ML19331D950
| ML19331D950 | |
| Person / Time | |
|---|---|
| Site: | Farley  |
| Issue date: | 07/26/1980 |
| From: | ALABAMA POWER CO. |
| To: | |
| Shared Package | |
| ML19331D947 | List: |
| References | |
| 501-7-002, 501-7-2, NUDOCS 8009040390 | |
| Download: ML19331D950 (48) | |
Text
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t D RLAET
=01-7-002 July 26, 1980 Revision 0 FARIZE NUCLEAR PLANT 4
UNIT 2
?HASE III TEST PRCCEDURE i
501-7-002 NA"' URAL CIRCULATIC.N o, 2 L4b fd.x'j w
Approved:
Plant Manager Date Issued:
l Diskette No. 4 8009040 390
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LIST OF I: :.CTIYi ?;GES 501-7-002 l *.
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LIST OF E:::.CTIVE PAGES 301-7-002 REVISICN NO. 0 l
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APPENDIX E 1
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501-7-002 FARLEY NUCLEAR PLANT UNIT 2 PHASE III TEST PROCEDURE 501-7-002 NATURAL CIRCULATICN 1.0 Purcose This procedure contains the information necessarf to verify plant performance capabilities and provide operator experience and training in the following conditions:
1.1 Core heat removal by NATURAL CIRCULATION after all RC?'s are stopped.
1.2 Continued NATURAL CIRCULATION WITH LOSS OF PRESSURIZER EEATERS.
1.3 Core heat removal by NATURAL CIRCULATION AT REDUCID RCS PRESSURE.
2.0 Initial Conditions 2.1 T
is approximately 547*F.
The Steam Dump idV8perating (or available) to maintcin T"V" in
/
the Steam Pressure Mode.
2.2 Pressurizer pressure is being thaintained at
/
approximately 2235 psig by automatic operation of the Pressuriner Pressure Control System.
2.3 Pressurizer level is being maintained at
/
approximately 22% by automatic operation of the Pressuriser 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 1evels.
2.5 All three RC?'s are running.
/
2.6 The CVCS is in a normal at-power lineup.
/
2.7
" cess letdown is available for operation.
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t 1
Rev. 0
c 501-7-002 1
2.8 Both Shutdown Banks are fully withdrawn.
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2.9 The reactor is critical at approximately 3%
/
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 moni-
/
tor the parameters specified in Appendix C of this procedure.
2.14 All test equipment to be used during the
/
performance 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 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 Cne 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 incore T/C map.
2.19 Prior to commencing this test, record the
/
following information (as applicable) on each recorder strip chart.
Test Procedure Number Recorder Number Time and Date Chart Speed Scale of each Pen Input to each Pen s.
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501-7-002 e
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 trends are of great valve in evaluating plant conditions.
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 change however, can occur suddenly with large fluctuations.
3.3 The Operational Safety Criteria is to be prominently 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 lo0VIlow in the RTD manifolds).
AT and T shall be calculated using wide range T andV*
y T
Incore thermocouples will also"35 monitored tbhNo. vide additonal T ct indication.
a i
3.5 Maintain T at approximately the Pre-RCP Trip temperature kN order to reduce the errors in the NIS instruments.
l 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 pressuri=er heatup rate to 100 F/ER.
3.10 Limit the pressuri=er cooldown rate to 200* F/ER.
l 3.11 Reactor Coolant System heatup and cooldcun rate should be limited to 50*F/ER.
3.12 The combination of Reactor Coolant System pressure and temperature should be limited to the restric-tions of figure 3.4-2 and 3.4-3 in Technical Specifications.
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I 501-7-002 C
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 RCP 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.
3.16 Should a reactor trip occur while in natural circulation cepration, close the Aux Spray valve 2-CVC-EV-8145, open normal charging valve 2-CVC-HV-8140 close spray valves PCV-444C & D, and restart RCP 23 prior to reclosing the reactor trip breakera.
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 control bank D and restart 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.
3.20 During the conduct of this test the Test Super /isor 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 Supervisor will meet the qualifications of a Test Superiisor as defined in FNP-0-AP-31.
3.21 Anytime speed is changed on any recorder; initials, time, date and speed should be listed on the recorder chart.
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501-7-002 C
4.0 Instructions 4.1 Prepare the plant computer to record the
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Data specified in Appendix C.
Record the initial plant conditions on Data Sheet 2.
