ML19331D952
| ML19331D952 | |
| Person / Time | |
|---|---|
| Site: | Farley  |
| Issue date: | 07/28/1980 |
| From: | ALABAMA POWER CO. |
| To: | |
| Shared Package | |
| ML19331D947 | List: |
| References | |
| 501-7-003, 501-7-3, NUDOCS 8009040393 | |
| Download: ML19331D952 (41) | |
Text
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- ;L 501-7-003 D,a' '~
July 28, 1960 j
Revision 0 '
i FARIrl NUCLEAR PUlc UNIT 2
?HASE III TEST PRCCEDURE 501-7-003 NATURAL CIRCUI.a\ TION WITH SIMULATED LOSS OF POWER CONDITIONS i js '
p,b_xw -
Approved:
Plant Manager Date Issued: I l
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APPENDIX C I 1 X I
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APPENDIX D 1 X ,,_
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501-7-003 '
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FARIrl NUCLEAR PLANT UNIT 2 PEASE III TEST PRCCEDURE 501-7-003 NATURAL CIRCULATION WITH SIMULATED LOSS OF PCWER CONDITIONS 1.0 Purcose This procedure contains the information necessary to verify plant performance capabilities and provide operator experience and training in the following conditions:
1.1 Core heat removal by NATURAL CIRCULATICN WITH SIMULATED LOSS OF OFF-SITE PCWER.
1.2 Core heat removal by NATURAL CIRCULATION WITH SIMULATED LOSS OF ALL CN-SITE AND OFF-SITE PCWER.
2.0 Initial Conditions 2.1 T , is approximately 547*F. The Steam
/ Dt39 is operating (or available) to maintain T,y, in the Steam Pressure Mode.
2.2 Pressurizer pressure is being maintained
/ at approximately 2235 psig by autcmatic operation of the Pressurizer Pressure Control System.
2.3 Pressurirer level is being maintained at
/ approximately 22*; by autcmatic operation of the Pressurirer Level Control System.
2.4 The S/G's are being maintained at approxi-
/ mately 33%. The Main Feedwater or AFW System is operating (or available) to maintain S/G levels.
2.5 All three RC?'s are running.
/
l 2.6 The CVCS is in a normal at-power lineup. l
/ i 2.7 Excess Letdown is available for oceration.
/ l 1 _ _
Rev. O
501-7-003
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2.8 Both Shutdown Banks are fully withdrawn.
/
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.
/
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 paramecers specified in Appendix C of this procedure.
2.14 All test equipment to be used during the
/ performance of this procedure is operational and J
in calibration, as verified on the Test Equipment Record, Data Sheet 1 of this procedure.
2.15 The temporary SSPS and ESF modifications
/ specified in Appendix D of this procedure have been made.
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
- / blowdown may be isolated for the duration of the test.
2.18 Phone communications are available between
/ the Control Room and the Main Steam and Feed Valve Room, 127' Elevation.
2.19 One of the MCB trend recorders is set up
/ to monitor the highest reading T/C in the two hottest core quadrants, as determined by the F-250 incere T/C Map.
2.20 Prior to commencing this test, record the
/ following information (as applicable) on ea-h recorder Strip Chart:
Test Procedure Number Recorder Number Time and Date
' Chart Speed Scale of each Fen Input to each Pen f
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2 - . - -
Rev. O
501-7-003 s ;
3.0 Precautions and Limitations 3.1 During natural circulation operation, Reactor Coolant flow rates are a small fraction of normal 100% flow. Consequently temeerature trends are of great valve in evaluating plant conditions.
Avoid rapid changes in the feeding or steaming 4
j 3.2 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 promi-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 beccme unreliable (due to lodY? low in the RTD manifolds). AT and T andY" shall be Incore T
calculated using wide range thermocouples T 82 monitored will also" tbhho. vide additional Tn ot indication.
3.5 Maintain T at approximately the pre RC? Trip temperature kN order to reduce the errors in the NIS instruments.
3.6 Do not exceed 5% thermal power at anytime during the test.
3.7 Do not exceed a primary to secondary differential pressure of 1600 psi.
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/HR.
3.10 Limit the pressurizer cooldown rate to 200*F/ER.
3.11 Reacter 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 limited to the restrictions of figure 3.4-2 and 3.4-3 in Technical Specifications.
