ML19331D953
| ML19331D953 | |
| Person / Time | |
|---|---|
| Site: | Farley  |
| Issue date: | 07/29/1980 |
| From: | ALABAMA POWER CO. |
| To: | |
| Shared Package | |
| ML19331D947 | List: |
| References | |
| 501-7-004, 501-7-4, NUDOCS 8009040395 | |
| Download: ML19331D953 (42) | |
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501-7-004 July 29, 1980 Revision 0 FARIEf NUCLEAR FIANT UNIT 2 PEASE III TEST PROCEDURE 501-7-004 DPA%
EFFECT OF S/G SECONDAR'I SIDE ISOLATION ON NATURAL CIRCULATION Approved:
-pp
,_ L Plant. Manager Date Issued:
Diskette No. 5 8 0 OD040 37
LIST OF E rCTIVE PAGES 501-7-004 6
REVISION NO. 0 PAGE NO.
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DATA SH. I 1
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APPENDII 3 1
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i 501-7-004 1
FARIZI NUCLEAR PLANT UNIT 2 PHASE III TEST PROCEDURE EFFECT OF S/G SECONDARY SIDE ISOLATICN ON NATURAL CIRCULATION 1.0 Purpose This procedure contains the information necessary to verify plant performance capabilities and provide operator experience and training in the following conditions :
1.1 S/G SECONDARY SIDE ISOLATION during NATURAL CIRCULATICN Core heat removal.
1.2 Continued Core heat removal during natural circulation with a partial loss of heat sink.
1.3 Restoration of natural circulation in a RCS loop after its S/G is unisolated.
2.0 Initial Conditions 2.1 T
is 515*F 5 F.
The Steam Dump is ocerating (8E*available) to maintain T"V" in the St'eam
/
Pressure Mode.
2.2 Pressurirer pressure is being maintained at
/
approximately 2000 psig by automatic operation of the Pressurizer Pressure Control System.
2.3 Pressurizer level is being maintained at approx-
/
imately 22% by automatic operation of the Pressurirer Level Control System.
2.4 The S/G's are being maintained at approximately
/
33%.
The Main Feedwater or AFW System is operating (or available) to maintain S/G levels.
2.5 All three RCP's are running.
/
l 2.6 The CVCS is in a normal at-power lineup.
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2.7 Excess Letdown is available for operation.
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1 1
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i 2.8 Both Shutdown Banks are fully withdrawn.
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2.9 The Reactor is critical at approximately 1%
/
power.
2.10 RCS Boron Concentration and Control Bank D
/
position have been adjusted to establish a zero Moderator Temperature Coefficient.
2.11 The Core Subcooling Monitor is operable.
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4 1
2.12 Temporary Instrumentation has been installed as
/
required by Appendix 3 of this procedure.
2.13 The Computer Trend Printer is set up to monitor
/
the parameters specified in Appendix C of this procedure.
2.14 All test equipment to be used during the perfor-
/
mance of this procedure is operational and in calibration, as verified on the Test Equipment Record, Data Sheet 1 of this procedure.
2.15 The temporary SS?S and ESF modifications specified
/
in Appendix D of this procedure have been made.
i 2.16 The Shift Supervisor has been notified of the
/
impending performance of this procedure.
2.17 S/G Chemistry is in a condition such that blow-
/ '
down may be isolated for the duration of the test.
2.18 One of the MC3 trend recorders is set up to
/
monitor the highest reading T/C in the two hottest core quadrants, as determined by the P-250 incere T/C Map.
l 2.19 The S/G 2A Atmospheric Relief Valve controller
/
is in AUTO and set at approximately 1025 psig.
j NOTE l
The above condition is necessary to minimize the possibility of lifting S/G 2A safeties when it is isolated.
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2 Rev. O
501-7-004 2.20 Prior to commencing this test, record the
/
following information (as applicable) on each Recorder Strip Chart:
Test Procedure Number i
Recorder Number Time and Date Chart Speed Scale of Each Pen Input to Each Pen 3.0 Precautions and Limitations 3.1 During natural circulation operation, reactor coolant flow rates are a small fraction of normal 100% flow.
Consequently, temperature l
trends are of great value in evalua:Ing plant Conaltlons.
3.2 Avoid rapid changes in the feeding or steaming rate.
Temperature changes will be delayed due to the relatively long loop transit time.
Pressure changes, however, can occur suddenly with large fluctuations.
3.3 The Operational Safety criteria is to be premi-nently displayed in the Control Room.
During the performance of this test, operation of the plant will be in accordance with the guidelines presented in the Operational Safety Criteria, Appendix A.
3.4 After the RCP's have been tripped, the normal AT and T indications will become unreliable (due to lo6VIlow in the RTD manifolds).
AT and T shall be calculated using wide range T andV*
Incore thermocouples will also g,e monitored E
T tgoho. vide additional T cT indication.
c 3.5 Maintain T at approximately the pre-RC? trip temperaturgogg order to reduce the errors in the NIS instruments.
~
3.6 Do not exceed 5% thermal power at any time during the test.
3.7 Do not exceed a primary to secondary differential pressure of 1600 psi.
s e
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1 3.8 Maintain <100 psi differential pressure between any two steam lines and Steam Generator pressure greater than 585 psig.
3.9 Limit the pressurizer heatup rate to 100 F/ER.
i 3.10 Limit the pressuriner cooldown rate to 200'F/ER.