4.2 Place the pressurizer level controller
/
LK 459F 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.
/
4.5 On a signal from the Test Supervisor simul-
/
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 Ccolant System cold leg temperatures should be maintained within 5 *F of 547*F.
CAUTION Continously monitor main steam line pressures and carefully control feedwater addition during the transient to insure that differential pressure between any two steam lines is < 100 psid.
4.6 Place the spray valve controllers in manual
/
and open the spray valves.
s.
i-501-7-002 NOTE At the initiation of Natural Circulation (RCP Trip), the following system response is expected:
.-increase (26 to Wide Range Tu8Cer) a.)
45'F at ~3% p b.)
Wide range TCold-slight decrease or constant c.)
Core exit thermocouples-increase (26 to 45*F at ~3% power) d.)
Pressurizer level-increase (10 to 16 percent at ~3% power) e.)
Pressurizer pressure-increase.
CAUTION After tripping the Reactor Coolant Pumps, Reactor Coolant System pressure i
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 Pump trip, T
and aT indication will be unre-if181e.
4.7 If Reactor Coolant System pressure exceeds 2285
/
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 ?
maximum temperature differential between pressu-ri er and spray water is not being violated.
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Rev. O
501-7-002
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4.8 If RCS pressure exceeds 2310 psig, close
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charging line valve 2-CVC-EV-8146 and manually throttle spray valves 444C & 444D as required to
)
maintain RCS Pressure below 2310 psig.
l CAUTION If Auxiliary Spray is initiated to limit RCS pressure, insure that a mi nimum continuous Auxiliary Spray flow is maintained to the pressurizer by turning on one bank of back up pressurizer heaters and adjusting the position of PCV 444C & 444D to maintain the RCS pressure at approximately 2235 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.
NOTE Pressuri=er level will increase as T 0U increases.
After T-becomes stable maintain constant pf8Isurizer level by adjusting charging flow.
4.11 Carefully control steam generator levels at
/
approximately 33% level.
NOTE q
After tripping Reactor Coolant Pumps the I
level may shrink slightly, then swell as i
natural circulation develops.
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l 501-7-002 4.12 If required,. adjust the pressure setpoint
/
on the steam dump pressure controller to maintain RCS cold leg temperatures within :5 F of 547*F.
NOTE Natural circulation flow will be stable (within approximately 10 to 20 minutes) when:
a.
AT is constant.
is approximatelv Wide range T Exit thermocouple b.
~
equal "o core average temperature.
4.13 After natural circulation steady state conditions
/
have been reached, mark each recorder.
Continue recording data for a minimum of 30 minutes.
NOTE Once equilibrium has been established adjust the trend printer printout intervals as specified by the Test Supervisor.
Mark the printout with time, initials and the new printing interval.
4.14 Complete auxiliary spray test Appendix F
/
(this can be performed in conjunction with the above step 4.13 )
4.15 Record the data indicated in Data Sheet 4.
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8 fSrC
501-7-002 l
NOTE The following steps will allow the pressurizer to cool and slowly decrease system pressure.
The purpose is to determine the time that saturation margin can be maintained without the use of pres 1urizer heaters and then verify the nargin can be re-established through charging or secondary stecm flow.
4.16 Turn off the pressurizer heater Groups 2A, 23,
/
2C, 2D, and 2E.
Mark the recorder.
4.17 Stop pressuricer spray by Opening PCV444C & D.
/
NOTE The primary system pressure will now be monitored to determine the rate of depressurizacion.
The saturation margin should be monitored closely.
Increase RCS charging flow when the saturation margin approaches 20*F oc as directed by the Test Supervisor.
Slowly increase the steam flow to the steam dump by manually operating PK 464 when RCS pressure indicates an increasing trend.
l 4.18 Complete Data Sheet 3, Depressurination Rate.
/
4.19 As Reactor Coolant System pressure decreases,
/
reduce RCP seal injection flow rate to maintain 6 to 13 gpm flow to all RC? seals.
4.20 When RCS pressure decreases to 2000 psig
/
verify the F-11 permissive and block the low pressurizer pressure safety injection signal, and close both PORV Block Valves, 2-RC-MOV-8000A and 3.
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9 Rev. O
501-7-002 4.21 When the Test Supervisor determines that suf-
/
ficient data has been collected to determine depressurir.ation rate, mark the recorders.
4.22 Set up conditions for low pressure natural'
/
circulation test.
