SEQ NIS PWR RANGE TILTS is DARK. o ( [36] ENSURE MFPTC vacuum normal (greater than 20 inches HG vacuum) using PI-2-331A and PI-2-331B on Panel L-69. 0 NOTE During power operation above 50%, condenser air inleakage should be maintained less than 6 CFM. [37] IF condenser air inleakage exceeds 10 CFM, THEN INITIATE actions to identify the source of inleakage and NOTIFY Engineering and the Operations Superintendent or Plant Manager.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 39 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTES 1) Steps 5.1[38] through 5.1[41] may be performed out of sequence. 2) O-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [38] PERFORM the following at approximately 55% reactor power: [38.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 34.55 = % --- o [38.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U1118 34.55 = % --- o [38.3] VERIFY that all operable NIS Power Range channel drawers are within +/- 2% of the calculated calorimetric power. N-41 N-42 N-43 N-44 (XI-92-5005B) (XI-92-5006B) (XI-92-5007B) (XI-92-5008B) YESD YESO YES 0 YES 0 NO D NOD NOO NOD ( [38.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 40 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) NOTES Date _ ( 1) More restrictive turbine load limit for Unit 1 is based on ensuring adequate MFP suction pressure to allow pumping against higher S /G pressures following S/G replacement. (Ref: DCN E21203A). 2) Siemens Westinghouse analysis has determined that the maximum Unit Two unit power with 1 MFP operation is 65% under worst case conditions. Operation at higher power levels are dependent on current conditions. This would require System Engineering evaluation.(Ref: DCN D21732A). [39] ENSURE second MFPT is in service PRIOR TO increasing turbine load above 55% (Unit 1) or 65% (Unit 2). [40] EN_SURE at least one bus duct cooler is in service USING 0-SO-58-1 PRIOR TO increasing load above 729 MWe. CAUTION
- 3 and #7 heater drains must be pumping forward prior to exceeding 60% turbine
load. This load limit assumes that both MFW pumps are in service. If only one MFWP is running, turbine load must be further limited to maintain adequate MFWP suction pressure. [41] ENSURE both #3 and #7 heater drain tank systems are pumping forward PRIOR TO increasing turbine load above 60%.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pane 41 of 93 STARTUP No. _ Unit __ Oate _ 5.1 Power Ascension From 30% to 100% (continued) CAUTIONS 1) Valves 106A and 106B shall be verified to be operating properly after each #3 HOT pump start. 2) At approxima tely 79% turbine load with LCV-6-105A or B open and only two #3 HOT pumps are in service, the required NPSH for the MFP will be insufficient. NOTES 1) When placing HDT pumps in service. ensure main feedwater pumps and main reg valves respond correctly and then stabilize in an acceptable band. 2) LCV-6-105A will come open at about 70% turbine load if condensate discharge pressure is high. Minimize duration at this load to reduce wear on the valve. As load is increasedlo 100% condensate pressure will gradually decrease allowing the #3 HDT pumps to pump forward and the condenser bypass valve(s) to close. ( 3) Steps 5.1[42] through 5.1 [45] may be performed in any order. [42] WHEN approximately 70% turbine load, THEN [42.1] PLACE the third #3 heater drain pump in service in accordance with 1,2-S0-5-2. [C.2] [42.2] ENSURE valves LCV-6-106A and LCV-6-106B are controlling #3 heater drain tank level properly. (
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 42 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) CAUTION Date _ Evaluate starting and stopping of Condensate Demineralizer pumps using condensate pressure, MFP inlet pressure, condensate booster pump inlet pressure, and #3 and #7 HDT pump and bypass valve operation. The USISRO may start or stop Condensate Demineralizer pumps at his discretion, but if any of the following occurs the pumps must be started: 1) Condensate Booster Pump suction pressure is less than 125 psig, as indicated on [PI-2-771. 2) Main Feedwater Pump suction pressure less than 420 psig, as indicated on [PI-2-1291. 3) Injection Water Pump discharge pressure is less than 265 psig, as indicated by an alarm on_XA-55-3B window E-1. NOTES 1) Should #7 heater drain tank pump(s) amps swing or if system pressure needs to be increased by approximately 40 psig, then Cond DI Booster pumps can be started; however, two of the three pumps must be started at the same time. 2) When placing condensate pumps in service, ensure main reg valves respond correctly and then stabilize in an acceptable band. [43] EVALUATE starting two condensate demineralizer booster pumps in accordance with 1,2-S0-2/3-1 (This step can be N/A'd or signed-off at time when pumps are started). NOTE If starting up following refueling operations and reactivity calculations and tests were completed at ", 30% reactor power, then reactivity calculations and tests must be performed again at ", 75% RTP. ( [44] IF all applicable portions of 0-RT-NUC-000-001.0 are complete for power increase above 75% of rated thermal power, THEN NIA the following Step 5.1 [45]. (Reactor Engineering)
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 43 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) CAUTION Date _ After refueling, NIS indications may be inaccurate until calibration at higher power levels. DO NOT increase power above 75% until applicable portions of O-RT-NUC-000-001.0 are complete. [45] IF startup is following refueling , THEN PERFORM the following prior to operation above 75% power: (may be performed in any order) [45.1] ENSURE the following have been performed (may be N/A'd by Reactor Eng. and Instrument Main!. if NOT required): A. O-SI-NUC-OOO-126.0, Hot Channel Factor Determination. Rx Eng B. O-SI-NUC-092-079.0, lncore-Excore Axial Imbalance Comparison. Rx Eng Date Date
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 44 of 93 STARTUP No. _ Unit __ Date _ ( 5.1 Power Ascension From 30% to 100% (continued) C. O-PI-NUC-092-036.0. Incore/Excore Detector Calibration (N/A if NOT required or if t.\\AFD < 3%). Rx Eng Date D. O-PI-NUC-092-002.0, Detector Single Point Alignment. Rx Eng Date E. O-PI-IXX-092-N45.0, PR NIS Calibration. Rx Eng Date [45.2] NOTIFY Systems Eng to perform O-PI-SXX-OOO-022.2 to check RCS Loop ~T Zeros. [C.7] 0 [45.3] ENSURE applicable portions of O-RT-NUC-OOO-001.0 are complete for operation above 75% RTP. Rx Engr.