3 Rev. 0 . _ _ _
501-7-003
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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 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 RC? seal injection flow is maintained between 6 and 13 gpm to each RCP. Adjustment of RCP seal injection may become necessary with decreasing primary pressure.
i 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-HV-814@
close spray valves PCV-444C & D, and restart RC?
23 prior to reclesing the Reactor Trip Breakers.
3.17 Maintain control rods greater than 100 steps withdrawn during the conduct of this test. If control rod position cannot meet this criteria, fully insert Control Bank D and restart 2B Reactor Coolant Pump. Contact the Reactor Engineer for further instructions.
3.18 The maximum differential temperature between the pressuriser and the spray water is 320 F.
3.19 Do not use Auxiliary Spray if letdown is isolated.
i 3.20 During the conduct of this test, the Test Supervisor will make determinations relating to the amount of data being recorded (i.e. speed of recorders, collecting of data, etc.). This determination l will be based on the ability of the collected l
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data to adequately reproduce the natural circu-l lation conditions. The Test Supervisor will meet the qualifications of a Test Supervisor as defined in the 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.
4 _
Rev. O
501-7-003 4.0 Instructions 4.1 Prepare the Plant Computer to record the data
/ specified in Appendix C. Record the initial steady state values as specified in Data Sheet 2.
4.2 Place the Pressuriser level controller LK459F
/ in manual and adjust as necessary to establish constant Pressurizer level before tripping the Reactor Coolant Pumps.
4.3 Record the time on the recorder charts
/ in the instrument rack area and/or control Room and start the recorders at an appropriate speed determined by the Test Supervisor.
4.4 Begin recording on the Reactivity Computer.
/
NOTE At the initiation of natural circulation (RC? Trip), the following system response is expected.
a.) Wide range Tugg - increase (7 to 26*F at i percent power) b.) Wide range T - slight decreaseorE8bNtant c.) Core Exit Thermocouple - increase (7 to 26*F at 1 percent power) d.) Pressuriser level - increase (3 to 10 percent at 1 percent power) e.) Pressurizer Pressure - increase i
5 Rev. O
501-7-003 c
CAUTION After tripping the Reactor Coolant Pumps, Reactor Coolant System Pressure is expected to increase as much as 50 psi depending on the power level. Be prepared to use Auxiliary spray to control pressure.
CAUTION Following Reactor Coolant Pu=p trip, T and AT indication will be" E eliable.
NOTE Steam Generator pressure, level and flow condition should be held as close as possible to : stable conditions as natural circulation develops.
4.5 To simulate the loss of offsite power,
/ perforn the following:
4.5.1 Place the Steam Dump Interlock Selector Switches in off for both Train A and Train B. Place the Steam Dump Steam Pressure Controller in manual.
4.5.2 Place the Pressurizer Heater Groups C, D, E in off.
4.5.3 Simultaneously trip all three Reactor Coolant Pumps and the operating Main Feed Pump.
4.6 Observe auto start of all three auxiliary l
/ feedwater pumps and auto isolation of blowdown.
4.7 Place spray valve controllers PK 444C & D
/ in manual and open the Pressurizer Spray valves.
6 _Rev. O
l 501-7-003 l 4.8 If Reactor Coolant System pressure exceeds
/ 2285 psig, open the Auxiliary Spray valve 2-CVC-HV-8145. Maintain regenerative heat ,
exchanger charging outlet temperature above '
350*F and confirm that the 320 F maximum temper-ature differential can be maintained.
4.9 If Reactor Coolant System Pressure exceeds
/ 2310 psig, close charging line ' alve 2-CVC-EV-8146 and manually throttle the spray valves PCV 444C
& D as required to maintain RC Uressure below 2310 psig.
4.10 Maintain RC? Seal Injection between 6 and
/ 13 gpm to each RC?.
4.11 Maintain a constant Reactor Coolant System
/ mass by ensuring charging flow is matched with letdown flow.
NOTE Pressurizer level will increase as Tu increases. After Ty beccM8h stable maintain cone 82nt Pressurizer level by adjusting charging flow.
4.12 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.
4.13 If required, adjrr .h. pressure setpoint
/ on the Steam Genrr n6 Ainospheric Relief Valve Controllers to maintain 3CS cold leg temperatures within 5*F of 547'F.