3.11 Reactor Coolant System Heatup and Cooldown Rates should be limited to 50*F/ER.
3.12 The combination of Reactor Coolant System pressure and temperature should be limit;d to th+n restric-tions of figure 3.1-2 and 3.4-3 in Techaical Specifications.
3.13 It is anticipated that the moderator temperature coefficient will be zero or slightly negative during the performance of this test.
It is possible, however, that the moderator temperature coefficient will become slightly positive.
The i
operator should be aware of the effect of a positive moderator coefficient on reactivity control.
3.14 Do not borate while in natural circulation with the reactor critical.
3.15 Ensure RCP seal injection flow is maintained between 6 and 13 gpm to each RC?.
Adjustment of RCP seal injection may become necessary with decreasing primary pressure.
3.16 Should a reactor trip occur while in natural circulation operation, close the Aux. Spray valve 2-CVC-EV-8145, open normal charging valve 2-CVC-EV-8146, close spray valves PCV-444C & D, and restart RCP 23 prior to reclosing the Reactor Trip Breakers.
3.17 Maintain Control Bank D greater than 100 steps withdrawn during the conduct of this test.
If control rod position cannot meet this criteria, fully insert Centrol Bank D and restar 23 Reactor Coolant Pump.
Contact the Reactor Engineer for further instructions.
3.18 The maximum differential temperature between the pressurizer and the spray water is 320 F.
3.19 Do not use Auxiliary Spray if letdown is isolated.
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501-7-004 i
c 3.20 During the conduct of this test, the Test Super-visor will make determinations relating to the amount of data being recorded (i.e. speed of recorders, collecting of data, etc.).
This determination will be based on the ability of the collected data to adequately reproduce the natural circulation conditions.
The Test Super-visor will meet the qualifications of a Test Supervisor as defined in FNP-0-AP-31.
3.21 Any time speed is changed on any recorder, initials, time, date and speed should be listed on the recorder chart.
3.22 When testing with the Reactor Coolant in the low temperature range of 450 to 500*F, maintain the lithium concentration at 2.0 to 2.2 ppm, the upper part ci the lithium range.
This is espe-cially necessary since high boric acid concentrations
(~ 1000 ppm) are being used.
4.0 Instructions 4.1 Prepare the Plant Ccmputer to record the data
/
specified in Appendix C.
Record the initial steady state values as specified in Data Sheet 2.
4.2 Place the pressurirer level controller LK 459F
/
in manual and adjust as necessary to establish constant pressuriser level before tripping the Reactor Coolant Pumps.
4.3 Record the time on the recorder charts in
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the instrument rack area and/or Control Room and start the recorders at an appropriate speed as determined by the Test Supervisor.
4.4 Begin recording on the Reactivity Computer.
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NCTE At the initiation of natural circulation (RCP Trip), the following system response is expected:
Wide range T_b,er) increase (26 to a) 45' Fat ~3%ho e
Sc2L. B
1 501-7-004 i
b)
Wide range T
- slight decrease COLD or constant c)
Core exit thermocouples - increase (26 to 45*F at ~3% pcwer) d)
Pressuriser level - increase (10 to 16 percent at ~3% power) e)
Pressuriser pressure - increase.
CAUTION After tripping the Reactor Coolant Pumps, l
Reactor Coolant System pressure is expected to increase as much as 50 psi depending on the power level.
Be prepared to use Aux.
Spray to control pressure.
CAUTION Following Reactor Coolant Pumo tric, T"V" and aT indication will be unr'eliab'le.
4.5 On a signal from the Test Superrisor, simultan-
/
taneously trip all three Reactor Coolant Pumps.
NOTE Steam Generator pressure, level and flow conditions should be held as close as possible to stable conditions as natural circulation develops.
Reactor Coolant System cold leg temperatures should be maintained within 5*F of 515*F.
['
501-7-004 CAUTION Continuously monitor main steam line pressures and carefully control feed-water addition during tha transient to insure that differential pressure between any two steam lines is <100 psid.
4.6 Place sp ay valve controllers in manual and open
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the spray valves.
4.7 If Reactor Coolant System pressure exceeds 2050
/
psig, open the Auxiliary Spray valve 2-CVC-EV-8145.
Maintain regenerative heat exchanger charging outlet temperature above 350 F by increasing letdown if necessary.
Confirm that the 320*F temperature differential between Pressurizer and spray water is not being violated.
4.8 If RCS pressure exceeds 2075 psig, close charging
/
lane valve 2-CVC-EV-8146 and manually throttle spray valves 444C & 444D as required to maintain k
RCS pressure below 2075 psig.
CAUTION If Auxiliary Spray is initiated to limit RCS pressure, insure that a minimum continuous Auxiliary Spray flow is main-tained to the pressurizer by turning on one bank of backup pressurizer heaters i
and adjusting the position of PCV 444C
& 444D to maintain the RCS pressure at approximately 2000 psig.
4.9 Maintain RCP seal injection between 6 and 13 gpm
/
to each RCP.
4.10 Maintain a constant Reactor Coolant System mass
/
by ensuring charging flow is matched with letdown flow.
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301-7-004
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a NOTE Pressuriser level will increase as T gT increases.
After T becomes stablg maintain constant prk,ssuriser level by y
adjusting charging flow.
4.11 Carefully control Steam Generator levels at
/
approximately 33% level.