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 45 of 93 5.1 STARTUP No. . Unit__ Power Ascension From 30% to 100% (continued) Date--- NOTES 1) O-SI-OPS-092-078 .0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. 2) Steps 5.1[46] and 5.1[47] may be performed out of sequence. [46] PERFORM the following at approximately 75% reactor power: [46.1] IF LEFM indication is available , THEN CALCULATE Calorimetric power: Calorimetric power= U2118 34.55 = % --- D [46.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calo rimetric power= U1118 34.55 = % --- D [46.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 N-42 N-43 N-44 (XI-92-5005B) (XI-92-5006B) (XI-92-5007B) (XI-92-5008B) YES D YES D YESD YES 0 NOD NOD NOD NOD [46.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 46 of 93 STARTUP No. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) CAUTIONS 1) LCV-6-105A and/or 1058 may be th rottling open due to condensate system pressure being higher than #3 HOT pump discharge pressure. 2) Turbine runback will occur if #3 HOT pump flow to the condensate system drops below 5500 gpm (for greater than 10 seconds), condensate bypass valve LCV-6*105A or 1058 opens, and turbine load is above 81 % (Unit 1) or 82% (Unit 2). [47] PRIOR to increasing turbine load above 77%: ENSURE the following: [47.1] _ LCV-6-106A and -1068 are controlling properly. [47.2] LCV-6-105A and -1058 are CLOSED. NOTE Ramp load rate increases shall be within the limits of TI-40. [48] RECORD power ascension ramp rate from TI-40. _ NOTES o 1) Operation above 75% Load with only two Hotwell Pumps in service requires further evaluation. 2) Steps 5.1[49] through 5.1[52] may be performed out of sequence. [49] CONTINUE the power ascension to 90% reactor power. o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 47 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Control rods may be used along with dilution during reactor power increase to maintain AFO within the target control band. [50) IF diluting the RCS to increase TAVG, THEN CONTINUE dilution and increase turbine load to maintain TREF with TAVG. (0-SO-62-7) D NOTE Guidance on restoration of EHC Controls after a BOP runback via the valve position limiter is contained in Appendix B, Turbine Runback Restoration. [CA) [51] MONITOR the turbine load increasing and MAINTAIN valve position limit approximately 10% above the current governor control indication as turbine load is changed. D NOTE When the turbine impulse pressure relay number is illuminated on Panel L-262, the relay is closed and Runback circuit is armed. [52] WHEN greater than 77% Turbine Load, THEN VERIFY [PIS-47-13RLY11 light W ,'Turbine Runback From Loss of 1 MFP' is illuminated on Panel L-262. [53] WHEN greater than 82% Turbine Load, THEN ( VERIFY the following relay lights are illuminated on Panel L*262: [53.1] [PIS-47*13RLY2)l Turbine Runback From #3HOT.[2) [53.2] [PIS-47*13RLY 3)1 NPSH Protection VLV-6-106B closes on #3 HOT pump trip. QJ D D
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 48 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTES 1) Reactor power can be increased greater than 90% as long as adequate MFP suction is maintained. 2) Steps 5.1[54] through 5.1[58] may be performed out of sequence. [54] WHEN approximately 85 to 90% reactor power OR when determined by Unit SRO (if power raised above 90%), THEN ENSURE third condensate booster pump in service in accordance with 1,2-80-2/3-1. [C.2] NOTE A nominal CBP suction pressure of approximately 180 psig, as indicated on [PI-2-77], will alleviate bypassing to the condenser at full power. [55] IF condensate pressure is high resulting in #3 or #7 heater drain tank bypassing to the condenser. OR the normal level control valves are near full open, THEN [55.1 ] THROTILE [14-550] to attain desired condensate pressure. [55.2] IF unable to throttle [14-550] , THEN REFER to 1,2-S0 -5-2, Section 8.0 to adjust condensate pressure. OR [55.3] EVALUATE removal of the condensate demineralizer booster pumps (N/A if NOT in service). o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 49 of 93 STARTUP No. _ Unit __ Date _ ( 5.1 Power Ascension From 30% to 100% (continued) NOTE Two Cond 01 Booster pumps must be started at the same time. [56] EVALUATE starting available condensate demineralizer booster pump(s) to raise system pressure - 40 psig. Pump Started YES 0 NO 0 [57] WHEN reactor power is approximately 90%, THEN PERFORM the following: [57.1] - ADJUST Power Range instrumentation in accordance with 0-SI-OPS-092-078.0. [57.2] INITIATE performance of 1-PI-OPS-000-020.1 or 2-PI-OPS-000-022.1, Appendix B. CAUTION The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated. [57.3] ENSURE the following level controllers are maintaining levels within normal ranges: A. Secondary plant heaters. B. MSR drain tanks. CAUTION DO NOT exceed an average of 3455.0 MWT during an a-hour period. rC.11 [58J MONITOR NIS, dT and calorimetries on plant computer (pt. U2118) while increasing reactor power. o o o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 50 of 93 STARTUP No. _ Unit __ Date _ ,. 5.1 Power Ascension From 30% to 100% (continued) NOTES 1) Feedwater venturi unfouling may impact U1118 indication. LEFM calorimetric power (U2118) is not affected by venturi unfouling. 2) If U1118 is being used to monitor reactor power due to LEFM unavailable, then Calorimetric Calculation should be performed prior to exceeding 97% reactor power. 3) Steps 5.1[59] through 5.1[63] may be performed out of sequence. [59] IF Unit is returning to full power after a turbine load reduction to less than 50% AND U1118 is being used to monitor power, THEN PERFORM the following prior to exceeding 97% power: [59.1] NOTIFY Systems Engineering to perform O-PI-SXX-000-022.2, Calorimetric Calculation, Section 8.1 , if necessary. 0 [59.2] PERFORM applicable sections of 0-PI-SXX-OOO-022.2 to adjust Feedwater Flow Constant. (N/A if NOT required) BOP Eng
