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 Appendi x D Scenario Outline Form ES-D-1 I
Facilit y: Sequoyah Scenario No.: 1 Op Test No.: NRC
\.. Examiners: Ope rators :
Initial Cond itions: 100% Power.
B PZR Spray Valve Isolated
BCCPOOS
Turn ove r: Reduce Power to 90% for Turbi ne Steam Valve testing
Target CTs: Insert negat ive reactivity using rods and/or borat ion prior to compie tion of FR-S.1 step 4.
Isolate AF'N flow to the faulted SG prior to transi tion 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 pressu re channei fails high - Tech Spec evaiuation .
( T+ 15 TS-SRO
3 lor C-BOP/S RO MFP Master Pressure Controlle r Drifts iow - Require s taking manua l
rxcOpc4620 control of the Master controller to match steam and feed flow,
T+25
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 #1 SG Safe ty Valve failed open; Requires isolation of Faulted SG ,
. (N)or ma l, (R)eactivity, (I)nstrument, (C)ompo nent, (M)ajor
(
Appendix D 1 NUREG 1021 Revision 9
I Appendix D Scenario Outline Form ES-D-1 I
Scenario 1 Summary
\
The crew will assume the shift at 100% power with instructions to reduce power.
Short ly after turnover, the input to the PZR pressure controller fails high, requi ring
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.
Wh en vacuum is restored, one rod will drop . The crew will take action to stabilize the
plant in accord ance with AOP-C .01. Wh en stabilization steps have been performed,
a second rod will drop, requiring a reactor trip.
Th e 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.
Th e 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 2 NUREG 1021 Revision 9
_._---
ESG-I SCN File 0 1/2 5/07
EVENT IC/l\IFIRF/OR # DESCRIPTION/EXPECTED ACTl Ol'lSIBO OT H FEEDBACK
Simulator IC*16 100%, BOL 1-1000 M\VD/MT UI
IC ' B' T ra in work week cn ' 0' Rods @21 6 step s,all others @ 228 step s;
[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 T ag.
- Place Train \ Veek n sign
MFs, RFs, IRF RMR19 f:3 SG BD Rad Moni tor OO S: I-IUI-l20A & I2IA. Place Pink Tags on
OR s are UHF RM90l20 f:1 srcn modules.
active IMF AN OV 723 f:2
w he n the
IMF RC06B f:O Loop I PZR Spray Valve Isolat ed (I-PCV-68-340D)
sex file is
loaded.
IM F CVOIB f:1 \B-B CC P OOS (Initial cond itions)
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.
( Pzr Press Ch, PT- 68-340 fails high.
2. IM F RX07 A f:1 k:2
Support staU'reporl:
When 1Ms or MSS is contacted to trip blstables using AOP-I.04 App endix A.
inform the crew thai the 1Ms will report to the MCR in - 45 minutes.
3. lOR RX COPC4620 MFP Master Controller failure ; controller output fails low resulting in
f: .OOI k:3 lowering feed flow to all SGs.
Suv port 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 Loss Of Condenser Vacuum
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;\l F CN09 after rep ort that vacuum breaker fla nge 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
G:\Pre p Week filcs\As Su bmitte d Ope rati onal Exam\Scenarios\S cenario 1\3-19 -07 ESC- I.doc
--'---'---
ESG-l SCN File 0 1/25/07
EVENT IC/MF/RF/OR # D ESCRIPTION/EXPECTED ACTIONS/BOOTH F EEDBACK
( 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 Not ify UO that System Engin eerfound
blow n f use in stationary gripper coil circuit. Fuse is rep laced, and rod
is ready for retrie val.
- Reactor Eng. notified for po wer peaking. [uel failure, & xenon
oscillation considerations, inform crew to proceed with rod retrieval
usinv A OP-C.01 consi derations (i.e.: <1 hour).
6. IM F RD07FI0 f: l k: 6 Dropped Rod-R x Trip initiator: FlO cs ' 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 fro m a Hi-Hi S/G level or S1 signal. Any
in follo wing step. functions that receive an initiation signal from P-4 auxiliary contacts of the
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
IRF RPR05B f:l D:15
Associated Remote Fu nctio ns- wa it 5 minutes follow ing AUO
not ificati on to insert : RPR05A & RP R05B - simulates local opening Rx
k: 9 Trip Breakers (RTA & RTB)
Support sta([report:
- A UG rep orts to crew that the RTBs are op en.
9. IMF MS 03A f:l00 e:7 Single main steam safety valve fails open (SC #1) triggered on MT trip .
Support sta([report:
- Rep ort (as outside A UO) to crew that you observe steam comingfrom
too 0{U1 West Valve Vault (for S/Gs #1 or #4).
Termination Criteria Complete Fa ulted SG Iso lation 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
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # ....:...____ Page 3 of _ 4;,,:.
0--1
Event Description: Reduce Power
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
SRO 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 mus t
be exercised to properly flush the Boric Acid pip ing 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 NUREG 1021 Revision 9
I App endix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # -'-_ _ _ _ Page 4 of _ 4"'
0---1
(
Event Description: Reduce Power
Time I Position I Aoolicant's Actions or Behavior
maint ain shutdown marg in, to maintain rods above the insertion limit, du ring an
emergency shutdown (AOP-C.03), du ring recovery of a dropped/misaligned rod (AOP-
C.01), or at Chemistry recommendation in mod e 3, 4, 5 or 6.
RECORD the quantity of bo ric acid required to achieve desired
boron concentration using Appendix D.
RO gals
PERFORM Appendix I Independ ent Verification of
- Calculation for Amount of Boric Acid or Primary Water.
(N/A if App. D was periormed by SRO to verify data
Cre w
from Rx Engin eering)
(
DETERMINE availab le bo ric acid volume in in-se rvice 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 th e
RO desired flow rate.
App endix D 4 NUREG 1021 Revision 9
- ---- --
I Appendix D Required Operator Actions Form ES*D *2 I
Op Test No.: NRC Scenario # 1 Event # -'- Page 5 of _4:.::;
0-i
(
Event Description: Reduce Power
Time I Position I Applicant's Actions or Behavior
SET [FQ -62-139]. Batch Integ rator 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-62-23 2A].
(
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.
RO IF reactor is critical. THEN MONITOR nuclear instrumentation
Appendix D 5 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D -2 I
Op Test No.: NRC Scenario # 1 Event # ....:..____ Page 6 of _4
~O::--I
(-,
Event Description: Reduce Power
Time I Position I Applicant's Actions or Behavior
and reactor coolant temperature to ensure prop er response
from boration.
NOTE
BAT op erability limits are prescribed by TR M 3.1.2.6 (Modes 1-3) or 3.1.2.5 (Modes 4-6).
MONITOR Boric Acid Storage Tank level.
-
IF Volum e Control Tank level increases to 63 percent,
( THEN ENSURE [LCV-62-118] , Volum e Controi Tank Divert
RO Valve OPENS to divert excess water to the Holdup Tank.
NOTE
Sample may be obtained at norm al 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 W ater to Blender Flow
- Controll er is in AUTO position and the potentiometer
(dial indicator) is set at 35%.
- ADJUST [FC-62-139], Boric Acid Flow Contr oller to the
( desired blend solution in accordance with TI-44 Boron
Table s.
App endix 0 6 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # ....:.... Page 7 of _4.:.:0 '---1
( Event Description: Reduce Power
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.
Lab to obtain RCS boron sample.
(
(
Appendix D 7 NUREG 1021 Revision 9
I Appendix D Reguired Operator Actions Form ES*D*2 I
Op Test No.: NRC Scenario # 1 Event # ....:....__ _ _ Page 8 of _ 4""
0--t
(
Event Description: Reduce Power
Tim e I Position I Applicant's Actions or Behavior
NOTE
Boration is done in batch es until the total boron and/or power change is comp leted.
REPEAT this section as required to complete total boron
RO change.
WHEN total boration is complete, THE N:
- 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 Gene rator will cause VARs to trend in the positive direction
(towa rd outgoi ng). Th is will require lowering generator voltage. Refer to GOI-6 Section E
for MVAR limits for generator stability.
(
Appendix D 8 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # ....:... Page g of 40
(
Event Description: Reduce Power
Time I Position I Aoolicant"s Actions or Behavior
PERFORM the following as required:
IF Automatic Voltage Control is in service,
BOP 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 powe r maneuvers, contact Reactor Engineering for guidance.
3) It is recomme nded that AFD be controlled within the target band.
4) Th e 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 th e 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.
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 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # . 1 Event # ....:..____ Page 10 of ....:4::;:
0----l
(
Event Description: Reduce Power
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.
MONITO R 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
BOP governor control indication as turbine load is changed.
Le ad Exa miner may d irect initiation of t he next event at his discretion
(
Appendix D 10 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # ...;2 =---____ Page 11 of 40
( Event Description: Controlling PZR pressure channel PT 68-340 fails high
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 cont rolling pressure channel failure,
and takes Prudent Operator Action (POA) to manually close
RO the PZR Spray Valve.
Refer to alarm response procedures
Crew
-
Determine Instrument Failure has occurred and direct entry to
US AOP-1. 04, Pressurizer Instrume nt 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 fail ure of chann el IV (P-68-322) will affect the automat ic actuation of PCV 68-340A,
PZR PORV , in the normal pressure control circuit. LTOPS operation of this PORV is
unaffected by this failure.
(
Append ix D 11 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
(
Op Test No.: NRC Scenario # 1 Event #
...;;....---
2 Page 12 of 40
Event Description: Controlling PZR pressure channel PT 68-340 fails high
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
RO * PZR Spray controllers
PIC-68-340D (Loop 1)
AND/OR
PIC-68-340B (Loop 2)
- Pres surizer Heaters
CHECK PI-68-340A indicates NORMAL. NO
( PERFORM the following:
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-6 8-322.
EVALUATE th e following Tech Spe cs 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
( RO
controllers in AUTO.