NOTE After tripping Reactor Coolant Pumps, the level may shrink slightly then swell as natural circulation develops.
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4.12 If required, adjust the pressure setpoint on
/
steam dump pressure controller to maintain RCS cold leg temperatures within 5*F of 515 F.
NOTE Natural circulation flow will be stable (within approximately 10 to 20 minutes) when:
a.
aT is constant b.
Wide range Two, is approximately equal to core exit thermocouple average temperature.
4.13 Verify / restore the RCS pressure to approximately 2000 psig.
i b
501-7-004 9
NOTE Upon isolating the steam generator in the next step, the primary pressure is expected to increase 100 psi within 10 minutes and the primary to secondary differential pressure is expected to reach 1300 to 1400 psi.
In the event the primary pressure rises to 2075 psig adjust Auxiliary Spray to limit RCS pressure.
NOTE Allow the pressurizer level to increase when T is increased (expected increase is 3/4fY,er 1 F rise in Tave)*
p NOTE
(.
When Steam Generator 2A is isolated, the differential pressure between Steam Generator 2A and the other steam generators is expected to be in the range 50 to 250 psid.
4.14 Isolate 2A Steam Generator by closing the MSIV's
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and Bypass Valves, Steam Generator Slowdown valves, and Auxiliary Feed Regulating Valves or Main Feed Regulating Valve and Bypass Valve as required.
4.15 Carefully control feedwater additions to the
/
remaining steam generators to hold level at approximately 33 percent.
It may be necessary to adjust the steam dump steam pressure controller in the unisolatec loops setpoint to reduce T so that the steam geb $ tor pressure in the isolated loop remains below the 1025 psig setpoint of the Steam Generator Atmospheric Relief Valve.
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/A
501-7-004 o
NOTE During this transient, the following responses can be expected:
1.
Wide range T increase 3
- ROT, to 9*F 2.
Wide range T f# 1 PA increase t gotD
'EOT 3.
Wide range T for loops 3 and C, constEbbusingsteam dump 4.
Core exit thermocouples, increase 3 to 9*F.
5.
Pressurizer level, increase approximately 4 percent 6.
Pressurizer pressure, increase to 2100 psig.
4.16 Allow natural circulatica conditions to stabilize
/
as determined when:
1)
The AT for Loop A is approximately zero and stabilized.
The AT between wide range T for loops 3 and C are constNbI.and T 2)
CCD 3)
The aT between wide range T and core exit thermocouples is constEbb9 is approximately equal Wide range T g,ermoccuples temperature.
4) to core exit'wt 4.17 Slowly reduce the setpoint on the atmospheric
/
relief controller PC-3371A allowing Steam Generator 2A to reach equilibrium with the steam header pressure.
SLOWLY restore deed to the 2A Steam Generator using auxiliary or main feed as applicable to maintain approximately 33 percent leve.l.
4.18 Re-establish blowdown from Steam Generator 2A
/
if required.
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4.19 Open the 2A S/G MISV's using FNP-2-SOP-17.0.
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4.20 Adjust the setpoint on the 2A S/G atmospheric
/
relief valve controller PC-3371A to 1025 psig.
4.21 Allow natural circulation to stabilize as deter-
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nined by:
1)
AT between wide range T and T i8 HOT COLD constant.
2)
AT between wide range T and core exit thermoccuple tempeE2bSre is constant.
is approximately equal Wide range T E,nermoccuple temperature.
3) to core exit" 4.22 Fully insert Control Bank D.
Verify using the
/
reactivity computer that the Reactor is shutdown.
4.23 Continue collecting data while the AT reduces
/
to less than 5*F.
4.24 When the AT is <5 F prepare to start RC? 23 by
/
performing the following.
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4.24.1 Open the normal charging valve 2-CVC-EV-8146 and close the Aux. Spray valve 2-CVC-EV-8145.
4.25 Place the pressurizer spray valve controllers in
/
manual and closed.
4.26 Verify AT is <S*F.
Start RCP 23 in accordance
/
with FNP-2-SOP-1.1.
Record data through the restart.
4.27 When steady state conditions have been reached,
/
restart RC? 2A in accordance with FNP-2-SOP-1.1.
Continue recording data through the restart.
4.28 when steady state conditions have been reached,
/
start RC? 2C in accordance with FNP-2-SOP-1.1.
4.29 Stop the recorders and trend printers.
/
4.30 Return pressurizer level control to automatic.
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4.21 Return Pressuriser Press. Control to automatic
/
by placing the spray valve controllers in automatic, and returning the pressurice.t heater control to automatic.
L5L W
501-7-004 4.32 Return the Steam Dump steam pressure controller
/
setpoint to 1005 psig.
4.33 Remove ESF and Solid State Protection actuation
/
blocks in accordance with Appendix D, unless the next test to be performed requires this modifica-tion.
If the next test requires ESF and Solid State Protection modification, place N/A in the signature line of the appendix and initial.
NOTE Reinstate all safety functions if a delay of testing of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> or more is anticipated.
4.34 Attach the printouts and charts frcm the recorders
/
and trend printer to this procedure and remove the recorders if this concludes the natural i
circulation testing.
4.35 Reset low steam line pressure bistables to
/
585 psig.
4.36 Notify the' Shift Supervisor that the test is complete.
Completed by Time /Date i
i 99; C
501-7-004 o
5.0 Acceptance Criteria 5.1 With a partial loss of heat sink (i.e., one S/G) i sufficient natural circulation flow exisrs.to remove 1*f, reactor power.