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 51 of 93 STARTUP No. _ Unit-- Date--- 5.1 Power Ascension From 30% to 100% (continued) NOTE Ramp load rate increases shall be within the limits of TI-40. [60] RECORD the following fromTI-40: [60.1] Power ascension ramp rate from TI-40. _ NOTE N/A substep 5.1[60.2] and 5.1 [60.3] if not initial startup after refueling outage. [60.2] Intermediate power threshold setpoint'--__ [60.3] Ramp Rate above the intermediate power threshold.- -- [61] CONTINUE power ascension to 100% RTP. NOTE o o o o Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band. [62] IF diluting the RCS to increase TAVG, THEN CONTINUE dilution and increase turbine load to maintain TREF with T AVG. (0-SO-62-7) 0 NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). [63] MONITOR the turbine load increasing AND MAINTAIN valve position limit approximately 10% above the current governor control indication as turbine load is changed. 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 52 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Asc ension From 30% to 100% (continued) NOTE Steps 5.1[64] through 5.1 [66] may be performed out of sequence. [64] WHEN reactor power approaches 100%, THEN ADJUST governor valve position limiter - 2% above governor valve position. 0 CAUTION Governor valve position limit meter may NOT match the governor valve position meter; therefore, mon itor the megawatt meter and valve pos ition limit light con tinuously during the following step. NOTES 1) Operation with the VALVE POS LIMIT light LIT is acceptable if unsatisfactory load swings are experienced. 2) Actions effecting reactivity are directed in the following step. All appropriate verifications and peer checks shall be utilized during performance. [65] IF unsatisfactory load swings are experienced as the unit approaches full power, THEN [65.1] WITH turbine load set for maximum of 100% power, SLOWLY and CAUTIOUSLY PULSE the governor VALVE POSITION LIMIT in LOWER direction while monitoring megawatts for a decrease and VALVE POS LIMIT light to ILLUMINATE. 0 [65.2] WHEN the limiter just reaches the governor valve position, THEN STOP limiter adjustment. o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 53 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) CAUTION Do not raise the limiter position unless the turbine control is positively controlling the turbine (limit light NOT LIT). NOTE Actions effecting reactivity are directed in the following step. All appropriate verifications and peer checks shall be utilized during performance. [66] PERFORM the following if the limiter prevents reactor operation at approximately 100%: [66.1] ADJUST SETTER/REFERENCE controls to reduce - turbine loading until the VALVE POS LIMIT light is NOT LIT. 0 [66.2] INCREASE VALVE POSITION LIMIT to allow a load increase using the SETTER/REFERENCE controls, NOT to exceed 3455.00 MWT. 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 54 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) Date _ NOTES 1) Full power operation is defined as 100% power operation at approximately 3455 MWT instantaneous value, U2118 not to exceed 3455.00 MWT average thermal power in an 8-hour period. [C.1] 2) Do not intentionally operate the reactor at greater than 100% power (e.g., if reactor power is less than 100% for any time period then operation at slightly greater than 100% to "make up" for "lost" power is not permissible). [C.1] 3) Computer point U2118 should be trended on a trend recorder in the unit horseshoe and monitored for increasing reactor power trends above 3455 MWT. Prompt action shall be taken to decrease reactor power whenever an increasing power trend is observed. [C.1] 4) Do not exceed an 8-hour average value (U2126) of 3455.00 MWT. Do not allow U2125 (one hour avg) to exceed 3455.00 MWT (100%) for more than one hour. [C.1] 5) Portions of step 5.1[681 may be performed in paralle l with step5.1 [67] if required. [67] WHEN the unit stabilizes at 100% reactor power, THEN PERFORM the following: (may be performed in any order) [67.1] ADJUST Governor Valve position, rod height, and/or RCS boron concentration as necessary to establish core thermal power at desired value and Auctionee red Hi T-avg approximately equal to T-ret. 0 [67.2] NOTIFY load coordinator that the power increase is complete . 0 [67.3J NOTIFY RADCON that power has stabilized at 100%. 0 (step continued on next page)
(, SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 55 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Use of seal steam spillover bypass FCV-47-191 should be minimized to reduce the effect of unit trip on seal steam pressure. [67.4] IF Seal Steam spillover bypass [FCV-47-1911 is IN SERVICE, THEN THROTTLE Seal Steam spillover bypass to control [FCV-47-1911 as required to control seal steam pressure. [67.5] IF river temperature is less than 45°F, THEN D CONSULT Engineering to determine if third CCW pump should be removed from service. D [67.6] CONTACT vibration engineer in Predictive Maintenance Group to monitor MFWP vibration. 0 CAUTION A bias adjustment in the upward direction (> 50%) should NOT be used unless evaluated by Systems Engineering si nce this could impact a MFPT's maximum speed and the ability to fUlly load in the event the other MFPT trips. [67.7] IF feed pump vibration is above desired levels, THEN CONSULT with vibration engineer and system engineer to determine which feed pump to bias to reduce vibration. 0 [67.8] IF MFPT master controller output is NOT indicating 45% to 55% THEN CONSULT with MFPT controls system engineer to evaluate if adjustment is required per 1,2-S0-2/3-1. 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 56 of 93 STARTUP No. _ Unit __ Date _ 5.1 Power Ascension From 30% to 100% (continued) [68] IF startup is following refueling activities, THEN ENSURE the following are performed at approximately 100% Rated Thermal Power: (may be performed in any order) [68.1] 0-PI-SXX-000-022.2, Calorimetric Calculation. [68.2] 0-PI-SXX-000-022.1, Delta T and Tavg Update. [C.7] [68.3] 0-SI-NUC-000-126.0, Hot Channel Factor Determination. Systems Eng. Systems Eng.. Rx Eng Date [68.4]- 0-SI-NUC-000-120.0, Reactivity Balance Rx Eng Date [68.5] 0-SI-NUC-092-079.0, Incore-Excore Axial Imbalance Comparison. Rx Eng Date [68.6] 0-PI-NUC-092-036.0, Incore-Excore Detector Calibration. Rx Eng Date [68.7] 0-PI-IXX-092-N45.0, PR NIS Calibration (May be N/A'd if Engineering determines calibration performed at < 75% RTP is adequate.) Inst Maint [68.8] Applicable portions of 0-RT-NUC-000-001.0 are complete for full power operations. Rx Engr
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 57 of 93 5.1 STARTUP No. Unit __ Power Ascension From 30% to 100% (continued) NOTE Date _ c, This step may be performed out of sequence if required. [69] IF Steam Generator WR level recorders were re-scaled to 80% - 90% in 0-GO-2, THEN NOTIFY MIG to re-scale LR-3-43A and LR-3-98A, Steam Generator Wide Range Level Recorders, to 0% - 100%, [70] IF unit shutdown to minimum load, THEN GO TO Section 5,3. [71] IF-unit is to be maintained at normal power, THEN GO TO Section 5.2. END OF TEXT
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pace 58 of 93 STARTUP No. _ 5.2 At Power Conditions Unit __ Date _ ( CAUTIONS 1) Full powe r operation is defined as approximately 3455 MWT NOT to exceed 3455.0 MWT averaged ove r an a-hour period. [C.1) 2) Power should NOT exceed one hour average (U2125) of 3455.00 MWT for more th an one hour. 3) Power shall NOT exceed an a-hour average value (U2126) of 3455.00 MWT (readin gs at 0700,1500 and 2300 hours). NOTES 1) Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Quty Specialist (ODS) within twenty four (24) hours. 2) Main Generator operation outside of the Voltage Schedule in GOI-B requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1) hour. 3) Operation of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator. Also, refer to Section E of GOI B for MVAR limits. 4) Do not intentionally operate the reactor at greater than 100% power (e.g. if reactor power is less than 100% for any time period then operation at slightly greater than 100% to make UP for LOST power is not permissible). [C.1) 5) Steps in this section may be performed out of sequence. [1 ] ( TREND Computer point U2118 on a trend recorder in the unit horseshoe and monitor for increasing reactor power trends above 3455 MWT. [2] IF increasing power trend is observed , THEN ENSURE PROMPT action is taken to decrease reactor power as necessary. [C.1) 1st o CV
( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pace 59 of 93 STARTUP No. _ 5.2 At Power Conditions (continued) Unit __ Date _ CAUTION If LEFM is lost with reactor power at 100%, core thermal powe r should NOT be raised to take advantage of U-1118 reading lower. NOTE The following restrictions apply if LEFM calorimetric power indication (U2118) is unavailable: Applicable action of TRM 3.3.3.15 must be entered. AFD limits in COLR and TI-28 must be made more restrictive by 1%. Rod insertion limits in COLR must be raised by 3 steps. [3] IF ICS point U2118 is unreliable or unavailable, THEN PERFORM the following: [3.1] MONITOR thermal power by using one of the following: [3.2]
ICS point U1118 (if available)
highest reading NIS power range channel. [C.1] RESTORE calorimetric power indication prior to next required performance of O-SI-OPS-092-078.0, [3.3] IF LEFM CANNOT be restored prior to O-SI-OPS-092-078.0 being required, THEN ENSURE power is less than or equal to 98.7% (3411 MWr) prior to performing O-SI-OPS-092-078.0:
REDUCE turbine load as necessary.