Appendi x 0 12 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES*D*2 I
Op Test No.: NRC Scenario # 1 Event # _ 2=-- Page 13 of 40
(
Event Description: Controlling PZR pressure channel PT 68*340 fails high
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
contro ller, 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 bistab les 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
Whe n Techni cal Specifications ar e id entifi ed or at discret ion of the Lead
Examiner , proceed t o the next event
(
Appendix D 13 NUREG 1021 Revision 9
I Appendi x D Reguired Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # _3~ Page 14 of 40
( Event Description: MFP Master Speed Controller Failure
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
Refer to alarm response procedure
Crew
-
Direct entry to AOP S.01 , Loss of Normal Feedwater, Section
( US 2.2
NOTE:
Appendix C may be used to determin e the program feedwater DIP for current power.
MAINTAIN feed water pressure on program:
PLACE affected MFP speed controller(s) in MANUAL:
- PC-46-20, MFPT 1A(2A) 1B(2B) Speed Control.
BOP * SIC-46-20A, MFPT 1A(2A) Speed Controller
- SIC-46-20B , MFPT 1B(2B) Speed Controll er
CONTROL speed on affected MFP(s) to restore feedwater
pressure to program . (MFPC IIp '" 194 psid @ 100%)
(
Appendi x D 14 NUREG 1021 Revision 9
I Appendi x D Required Operator Actions Form ES-D-2 I
c Op Test No.:
Event Description:
NRC Scenario # 1 Event #
MFP Master Speed Controller Failure
....::,.3 Page 15 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
(
Appendi x D 15 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # 4 of 40
(
Event Description: Loss of Condenser Vacuum
TIme I Position I Aoolicant's Actions or Behavior
Booth Instructor:
When di rected , initiate Event 4
Indications ava ilable:
O-M-12A, C-2, 1-RA-90-119B COND VAC PMP LO RNG AIR EXH MON INSTR
MALFUNC
1-AR-M2-C, CG, CONDE NSER VACUUM LOW
Condenser Vacu um deqradlnq, Air in leakaqe increasing.
Evaluator Note: Booth Operator is rnodu latino Condenser Vacu um
Refer to alarm response procedure
Crew
-
VERIFY alarm via [1-PlTR-2-2] recorder.
(' BOP
VERIFY required number of CCW pumps are inservice.
CHECK condense r vacuum exhaust on ICS using eithe r:
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
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # 4
( Event Description: Loss of Condenser Vacuum
Time I Position I Aoolicant's Actions or Behavior
IF alarm is valid, THEN GO TO AOP-S.02, Loss of Condenser
Vacuum .
US
NOTE:
Use of the highes t reading operable condenser pressure instrument is conservative
and recommended by engineering.
MONITOR condens er pressu re for turbine trip criteria.
-
BOP * CHECK turbine load greater than or equal to 30% .
MT Low Condenser Vacuum Trip @ 3.9 psia increasi na
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 Condense r Vacuum Pump
ENSURE condenser vacuum breaker CLOSE D.
Appendix D 17 NUREG 102 1 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # 4
( Event Description: Loss of Condenser Vacuum
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 condens er inleakage USING the
followi ng plant comput er points:
BOP * F2700A
- * F2263A
- F2260A
(
VERIFY inleakage value is < 45 elm as indicated by both
F2700A and F2263A. NO
PERFORM the following:
- ENSU RE FCV-2-255, Condenser Vacuum Exhaust
BOP 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-030-41 5.0.
Appendix D 18 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # 4
(
Event Description : Loss of Condenser Vacuum
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
- Conde nser 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 controll ing in AUTO .
- RO
(
CHECK condenser pressure STABLE or DRO PPING. (NO)
REDUCE turb ine load to maintain cond enser vacuum USING
one of the following:
BOP * AOP -C.03, Rapid Shutdown or Load Reduction.
(preferred)
- Valve Position Limiter.
On Lead Examiner's cue, erocee d 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 # 5
(
Event Descriplion: Dropped Rod
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
Acknowledge alarms
Crew
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.
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 # 5
( Event Description: Dropped Rod
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)
BOP * 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 fo llowing:
- 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
I App end ix 0 Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # 5
(
Event Description : Dropped Rod
Time I Position I Applicant's Actions or Behavior
NOTE :
Core therm al power must be reduced to less than 75% within one hour and shutdown
marg in 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 an d enters LCO 3.1 .3.1 action C. (Movable
Con trol 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 actio ns 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 # 5
(
Event Description: Dropped Rod
Time I Position I Applicant's Actions or Behavior
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 3.1 .3.1 action C.3 or 3.2.4 action A.1 .a USING 0-SI-IXX-092-
US
N40.0.
NOTIFY Reactor Engineer and COMPLETE notifications
USING SPP-3.5, Regulatory Reporting Requirements.
US
c
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
RO NEUTRO N FLUX RATE alarm DARK rM-6A, 811
App endix D 23 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # t Event # 5 of 40
( Event Description: Dropped Rod
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 Append ix D Required Operator Actions Form ES*D-2 I
Op Test No.: NRC Scenario # 1 Event # _ ;6;.:...:. 8=--_ _
7;.,;
. Page 25 of 40
(
Event Description; Dropped Rod, ATWS , Stuck open SG Safety Val ve
Time I Position I Appli cant's Actions or Behavior
Booth Inst ructor:
When directed, initiate eve nt 6
Indications available:
Second dropped rod .
No reactor t ri p indication.
EVALUATOR NOTE: S/G #1 main steam safety valve fails open on Turbine trip.
Recognize a second rod has dropped and determine reactor
- Crew
trip required
(
US Direct reactor trip and turbine trip
RO Attempt to trip reactor
BOP 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.: NRC Scenario # 1 Event # ..;6:::.,.:..
7~ , Sc--_ _ Page 26 of 40
('
Event Description: Dropped Rod, ATWS, Stuck open SG Safety Valve
Time I Position I Applicant's Actions or Behavior
VERIFY reactor TR IPPED:
CRITICAL
TASK
- Reactor trip breakers OPEN
- Reactor trip bypass breakers OP EN or
DISCONN ECTED
- Neutron flux DROPPING
- Rod bottom lights LIT
RO * 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 seco nd dropped rod,
-
VERIFY turb ine TR IPPED:
( BOP * ALL turbine stop valves CLOSED
CHECK AFW System operation:
- START pumps.
TD AFW pump RUNNING as necessary.
necessary.
FCV*3*401 CLOSED.
(
App endix D 26 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event #
(
Event Description: Dropped Rod, ATWS, Stuck open SG Safety Valve
Time I Position I Aoolicanrs Actions or Behavior
EMERGENCY BORATE RCS by performing the following:
CRITICAL
TAS K
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 establish ed on [FI-
62-137A] .
0 IF boric acid flow less than 35 gpm,
THEN
- * CLOSE recirculat ion valve for the BAT aligned to the
blender:
0 1-FCV-62-237 for BAT A.
( 0
0
0-FCV-62-241 for BAT C.
2-FCV-6 2-237 for BAT B.
- VERIFY charging flow path established:
0 FCV-62-90 OP EN 0 FCV-62-91 OPEN
0 FCV-62-86 or FCV-62-85 OPEN.
- CHEC K pressurizer pressure less than 2335 psig.
VERIFY Containm ent Purge isolated:
VERIFY conta inment purg e and vent dampers (System 30)
Crew
CLOSED . [Panel 6K and 6L]
Append ix D 27 NUREG 1021 Revision 9
I App endix D Required Operator Actions Form ES-D-2 I
Op Test No .: NRC Sc enario # 1 Event # _ 6;;.:....;. , 8=---_
7.:..; _ Page 28 of 40
( Event Description: D ropped Rod , ATWS, Stuck open SG Safety Val ve
Time I Position I Aool icant'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 Injectio n, Main Steam Line
Isolation and/or isolate AFW prior to procedural direction (POAs/Fold out page) if
cond itions dictate based on excessive cooldown.
Crew Reactor T RIPPED.
PERFORM the following:
-
- DISPATC H personne l to locally open reactor trip
breakers and MG set output breakers [MG Set Room,
US Aux Bldg el. 759].
- DISPATCH perso nnel to locally open breakers to MG
sets [480V Unit Boards A and B].
Turbine TRIPPED:
BOP * ALL turbine stop valves CLOSED,
MONITOR reactor subcritical:
RO * Power range channels less than 5%.
- Intermediate range SUR NEGATIV E.
(
Appendix D 28 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES*D- 2 I
Op Test No.: NRC Sce nario # 1 Event # ....;:.:
6,..:.
7.:.;
, 8::...-_ _ Page 29 of 40
( Event Description: Dropped Rod, ATWS. Stuck open SG Safety Valve
Time I Position I Aoo licant's Actions or Behavior
US
GO TO Step 19,
ENSURE status tree monitoring initiated .
US
MONITOR boration termination criteria:
concentration.
- * CHEC K for all of the following:
0 all control rods FULLY INSERTE D
0 RCS temperature greater than 540°F
0 no RCS dilution has occurred.
WHEN emergency boration is no longer needed, THEN STO P
eme rgency boration USING EA-6S-4, Emergency Boration.
RO/US RET URN TO procedure and step in effect.
Directs transition to E-O, Reactor Trip or Safety Injection
US
App endix D 29 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I
Op Te st No .: NRC Sce nario # 1 Event # _ :6:<,..:. , 8::....-_
7.....: _ Page 30 of 40
( Event Descripti on : Dropped Rod, ATWS, Stuck open SG Safety Valve
Tim e I Posit ion I App lican 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:
-
BOP * 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 exce ssive cooldown.
PERFORM ES-0.5, Equipment Verifications WHILE continuing
BOP in this procedu re. (At end of scenario)
(
-. RO DETERMINE if secondary heat sink available:
Appendix 0 30 NUREG 1021 Revision 9
I Append ix D Required Operat or Act ions Form ES*D*2 I
Op T est No .: NRC Sc enario # 1 Event # ...;6:::,
- ..:..