5.2 Natural circulation was re-established in the RCS loop after the associated S/G was unisolated.
6.0 References 6.1 PLS Document 6.2 Farley Unit 2 T.chnical Speci. cations 6.3 VE?CO North Anna Unit 2 Procedure 2-ST-il 6.4 Westinghouse Safety Evaluation for Farley Unit 2 Natural Circulation Testing
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7.0 Data Sheets, Appendices and Attachments 501-7-004 Data Sheet 1:
TEST EQUIP M RECORD 501-7-004 Data Sheet 2:
INITIAL PLANT CONDITIONS 501-7-004 Appendix A:
OP m TIONAL SAFETY CRITERIA 501-7-004 Appendix 3:
TEMPORARY RECORDERS 501-7-004 Appendix C:
PROCESS COMPUTER TREND BLCCKS 501-7-004 Appendix D:
ESF AND REACTOR PROTECTION MODS.
501-7-004 Appendix E:
CORE.1T WITH NATURAL CIRCULATION 501-7-004 Attachment 1:
TRAINING ATTENDANCE SEEET l
SLTt M
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501-7-004
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Data Shoot 1 Revision 0 Page 1 of 1 DATA SEEET 1 TEST EQUIPMENT RECORD TEST EQUIPMENT" FNP or CAL DUE DATES DESCRIPTION ID NUMBER DATE USED This applies only to temporarily installed test equipment or instrumentration.
Permanent instrumentation which is pa_~.
of the system and shown on drawings, should not be included.
Test Supervisor
/
Signature Date
501-7-004 Data Shoot 2 Revision 0 Page 1 of 3 l
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DATA SEEET 2 INITIAL PLANT CONDITIONS - STEADY STATE REACTOR COOLANT SYSTEM Pressurizer Pressure PR-444 (Red Pen) psig Pressurizer Level LR-459 (Red Pen)
RCS Loop 1 Eot Leg Temperature TR-413 (Red Pen)
- F RCS Loop 1 Cold Leg Temperature TR-410 (Red Pen)
_F RCS Loop 2 Ect Leg Temperature TR-413 (Blue Pen)
F RCS Loop 2 Cold Leg Temperature TR-410 (Blue Pen)
- F RCS Loop 3 Ect Leg Temperature TR-413 (Green Pen)
- F RCS Loop 3 Cold Leg Temperature TR-410 (Green Pen)
- F Reactor Coolant Loop 2A T,yg TI-412D F
Reactor Coolant Loop 23 T TI-422D
- F avg Reactor Coolant Loop 2C T TI-432D
- F avg Reactor Coolant Loop 2A AT TI-412A Reactor Coolant Loop 23 AT TI-422A Reactor Coolant Loop 2C AT TI-432A STEAM GENERATORS 4
Steam Gererator 2A Level (NR)
LI-474 Steam Generator 23 Level (NR)
LI-484
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Steam Generator 2C Level (NR)
LI-494
501-7-004 Data Shoot 2 Revision 0 Page 2 of 3 c
Steam Generator 1 Level (WR) LR-477 Pen 1 (Red)
Steam Generator 2 Level (WR) LR-477 Pen 2 (Green)
Steam Generator 3 Level (WR) LR-477 Pen 3 (Blue)
Steam Generator 2A Pressure PI-474 psig Steam Generator 23 Pressure PI-484 psig Steam Generator 2C Pressure PI-494 psig 6
I Steam Generator 2A Feedwater Flow FI-476 x 10
- /hr.
6 Steam Generator 23 Feedwater Flow FI-486 x 10
- /hr.
0 i
Steam Generator 2C Feedwater Flow FI-496 x 10
- /hr.
6 Steam Generator 2A Steam Flow FI-474 x 10 lbs/hr.
6 Steam Generator 23 Steam Flcw FI-484 x 10 lbs/hr.
6 Steam Generator 2C Steam Flow FI-494 x 10 lbs/hr.
REACTOR POWER NIS Channel N-41 NIS Channel N-42 1
NIS Channel N-43 1
NIS Channel N-44 l
NIS Channel NI-35 amps NIS Channel NI-36 amps 1
NOTE l
Attach a copy of the computer printout of the Incore Thermoccuple Temperature Map.
l L.
1
501-7-004 Data Shoot 2 Revision 0 Page 3 of 3 J
MISCELLANEOUS TDAW Pump Room Temperature (Test Inst. )
- F Control Room Temperature (Test Inst.)
- F Outside Air Temperature (Computer)
- F S
{
s Data Taken by
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Signature Date
501-7-004 Appcndix A Revision 0 Page 1 of 2 e
APPENDIX A OPERATIONAL SAFETY CRITERIA During the performance of these tests, plant operations will be controlled er limited by the following set af criteria for operation.
1.
Operational Guidelines (for all Tests) a.
Primary System Subcooling (T Margin)
(later) sat b.
Steam Generator Water Level
~ 33 percent c.
Pressurizer Water Level (1)
With RCP's running
> 22 percent Span (2)
Natural Circualtion
> Value when RCP's
~
are tripped d.
Loop AT (later)
T,y, (later) e.
f.
Core Exit Temperature (highest)
(later) g.
Power Range Neutron Flux
< 5 percent Reactor Power h.
Control Bank D (later) 2.
Reactor Trip and Test termination must occur if any of the following limits are reached.
i a.