MAINTAIN TAVG and AFD on program using boration and/or rod insertion as necessary. o o o o o
( SQN NORMAL POWER OPERATION O-GO*S Unit 1 & 2 Rev. 0047 Page 60 of 93 STARTUP No, _ 5.2 At Power Conditions (continued) Unit __ Date _ [3.4] [3.5] PERFORM O-SI-OPS-092-078,O using U-1118 or alternate method , MAINTAIN power less than or equal to 98.7% (3411 MWf) UNTIL LEFM is restored and O-SI-OPS-092-078,O is re-performed using LEFM data. o o ( [4] [5] [6] [7] MAINTAIN rod control system in automatic to allow proper plant response to load reductions and runbacks. DURING steady state operation ~ 85% RTP MAINTAIN control bank 0 greater than 215 steps if possible and AFD within the nominal +/- 5% target band and also within the AFD limits specified in the COLR. DURING steady state operation < 85% RTP MAINTAIN control bank 0 greater than 165 steps if possible and the axial flux difference (AFD) within the nominal +/- 5% target band and also within the AFD limits specified in the COLR. OPERATE the turbine in IMP OUT due to inherent system swings during operation in IMP IN. (Operation in IMP IN is permitted during governor valve testinq.) NOTE o o o o ( Valve position limiter should normally be maintained - 2% above governor valve position unless load swings occur. [8] IF unsatisfactory load swings are observed , THEN ADJUST governor valve position limiter as necessa ry to limit governor valve motion. 1st CV
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 61 of 93 STARTUP No. _ 5.2 At Power Conditions (continued) Unit __ Date _ CAUTION Do NOT raise the limiter position unless the turb ine control is positively co ntrolling the turbine (limit light NOT LIT). [9] IF governor valve motion limiting is no longer needed , THEN [9.1] ADJUST SETTER/REFERENCE controls to reduce turbine loading until the VALVE pas LIMIT light is NOT LIT. o [9.2] ( INCREASE VALVE pas LIMITER setpoint to - 2% above current load, ENSURIN G load does NOT change. [10] IF an axial xenon oscillation develops and requires suppression, THEN [10.1] MOVE control bank inward when AFD is moving positive above target AFD, OR [10.2] MOVE control bank outward when AFD is moving negative below target AFD, AND HOLD AFD at target until oscillation is suppressed. [10.3] IF this basic first overtone control is insufficient, THEN CONTACT Reactor Engineering for assistance. o o o
( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pane 62 of 93 STARTUP No. _ 5.2 At Power Conditions (continued) Unit __ Date _ NOTE Lowering load on the Main Generator will cause VARs to trend in the positive direction (toward outgoing ). This will require lowering generator voltage. Conversely, raising generator load will cause VARs to trend in the negative direction and will require raising generator voltage. Refer to GOI-6 Section E for MVAR limits for generator stability. Refer precautions Q . R. and S. [11) PERFORM the following as required: [11.1] IF Automatic Voltage Control is in service. THEN ADJUST Main Generator VARs USING [HS-57-22] Exciter Voltage Auto Adjuster as necessary during power escalation. [11.2) IF Automatic Voltage Control is NOT in service, THEN ADJUST Main Generator VARs USING [HS-57-231 Exciter Voltage Base Adjuster as necessary during power escalation. NOTE Deboration using a mixed bed demin is normally used when less than 50 ppm but may be used between 50-100 ppm if recommended by Chemistry or if required due to dilution capability NOT available. [12] PERFORM the following as necessary to maintain T-avg and thermal power at desired value: [12.1] ADJUST RCS boron concentration in accordance with 0-SO-62-? Boron Concentration Control 0 OR ( [12.2] ADJUST control rod position in accordance with 0-SO-85-1. Control Rod Drive System OR o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 63 of 93 STARTUP No. _ 5.2 At Power Conditions (con tinued) Unit __ Date _ [12.3] ADJUST turbine load slightly OR o ( [12.4] DEBORATE RCS periodically using a mixed bed demin in accordance with 1,2-S0 -62-9 (if RCS boron less than 100 ppm) 0 NOTE Appendix 0 provides recommended power values for maintaining condensate pressure if secondary plant equipment must be removed from service for maintenance. [13] IF unit shutdown or load reduction is required, THEN GO TO Section 5.3 of this instruction. [14] IF Load Follow is required, THEN PERFORM Section 5.5, Load Follow Operations. [15] IF at end of cycle and a power coastdown is required, THEN PERFORM Section 5.4, Power Coastdown At End Of Life. END OF TEXT
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev,0047 Page 64 of 93 5.3 STARTUP No. Unit I Power Reduction From 100% to 30% Date Tu4, NOTES 1) Th is section may be used to reduce power to -30% during plant shutdown OR a portion of this section may be performed to reduce power as required by plant conditions. Steps which are not required for partial load reduction may be marked N/A with SM concurrence as specified by SPP-2.2. 2) Appendix D provides guidan ce on recommended power values to maintain condensate pressure if secondary plant equipment must be remo ved from service for maintenance. 3) Steps 5.3[2J through 5.3[6] may be performed out of sequence. [1] ENSURE Section 4.0, Prerequisites complete. RIll' [2] REVIEW of Precautions and Limitations Section 3.0 has been completed. ~ [3] NOTIFY RADCON of impending load reduction. J!( [4) NOTIFY CON DI operators of load reduction and to remove [B'" beds as needed. [5] NOTIFY Load Dispatcher of impending load reduction. IQ'" NOTE Lowering load on the Main Generator will cause VARs to trend in the positive direction (toward outgoing). This will require lowering generator voltage. Refer to GOI-6 Section E for MVAR limits for generator stability. [6] PERFORM the following as required: [6.1] [6.2) IF Automatic Voltage Con trol is in service, THEN ADJUST Main Generator VARs USING [HS-57-221 Exciter Voltage Auto Adjuster as necessary during power escalation. IF Automatic Voltage Control is NOT in service , THEN ADJUST Main Generator VARs USING [HS-57-231 Exciter Voltage Base Adjuster as necessary during power escalation. !/fl