' T Sr C
501-7-003 O
NOTE Natural Circulation will be stable (within approximately 10 to 20 minutes) when:
a.) ST is constant b.) Wide range Ty is approxi-mately equal-88 core exit thermocouple average tempera-ture.
4.14 When directed by the Test Supervisor (after
/ approximately 30 minutes of steady-state conditions. )
Station personnel in the MSIV Room and man the headsets in preparation for simulated loss of all AC power.
4.15 Shutdown the Lower Equipment Rooms Air Handling
/ Unit.
4.16 Isolate the instrument air to the Turbine
/ Driven Auxiliary feed pump.
NOTE The air accumulator should allow operation of the turbine driven Auxiliary feed pump for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
4.17 Establish communication with sound powered
/ phones between the Auxiliary Feedwater Flow Control Valves, the Atmospheric Relief Valves, the Turbine Driven Auxiliary Feud Pump Room and the control Room.
4.18 Isolate the instrument air to the Turbine
/ Driven Auxiliary Feedwater Pump header flow control valves. Use the handwheels to throttle auxiliary feed flow to the Steam Gencrators on orders from the Control Room.
4.19 Isolate the instrument air to the Atmospheric
/ Relief Valves and control steam flow with the handwheels on orders from the Control Room.
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! 8. Rev. O
501-7-003 4.20 Turn off the Motor Driven Auxiliary Feed Pumps.
/ __
4.21 Turn off Pressurizer Heater Groups A & B.
/
NOTE Auxiliary Spray flow should be reduced as necessary by adjusting the spray valves PCV 444C & D. If necessary, stop all auxiliary spray by opening the normal charging line 2-CVC-EV-8145 and closing 2-CVC-EV-8145 the Auxiliary Spray Valve.
4.22 When directed by the Test Supervisor (after
/ approximately 30 minutes of steady state conditions) perform the following.
4.22.1 Adjust the Steam Dump Steam Pressure
/ Controller for "0" output.
4.22.2 Position the Steam Dump Interlock
/ Selector Switches to ON for both Train A and Train B.
4.22.3 Place the Steam Dumo Steam Pressure
/ Controller in Auto 'and adjust the setpoint to continue to maintain T Cold at a constant temperature.
4.22.4 Return the Atmospheric Relief Valves
/ to normal by opening the instrument air isolation and placing the controllers in Automatic with a setpoint of 1025 psig.
4.22.5 Unisolate the instrument air to the
/ Turbine Driven Auxiliary Feed Pump.
4.22.6 Start the Lower Equipment Room Air
/ Handling Unit.
4.22.7 Place the switches for Pressurirer Heater Groups A, 3, C, D, E to Automatic.
4.23 Fully insert Control Sank D. Verify with
/ the Reactivity Computer that the Reactor is shutdown.
9 Rev. O
501-7-003 4.24 Continue collecting data while the AT reduces
/ to less than 5*F.
4.25 When the AT is < 5*F prepare to start RCP
/ 2B by performing the following.
4.25.1 If Pressure has been controlled
/ with Auxiliary Spray open the normal charging valve 2-CVC-HV-8146 and close the Aux Spray Valve 2-CVC-EV-8145.
4.25.2 Place pressurizer spray valve controllers
/ in manual - closed.
4.26 Verify AT is < 5*F. Start RCP 2B using
/ FNP-2-SOP-1.1. Record data through the Restart.
4.27 When steady state conditions have been reached,
/ restart RCP 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 RCP 2C in accordance with FNP-2-SOP-1.1.
l 4.30 Return pressuriser level control to Automatic.
/
4.31 Return Pressurizer Pressure Control to Automatic
/ by placing the spray valve controllers in Automatic.
4.32 Start a Main Feedwater Pump in accordance with FNP-2-SOP-21.0. Verify the Turbine Driven Auxiliary Feedwater Pump stops. Control Steam Generator levels t3 maintain ~ 33% level.
4.33 Place the Control Switches for the Motor Driven Auxiliary Feed Pumps to Auto.
4.34 Remove ESF and Solid State Protection actua- l
/ tion blocks in accordance with Appendix D, j unless the next test to be performed requires i this modification. If the next tes requires j ESF & Solid State Protection Modification, place N/A in the signature line of the Appendix and ]
initial.
NOTE Re-instate 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 /> i
or more is anticipated.
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501-7-003 O
4.35 Notify the Shift Supervisor that the test is
/ completed.