Primary System Subccoling (T Mo#9 U)
(1***#)
sat b.
Steam Generator Water Level
< 5 percent Narrow Range Span c.
NIS Power Range, 2 Channels
>7 percent Reactor Power d.
Pressuriser Water Level
< 17 percent Span or an unexplained decrease of more than (later) percent not concurrent with a T"V7 l
change
501-7-004 Appsndix A Revision 0 Page 2 of 2 e
e.
Any Loop AT (later) f.
T,y, (later) g.
Core Exit Temperature (later) h.
Uncontrolled Rod Motion (later) 3.
Safety Injection must be manually initiated if any of the followd.1g limits ne reached.
i a.
Primary System Subcooling (T M*#9 2)
(1***#)
sat b.
Steam Generator Water Level
<0 percent Narrow Range Span or Equivalvent Wide Range level c.
Containment Pressure (later) i t
d.
Pressurizer Water Level
< 10 percent Span or an unex-plained decrease of more than 10 percent not concurrent with a T"V9 change.
e.
Pressurizer Pressure Decreases by 200 psi or more in an unexplained manner.
NOTE Safety Injection termination will be in accordance with the termination criteria set forth in ni?-2-EOP-0.
k.
501-7-004 t
Appcndix 3 Revision 0 Page 1 of 3 c APPENDIX 3 TEMPORARY RECORDERS Conn;ct temporary strip-chart recorders as indicated below.
1.0 Reactivity-Computer Recorder a.
Flux b.
Average wide range T COLD c.
Average wide range T ET d.
Reactivity l
NOTE Set the chart speed on the following records to '2s mm/ min.
m 2.0 Strip-Chart Recorder No. 1 I Channel Connection Monitoring 1
F?-414B, Cl-432 RCS Flow, Loop 1 i
2
??-424B, Cl-433 RCS Flow, Loop 2 3
FP-434B, Cl-434 RCS Flow, Loop 3 4
PP-455F, C1-428 Pressuriser Pressure 5
LP-4593, Cl-442 Pressurizer Level s
501-7-004 AppOndix B Revision 0 Page 2 of 3 e 3.0 Strip Chart Recorder No. 2 Channal Connection Monitoring 1
PP-474D, C2-443 S/G No. 1 Pressure 2
LP-474B, Cl-429 S/G No. 1 Level 3
FP-474B, C3-741 S/G No. 1 Steam Flow 4
PP-4843, C2-444 S/G No. 2 Pressure 5
LP-4843, Cl-430 S/G No. 2 Level 6
FP-4843, C3-746 S/G No. 2 Steam Flow 4.0 Strip-Chart Recorder No. 3 Channel Connection Monitoring 1
PP-494B, C2-445 S/G No. 3 Fressure 2
LP-4943, Cl-431 S/G No. 3 Level 3
F?-4943, C3-748 S/G No. 3 Steam Flow 4
FQ-3229A, CJ-234, Pins 21 & 22 S/G No. 1 Aux Feed Flow.
5 FQ-3229B, CJ-234, Pins 29 & 30 S/G No. 2 Aux Feed Flow 6
FQ-3229C, CJ-234, Pins 33 & 34 S/G No. 3 Aux Feed Flow 5.0 Strip-Chart Recorder No. 4 Channel Connection Monitoring 1
FQY-122, C6-522 RCS Charging Flow 2
FQY-150, C6-433 RCS Lerdown Flow 3
PP-403B, C4-433 Wide Range RCS Pressure l 4
TD-454, CS-636 Pressurizer Steam Tamp.
(.
5 TD-453, C6-636 Pressurizer Liquid Temp
501-7-004 Appendix B Revision 0 Page 3 of 3 6.0 Strip-Chart Recorder No. 5 Channel Connection Monitorinc 1
TP-413A, Cl-435 Wide Range T L op 1 ECT 2
T?-410A, C2-435 Wide Range T Loop 1 COLD 3
TP-423A, Cl-436 Wide Range T Loop 2 ECT 4
T?-420A, C2-436 Wide Range T E
COLD 5
TP-433A, C1-441 Wide Range T L
p3 ECT 6
T?-430A, C2-441 Wide Range T L op 3 COLD
- The above installation has been completed and check-out is satisfactory.
Completed by:
/
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Signature Date Test Supervisor
/
Signature Date The above installation has been removed.