4.22.1 Decrease RCS pressure slowly to between 20-30 F saturation margin using auxiliary spray, if necessary.
CAUTION Do not go below 20*F saturation margin.
As indicated by the margin to saturation meters.
4.22.2 Once it is determined by the Test
/
Supervisor that RCS pressure and saturation margin meet the intent of this test, establish an increasing RCS pressure by increasing charging flow.
Then slowly increase steam dump flow to increase saturation margin by 10*F.
CAUTION Excessive stean dump flow could cause a large decrease in RCS pressure.
4.23 Once control of saturation margin using charging
/
has been demonstrated or if it cannot be increased in the above mode, turn the pressurizer heaters on and place the pressurizer pressure controller in autcmatic with a setpoint corresponding to 2235 psig.
4.23.1 When RCS pressure increases above
/
2000 psig, open the FORV Block Valves 2-RC-MOV-8000A & 3.
4.23.2 Verify safety injection block is
/
reset above 2000 psig.
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10 Rev. O
501-7-002 4.24 Place the steam dump steam pressure controller
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PK 464 in automatic with a setpoint correspond-ing to a 1005 psig.
4.25 Fully insert Control Bank D.
Verify with
/
the Reactivity Computer that the Reactor is shutdown.
4.26 Continue collecting data while the AT reduces
/
to less than 5*F.
4.27 When the AT is < 5'F prepare to start RCP
/
23 by performing the following:
4.27.1 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.
4.27.2 Place pressuricer spray valve controllers
/
in manual - closed.
4.28 Verify AT is < 5*F.
Start RCP 23 using
/
FNP-2-50P-1.1.
Record data through the restart.
4.29 When steady state conditions have been
/
reached, restart RCP 2A in accordance with FNP-2-SOP-1.1.
Continue recording data through the restart.
4.30 When steady state conditions have been reached,
/
start RCP 2C in accordance with FNP-2-SCP-1.1.
4.31 Stop the recorders and trend printers.
/
4.32 Return pressurizer level control to automatic.
4.33 Verify that the pressuriser pressure controller
/
is in automatic, then place both spray valve controllers in automatic.
4.34 Remove ESF and Solid State Protection actua-
/
tion blocks in accordance with Appendix D, unless the next test to be performed requires this modification.
If the next test requires ESF & Solid State Protection modification, place N/A in the signature line of the appendix and initial.
s 11 Rev. 0
501-7-002 l
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.
4.35 Notify the shift supervisor that the test
/
is completed.
4.36 Using ASME steam tables, determine the satura-
/
tion margin using the pressure and temperature i
recorded on Data Sheet 4 and plot these values along with saturation margins taken from the margin to saturation meters vs. time and attach j
to this procedure.
)
4.37 An evaluation of the accuracy of the satura-
]
/
tion meter should be done at this time.
NOTE This evaluation should include a check of the margin to saturation meter using meter inputs and an evaluation that these meter inputs are representitive of the Reactor Coolant System conditions.
4.38 Attach the printouts and charts from the record-
/
ers and trend printer to this procedure and remove the temporary instrumentation if this concludes the Natural Circulation testing.
Completed by:
Time /Date:
f 22 Rev. 0.
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501-7-002 5.0 Acceptance Criteria, 5.1 Natural circulation is established.
/
5.2 Saturation mar Jin is maintained without
/
pressurizer spray flow.
5.3 Saturation margin is maintained without
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pressurizer heaters and reactor coolant pump flow.
5.4 Saturation meters indicate a saturation
/
margin within 1.0 degree fahrenheit of the margin as determined from the steam tables.
5.5 RCS depressurization rate with loss of
/
pressuriser heaters is determined.
5.6 Effects of charging and steam flows on
/
saturation margins are determined.
6.0 References
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6.1 PLS Document 6.2 Farley Unit 2 Technical Specifications t
6.3 VEPCO North Anna Unit 2 Procedure 2-ST-8 6.4 Westinghouse safety Evaluation for Farley Unit 2 Natural Circulation Testing.
7.0 Data Sheets, Appendices, and Attachments 501-7-002 Data Sheet 1:
TEST EQUIPMENT RECORD 501-7-002 Data Sheet 2:
INITIAL PLANT CONDITIONS 501-7-002 Data Sheet 3:
DEPRESSURIZATICN RATE 501-7-002 Data Sheet 4:
MARGIN TO SATURATION 1
501-7-002 Appendix A:
OPERATIONAL SAFETY CRITERIA 501-7-002 Appendix 3:
TEMPCRARY RECORDERS
501-7-002 o
4 501-7-002 Appendix C:
PROCESS CCMPUTER TREND BLCCKS f
501-7-002 Appendix D:
ESF AND REACTOR PROTECTICN MODS.