4.36 Attach the printouts and charts from the recorders
/ and Trend Printer to this procedure, and remove the recorders if this concludes the Natural Circulation testing.
Completed by Time /Date 5.0 Accentance criteria 5.1 Natural circulation cooling can be established
/ and maintained while maintaining S/G 1evels with the Ard Pumps (simulated loss of off-site power) .
5.2 Natural circulation cooling can be maintained
/ while maintaining S/G levels with the TDAEW Pump (simulated loss of on-site and off-site power) .
6.0 References 6.1 PLS Document 6.2 Farley Unit 2 Technical Specifications 6.3 VE?CO North Anna Unit 2 Procedure 2-ST-9 6.4 Westinghouse Safety Evaluation for Farley Unit 2 Natural Circulation Testing l
l _ . 11 Rev. 0
I 501-7-003 l I
7.0 Data Sheets, Appendices, and Attachments 501-7-003 Data Sheet 1: TEST EQUIPMENT RECORD 501-7-003 Data Sheet 2: INITIAL PLANT CONDITIONS 501-7-003 Appendix A: OPERATIONAL SAFETY CRITERIA 501-7-003 Appendix B: TEMPORARY RECORDERS 501-7-003 Appendix C: PROCESS COMPUTER TREND BLOCKS 501-7-003 Appendix D: ESF AND REACTOR PROTECTION MODS 501-7-003 Appendix E: CORE AT WITH NATURAL CIRCULATION 501-7-003 Attachment 1: TRAINING ATTENDANCE SHEE*
l 12 Rev. 0 l
501-7-003
. Data Sheet 1 Eavision 0 Page 1 of 1 ,
DATA SEEET 1 i 1
TEST EQUIPMENT RECORD l l
i TEST EQUIPMENT
t i
t ,
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- This applies only to temporarily installed test equipment or instrumentration. Per::tanent instrumentation which is part of the system and shown on drawings, should not be included.
l l Tes. Supervisor /
Signature Date !
501-7-003
- ** Data Shtot 2 Revision 0 Page 1 of 3 ,
DATA SEEET 2 INITIAL PLANT CONDITIONS - STEADY STATE REACTOR COOLANT SYSTEM Pressurizer Pressure PR-444 (Red Pen) psig Pressurirer Level LR-459 (Red Pen) %
RCS Loop 1 Hot Leg Temperature TR-413 (Red Pen) __
F RCS Loop 1 Cold Leg Temperature TR-410 (Red Pen) *F RCS Loop 2 Hot Leg Temperature TR-413 (Blue Pen) *F RCS Loop 2 Cold Leg Temperature TR-410 (Blue Pen) *F RCS Loop 3 Eot Leg Temperature TR-413 (Green Pen) *F RCS Loop 3 Cold Leg Temperature TR-410 (Green Pen) *F Reactor Coolant Loop 2A T TI-412D F avg Reactor Coolant Loop 23 T avg TI-422D *F Reactor Coolarit Loop 2C T avg TI-432D *F Reactor Coolant Loop 1A AT TI-412A %
l Reactor Coolant Loop 23 AT TI-422A %
Reactor Coolant Loop 2C AT TI-432A %
S M M GENERATORS Steam Generator 2A Level (NR) LI-474 %
Steam Generator 23 Level (NR) LI-484 %
l Steam Generator 2C Level (NR) LI-494 %
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501-7-003
. - Data Sheat 2 Revision 0 Page 2 of 3 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
Steam Generator 2A Feedwater Flow FI-476 x 10 473r, 6
Steam Generaror 23 Feedwater Flow FI-486 x 10 #/hr.
6 Steam Generator 2C Feedwater Flow FI-496 x 10 #/hr.
0 Steam Generator 2A Steam Flow FI-474 x 10 lbs/hr.
6 Steam Generator 2B Steam Flow FI-484 x 10 lbs/hr.
Steam Generator 2C Steam Flow FI-494 x 10 lbs/hr.
REACTOR POWER l l
NIS Channel N-41 %
NIS Channel N-42 %
NIS Channel N-43 %
NIS Channel N-44 %
l NIS Channel NI-35 amps NIS Channel NI-36 amps NOTE Attach a copy of the computer printout of the Incore Thermocouple Temperature Map.
501-7-003
- - Data Sheet 2 RGvision 0 Page 3 of 3 .