Completed by:
/
Signature Date Test Supervisor
/
Signature Date I
501-7-004 Appendix C Revision 0 Page 1 of 3 c
APPENDIX C PROCESS COMPUTER TREND BLCCK A COLUMNS ADDRESS PARAMETER UNITS 1
T0406A RCL A TCOLD 2
T0426A RCL 3 TCOLD 3
T0446A RCL C TCOLD 4
T0419A RCL A T F
HOT 5
T0439A RCL 3 TECT 6
T0459A RCL C TECT 7
T0400A T
LOOP A
- F gyg 8
T0420A T
LOOP 3
- F gyg 9
T0440A T
LOOP C F
gyg
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10 T0403A aT LOOP A 11 T0423A AT LCOP 3 12 T0443A AT LOOP C 13 F0128A CHARGING FLOW GPM 14 F0134A LEIDOWN FLCW GPM 15 U1250 EIGEEST REL FUEL ASSY PWR 16 LO480A PRESSURIZER LEVEL 17 LO112A VCT LEVEL 18 U1251 EIGHEST REL ASSY PWR INDDIT l
s
501-7-004 Appendix C Revision 0 Page 2 of 3 _
PROCESS COMPUTER T M BLOCK 3 COLUMNS ADDRESS PARAMETER UNITS 1
LO400A S/G A LEVEL 2
LO420A S/G B LEVEL 3
LO440A S/G C LEVEL 4
PO400A S/G A PRESS PSIG 5
PO420A S/G B PRESS PSIG 6
PO440A S/G C PRESS PSIG 7
PO483A PRESSURIZER P PSIG 8
P0499A RC SYSTEM P PSIG 9
P0142A CHARGING PRESS PSIG 10 UO482 AVG PZR PRESS PSIG
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11 UO483 AVG PZR LEVEL i
12 U1118 RX THERMAL POWER MW 13 U1170 AVG T/C TEMP F
14 AS REQUIRED ECTTEST T/C (QUADRANT 1)
- F 15 AS REQUIRED ECTTEST T/C (QUADRANT 2)
- F 16 AS REQUIRED EOTTEST T/C (QUADRANT 3)
F 17 AS REQUIRED ECTTEST T/C (QUADRANT 4)
F
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501-7-004 Appendix C Revision 0 Page 3 of 3 e
PROCESS COMPUTER TREND BLOCK C COLUMNS ADDRESS PARAMETER UNITS 1
T0003A INCORE T/C
'F 2
T0006A INCORE T/C
- F 3
T0002A INCORE T/C F
4 T0005A INCORE T/C F
5 T0020A INCORE T/C F
e 6
T0024A INCORE T/C
'F 7
T0022A INCORE T/C
- F 8
T0023A INCORE T/C
- F 9
T0045A INCORE T/C F
10 T0033A INCORE T/C F
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11 T0036A INCORE T/C
- F 12 T0029A INCORE T/C F
13 T0030A INCORE T/C
- F 14 T0046A INCORE T/C F
15 T0048A INCORE T/C
- F 16 T0044A INCORE T/C
501-7-004 Appendix D Revision 0 Page 1 of 12 APPENDIX D ENGINEERED SAFETY FEATURES AND REACTOR PROTECTION MODIFICATIONS During the performance of these tests, modifications will be made to the Engineered Safety Features and the Reactor Protection Systems.
The systems will operate as specified below.
1.
All auto Safety Injection (SI) functions, except Reactor Trip will be blocked.
A Safety Injection actuation signal will result in the following:
a.
Reactor Trip, b.
Control Room Trip Indication and Alarms.
2.
Safety Injection actuation can be initiated by manual switch operation.
3.
The Eigh Steam Line Differential Pressure signal will be blocked.
4.
Containment Spray and actuation system will not be changed.
5.
Containment Phase A Isolation will not operate automa-tically.
It can be initiated manually by Phase A manual actuat:.on or Safety Injection manual actuation.
6.
Phase B Isolation system will not be changed.
7.
Steam Line Isolation will result from any one of the following:
a.
Containment Pressure - Eigh 2.
b.
Steam Line Pressure Low with Manual Unblock.
Eigh Steam Flow coincident with Low-Low T"V" c.
with Manual Unblock.
8.
Feedwater Isolation will result from:
a.
High-Eigh Steam Generator Water Level.
b.
Manual Safety Injection.
c.
Reactor Trip with Low Tave'
501-7-004 Accendix D R'evision 0 Page 2 of 12 9.
Motor Driven Auxiliary Feedwater Pumps will start from any one of the following:
a.
LOSP Sequencer signal.
b.
Main Feedwater Pump Trip and NO Blackout signal present.
c.
2 of 3 Low-Low Level signals on one Steam Generator.
NOTE Setpoint is changed from 17 percent NR Level to 5 percent NR Level.
d.
ESS Sequencer signal following Manual initiation of Safety Injection.
10.
Turbine Driven Auxiliary Feedwater Pump will start frem any one of the following:
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a.
Undervoltage on 2 of 3 Reactor Ccolant Pump Buses.
b.
2 of 3 Low-Low Levels on 2 of 3 Steam Generators.
11.
The following Reactor Trip signals will be blocked.
a.
Overtemperature aT b.
Overpower AT 12.
The following Reactor Trip signals will be blocked by the normal P-7 interlock.
a.
Low Primary Coolant Flow.
b.
Undervoltage c.
Underfrequency d.
Pressurizer Low Pressure e.
Pressurizer Eigh Level f.
Turbine Trip signal l
501-7-004 Appendix D P.cvision 0
? age 3 of 12 13.
The following Reactor Trip signals will be operable at the setpoint specified.
a.
Power Range, Low Range (later) percent Neutron Flux Reactor Power b.
Intermediate Range, (later) percent Neutron Flux Reactor Power.
c.
Steam Generator Water Level (later) percent NR Level 14.
The following Reactor Trip signals will not be changed.
a.
Pressurirer Eigh Pressure b.
Low Feedwater Flow c.
Safety Injection input d.
Manual Reactor Trip Power Range, Neutron Flux High Positive Rate e.
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f.
Power Range, Neutron Flux High Negative Rate g.
Source Range, Neutron Flux h.
Power Range, Eigh Range Neutron Flux.
1.0 Modify the Solid State Protection System for performing Natural Circulation Testing as follows:
1.1 Place Train A Solid Stata Precection System in Test as follcws:
1.1.1 Place the Multiplexer Test switch for l
Train A in the INEIBIT position.