7,:..:
8:...-_ _ Page 31 of 40
( Event Desc ription: Dropped Rod , ATWS, Stuck open SG Safety Valve
Time I Position I Ap plicant'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 on e S/G.
c. CONTROL feed flow to maint ain narro w range level
between 10% [25% ADVj and 50% in all S/Gs .
CHECK if main steam lines should be isolated:
a. CH ECK if any of the following conditions have
occ urred:
- * Any S/G pressure less than 600 psig AND
ST EAMLIN E PRESS ISOL SI BLOCK RATE
ISOL ENABLE permissive DARK [M*4A , A4]
( OR
RO * Any S/G pressure dropping
UNCONTROLLED.
- Phase B actuat ion
b. ENSURE MSIVs and MSIV bypass valves CLOS ED.
May have alread y closed MSIVs.
NOTE :
Loss of seal injection flow could adversely affect RCP seals.
Ap pend ix D 31 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scenario # 1 Event # ..;6~,..:.7,.,:,8::....-_ _ Page 32 of 40
( Event Description: Dropped Rod, AlWS, Stuck open SG Safety Valve
Time I Position I Applicant' s Actions or Behavior
CHECK RCP trip criteria:
a. CHECK the fo llowing:
- RCS pressure less than 1250 psig. (NO)
AND
MONITOR RCS temperatu res:
- IF any RCP running ,
THEN
CHECK T-avg stable at or trending between 547 degrees F
and 552 degrees F.
_ RO
- 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 .
RO 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 .: NRC Scena rio # 1 Event # ...;6"'-,.;,.
7,:..:
8'--_ _ Page 33 of 40
( Event Description: Dropped Rod , ATWS , Stuck open SG Safet y Valve
Time I Position I Aoolican t's Actions or Behavior
CHECK S/G secondary pressure boundaries INTACT:
RO * 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.
Append ix D 33 NUREG 1021 Revision 9
I Appendix 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.
Caut ion
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.
(
Eval uato r Note: AFW may have previously been isolated per E-O fold-out page
ISOLATE Faulted S/G (s):
CRITIC AL
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-1-1 6 (S/G 4).
- VERIFY S/G blowdown valves CLOSED ,
- VERIFY atmospheric relief CLOSED .
CHECK CST level greater than 5%.
RO/BOP
Note:
Chem Lab samples mav reauire resettina Phase A and ooenlnq blowdown isolation
Appendix D 34 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I
Op Test No.: NRC Scena rio # 1 Event # ...;6;:,....:.,
7,:..::8:....-_ _ Page 35 of 40
(-,
Event Description: Dropp ed Rod . ATWS, Stuck open SG Safety Val ve
Tim e I Position I Applica nt' s Actions or Behavior
valves as necessa ry.
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 steaml ine NORMAL
- Condenser exhaust NORMAL
- * S/G blowdown recorder RR-90-120 NORMAL
- Post-Accident Area Radiation Monitor recorder
RR-90-26 8B, points 3 (blue), 4 (violet), 5 (black) and 6
(brown) NOR MAL. 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.: NRC Sce nario # 1 Event # . 8::......._
_ 6:::.,:,..:.7",,: _ Page 36 of 40
(
" Even t Description: D ropped Rod. ATWS. Stuck open SG Safety Val ve
Time I Position I Apolicant's Action s or Behavior
CHECK SI termina tion 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 pressur e stable or rising.
Pressurizer level
greate r than 10% [20% ADV].
GO TO ES-1.1 . SI Termination.
Sc enario ma y be termin ated when c rew t ransit ion s to ES-1.1, SI Termi nation
(
App endix D 36 NUREG 1021 Revision 9
Appendix 0 Required Operator Actions Form ES-D-2
Op Test No.: NRC Scenario # 4 Event # ES-0.5 Page 37 of 40
( - -
Event Description : Equipment Verifications
Time I Position I Applicant's Actions or Behavior
ES-O.5 Act ions
CHECK ERCW system oper ation:
BO P * VERIFY at least fou r ERCW pumps RUNNING.
- VERIFY DIG ERCW supply valves OP EN.
VERIFY CCS pumps RUNNING:
- Pump CoS.
VERIFY EGTS fans RUNN ING.
VERIFY generator breakers OPEN.
VERIFY AFW pumps RUNNING:
- TO AFW pump .
(
App endix D NUREG 1021 Revision 9
Appendix D Required Operator Actions Form ES*D-2
Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 38 of 40
( Event Description : Equipment Verification s
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 alignmen t:
a. VERIFY MD AFW LCVs in AUTO.
c. VERIFY MD AFW pump recirculation valves FCV-3- 400
and FCV-3-401 CLOSED.
VERIFY MFW Isolation:
- MFW pumps TRIPPED
BOP * MFW regulating bypass valve controller outputs ZERO
- MFW isolation valves CLOSED
- MFW flow ZERO .
MONITOR ECCS operation:
VERIFY ECCS pump s RUNNING:
BO P * CCPs
- RHR pumps
- SI pumps
Appendix D NUREG 1021 Revision 9
App endi x 0 Requ ired Operator Actions For m ES-D -2
Op Test No.: NRC Scenario # 4 Event # ES-0.5
- - of 40
Page 39
( Event Description: Equipment Verifications
Time I Position I Applicant's Actions or Behavior
VERIFY CCP flow through CC PIT.
- CHECK RCS pressure less than 1500 psig .
- CHECK RCS pressure less than 300 psig.
- VERIFY RHR pump flow .
VERIFY ESF systems ALIGNED:
- Phase A ACTUATED:
0 CONTAINM ENT ISOLATION PHASE A T RAIN
- A alarm LIT [M-6C , B5] .
0 CONTAINMENT ISOLATION PHASE A TRAIN
B alarm LIT [M-6C, B6].
- Containment Ventilation Isolation ACTUATED :
0 CO NTAINMENT VE NTI LATION ISOLATION
TR AIN A alarm LIT [M-6C , C5] .
0 CONTAIN MENT VENTILATION ISOLATION
TRAIN B alarm LIT [M-6C , C6].
BOP * 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 Revisi on 9
Appendix 0 Required Operator Actions Form ES-O-2
Op Test No.: NRC Scenario # 4 Event # ES-0.5 Page 40 of 40
(
Event Description: Equipment Verifications
Time I Position I Applicant's Actions or Behavior
MONITOR containm ent 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
- * HS-77-411, Rx Bldg Aux Floor and Equipm ent Drain
Sump pump B.
DISPATCH personn el to perform EA-0-1 . Equipment Checks
Following ESF Actu ation.
(
Appendix D NUREG 102 1 Revision 9
Operations Chemistry Information
( . --
.' .
Bor,o~ Results ' -
Sam ple Po in t Bo ron Date I Tim e Goa l Limit
U1 RCS ppm 1093 Today / Now Variable Variable
U2 RCS ppm 816 Today / Now Variable Variable
U1 RWST ppm 2601 Tod ay / Now 2550 - 2650 2500 - 2700
U2 RWST ppm 2569 Tod ay / Now 2550 - 2650 2500 - 2700
BAT A ppm 6850 Today / Now Variable Variable
BATB ppm 6850 Tod ay / Now Variable variable
BATC ppm 6850 Today / Now Variable Variable
U1 CLA #1 ppm 2556 Toda y / Now 2470-2630 2400-2700
U1 CLA #2 ppm 2575 Today / Now 2470-2 630 2400-2700
U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700
U1 CLA #4 ppm 2589 Toda y / 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 Tod ay / Now 2470-2630 2400-2700
U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700
Spent Fuel Pool ppm 2547 Toda y / Now ~2050 ~2000
. Midpoint, . >
, r* .. : . ", .(.l. o,'.. ~_. ~::~ .. .. ....
>1
2.18-2.48 2.33
" . ~ , '.~ ';~" :. *~: Pri ~~y. .t o ~e.c 9ndary. 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 Toda y / Now No Today / Now
S1137.5 CVE Leak rate gpd < 0.1 Toda y / Now < 0.1 Today / Now
5 gpd leak equivalent cpm 380 Toda y / Now 68 Toda y / Now
30 gpd leak equival ent cpm 1980 Tod ay / Now 83 Today / Now
50 gpd leak equivalent cpm 3250 Today / Now 206 Today / Now
75 gpd leak equ ivalent cpm 4850 Toda y / Now 455 Today / Now
150 gpd leak equivalent cpm 9750 Toda y / Now 870 Toda y / Now
CVE Air Inleakage cfm 10 Tod ay / 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
APPENDIX C
( SHIFT TURNOVER CHECKLIST Page 1 of 3 Today
0 SM
0 US/MCR Unit 1
0 UO Unit 1 Off-going - Name
0 AUO Station SON
0 STA (STA Function) AUG Camp Actions On-coming - Name
Part 1 - Co mp let ed by Off-go ing Shift/Reviewed by On-coming Shift:
Abnormal E *
..
- tL u *ICondltlons
MAIN CONTROL ROOM(7690) (593-5409)
Train B Week
- 1-PCV-68-340D Valve Controller setpoint drift; (WO 06-080000-000). Pin k tag on 1-M-4.
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). Pin k tag on 1-M-12.
(
- All equipment normal
AUXILIARY BUILDING (7775) (593-54 14)
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 Iden t ified 0.02gpm I Unidentified 0.Q1 gpm. (Today 0600)
Gi' Prep Week files'As Submitted Operational Exam'S cenarios'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.