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 65 of 93 Power Reduction From 100"10 to 30"10 (continued) 5.3 STARTUP No, _ Unit I Date~ NOTES 1) Guidance on restoration of EHC Controls after a BOP runback is contained in Appendix B, Turbine Runback Restoration. [CAl 2) For core operating recommendations for situations such as end of core life coast down or unusual power maneuvers , contact Reactor Engineering for guidance . [C.5] 3) It is recommended that AFD be controlled within the target band. 4) The following general approach should be used during power reduction: (a) borate RCS to reduce RCS TAVG within limits of TREF. (b) reduce turbine load to match TREF with TAVG (c) periodically take rod control to MANUAL from AUTO and insert the bank to move AFD near the target value, (d) return rod control to AUTO when not using the bank to control AFD;' and (e) repeat the above as necessary to accomplish the load change. 5) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (Le. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance. ( [7] INITIATE a load reduction. o
( SQN NORMAL POWER OPERATION 0*GO-5 Unit 1 & 2 Rev. 0047 Paqe 66 of 93 STARTUP No. _ Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) [8] MONITOR turbine load decreasing. CAUTION o Do NOT exceed a load change rate of plus or minus 5%/minute or a step change of 10%. NOTE TAVG is programmed from 578.2°F at 100% power to 547°F at zero power at a rate of 0.312°F per % power. [9] MONITOR the following during the load reduction: [9,1] [9,2] [9.3] TAVG following TREF program, All RPls, group step counters for rod insertion limits and inoperable rods or rod misalignment, Loop "'T, and NIS for correct power distribution and quadrant power tilts. Core AFD within +/- 5% control band around the power level dependent target value. NOTE o o o [9.4] Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). Valve position limit approximately 10% above the current governor control indication as turbine load is changed. [1 0] IF AFD remains outside the AFD target band for approximately 30 min or more, THEN o CONTACT Reactor Engineering as to why and when the AFD might be returned to the target band. 0
(' SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 67 of 93 5.3 STARTUP No. Unit _ _ Powe r Reduction From 100% to 30% (con tinued) Date _ NOTES 1) 8hutdown of the condensate demineralizer booster pumps should be based on header pressure, the ability of the drain tank pumps to pump forward, or 8ystem Engineering evaluation. 2) The following step may be marked N/A if reducing power as specified by AOP-8 .04, Condensate and Heater Drains Malfunction , or as specified by Appendix D. In this case, all available condensate and heater drain pumps should remain in service to maintain adequate condensate pressure. [11] WHEN reactor power is approximately 85 to 90%, THEN PERFORM the following: [11.1 ] IF three condensate demineralizer booster pumps are in service, THEN EVALUATE removing one (1) condensate demineralizer booster pump in accordance with 1,2-80-213-1. [11.2J IF two condensate demineralizer booster pumps are in service, THEN EVALUATE removing both condensate demineralizer booster pumps in accordance with 1,2-80-2/3-1. [11.3] STOP one (1) condensate booster pump in accordance with 1,2-80-2/3-1.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 68 of 93 STARTUP No. _ Unit __ Date _ 5.3 Power Reduction From 100% to 30% (continued) NOTE 0-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [12] PERFORM the following at approximately 80% reactor power: [12.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = 34.55 % --- D [12.2}- IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U2118 = 34.55 --_% D [12.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 N-42 N-43 N-44 (XI-92-5005B) (XI-92-5006B) (XI-92-5007B) (XI-92-5008B) YES D YES D YES D YES D NOD NOD NOD NOD [12.4] IF any of the above steps are checked NO, THEN PERFORM 0-SI-OPS-092-078.0.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pa~e 69 of 93 STARTUP No. _ Unit _ _ Date _ ( 5.3 Power Reduction From 100% to 30% (continued) NOTE Turbine Impulse pressure relay lights are located on L-262.Relay lights are dark when relays are NOT armed. Relay NO.4 is a spare. [13] WHEN turbine load less than 71% (Unit 1) 72% (Unit 2), THEN PERFORM one of the following (N/A substep not performed): [1 3.1J VERIFY Turbine Runback circuits are NOT armed by performing the following: A. ENSURE [PIS-47*13RLY111 (Turbine runback from MFP loss) is NOT LIT. B. ENSURE [PIS-47*13RLY211 (Turbine runback from NO.3 HOT) is NOT LIT. C. ENSURE [PIS-47*13RLY31, (Closure of LCV-6-106B from Loss of any #3 HOTP) is NOT LIT. [13.2] VERIFY Turbine Runback circuits are NOT armed by performing the following: A. ENSURE [FU2*47 *13AJ, (Turbine runback from MFP loss) REMOVED (Aux Inst Rm. R71). B. ENSURE [FU2*500*R071 K3J1 (Turbine runback from NO.3 HOT) REMOVED (Aux Inst Rm R-75). C. ENSURE jumper between P1 8-1 and P1 8-2 in Pnl 262, (Closure of LCV-6-106B from Loss of any
- 3 HDTP) REMOVED.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 70 of 93 STARTUP No, _ Unit __ Date _ l 5.3 Power Reduction From 100% to 30% (continued) CAUTION Valves LCV-6-106A and 106B shall be verified to be controlling properly during unit load reduction. NOTES 1) One MFWP is normally removed from service at 45% turbine load but, if necessary, may be removed from service at power level less than 55% (Unit 1) or 65% (Unit 2) if approved by the Operations Superintendent 2) If holding at a power level less than 60% the condensate demineralizer booster pumps may be left running. 3) Shutdown 01 the condensate demineralizer booster pumps and
- 3 heater drain pumps should be based upon header pressure and ability of the drain
tank pumps to pump forward. [14] WHEN between 55 to 70% turbine load, THEN PERFORM the following: [14.1] SIMULTANEOUSLY STOP both operating condensate demineralizer booster pumps in accordance with 1,2-S0-2/3-1 (N/A if NOT in service). [14.2] VERIFY #3 HOT runback NOT armed by ensuring either (N/A method NOT used) Step 5.3[13.1]B completed OR Step 5.3[13.2]B completed.