MISCELL\NEOUS l TDA?4 Pump Room Temperature (Test Inst.) *F Control Room Temperature (Test Inst.) *F Cutside Air Temperature (Computer) *F i
s Data Taken by /
Signature Date
l 501-7-003 l
. , Appondix A l
' Rsvision 0 l Page 1 of 2 _
i APPENDIX A OPERATIONAL SAFETY CRITERIA During the performance of these tests, plant operations will be controlled or limited by the following set of criteria for operation.
- 1. Operational Guidelines (for all Tests)
- a. Primary System Subcooling (T sat Margin) (later)
- b. Steam Generator Water Level ~ 33 percent
- c. Pressurirer Water Level (1) With RCP's running 1 22 percent Span (2) Natural Circualtion L Value when RCP's are tripped
- d. Loop aT (later)
- e. T (later) ave
- 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.
- a. Primary System Subcooling (Tsat M"#9iU) II"t"#I
- b. Steam Generator Water Level < 5 percent Narrow Range Span
- c. NIS Power Range, 2 Channels > 7 percent i Reactor !
Power
- d. Pressurirer Water Level < 17 percent Spkn or an unexplained decrease of more than (later) percent not concurrent with a T"Y9 change l
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501-7-003
,. .. Appendix A Revision 0 Page 2 of 2 e
- e. Any Loop AT (later)
- f. T,y, (later)
- g. Core Exit Temperature (later) )
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- h. Uncontrolled Rod Motion (later) l l
- 3. Safety Injection must be manually initiated if any of the following !
limits are reached.
- a. Primary System Subcooling (T_ag
= Margin) (later) i
- b. Steam Generator Water Level <0 percent Narrow Range Span or Equivalvent Wide Range level
- c. Centainment Pressure (later)
- d. Pressurirer Water Level < 10 percent Span or an unex-plained decrease of more than 10 percent not concurrent with a T"V9 change.
- e. Pressurirer Pressure Decreases by 200 psi or more in an i unexplained manner.
NOTE l
Safety Injection termination will be in accordance j with the termination criteria set forth in FNP-2-EOP-0. I
501-7-003
, Appendix B Revision 0 Page 1 of 3 '
APPENDIX B TEMPORARY RECORDERS Connect temperary strip-chart recorders as indicated below.
1.0 Reactivity-Computer Recorder
- a. Flux
- b. Average wide range T COLD I
- c. Average wide range TECT
- d. Reactivity NOTE ,
Set the chart speed on the following records to 125 mm/ min.
2.0 Strip-Chart Recorde:: No. 1 Channel Connection Monitorinc 1 F?-4143, Cl-432 RCS Flow, Loop 1 2 FP-424B, Cl-433 RCS Flow, Loop 2 3 FP-4343, Cl-434 RCS Flow, Loop 3 l 4 PP-455F, Cl-428 Pressuriner Pressure 5 LP-4598, Cl-442 Pressurizer Level l
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501-7-003
- AppOndix B-Revision 0 Page 2 of 3 m a
3.0 Strip Chart Recorder No. 2 Channel Connecrion 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-484B, C2-444 S/G No. 2 Pressure 5 LP-484B, Cl-430 S/G No. 2 Level 6 F?-4843, C3-746 S/G No. 2 Steam Flow 4.0 Strip-Chart Recorder No. 3 Channal Connection Monitorinc 1 PP-494B, C2-445 S/G No. 3 Pressure 2 LP-494B, Cl-431 S/G No. 3 Level 3 FP-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-32293, 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, C5-522 RCS Charging 71ow 2 FQY-150, C6-433 RCS Letdown Flow 3 ??-4033, C4-433 Wide Range RCS Pressure
& TD-454, C6-636 Pressurizer Steam Temp.
- 5 TD-453, C6-636 Pressuriner Liquid Temp
501-7-003 Appendix B Rcvision 0 Page 3 of 3 .
6.0 Strip-Chart Recorder No. 5 Channel Connection Monitorinc 1 TP-413A, Cl-435 Wide Range T ECT b E1 2 TP-410A, C2-435 Wide Range T COLD Loop 1 3 TP-423A, Cl-436 Wide Range TEOT E 4 TP-420A, C2-436 Wide Range T COLD E 5 TP-433A, Cl-441 Wide Range TEOT L p3 6 TP-430A, C2-441 Wide Range T COLD Lo p 3 The above installation has been completed and check-out is satisfactory.