Maj or 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 Dur ing Shift:
None
V ~ '~"¥0~~ ,: " , ',~ ; ;::8 '",.£:, '"7 ,!, ' LCO/ODCMfTRM ACTIONS . ':
S', ~
'
.~ , (' '~ :;;$" ;; -;.;-,,:" ,~¥ '\L " ~ -", I
- 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 bo th off-going and on-com ing sh ift
0 Walkdown of MCR Controi Boards (NIA for AUG's)
Relief Time: Relief Date: today
TVA 40741 [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 T oday
Disabled Annunciato rs
( PANEL WINDOW ANNUNCIATOR WO I PER Number
Equ ipment Off* Norma l (Pink Tags)
UNID And No un Name Panel Pro blem Descrip t ion w o I PER Number
10 And Noun Nam e Panel Probl em Descriptio n WOlPER Number
I
(
(
G:\Prep Week filcs\As Submitted Operational Exam\Scenarios\Sce nario 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 contro ller IS set at Adjusted SA Controller Setting law 0-SO-62-7 section 5.1
f'?" : " , ;' '::,: . '.-~ :;< . ... *.~ '. '*:f ..' :;Estim. ated ' 'f*o*-r a. ~1 c*.-Chang*e in Tave **
va lu' e's
~ _ . __~. . ~. , I: ~ * * ~ \ . " ~ . . * * * *
- 1
_ __ Ga __llons of_ac id:
_ 26
_ _ _- ' - Ga llons of wat er: 138 Rod Steps: 4 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 approximat ions and not intended nor expected to be exact. The values may be superceded by
Rx Enginee ring or SO-62-7 calculated values. The se values are calculated assum ing 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 borati ons: 0 Rod steps in: 0
Gallons per dilution : 0 Ga llons per boration: 0 Rod steps out: 0
Tota l amo unt diluted: 0 Total am ount borated: 0 Net chang e: 0 IN/O ut
. ::~ ' "~, ~ 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 bo ration: 0 Net change : 0 In/O ut
Remarks:
Rx Power - 100% MWD /MTU - 1000 Xenon & Samarium at Equilibr ium
Next Un it 1 Flux .Map is scheduled - three weeks from now
Unit Supervisor:
Na melDate
(
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 .Res ults ... :. ~ .. .
'l:
-
, 1
.~
~
.-
.. :
-- ~ ~~. ~
...:.:...-
Sample Point Boron Date /Time Goal Limit
U1 RCS ppm 1093 Today / Now Variable Variable
U2 RCS ppm 816 Toda y / Now Variable Variab le
U1 RWST ppm 2601 Today / Now 2550 - 2650 2500 - 2700
U2 RWS T 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!lf9 rma~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 Leakr ate 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 Submitt ed Operat ional Exam\Scenarios\Sccnario 1\3-19,07 ESG- I TO Sheets.doc 02/13107
APPENDIX C
( SHIFT TURNOVER CHECKLIST Page 1 of 3 Toda y
0 SM
0 US/MCR Unit 1
0 UO Unit 1 Off-going - Name
0 AUO Station SON
D STA (STA Function) AUO Comp Actions On-coming - Name
Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift:
Ab IE * tL
..
- *IC dt
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)
080880-000). Pink tag on 1-M-12.
(
- All equipment normal
AUXILIARY BUILDING (7775) (593-5414)
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 shi ft
0 Walkdown of MCR Control Boards (N/A for AUO's)
Relief Time: Reiief Date: today
TVA 4 074 1 [03-200 1) O POP-l -1 103-14-200 1
G t'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
Disabled Annunciators
( PANEL WINDOW ANNUNCIATOR WO I PER Numbe r
Equipment Off*Normal (Pi n k Tags)
UNIO And Noun Name Panel Problem Description WO I PER Num ber
MCRWO LIst
10 And Noun Nam e Pan el Problem Description WOlPER Numb er
G:\Prep Week f il es'As Sub mitted Operat ional Exam'S cenarios'S cenario 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% * I RCS B-10 Depletion: 2 ppm
Ope rable 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 Tota l 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 sched uled - three weeks from now
Unit Superv isor:
Name/Date
G:\ Prep Week filcs\As Subm itted Operati onal ExarrrSc enarios'Scenario 1\3- 19-07 ESG-l TO Sheets.doc 02J1 3i07
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 RWS T 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
2.18-2.48 2.33
~~~ ~y :.~.
* * ** *
t >*:*:.1 Pfimaiy; t~Si"c~ti~arY
0'- * * ",, >~ . . *--""leakrate Inforn1aflon
_~ , . '. . ~ To ' . . ;'%
{'f.p'tal 'CPM RM-90';991119) - ~~~~~~
" ", ""
. ~,
'.
Indicator Units U1 Date I Time U2 DatefTime
SI 50 S /G Leakage? Yes/No No Today 1 Now No Today 1 Now
SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today 1 Now
5 gpd leak equivalent cpm 380 Today 1 Now 68 Today 1 Now
30 gpd leak equivalent cpm 1980 Today / Now 83 Today 1 Now
50 gpd leak equivalent cpm 3250 Today / Now 206 Today / Now
75 gpd leak equivalent cpm 4850 Today 1 Now 455 Today / Now
150 gpd leak equivalent cpm 9750 Today / Now 870 Today / Now
CVE Air Inleakage cfm 10 Today 1 Now 12.5 Today 1 Now
Bkgd on 99/119 cfm 50 Today 1 Now 40 Today / Now
(
G:\Prep Week files\As SubmittedOperational Exam\Scenarios\Seenario 1\3-19-07 ESG- I TO Sheets.doc 02113/07
APPENDIX C
( 3HIFT TURNOVER CHECKLIST Page 1 of 3 Today
o SM
o US/MeR Unit 1
o UO Unit 1 Off-go ing - Name
o AUO Station SON
o STA (ST A Function) AUO Comp Actions On-coming - Name
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) I
Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600)
(
G:\Prep Week files'As Submitted Operational Exam'Sce narios'Scenario 1\3-19-07 ESG-I TO Sheets.doc 02/ 13/07
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
",',;:Fi'>, " t ,,: .,'" i,f . . " . LC()/ODCMITRM ACnONSf"i~¥; ;; -:""*.' .;:;;1 ' '" " l;Y "o ;~ :J (' *1
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 Wal kdown 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 S ubmitted Operat ional Exam' Scenarios' Scenari o 1\3-19-07 ESG* I TO Sheets.d oc 02/13/07
SHIFT TURNOVER CHECKLIST Page 3 of 3 Today
Disabled Annunciators
( PANEL WINDOW ANNUNCIATOR WO I PER Number
Equipment Off*Normal (Pink Tags)
UNID And Noun Name Pane l Problem Description WO I PER Numb er
MCRWO List
10 And Noun Name Panel Problem Description WOlPER Numb er
I
( (
G:\P rep 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
Nomina l Gallons per rod step from 219: 7 gallons of acid, 36 gallons of water
* Venfy boric acid flow controller IS set at Adjusted SA Co ntroller Se tting law 0-SO-62-7 section 5.1
'--- Gallons of acid: 26 1_' Gallons of water: 138 ~ Rod Steps: 4 _
,, '~"r;f,':¥' :' : <; '< >>t>\ ., ,Estimatea ro~slDbror( for:~merge.ncy steRP'~wer 'reduCtion *~.. *r:z " . > :~J,
, , . ~. ; . (Assuming Xenon e.quilibJiLm and no'r:eac.\ivity effects di.jeto')~enon. 2l3 total'reactivityfrom reds, 1JQfrom boronj .: t i; ':
Power reduction amount Estimated Final Rod Position Est imated 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 appr oxim ations and not intended nor expected to be exact. The values may be sup erceded by
Rx Engineering or SO-62-7 ca lculated va lues. These va lues are ca lculated ass um ing 100% steady state power
ope rat ion only. Engineering data last updated one wee k ago . Data Va lid until one week f rom now .