( '. SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 71 of 93 5.3 STARTUP No. Unit __ Power Reduction From 100% to 30% (continued) [14.3J .STOP one of the three #3 heater drain tank pumps in . accordance with 1,2-80-5-2. [14.4] DISPATCH an AUO to perform one of the following to align steam seals to the unit: A. IF Auxiliary 8team Header is available and other unit is greater than 55% load, THEN Date _ ALIGN opposite units #3 Extraction to supply steam seals in accordance with 0-80-12-1 . D B. IF the #3 Extraction on the opposite unit is NOT available THEN PLACE the Auxiliary Boiler in service in accordance with 0-80-12-1 , OR ENSURE steam seals are being supplied from the unit's main steam supply. D NOTE 0-81-0P8-092-078.0 may be performed at discretion of Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [15] PERFORM the following at approximately 60% reactor power: [15.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = 34.55 --_% D 34.55 [15.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U1118 = 34.55 --_% D 34.55
(, SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 72 of 93 STARTUP No.. _ Unit __ Date _ 5.3 Power Reduction From 100% to 30% (continued) [15.3J VERIFY that all NIS Power Range A channel drawers . are within +/- 2% of the calculated calorimetric power. N-41 N-42 N-43 N-44 (XI-92-5005B) (XI-92-5006B) (XI-92-5007B) (XI-92-5008B) YES 0 NO 0 YES 0 NO 0 YES 0 NO 0 YES 0 NO 0 ( [15.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.
( SQN NORMAL POWER OPERATION O-GO-S Unit 1 & 2 Rev. 0047 Page 73 of 93 5.3 STARTUP No. Unit __ Power Reduction From 100% to 30% (continued) Date _ NOTE Steps 5.3[16] through 5.3[18] may be performed out of sequence. [16] WHEN between 40% and 65% turbine load, THEN STOP one of the two #7 heater drain tank pumps in accordance with 1,2-S0-5-3. [17] WHEN reactor power is approximately 50%, THEN VERIFY annunciator XA-55-4A, window E-4: P-9 LOW POWER TURB TRIP-REAC TRIP BLOCK is LIT. [181 WHEN approximately 45% turbine load, THEN PERFORM the following: [18.1] IF operating with two main feedwater pumps in service, THEN SHUTDOWN one main feedwater pump in accordance with 1,2-S0-2/3-1. [18.2] STOP the second #7 heater drain tank pump in accordance with 1,2-S0 -5-3. o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 74 of 93 STARTUP No. _ Unit __ Date _ 5.3 Powe r Reduction From 100% to 30% (continued) NOTE 0-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [1 9] PERFORM the following at approximately 40% reactor power: [19.1] IF LEFM indication is available, THEN CALCU LATE Calorimetric power: Calorimetric power= U2118 = 34.55 - -_% D [19.2J IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U2118 = 34.55 % - - - D ( [1 9.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 (XI-92-5005B) YES D NOD N-42 (XI-92-5006B) YES D NO D N-43 (XI-92-5007B) YES D NOD N-44 (XI-92-5008B) YES D NOD [19.4] IF any of the above steps are checked NO, THEN PERFORM 0-SI-OPS-092-078.0.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 75 of 93 STARTUP No. _ Unit __ Date _ 5.3 Power Reduction From 100"/0 to 30"/0 (continued) NOTE AM8AC is blocked when less than 40"10 turbine load for greater than 360 seconds (time delay). [20] WHEN less than 40"10 turbine load, THEN VERIFY annunciator XA-55-4A, window E-7: C-20 AMSAC ARMED is DARK. o [211 WHEN approximately 35"10 reactor power, THEN VERIFY annunciator XA-55-4A, window C-5: P-8 LOW POWER LOW FLOW TRIP BLOCK is LIT. o [22) WHEN approximately 30"10 turbine load, THEN [22.1] STOP the two operating #3 heater drain pumps in accordance with 1,2-80 -5-2. [22.2) STOP one of the two operating condensate booster pumps in accordance with 1,2-80-2/3-1. [22.3] STOP one of the three operating hotwell pumps in accordance with 1,2-80-2/3-1.