Completed by: /
Signature Date Test Supervisor /
Signature Date Tha above installation has been removed.
Completed by: /
Signature Date Test Supervisor /
Signature Date l
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501-7-003 Appendix C
.. l Rcvision 0 Page 1 of 3 l APPENDIX C ci l
, PROCESS CCMPUTER TREND BLCCK A 1 COLUMNS ADDRESS PARAMETER UNITS 1 T0406A RCL A T COLD 2 T0426A RCL B T COLD 3 T0446A RCL C T COLD 4 T0419A RCL A THOT F 5 T0439A RCL B TECT 6 T0459A RCL C TEOT 7 T0400A T gyg LCOP A *F 8 T0420A T LOOP B F AVG 9 T0440A T LCOP C *F AVG
, 10 T0403A AT LCOP A %
i 11 T0423A AT LOOP 3 %
12 T0443A AT LCOP C %
13 F0128A CHARGING FLOW GPM 14 F0134A LETDOWN FLOW GPM 15 U1250 EIGEEST REL FUEL ASSY P%E 16 LO480A PRESSURIZER IEJEL %
17 LO112A VCT LEVEL %
18 U1251 EIGEEST REL ASSY P%1 INDENT
501-7-003 Appendix C Revision 0 Page 2 of 3 PROCESS CCMPUTER TREND BLOCK B 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 S PO420A S/G B PRESS PSIG 6 PO440A S/G C PRESS PSIG 7 PO483A PRESSURIZER P PSIG 8 PO499A RC SYSTEM P PSIG 9 P0142A CHARGING PRESS PSIG 10 UO482 AVG PZR PRESS PSIG 11 UO483 AVG PZR LEVEL %
12 U1118 RX THERMAL POWER MW 13 U1170 AVG T/C TEMP *F 14 AS REQUIRED ECTTEST T/C (QUADRANT 1) ?
15 AS REQUIRED ~ ECTTEST T/C (QUADRANT 2) *F 16 AS REQUIRED EOTTEST T/C (QUADRMT 3) F l l
17 AS REQUIRED HOTTEST T/C (QUADRANT 4) l l
1
501-7-003 Appandix C Revisien 0 l Page 3 af 3 l 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 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 2
11 T0036A INCORE T/C *F 12 T0029A INCORE T/C *F
'l 13 T0030A INCORE T/C 'F 14 T0046A INCORE T/C *F 15 T0048A INCORE T/C *F 16 T0044A INCORE T/C *F 17 PO499A RC SYSTEM P PSIG 18 PO484A PRESSURIZER ? PSIG l
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- 501-7-003 Appendix D Revision 0 Page 1 of 12 1
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 High 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 actuata.on or Safety Injection manual actuation.
- 6. Phase B Isolation system will not b_e_ 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.
- c. Eigh steam Flow coincident with Low-Low T"V" 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 T 3y,.
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- 9. Motor Driven Auxiliary Feedwater Pumps will start from any one of the following:
f 1
- a. LOS? Sequencer signal.
- b. Main Feedwater Pump Trip and NO Blackout signal j 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 from any one of the following:
- a. Undervoltage on 2 of 3 Reactor Coolant 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. Pressurirer Eigh Level
- f. Turbine Trip signal r
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- 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 Flu.t Reactor Power.
- c. Steam Generator Water Level (later) percent NR Level
- 14. The following Reactor Trip signals will not be changed.
- a. Pressurizer Eigh Pressure
- b. Low Feedwater Flow
- c. Safety Injection input
- e. Power Range, Neutron Flux High Positive Rate
- f. Power Range, Neutron Flux High Negative Rate
- g. Source Range, Neutron Flux
- h. Power Range, High Range Neutron Flux.
1.0 Modify the Solid State Protection System for performing Natural Circulation Testing as follows:
1.1 Place Train A Solid State Protection System in Test as follows:
1.1.1 Place the Multiplexer Test switch for Train A in the INEI3IT position. Then, have the Operator close the BY? ASS breaker which parallels the reactor trip i breaker for Train A. Confirm this !
action by verifying the following: l l
1 NOTE A The Cperator must rack-in the 3YPASS breaker prior to closing.
1 1
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l.1.1.1 The General Warning lamp 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 INHIBIT position.