Numbe r 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
Numbe r 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 :\Pr ep 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 DE LTA RHO BO RON DELTA RECOMMEND RECOMMEND IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DI LUTIO N BORATION CONC (hrs) ( %) (pcm) (s t e p s ) (pcm) (p c m) (p cm) (p pm ) (ppm ) ( g a l) (g a l ) (% eq )
0.0 10 0 .0 1732 . 0 216 . 0 -24 . 5 -2 72 8 . 0 1 0 9 3. 0 100 .0 1.0 93 .0 1608 .0 204.0 - 83 . 7 - 2742 . 5 - 50 . 4 1100 .8 7.8 0 87 99 . 7 2.0 93 .0 1 604 .5 204 .0 - 83 . 7 - 2764 . 3 18.4 1 09 8 .0 -2.9 168 0 99.0 3.0 10 0. 0 17 2 9 . 6 216 .0 -2 4. 5 - 2 7 62 . 9 6 4 .4 108 7 .9 -10 .0 594 0 9 8.8 4.0 10 0 . 0 1 7 34 .4 21 6 . 0 - 24. 5 - 274 7 . 7 - 1 0 .4 1089 .6 1. 6 0 18 98 . 9 5.0 1 00 .0 17 33 . 7 21 6 . 0 - 24 . 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 0 92 .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 10 0 . 0 17 31. 7 216.0 -2 4 . 5 -272 0 . 1 - 4.1 1094 . 3 0.6 0 7 9 9 .3 9 .0 100 .0 17 31. 4 21 6 . 0 - 24 . 5 -2 71 7 . 8 -2 .6 109 4 . 7 0 .4 0 4 99 .3
1 0 .0 1 0 0 .0 17 31.2 2 16 .0 -24 . 5 -2716 . 4 - 1. 5 109 4 . 9 0 .2 0 3 99 . 4 11. 0 100 . 0 17 31.1 216 .0 -2 4 .5 -2715 . 7 - 0.8 1095 . 1 0.1 0 1 99 . 5 12 .0 1 00 . 0 17 31. 0 216 .0 -2 4 .5 -2 715 .6 -0 .2 1095 . 1 0.0 0 0 99 . 5 1 3.0 100.0 1 73 1. 0 21 6 . 0 - 24 .5 - 2 71 5. 7 0.1 10 95 .1 0 .0 1 0 99 .6 14 .0 1 0 0.0 17 31. 0 216 .0 -2 4 .5 -271 6 . 1 0.4 1095 . 0 -0. 1 4 0 99 .6 15 .0 100 . 0 17 3 1.1 216 .0 - 24 . 5 - 2 71 6 . 7 0. 6 10 9 4 . 9 - 0.1 5 0 99 .6 1 6.0 100 .0 17 31.1 216 .0 -2 4 .5 - 2 71 7 . 3 0 .7 109 4 .8 -0 .1 6 0 99 . 7 17.0 10 0 . 0 17 31. 2 21 6 . 0 - 24. 5 - 2 71 8 . 0 0. 7 1094 .7 - 0. 1 7 0 99 .7 18 . 0 10 0 .0 1 73 1.2 216 .0 - 24 . 5 - 271 8.7 0 .8 1 0 94 .6 - 0. 1 7 0 99.7 19 .0 100 . 0 17 31. 3 2 16 .0 - 24 . 5 - 2 71 9 . 4 0.8 1094 .5 - 0.1 7 0 99 . 8 20 . 0 1 00. 0 1731. 3 216 .0 -2 4 .5 - 2 72 0 .1 0.7 109 4 .3 - 0 .1 7 0 99.8 2 1. 0 100 . 0 1 7 31. 4 2 16 . 0 - 24. 5 -2 72 0 . 7 0 .7 1 09 4.2 - 0. 1 6 0 99 . 8 22. 0 10 0. 0 1 7 31. 4 216. 0 -2 4 .5 -272 1 .4 0.7 1 094 . 1 -0 .1 6 0 99.8 23 .0 10 0. 0 17 31. 5 21 6 .0 - 24 . 5 - 272 1. 9 0 .6 109 4 . 0 -0.1 6 0 99 .8 24 . 0 1 00 .0 1 7 31. 5 216.0 - 24 .5 - 2 72 2.5 0.6 1093 . 9 - 0. 1 5 0 99 . 9 25 . 0 1 00. 0 17 31. 6 2 16 .0 - 2 4. 5 -27 23.0 0.5 1093 .8 -0. 1 5 0 99 .9 26 .0 100 . 0 17 31. 6 21 6 .0 - 24 . 5 -2 7 2 3 . 4 0 .5 1 09 3 . 8 - 0 .1 5 0 99 . 9 27 . 0 10 0 . 0 1 731. 6 2 16 .0 - 24 . 5 - 27 2 3 . 9 0.5 10 9 3 .7 - 0 .1 4 0 99 . 9 28 . 0 100 .0 17 31. 7 21 6 .0 - 2 4. 5 - 2 72 4 . 2 0.4 1 093 .6 - 0. 1 4 0 99 .9 29 .0 100 .0 1 731. 7 216 .0 -2 4 .5 -272 4 .6 0 .4 109 3 .6 -0.1 4 0 99.9 3 0 .0 1 0 0. 0 1 73 1.7 216 .0 - 24 . 5 -2 72 4 . 9 0.4 1093 .5 - 0. 1 3 0 99 .9 31. 0 1 00 . 0 17 31. 8 2 16 . 0 - 24.5 - 2725 . 2 0. 3 109 3 . 5 0 .0 3 0 99 .9 32 . 0 10 0 . 0 17 3 1. 8 216 .0 -2 4 . 5 -2725 .5 0 .3 1093 . 4 0 .0 3 0 9 9.9 33 .0 100 . 0 1 7 31. 8 216.0 -24 .5 -2 72 5 . 7 0 .3 1093 .4 0.0 2 0 99 .9 34 . 0 100 .0 1 731 . 8 216 .0 - 24 . 5 - 2725 . 9 0 .2 109 3 . 3 0.0 2 0 99 .9 3 5 .0 1 00 . 0 1 7 31 . 9 216 . 0 - 24. 5 - 2 72 6. 1 0.2 1 093 .3 0.0 2 0 10 0 .0
::--.-, i '""'\., ' -..., "
Unlt 1
36.0 1 0 0. 0 1 7 31. 9 216 .0 -2 4 .5 - 2726 . 3 0 .2 1 09 3 . 3 0 .0 2 0 100 .0
37 .0 1 0 0 .0 17 31. 9 2 16 .0 - 24 . 5 - 2726 . 5 0 .2 1093 . 3 0.0 2 0 1 00 . 0
3 8 .0 100 . 0 1 7 31. 9 2 16 .0 - 2 4. 5 -2 72 6 . 6 0. 2 1093 .2 0.0 1 0 1 00 . 0
39 .0 1 0 0. 0 173 1 . 9 2 16 .0 - 24. 5 - 272 6 . 8 0. 1 1093 .2 0 .0 1 0 1 0 0. 0
40. 0 100 . 0 1 7 31. 9 216 .0 - 24 . 5 -2726 .9 0.1 1093 .2 0 .0 1 0 100 .0
41. 0 10 0 . 0 17 31. 9 216.0 -24. 5 - 2727 . 0 0. 1 1093 .2 0 .0 1 0 100 .0
4 2 .0 100 .0 1 731. 9 216 .0 -24. 5 - 2 72 7.1 0 .1 1 09 3 . 2 0.0 1 0 1 00 . 0
43 .0 100.0 1 7 31. 9 216 .0 - 2 4. 5 -2 72 7 .2 0.1 1 0 9 3 .1 0 .0 1 0 10 0 .0
4 4 .0 1 00 . 0 1 7 32. 0 2 16. 0 -24 . 5 - 2 72 7 . 3 0 .1 1093 . 1 0 .0 1 0 1 0 0. 0
45 .0 1 0 0. 0 17 3 2 . 0 2 16 .0 -2 4. 5 - 2 72 7 . 3 0 .1 1093 . 1 0 .0 1 0 1 0 0 .0
46 . 0 100.0 17 3 2. 0 216.0 - 24 . 5 -2 7 2 7. 4 0.1 1093 . 1 0 .0 1 0 100 . 0
4 7 .0 1 0 0.0 1 7 32. 0 216 .0 - 2 4.5 - 2727 . 5 0.1 1093 . 1 0 .0 1 0 1 00 .0
48 .0 1 00 . 0 17 3 2 . 0 2 16 .0 -24. 5 - 2 72 7 . 5 0 .1 1 09 3 . 1 0 .0 1 0 1 00 . 0
49 . 0 1 0 0. 0 17 3 2 . 0 216 .0 - 24 .5 - 2 7 2 7. 6 0 .1 1093 .1 0 .0 0 0 1 00 . 0
50 .0 100 . 0 17 3 2 . 0 216 .0 - 24 .5 -2 72 7. 6 0 .0 1093. 1 0.0 0 0 100 . 0
51. 0 100 . 0 17 3 2 . 0 216 .0 -2 4.5 -2727.6 0 .0 1093.1 0 .0 0 0 100 . 0
52. 0 1 00 . 0 1 732 .0 216 .0 - 24 .5 - 2727 . 7 0. 0 1093 .1 0.0 0 0 100 . 0
53 . 0 100.0 1 7 32 . 0 2 16 .0 -24 .5 - 2 7 2 7. 7 0 .0 1093 .0 0 .0 0 0 1 0 0. 0
54 .0 100 .0 17 3 2 . 0 216.0 -2 4. 5 -2727 .7 0 .0 1093 . 0 0 .0 0 0 100.0
55 .0 100.0 1 7 32 . 0 21 6 . 0 - 24 . 5 - 2 7 2 7. 8 0 .0 1093.0 0 .0 0 0 1 00 . 0
56 . 0 100.0 1 7 3 2. 0 216 .0 -24 . 5 - 2 72 7 . 8 0 .0 1093 .0 0 .0 0 0 1 0 0. 0
57 . 0 1 0 0. 0 173 2 . 0 216.0 -2 4 .5 -2 72 7 .8 0 .0 1093 .0 0 .0 0 0 100 . 0
58 .0 10 0 .0 17 3 2 . 0 216 .0 - 24 . 5 - 2727 . 8 0 .0 1093 .0 0 .0 0 0 100 . 0
59 .0 100 .0 1 7 32 . 0 216 .0 -24 . 5 -2727 .8 0 .0 1093 .0 0.0 0 0 1 00 . 0
60.0 1 00 . 0 17 3 2. 0 2 16.0 -24. 5 - 2 72 7 . 9 0 .0 1 0 9 3. 0 0 .0 0 0 100.0
Tota l 88 4 166
1 000 IMWD / MTU Ho l d Tavg = Tref + / - 1.5 F Small hourly b o r a t i on / dil u t i o n
682 0 BAT ppm v olumes ma y b e a c c umu l at ed
for l ar ger single addi tions
Reason fo r Downpower Unit 1 Cyc le 1 5 TV test Date RxENG Name Beepe r 70808 Comments
SQN 0-80-62 -7
f 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 One calculation is requ ired for each major change .
NOTE 2 Boric acid amounts to 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 wa ter or boric acid required using TI-44 .
RCS BORON PPM CHANGE
*1t):1 ppm
Current
*
TOTAL GAL(s)
NOTE REACTF datasheets are to be signed by the prepa rer 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 provi ded by Rx. Eng.
[3] ENSURE independently verified by an SRO in acco rdance
with Appendix I.
( END OF TEXT
SQN 0-SO-62-7
BORON CONCENTRATION CONTROL
( 1,2 Rev. 45
Page 29 of 195
Unit_ _ -l-
I _ Date---,,--,,,,"-'"i!-_ _
TrJJ,,!'
6.4 Borate
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 accordanc e 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 0-SO-62-7
BORON CONCENTRATION CONTROL
( 1,2 Rev. 45
Page 30 of 195
Un it. _ Oate _
6.4 Borate (Continued)
[6] PLACE [HS-62-1 40Bl, CVCS Make up Selector Switch to the
BORATE position.
[7] ADJUST [FC-62-1391, Boric Acid Flow Contro ller to the
desired flow rate . /
- 1* - rsr:
[8] SET [FQ-62-139] , Batch Integrator to the desired quantity.