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 76 of 93 STARTUP No., _ Unit __ Date _ 5.3 Power Reduction From 100% to 30% (continued) [23] STABILIZE the plant at approximately 30% reactor power with reliable steam flow/feed flow indications. 0 [24] IF further load reduction is required,THEN GO TO 0-GO-6, Power Reduction from 30% Reactor Power To Hot Standby, [25] IF main turbine shutdown is desired while holding reactor power at approximately 30%, THEN GO TO 0-GO-11, Turbine Shutdown Without Reactor Shutdown, [26] IF reactor shutdown and turbine shutdown is required THEN GO TO 0-GO-6, Power Reduction from 30% Reactor Power To Hot Standby. [27] IF unit is to return to 100% power operation, THEN GO TO Section 5.0 of this instruction. END OF TEXT
( " saN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 77 of 93 STARTUP No. _ 5.4 Power Coastdown at End of Life Unit __ Date _ CAUTION Do NOT exceed the positive Axial Flux Difference (AFD) limit of TI*28 during power coastdown. NOTES 1) The power level of the reactor and turbine slowly coastdown from full power approximately 0.8% per day with TAVG and TREF maintained on program. The core cycle may be extended for 30 days or more. The coastdown enables the plant to reach the refueling date with a core bumup within the prescribed bumup window if the normal cycle length is insufficient for the calendar refueling date. 2) For core operating recommendations during coastdown or unusual power maneuvers , contact Reactor Engineering for guidance. [C.5] o ENSURE Precautions and Limitations have been reviewed. ENSURE ReS boron concentration is less than 50 ppm, OR at a higher level acceptable to chemistry. [3] ENSURE HUTs have sufficient capacity to hold excess water from the dilution process. [1] [2] NOTE TAVG is programmed from 578.2°F at 100% power to 54JOF at zero power at a rate of 0.312°F per % power. [4] MONITOR TAVG on program with TREF within +/- 1.5°F. o
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 78 of 93 STARTUP No. _ Unit _ _ Date _ ( 5.4 Power Coastdown at End of Life (continued) NOTE Lowering load on the Main Generator will cause VARs to trend in the positive direction (toward outgoing). This will require lowering generator voltage. Refer to GOI-6 Section E for MVAR limits for generator stability. Refer to precautions Q , R, and S. [5] PERFORM the following as required: [5.1] IF Automatic Voltage Control is in service, THEN ADJUST Main GeneratorVARs USING [HS-57-221 Exciter Voltage Auto Adjuster as necessary during power escalation. [5.2] - IF Automatic Voltage Control is NOT in service, THEN ADJUST Main Generator VARs USING [HS-57-231 Exciter Voltage Base Adjuster as necessary during power escalation. [6] WHEN RCS boron is less than or equal to approximately 40 ppm OR when recommended by Chemistry, THEN DE-BORATE RCS periodically as necessary to maintain TAVG on program using 1,2-S0-62-9 (Placing Mixed Bed Demin in ~~~) . 0 [7] IF de-boration using Mixed Bed Demineralizer or dilution becomes ineffective for maintaining TAVG on program with TREF, THEN WITHDRAW control rods to maintain TAVG on program USING 0-SO-85-1 .
( \\.. SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 79 of 93 STARTUP No. Unit Date 5.4 Power Coastdown at End of Life (continued) [8] IF an axial xenon oscillation develops and requires suppression, THEN [8.1] MOVE control bank inward when AFD is moving positive above target AFD, 1st CV OR [8.2J MOVE control bank outward when AFD is moving negative below target AFD, 1st CV AND HOLD AFD at target until oscillation is suppressed. 0 [8.3] IF this basic first overtone control is insufficient, THEN CONTACT Reactor Engineering for assistance. 0
( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 80 of 93 5.4 STARTUP No. Unit __ Power Coastdown at End of Life (continued) Date _ NOTE The annunciator for Bank 0 Rod Withdrawal Limit High (XA-55-4B, window 21) will be illuminated wh en rods are withdrawn to z 220 steps on 0 control rod bank. (9) WHEN control rods have been withdrawn to the fully withdrawn position, THEN [9.1) [9.2] DECREASE turbine load slowly (less than 1% per hour) as necessary to maintain TAVG on program with TREF. MAINTAIN valve position limit approximately 10% above the current governo r control indication as turb ine load is changed. o o ( CAUTION The governor valve position limit meter may NOT match the governor valve position meter; therefore, monitor the megawatt meter and valve position limit light continuously during the following adjustment. NOTE Operation with the VALVE POS LIMIT light LIT is acceptable if unsatisfactory load swings are experienced. [10] IF unsatisfactory load swings are expe rienced as the turbine load is decreased, THEN [10.1) SLOWLY and CAUTIOUSLY PULSE the governor VALVE POSITION LIMIT in the LOWER directio n while monitoring megawatts for a decrease and the VALVE POS LIMIT light to ILLUMINATE. 1st CV ( [10.2) WHEN the limiter just reaches the governor valve position (Valve Pos Limit light should be lit), THEN STOP limiter adjustment. o }}