1.2 Install Test Jumpers in Train A Solid State Protection Cabinet as follows:
1.2.1 Using a Test Jumper, connect Universal
( Board A313 pin 36 to logic ground.
i 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 l
1.2.3 Using a Test Jumper, connect Universal l Board A213 pin 42 to logic ground.
A213-42 to logic ground-Train A 1.2.4 Using a Test Jumper, connect Universal l Board A216 pin 36 to logic ground. l A216-36 to logic ground-Train A 1.2.5 Using a Test Jumper, connect Universal ,
Board A312 pin 4 to logic ground. l l
A312-4 to logic ground-Train A i'
1.2.6 Using a Test Jumper, connect Universa' '
Board A313 pin 4 to logic ground.
A313-4 to logic ground-Train A
- 501-7-003 Appcndix D Rcvision 0 Page 5 of 12 l.3 Return Train A Solid State Protection System to service as follows:
1.3.1 Place the Mode Selector switch to CPERATE.
1.3.2 Have the Operator place the following manual block switches for Trains A and B in the BLOCK position.
NOTE Blocks will not be set unless their associated permissives are present.
1.3.2.1 Source Range Block and Reset 1.3.2.2 Intermediate Range Block 1.3.2.3 Power Range Block LO S.P.
1.3.2.4 LO T,y, SI-A(B) Block and Reset 1.3.2.5 LO PRZ SI-A(B) Block and Reset 1.3.3 Place the Input Error Inh 7 bit switch to NORMAL.
1.3.4 Verify that both Reactor Trip Breakers are closed.
1.3.5 Havc 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.
. 501-7-003 i Appendix D Rovision 0 Page 6 of 12 1.3.6 Return the Multiplexer Test switch for Train A to the NORMAL position.
l 1.3.7 Verify that MCB annunciator E24 for
! Train A is extinguished.
s 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 clocing.
(
l.4.1.1 The General ilarning lamp for Train B illuminates.
1.4.1.2 The red breaker position indicator BYB (for Train B under test) is illmainated on the MCB.
1.4.1.3 Annunciator E25, SSPS TR P TRCUBLE actuates.
1.4.2 On the Cutput Relay Test Panel, place the Mode Selector switch in the TEST position and verify that the OPERATE 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 1.5.1 Using a Test Jumper, connect Universal Board A313 pin 36 to logic ground.
A313-36 to logic ground-Train B
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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 Ur.ing 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 f
1.6 Return Train B Solid State ProtIction System to service as follows:
1.6.1 Place the Mode Selector switch to OPERATE.
1.6.2 Have the Operator place the following manual block switches for Trains A and B in the BLCCK position.
NOTE Blocks will not be set unless their associated permissives are present.
1.6.2.1 Source Range Block and Reset 1.6.2.2 Intermediate Range Block 1.6.2.3 Power Range Block.LO S.?. ;
~
- j 1.6.2.4 LO T SI-A(B) Block and )
'- Rese6Y" 1.6.2.5 LO PRZ SI-A(B) Block and Reset
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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 BYPASS 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 B to the NORMAL position.
l 1.6.7 Verify that MCS annunciator E25 for Train 3 is extinguished.
Test Supervisor /
Signature Date i
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501-7-003 Appondix D Rovision 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 Comparator 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-ST?-213.9 2.2 Verify Power Range Low Neutron flux trip is set at percent Reactor Power per FNP-2-STP-228.5, 228.6, 228.7, and 228.8.
2.3 Verify Intermediate Range Neutron flux is set at IR Amps equivalent to percent Reactor Power per ENP-2-STP-228.3 and 228.4.
l Test Supervisor __, /
Signature Date l
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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
( 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 B 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 P
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3.6 Return Train B Solid State Protection System to service in accordance with Section 1.6.
Test Supervisor /
Signature Date I
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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 Comparator 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 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.
Test Supervisor /
Signature Date
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501-7-003 App;ndix E RGvicion 0 Page 1 of 1, APPENDIX E l l
l CORE AT WITH NATURAL CIRCULATION l (Estimated Range) l POWER LEVEL (%) (2) OPERATING LCOPS (3) OPERATING LOOPS 1 (later) (later) 1b (later) (later) 3 (later)
NOTE These values of at reflect an uncertainty of 0.5% core power.
A t
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NOTE The Training Attendance Sheet will be provided in the Control Recm by the Training Depart:nent, prior to the performance of this procedure.
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