--'--
lSI CV
[9] PLACE [HS-62-1 40Al, Boric Acid to Blender Flow Control
Switch to the START position. I
-1-* - ----c::;-
( [10] ENSURE Boric Acid Pump alig ned to blender in FAST speed
by right red light LIT on [HS-62-230A] OR [HS-62-232AJ.
NOTE Flow oscillations and/or erratic controller resp onse may require
manual opera tion of Boric Acid Flow Cont roller [FC-62-1391
until stable conditions exist.
[11] VERIFY Boric Acid Flow established .
NOTE It may take appro ximately 15 minutes before any changes to
reactivity are indicated on nuclea r instrume ntation or RCS
temperatu re indication.
[12] IF reactor is critical,
THEN
MONI TOR nuclear instrumentation and reactor coolant
temp eratu re 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 0-SO-62-7
BORON CONCENTRATION CONTROL
( 1,2 Rev. 45
Page 31 of 195
Unit'--- _ Date _
6.4 Borate (Continued )
[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.
-1 s ;-
t
cv
( [b] CHECK no primary water flow on eithe r
[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. - 1" -
t
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. -1- "-
t
cv
[h] IF RCS boron sample required , THEN
NOTIFY Chem Lab to obtain RCS boron sample.
" "
SQN 0-SO-62-7
( 1,2 BORON CONCENTRATION CONTROL Rev. 45
Page 32 of 195
Unit. _ Date _
6.4 Borate (Continued)
NOTE 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 requireme nts 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. o
End of Section 6.4
(
Seq uoyah Nuclear Plant
(
Un it 1 & 2
Genera l Operating Instructions
O-GO-5
NORMAL POWER OPERATION
Revision 0047
Qual ity 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 .
c.
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Page 2 of 93
Table of Contents 1.0 INTRODUCTION 3 1.1 Purpose : 3 1.2 Scope 3 2.0 REFERENCES 4 2.1 Performance References 4 2.2 Developmental References 5 3.0 PRECAUTIONS AND LIMITATIONS 6 3.1 Precautions , , 6 3.2 Limitations 11 4.0 PREREQUiSiTES 14 5.0 INSTRUCl:IONS 16 5.1 Power Ascension From 30% to 100% 17 5.2 At Power Conditions 58
(
5.3 Power Reduction From 100% to 30% 64
5.4 Power Coastdown at End of Life " 77
5.5 LOAD FOLLOW OPERATIO NS __ 82
6.0 RECORDS 86
Append ix A: DELETED 87
Appe nd ix B: TURBINE RUNBACK RESTORATION 88
Ap pendi x C: ISOLATION OF MSR STARTUP VENTS 90
Appe nd ix 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 operati ons, and Load Follow
operations.
This instruction provides additional guidance for turbine control restoration following
a turbin e 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 Rang e Neutron Flux Channel Calibration By Heat
Balance Comparison
P. 0-SI-CEM-000-050.0, 72-Hour Chemistry Requirements
Q. 0-SI-CEM-0 30-407.2, Radioactive Gaseous Waste Effluent Particulate and
Iodine Dose Rates from Shield and Auxiliary Building Exhausts
(Wee kly/Special) and Condenser Vacuum Exhausts (Special)
R. 0-SI-CEM-030-415.0 , Gaseous Efflu ent Requirements (Gross Alph a, 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 Refere nces
A. Mem orandum 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 Lette r GP 86-02( B44 86 1112 002)
G. SSP-2.3, Administration of Site Procedures
H. TVA-NQA-PL N89-A
I. GOI.J 0, Reactivity Contro l at End of Cycle Life (Troja n Nuclear Plant)
J. FSAR, Section 13.5
K. Memo from Reactor Engineering - Aug ust 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 T8502M A) 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 powe r asce nsion are controlled by
stay ing within system parameters and by recomme ndations from the Chemistry
Section.
G. The valve position limiter should be periodically positioned appro ximately 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 faste r 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 fat igue crack ing in the blades . Off-frequency
operation is permitted to the degree and time limit specified on the chart
"Off-Frequency Turb ine Operation", Figure A.26 of TI-2 8.
J. The potential exists for condensation formation in steam extraction lines when
feedwater heaters are isolated.
K. Initial Startup After Refueling - After refueling operat ions, 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 dete rmine
procedure performance. [C.3]
1. At < 50% RTP a flu x 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
perfo rmed , EAGLE-21 updated prior to increasing power, a flux map , a hot
channel factor determination, an axial imbalance comparison may be
requi red 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
( Paq e 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 West inghouse recommendations, a lowe r
power ramp rate limit has been implemented for power levels above the
intermediate power threshold. The Intermediate Power Thres hold is
uniUcycle dependent and is determ ined by the Vendo r. 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 depend ing 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. U0 103 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 reacto r power
rate-of-change fitted over a 1 hour period. U0104 is used in
demon strating compliance with fuel pre-conditioning power ramp rate
limits.
d. Point K0058 is the current ly qualified (or pre-cond itioned) 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-trans ient 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 concentrat ion 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
T AVG 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 GO I 6 for MVAR limits.
R. Main Generator operation withou t Automatic Voltag e control requires that
Narrati ve 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 GO I-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 Conde nsate Demineralizer pumps are in service. Current
practice is to run two Cond DI Pumps and I or throttle the conde nsate
( system to reduce backpressu re. The preferred method is to throttl e
condens ate pressure instead of running only two Conden sate
Demineralizer booster pumps at full power due to pump runout concerns.
2. Siemens-Wes tinghouse 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 backpressu re 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 .
(
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Pace 12 of 93
3.2 Limitations (c ontinued)
H. The following Main Turbine vibration limitations and actions should be adhered
to :
1. Vibration levels wh ich exceed 7 mils (alarm setpo int) should be verified by
Predictive Maintenance Group .
2. Vibratio n levels greater than 7 mils and less than 14 mils should be
continuously monitored by Predictive Maintenance Group .
3. IF vibration level is grea ter 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 coole r up to appro ximately
729-MW turbine load .
K. To ensure sufficient voltage for a safe shutdo wn after loss of both units, voltage
and reac tive power shou ld be maintained within the limits of GOI-6.
L. With LEFM calorimetric power indication available, full power operation is
defined as approximately 3455 MW T not to exceed 3455.0 MW T averaged over
a 8-hour period. [C.1] If LEFM is available, power shall be monitored using
plant computer point U211 8 Instantaneous Value. DO NOT allow averag e
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 ente red.
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 unava ilable , 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
l .. 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
STARTUP No. _ Unit l Date nil.,
4.0 PREREQUISITES
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 T REF.
[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
STARTUP Noo _ Unit I Date~
4.0 PREREQUISITES (continued)
[9] ENSURE each performer documents their name and initials :
Pr in t 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
Append ix 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. _ Unit _ _ Date _
5.1 Power Ascension From 30% to 100%
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] ENSURE Section 4.0, Prerequisites complete.
[2] 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100 % (continued)
NOTES
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 (XI-92-5005B) YES D NO D
N-42 (XI-92-5006B) YES D NO D
N-43 (XI-92*5007B ) YES D NO D
N-44 (XI-92-5008B) YES D NO D
[4.4] IF any of the above steps are checked NO,
THEN
PERFORM O-SI-OPS-092-078.0.
SQ N NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Paqe 19 of 93
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
NOTES
1) With reactor enginee ring concu rrence, 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 perfo rmed 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
exceedi ng 50% rated therma l power: (May be performed in
any order)
[5.1] 0-SI-NUC-000-126.0, Hot Channel Factor Determination.
(
Rx Eng Date
[5.2] 0-SI-NUC-092-079.0, Incore-Excore Axial imba lance
Comparison.
Rx Eng Date
[5.3] 0-PI-NUC-0 92-002.0, Detector Single Point Alignment.
Rx Eng Date
(
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Pane 20 of 93
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (con ti nued)
[5.4J 0-PI-IXX-092-N45.0, PR NIS Calibration.
MIG Date
[5.5] PR High Flux Trip reset to 109%. [C.3].
MIG Date
[5.6] Applicable portions of 0-RT-NUC-000-0010
COMPLETE for operation above 50% power.
Rx Eng Date
[6J DETERMINE the following from TI-40 AND RECORD in
narrative log AND below:
[6.1J Reactor preconditioned power level. _ o
[6.2J Ramp rate restrictions. _ o
NOTE
N/A Substep 5.1[6.3] and 5.1[6.4] if not initial startup after refueling outage.
[6.3] Intermediate power threshold _ o
[6.4] Ramp Rate above the intermediate power threshold.
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. _ Uni t _ _ 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 necessa ry
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) V alve position limit and governor control meter are displayed on EHC Display
panel 1,2-XX-047-2000 (M-2).
4) Act ions 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
perfo rmance.
[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
Contro l 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 T REF
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 . o
[11.2] MONITOR pressurizer level on program
(25 to 60% as a function of TAVG). 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%. Automat ic 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 Sect ion 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). o
[1 1.6] IF main feedwater reg. valves are NOT maintaining
within the 5% band, THEN
NOTIFY Instrument Maintenance. o
CAUTION
The potential exists for condensation formation in steam extraction lines when
feedwater heaters are isolated.
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 Ascensio n From 30% to 100% (co ntinued)
[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. o
( [15.2] Hotwell pump. o
SON NORMAL POWER OPERATIO N 0-GO-5
Unit 1 & 2 Rev. 0047
( Paae 25 of 93
STARTUP No.. _ Unit _ _ Date _
5.1 Power Ascension From 30% t o 100% (continued)
NOTES
1) Whe n placing additional condensate pumps inservice, or HDT pumps in service,
ensu re 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 6.1 r 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
STARTUP No. Unit _ _ Date _
5.1 Powe r Ascensio n From 30% to 100% (con tinued)
CAUTION
Valves 106A and 1068 shall be verified t o 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension Fro m 30% to 100% (con ti nued)
CAUTIONS
1) MSR heatup limits are restricted to 100°F per hour or 25°F in a 15-minute period
(aut omati c mode) or 50°F in a 30*minute period (manua l mode). (SECO limits,
contract 85P62-836839)
2) On t he LP turbi ne in let, do NOT exceed an instantaneous chan ge of 50°F or a
rate of change of 125°F/Hr fo r turbi ne expansion co nsiderations .