- Then, have the Operator close the 3Y? ASS breaker which parallels the reactor trip breaker for Train A.
Confirm this action by verifying the following:
NOTE k
The Operator must rack-in the SY? ASS breaker prior to closing.
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501-7-004 Appendix D Revision 0 Page 4 of 12 1.1.1.1 The General Warning lang for Train A illuminates.
1.1.1.2 The red breaker position indicator BYA (for Train A under test) is illuminated on the MCB.
1.1.1.3 Annunciator E24, SSPS TR A TROUBLE actuates.
1.1.2 On the output Relay Test Panel, place the Mode Selector switch in the TEST position and verify that the OPERATE lamp goes off.
1.1.3 On the Logic Test Panel, place the Input Error Inhibit switch in the INEIBIT position.
1.2 Install Test Jumpers in Train A Solid State Protection Cabinet as follows:
1.2.1 Using a Test Jumper, connect Universal 1
Board A313 pin 36 to logic ground.
A313-36 to logic ground-Train A 1.2.2 Using a Test Jumper, connect Universal Board A213 pin 36 to logic ground.
A213-36 to logic ground-Train A 1.2.3 Using a Test Jumper, connect Universal Board A213 pin 42 to logic ground.
l A213-42 to logic ground-Train A 1.2.4 Using a Test Jumper, connect Universal Board A216 pin 36 to logic ground.
A216-36 to logic ground-Train A 1.2.5 Using a Test Jumper, connect Universal Board A312 pin 4 to logic ground.
A312-4 to logic ground-Train A 1.2.6 Using a Test Jumper, connect Universal Board A313 pin 4 to logic ground.
A313-4 to logic ground-Train A
501-7-004 Appendix D Revision 0 P age S o f 12 1.3 Return Train A Solid State Protection System to service as follows:
1.3.1 Place the Mode Selector switch to OPERATE.
1.3.2 Eave the Operator place the following manual block switches for Trains A and B i
in the BLOCK position.
NOTE 31ocks will not be set unless their associated permissives are present.
1.3.2.1 Source Range Block and Reset 1.3.2.2 Internediate Range Block 1.3.2.3 Power Range Block LO S.P.
1.3.2.4 LO T SI-A(3) 3 ck and Reset ave 1.3.2.5 LO PRZ SI-A(B) Block and Reset 1.3.3 Pl~ ace the Input Error Inhibit switch to NORMAL.
1.3.4 Verify that both Reactor Trip Breakers are closed.
1.3.5 Eave the Operator open and rack out the BYPASS breaker which was closed in Step 1.1.1.
NOTE The General Warning lamp should go off.
CAUTION Prior to performing Step 1.3.6, ensure that a General Warning does not exist for the opposite Train.
501-7-004 Appendix D l
Revision 0 Page 6 of 12 1
1.3.6 Return the Multiplexer Test switch for Train A to the NORMAL position.
1.3.7 Verify that MCB annunciator E24 for Train A is extinguished.
1.4 Place Train B Solid State Protection System in Test as follows:
1.4.1 Place the Multiplexer Test switch for Train B,in the INEIBIT position.
Then, have the Operator close the BYPASS breaker which parallels the reactor trip breaker for Train B.
Confirm this action by verifying the following:
NOTE The Operator must rack-in the BYPASS breaker prior to closing.
1.4.1.1 The General Warning lamp for Train B illuminates.
1.4.1.2 The red breaker position indicator BY3 (for Train 3 under test) is illuminated on the MCB.
1.4.1.3 Annunciator E25, SSPS TR B TROUBLE actuates.
1.4.2 On the Output Relay Test Panel, place the Mode Selector switch in the TEST position and verify that the OPERA"'E lamp goes off.
1.4.3 On the Logic Test Panel place the Input Error Inhibit switch in the INEIBIT position.
1.5 Install Test Jumpers in Train B Solid State Protection Cabinet as follows:
1.5.1 Using a Test Jumper, connect Universal Board A313 pin 36 to logic ground.
A313-36 to logic ground-Train B
501-7-004 Appendix D Revision 0 Page 7 of 12 1.5.2 Using a Test Jumper, connect Universal Board A213 pin 36 to logic ground.
A213-36 to logic ground-Train B 1.5.3 Using a Test Jumper, connect Universal Board A213 pin 42 to logic ground.
A213-42 to logic ground-Train B 1.5.4 Using a Test Jumper, connect Universal Board A216 pin 36 to logic ground.
A216-36 to logic ground-Train B 1.5.5 Using a Test Jumper, connect Universal Board A312 pin 4 to logic ground.
A312-4 to logic ground-Train B 1.5.6 Using a Test Jumper, connect Universal Board A313 pin 4 to logic ground.
A313-4 to logic ground-Train B
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1.6 Return Train B Solid State Protection System to service as follows:
1.6.1 Place the Mode Selector switch to OPERATE.
1.6.2 Eave the Operator place the following manual block switches for Trains A and B in the BLCCK position.
l l
NOTE Blocks will not be set unless their associated permissives are present.
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l 1.6.2.1 Source Range Block and Reset 1.6.2.2 Internediate Range Block 1.6.2.3 Power Range Block LO S.P.
1.6.2.4 LO T SI-A(B) Block and Rese6V8 1.6.2.5 LO PRZ SI-A(B) Block mad Reset
501-7-004 Apptndix D Revision 0 Page 8 of 12
=l 1.6.3 Place the Input Error Inhibit switch to NORMAL.