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. o
[19.2] CLOSE the following steam inlet leakoff isolation valves:
MSR VA LVE POSITIO N INITIALS
1-679 CLOSED
A-1
1-714 CLOSED
1-680 CLOSED
B-1
1-715 CLO SED
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
SQN NORMAL POWER OPERATION 0-GO-5
Un it 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
perform ed 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
STARTUP No. Unit _ _ Date _
5.1 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 .
[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. _ Uni t _ _ 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. o
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 .
[2 1] 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.
SON NORMAL POWER OPERATION 0*GO*5
Unit 1 & 2 Rev. 0047
( Page 31 of 93
STARTUP No. Unit _ _ Date _
5.1 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.
o
[22.2] CLOSE the drains on the operating main feedwater
pump turbine (N/A other pump).
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 sec ond MFPT is to be placed in service,
THEN
PLA CE 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
NOTE
Th is 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascens ion From 30% to 100% (continued)
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. o
CAUTION
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-S I-NUC-000-1 26.0, Hot Channel Factor Determ ination .
Rx Eng Date
B. 0-SI-NUC-092-07 9.0, Incore-E xcore Axial Imbalance
Com parison .
Rx Eng Date
C. 0-PI-NUC-092-00 2.0 , 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 port ions of 0-RT-NUC-000-001.0 COMPLETE
for operation above 50% power.
Rx Eng Date
[30] WHEN reactor power is appro ximately 49%, THEN
PERFORM the following: (in any order).
r [30 .1] ENSURE indicated Axial Flux Diffe rence is within the
'- limits specified in the CO LR (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. _ o
NOTE
NIA substep 5.1 [31.21and 5.1[31.3] if NOT initial startup after refueling outage.
[31.2] Intermediate power threshold setpoint. _ o
[31 .3] Ramp Rate above the intermediate power threshold. o
(
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Page 37 of 93
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
[32] CONTINUE reactor power ascension to 74%. o
NOTE
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 T REF
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
Un it 1 & 2 Rev. 0047
( Page 38 of 93
STARTUP No. Uni t _ _ Date _
5.1 Power Ascension Fro m 30% to 100% (continued)
[35.2) . VERIFY annunciator XA-55-4B, window B-3:
NIS POWER RANGE
UPPER DETECTOR
HI FLUX DEVN OR is DARK.
AUTO DEFEAT
o
[35.3] VERIFY annunciator XA-55-4B , window C-3:
NIS POWER RANGE
LOWER DETECTOR
HI FLUX DEVN OR is DARK.
AUTO DEFEAT
o
[35.4] VER IFY annu nciator XA-55-4B , window D-4:
COMPUTER ALARM
ROD DEV & SEQ
NIS PWR RANGE is DAR K.
TILTS
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 conde nser 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 (XI-92-5005B) YESD NO D
N-42 (XI-92-5006B) YESO NOD
N-43 (XI-92-5007B) YES 0 NOO
N-44 (XI-92-5008B) YES 0 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
NOTES
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 Ascensio n From 30% to 100% (co nti nued)
CAUTIONS
1) Valves 106A and 106B shall be verified to be operating properly after each #3
HOT pump start.
2) At appro xima 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 w ill be insuffi cient.
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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
CAUTION
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 sucti on 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
CAUTION
After refuel ing , 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 Date
B. O-SI-NUC-092-079.0, lncore-E xcore Axial
Imbala nce Comparison.
Rx Eng 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-N UC-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
STARTUP No. . Unit _ _ Date - - -
5.1 Power Ascension From 30% to 100% (continued)
NOTES
1) O-SI-OPS-092-078 .0 may be performed at the discretion of the Operator if one or more
PRMs is ind ica ting close to the +/- 2% tolerance.
2) Steps 5.1[46] and 5.1[47] may be perfo rmed out of seq uence .
[46] PERFORM the followi ng at approximately 75% reac tor powe r:
[46.1] IF LEFM indication is available , THEN
CALCULATE Calorimetric power:
Calorimetric power= U2118 = - - -% D
34.55
[46.2] IF LEFM indicat ion is NOT available, THEN
CALCULATE reactor power:
Calo rimetric power= U1118 = - - -% D
34.55
[46.3] VERIFY that all NIS Power Range A channel drawers
are with in +/- 2% of the calculated calorimet ric power.
N-41 (XI-92-5005B) YES D NOD
N-42 (XI-92-5006 B) YES D NOD
N-43 (XI-92-5007B) YESD NOD
N-44 (XI-92-5008B) YES 0 NOD
[46.4] IF any of the above steps are checked NO, THEN
PERFORM O-SI-OPS-092-078.0.
SQN NORMAL POWER OPERAT ION 0-GO-5
Unit 1 & 2 Rev. 0047
( Paqe 46 of 93
STARTUP No. _ Unit _ _ Date _
5.1 Power Ascension From 30% t o 100% (continued)
CAUTIONS
1) LCV-6-105A and/or 1058 may be th rottli ng open d ue t o condensate system
pressure being higher t han #3 HOT pump discharge pressure.
2) Turbine runback will occur if #3 HOT pump flow t o 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. _ o
NOTES
1) Operation above 75% Load with only two Hotwell Pumps in service requires further
evaluati on.
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 T REF
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) D
[53.2] [PIS-47*13RLY 3)1 NPSH Protection VLV-6-106B closes
( on #3 HOT pump trip. QJ 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. o
[57.2] INITIATE performance of 1-PI-OPS-000-020.1
or 2-PI-OPS-000-022.1, Appendix B. o
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
(
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Paae 50 of 93
STARTUP No. _ Uni t _ _ 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 U11 18 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 fromT I-40:
[60.1] Power ascension ramp rate from TI-40. _ o
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'--_ _ o
[60.3] Ramp Rate above the intermediate power
threshold.- - - o
[61] CONTINUE power ascension to 100% RTP. o
NOTE
Contro l 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 T REF
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% (co nti nued )
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
mete r; therefore, mon itor t he megawatt meter and valve pos ition limit light
con tinuously during th e fo llowi ng 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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
NOTES
1) Full power ope ration is defined as 100% power operation at app roximately 3455 MW T
instantaneous value, U2118 not to exceed 3455.00 MW T 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 decrea se reacto r 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 MW T (100%) for more than one hour. [C.1]
5) Portions of step 5.1[681 may be perfor med in paralle l with step5.1 [67] if required.
[67] WHEN the unit stabilizes at 100% reactor power,
TH EN
PERFORM the following: (may be performed in any order)
[67.1] ADJUST Governor Valve positio n, rod height, and/or
RCS boron concentration as neces sary 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% (contin ued)
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. D
[67.5] IF river temperature is less than 45°F, THEN
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%) shoul d NOT be used unless
evaluated by Sys tems Engineering si nce this could impact a MFPT's maximum
spe ed and the ability to fUlly load in the even t 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
Uni t 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.
Systems Eng.
[68.2] 0-PI-SXX-000-022.1, Delta T and Tavg Update. [C.7]
Systems Eng..
[68.3] 0-SI-NUC-000-126.0, Hot Channel Factor Determination.
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
STARTUP No. Unit _ _ Date _
5.1 Power Ascension From 30% to 100% (continued)
NOTE
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
c,
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Pace 58 of 93
STARTUP No. _ Un it _ _ Date _
5.2 At Power Conditions
CAUT IONS
1) Full po we 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 sho uld NOT exceed one hour average (U2125 ) of 3455.00 MWT f or more
th an one hour.
3) Power shall NOT exceed an a-hour ave rage value (U2126) of 3455.00 MWT
(readin gs at 0700,1500 and 2300 hours).
NOTES
1) Main Generator operation witho ut Automatic Voltage control requires that Narrative
Log ent ries be made (time, date, reason & duration) and that notification be made to
Operatio ns 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 powe r 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 ] TRE ND Computer point U2118 on a trend recorder in the unit
horseshoe and monitor for increasing reactor power trends
above 3455 MW T . o
[2] IF increasing power trend is observed , THEN
ENSURE PROMPT action is taken to decrease reactor power
as necessary. [C.1)
( 1 st CV
SON NORMAL POWER OPERATION 0-GO-5
Un it 1 & 2 Rev. 0047
( Pace 59 of 93
STARTUP No. _ Unit _ _ Date _
5.2 At Power Conditions (continued)
CAUTION
If LEF M is lost w ith reactor power at 100%, core thermal powe r should NOT be raised
t o 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 CO LR 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 unavailab le,
THEN
PERFORM the following :
[3.1] MONITOR thermal power by using one of the following:
* ICS point U1118 (if available) o
* highest reading NIS power range channel. [C.1] o
[3.2] RESTORE calorimetric power indication prior to next
required performance of O-SI-OPS-092-078.0, o
[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 perform ing O-SI-OPS-092-078.0:
* REDUCE turb ine load as necessary . o
* MAINTAIN T AVG and AFD on program using
boration and/or rod insertion as necessary . o
SQN NORMAL POWER OPERATION O-GO*S
( Unit 1 & 2 Rev. 0047
Page 60 of 93
STARTUP No, _ Unit _ _ Date _
5.2 At Power Conditi ons (continued)
[3.4] PERFORM O-SI-OPS-0 92-078 ,O using U-1118 or
alternate method , o
[3.5] 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
[4 ] MAINTAIN rod control system in automatic to allow prope r
plant response to load redu ctions and runbacks. o
[5] DURING steady state opera tion ~ 85% RTP MAINTAIN contro l
bank 0 greater than 215 steps if possible and A FD within the
nominal +/- 5% target band and also within the AFD limits
spe cified in the COLR. o
[6] DURING steady state operati on < 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. o
[7] OPERATE the turbine in IMP OUT due to inherent system
swings during operation in IMP IN. (Operation in IMP IN is
permitted during governo r valve testinq.) o
NOTE
Valve position limiter shou ld normally be maintained - 2% above governor valve position
unless load swing s occur.