1.6.4 Verify that both Reactor Trip Breakers are closed.
1.6.5 Have the Operator open and rack out the SYPASS breaker which was closed in Step 1.4.1.
NOTE The General Warning lamp should go off.
CAUTION Prior to performing Step 1.6.6, ensure that a General Warning does not exist for the opposite Train.
1.6.6 Return the Multiplexer Test switch for Train 3 to the NORMAL position.
1.6.7 Verify that MC3 annunciator E25 for Train 3 is extinguished.
Test Supervisor
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Signature Date e
501-7-004 Appandix D Revision 0 Page 9 of 12 2.0 The following Instrumentation Setpoint changes will be made for performing Natural Circulation Testing.
2.1 Change 17% Steam Generator Lo Lo trip to by adjusting the signal comparator card to VDC trip and VDC reset per the following Procedure.
Signal Comcarator Card Procedure No.
LT 474A FNP-2-STP-213.1 LT 475A FNP-2-STP-213.2 LT 476A FNP-2-STP-213.3 LT 484A FNP-2-STP-213.4 LT 485A FNP-2-STP-213.5 LT 486A FNP-2-STP-213.6 LT 494A FNP-2-STP-213.7 LT 495A FNP-2-STP-213.8 LT 496A FNP-2-STP-213.9 2.2 Verify Power Range Low Neutron flux trip is set
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at percent Reactor Power per FNP-2-STP-228.5, 228.6, 228.7, and 228.8.
j 2.3 Verify Intermediate Range Neutron flux is set at IR Amps equivalent to percent Reactor Power per FNP-2-STP-228.3 and 228.4.
2.4 Change the Low Steamline Pressure Safety Injection Setpoint from 585 psig to psig by adjusting the Signal Comparator Card to VDC trip and VDC reset per the following procedures.
Signal Comparator Card Procedure No.
PT-474A FNP-2-ST?-213.10 PT-485A FNP-2-STP-213.11 PT-496A FNP-2-STP-213.12 Test Supervisor
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Signature Date
501-7-004 Appendix D Revision 0 Page 10 of 12 3.0 Return the Solid State Protection System to Normal, following completion of Natural Circulation Testing or when directed by the Test Supervisor, as follows:
3.1 Place Train A Solid State Protection System in Test in accordance with Steps 1.1.1 through 1.1.3.
3.2 Remove the Test Jumpers from Train A Solid State Protection Cabinet that were installed in Section 1.2.
3.2.1 Test Jumpers removed:
A313-36 to logic ground-Train A A213-36 to logic ground-Train A A213-42 to logic ground-Train A A216-36 to logic ground-Train A A312-4 to logic ground-Train A
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A313-4 to logic ground-Train A 3.3 Return Train A Solid State Protection System to service in accordance with Section 1.3.
3.4 Place Train 3 Solid State Protection System in Test in accordance with Steps 1.4.1 through 1.4.3.
3.5 Remove the Test Jumpers from Train 3 Solid State Protection Cabinet that were installed in Section 1.5.
3.5.1 Test Jumpers removed:
A313-36 to logic ground-Train 3 A213-36 to logic ground-Train 3 A213-42 to logic ground-Train 3 A216-36 to logic ground-Train 3 A312-4 to logic ground-Train 3 A313-4 to logic ground-Train 3
501-7-004 Appendix D Revision 0 Page 11 of 12 3.6 Return Train B Solid State Protection System to service in accordance with Section 1.6.
Test Supervisor
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Signature Date a
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501-7-004 Appendix D Revision 0 Page 12 of 12 j
4.0 Return Instrumentation Setpoints to Normal, following completion of Natural Circulation Testing or when directed by the Test Supervisor, as follows:
4.1 Return Steam Generator Lo-Lo level trip from percent to 17% per the following procedures.
Signal Comoarator Card.
Procedure No.
LT 474A FNP-2-STP-213.1 LT 475A FNP-2-ST?-213.2 LT 476A FNP-2-STP-213.3 LT 484A FNP-2-STP-213.4 LT 485A FNP-2-STP-213.5 LT 486A FNP-2-STP-213.6 L"_' 494A ENP-2-STP-213.7 LT 495A FNP-2-STP-213.8 LT 496A FNP-2-STP-213.9 4.2 Return the Power Range Low Neutron flux trip Setpoint to 25% Reactor power, per FNP-2-STP-228.5, 228.6, 228.7 and 228.8.
4.3 Return the Intermediate Range Neutron flux trip Setpoint to Normal per FNP-2-STP-213.3 and 213.4.
4.4 Restore the Low Steamline Pressure Safety Injection trip Setpoint to 585 psig per FNP-2-STP-213.10, 213.11, and 213.12.
Test Supervisor
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Signature Date s
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501-7-004 Appendix E Revision 0 Page 1 of 1 m
APPENDIX E CORE AT WITH NATURAL CIRCULATION (Estimated Range)
POWER LEVEL (%)
(2) OPERATING LOOPS (3) OPERATING LOOPS 1
(later)
(later) 1 (later)
(later) 3 (later)
NOTE These values of AT reflect an uncertainty of 0.5% core power.
t l-
501-7-004
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NOTE The Training Attendance Sheet will be provided in the Control Room by the Training Department, prior to the performance of this procedure.
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