[8] IF unsatisfactory load swings are observed , THEN
ADJUST governor valve position limiter as necessa ry to limit
governor valve motion.
1st CV
(
SQ N NORMAL POWER OPERATION 0-GO-5
Un it 1 & 2 Rev. 0047
( Page 61 of 93
STARTUP No. _ Unit _ _ Date _
5.2 At Power Conditions (conti nued)
CAUTION
Do NOT ra ise t he l im iter position unless the tu rb ine control is posit ive ly co ntro lling
the t urbine (limit light NOT LIT).
[9] IF governor valve motion limiting is no longer needed ,
THEN
[9.1] ADJUST SETTER /REFERENCE contro ls to reduce
turbine loading until the VALVE pas LIMIT light is NOT
LIT. o
[9.2] INCREASE VA LVE pas LIMITER setpoi nt to
- 2% above current load, ENSURIN G load does NOT
change. o
[10] IF an axial xenon osci llation develo ps and requires
suppression, THEN
[10.1] MOVE control bank inward when AFD is moving posit ive
above target A FD, OR
[10.2] MOVE control bank outward when AF D is moving
negative below target AFD, AND
HOLD A FD at target until oscillation is suppressed . o
[10.3] IF this basic first overtone control is insufficient,
THEN
CONTACT Reactor Engineering for assistance. o
(
SON NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Pane 62 of 93
STARTUP No. _ Uni t _ _ Date _
5.2 At Power Conditions (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. 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 gener ator 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 Automa tic 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 recomme nded 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 o
OR
(
SQN NORMAL POWER OPERATION 0-GO-5
Uni t 1 & 2 Rev. 0047
( Paae 63 of 93
STARTUP No. _ Unit _ _ Date _
5.2 At Power Conditions (con tinued)
[12.3] ADJUST turbine load slightly o
OR
[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
STARTUP No. Unit I Date Tu4,
5.3 Power Reduction From 100% to 30%
NOTES
1) Th is section may be used to reduce power to -30% during plant shu tdown OR a
portion of this se ction may be performed to reduce power as req uired by plan t
co ndition s. Steps which are not required for partial load reduction may be marked N/A
with SM conc urrence as specified by SPP-2 .2.
2) Appendix D provides guidan ce on recomme nde d powe r valu es to maintain
condensate pressure if seconda ry plant eq uipment must be remo ved from service for
maintenance.
3) Steps 5.3[2J thro ugh 5.3[6] may be perfo rmed out of seque nce .
[1] ENSURE Section 4.0, Prerequ isites complete. RIll'
[2] REVIEW of Pre cautions and Limitations Section 3.0 has been
completed. ~
[3] NOTIFY RA DCO N of imp ending load red uction . J!(
[4) NOTIFY CON DI operators of load red uct ion and to remove
beds as needed . [B'"
[5] NOTIFY Load Dispatcher of impending load reduction. IQ'"
NOTE
Lowering load on the Main Gen era tor will cause VARs to tre nd in the positive direction
(toward outgoing). This will req uire lowering generator voltage. Refer to GOI-6 Se ction E
for MVAR limits for generator stability.
[6] PERFORM the followi ng as req uired:
[6.1] IF A utomatic Vo ltage Con trol is in service,
THEN
ADJ UST Main Generator VARs USING
[HS- 57-221 Exciter Voltage Auto Adjuster as necessary
during power escalation. !/fl
[6 .2) IF Automatic Vo ltag e Con tro l is NOT in service ,
THEN
ADJUST Ma in Generator VARs USING
[HS-57 -231 Exciter Voltage Base Adjuster as necessary
during power escalation.
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Paqe 65 of 93
STARTUP No, _ Unit I Date~
5.3 Power Reduction From 100"10 to 30"10 (continued)
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 T AVG within limits of T REF. (b) reduce turbine load to
match T REF 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
Uni t 1 & 2 Rev. 0047
( Paqe 66 of 93
STARTUP No. _ Unit _ _ Date _
5.3 Pow er Reduction From 100% to 30% (continued)
[8] MONITOR turbine load decreasing. o
CAUTION
Do NOT exceed a load change rate of plus o r minus 5%/minute or a step change of
10%.
NOTE
T AVG 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] TAVG following TREF program, o
[9,2] 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. o
[9.3] Core AFD within +/- 5% control band around the power
level dependent target value. o
NOTE
Valve position limit and governor control meter are displayed on EHC Display
panel 1,2-XX-047-2000 (M-2).
[9.4 ] Valve position limit approximately 10% above the current
governor control indication as turbine load is changed. o
[1 0] IF AFD remains outside the AFD target band for approximately
30 min or more, THEN
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
STARTUP No. Unit _ _ Date _
5.3 Powe r Reduction From 100% to 30% (con tinued)
NOTES
1) 8 hutdown of the condensate demineralizer booster pumps should be based on header
press ure, 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,
Conde nsate 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
EVA LUATE 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 = - - -% D
34.55
[12.2}- IF LEFM indication is NOT available, THEN
CALCULATE reactor power:
Calorimetric power= U2118 = - - _% D
34.55
[12.3] 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 NOD
N-43 (XI-92-5007B) YES D NOD
N-44 (XI-92-5008B) YES D 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 *13RLY11 1 (Turbine runback from
MFP loss) is NOT LIT.
B. ENSURE [PIS-47*13RLY21 1 (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 K3J 1 (Turbine runback
from NO.3 HOT) REMOVED (Aux Inst Rm R-75).
C. ENSURE jumper betwee n P1 8-1 and P1 8-2 in
Pnl 262, (Closure of LCV-6-106 B 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 _
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.
l
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Page 71 of 93 '.
STARTUP No . Unit _ _ Date _
5.3 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
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 = - - _% D 34.55
34.55
[15.2] IF LEFM indication is NOT available,
THEN
CALCULATE reactor power:
Calorimetric power= U1118 = - - _% D 34.55
34.55
SON NORMAL POWER OPERATION 0-GO-5
Uni t 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 (XI-92-5005B) YES 0 NO 0
N-42 (XI-92-5006B) YES 0 NO 0
N-43 (XI-92-5007B) YES 0 NO 0
N-44 (XI-92-5008B) 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
STARTUP No. Uni t _ _ Date _
5.3 Power Reduc tion From 100% to 30% (continued)
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.
o
[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.
SQN NORMAL POWER OPERATION 0-GO-5
Unit 1 & 2 Rev. 0047
( Page 74 of 93
STAR TUP No. _ Uni t _ _ Date _
5.3 Powe r Reduction From 100% t o 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 = - - _% D
34.55
[19.2J IF LEFM indication is NOT available,
THEN
CALCULATE reactor power:
Calorimetric power= U2118 = - - - % D
34.55
[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-O PS-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
AM8 AC 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 1,2-8 0 -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% (co ntinued)
[23] STAB ILIZE 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% Rea ctor 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. _ Unit _ _ Date _
5.4 Power Coastdown at End of Life
CAUTION
Do NOT exceed the positive Ax ial Flux Difference (AFD) limit of TI*28 d uring power
coastdown.
NOTES
1) The power level of the reactor and turbine slowly coastdown from full power
appro ximately 0.8% per day with TAVG and T REF 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 bum up window if the
normal cycle length is insufficie nt for the calendar refueling date.
2) For core operating recommendations during coastdown or unusual power maneuvers ,
contact Reactor Engineering for guidance. [C.5]
[1] ENSURE Precautions and Limitations have been reviewed. o
[2] ENSURE ReS boron concentrat ion 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.
NOTE
TAV G 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 T AVG on program with T REF 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 Li fe (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 Auto matic 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 T REF,
THEN
WITHDRAW control rods to maintain TAVG on program
USING 0-SO-85-1 .
(
SON NORMAL POWER OPERATION 0-GO-5
Un it 1 & 2 Rev. 0047
( Paae 79 of 93
STARTUP No. Unit Date
5.4 Power Coastdown at End of Life (cont inued)
[8] IF an axial xenon oscillation develops and requires
supp ression, THEN
[8.1] MOVE control bank inward when AF D is moving positive
above target AF D,
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
STARTUP No. Unit _ _ Date _
5.4 Power Coastdown at End o f Life (continued)
NOTE
Th e annu nc iato r fo r Bank 0 Rod Wi thdrawal Lim it High (XA-55-4B, window 21) will be
illuminated wh en rods are wit hdrawn to z 220 steps on 0 control rod bank.
(9) W HEN control rods have been withdrawn to the fully
withd rawn pos ition , THEN
[9.1) DECREASE t urbine load slowly (less than 1% per hour)
as necessary to mainta in TAVG on program with T REF. o
[9.2] MAINTAIN valve posi tion limit approxima tely 10% above
the current governo r control indication as turb ine load is
ch anged . o
CAUTION
( T he governor valve pos ition li mit meter may NOT match the governor valve position
meter; therefore, monitor t h e megawatt meter and valve position lim it light
continuously during t he fo ll owi ng adjustment.
NOTE
O peration with the VA LVE POS LIMIT light LIT is acceptable if unsatisfactory load swings
are experienced .
[10] IF unsatisfactory load swings are expe rienced as the tu rbine
load is dec reased , THEN
[10.1) SLOWLY and CAUTIOUSLY PULSE the governor
VALVE POS ITIO N LIMIT in the LOWER di rectio n wh ile
mo nitoring meg awatts fo r a decrease and the VALV E
POS LIMIT light to ILLUMINATE .
1st CV
[10 .2) WHEN the lim iter just reaches the governor valve
position (Valve Pos Limit light shou ld be lit), THEN
( STOP limiter adjustmen t. o }}