501-7-002 Appendix E:
CO?2 AT WITH NATURAL CIRCULATION 501-7-002 Appendix F:
AUXILIARY S? RAY TEST 502-7-002 Attachment 1:
TRAINING AT"'ENDANCE SHEET 1
1 14 Rev. O
l 501-7-002 Data Shoot 1 Revision 0 Page 1 of 1 DATA SEEET 1 TEST EQUI? MEN"' RECORD TEST EQUI? MENT
USED f
l 1
4
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This applies only to temporarily installed test equipment or instrumentration.
Permanent instrumentation which is part of the system and shown on drawings, should not be included.
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Test Supervisor
/
Signature Date
501-7-002 Data Shoot 2 Rovision 0 Page 1 of 3 DATA SEEET 2 INITIAL PLANT CONDITIONS - STEADY STATE REACTOR COOLANT SYSTEM Pressuriner Pressure PR-444 (Red Pen) psig Pressurizer Level LR-459 (Red Pen)
RCS Loop 1 Ect 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 Hot 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,yg TI-422D F
Reactor Coolant Loop 2C T,yg TI-432D F
i Reactor Coolant Loop 2A AT TI-412A Reactor Coolant Loop 23 AT TI-422A Reactor Coolant Loop 2C AT TI-432A i
i STEAM GENERATORS j
Steam Generator 2A Level (NR)
LI-474 Steam Generator 23 Level (NR)
LI-484 Steam Generator 2C Level (NR)
LI-494
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501-7-002 Data Shcot 2 Rcvision 0 Page 2 of 3 1
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 2B Pressure PI-484 psig Ste W Generator 2C Pressure PI-494 psig 6
Steam Generator 2A Feedwater Flow FI-476 x 10
- 4jgr, 6
Steam Generator 2B Feedwater Flow FI-486 x 10
- /hr.
6 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 2B Steam Flow FI-484 x 10 lbs/hr.
1 6
Steam Generator 2C Steam Flow FI-494 x 10 lbs/hr.
REACTOR POWER
.)
NIS Channel N-41 l
NIS Channel N-42 NIS Channel N-43 NIS Channel N-44 NIS Channel NI-35 amps NIS Channel NI-36 amps NOTE Attach a copy of the computer printout of the Incore Thermoccuple Temperature Map.
501-7-002 Data Shoot 2 Rnvision 0 Page 3 of 3 MISCELLANECUS TDAFW Pump Room Temperature (Test Inst.)
- F Control Room Temperature (Test Inst.)
- F Outside Air Temperature (Computer)
- F Data Taken by
/
Signature Date
l 501-7-002 Data Shcot 3 Revision 0 Page 1 of 1 e
DATA SEEET 3 DE?RESSURIZATION RATE Using data from the Computer Trend printout and the Brush Recorder charts, starting after equilibrum has been reached, calculate the Depressuri=ation Rate and the Pressuri=er Cooldown Rate (liquid temperature) and record results below.
NOTE Attach copiar of the Computer Trend print-out and the. Brush Recorder charts to this page.
Dcpressurization Rate psig/hr.
Pressuriser Cooldown Rate
- F/hr.
I t
!alculated by Rcviewed by Date NOTE A plot of the RCS Depressurization Rate vs. time can be made from the attached data if desired.
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501-7-002 Appandix A Revision 0 Page 1 of 2 APPENDIX A OPERATIONAL SAr~ETY 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 M^#9 ")
(1"E*#)
i 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 '2est termination must occur if any of the following limits are reached.
i a.
Primary System Subcooling (T M*#9 O)
(1^t*f) sat b.
Steam Generator Water Level
< 5 percent Narrow Range Span c.
NIS Power Range, 2 Chamels
> 7 percent Reacter
?ower d.
Pressurizer Water Level
< 17 cercent Scan
'or an uneicplained decrease of more than (later) percent not concurrenr with a T"V9 change
501-7-002 Appandix A R2 vision 0 Page 2 of 2 s
i e.
Any Loop AT (later) i f.
T (1"D"#)
ave g.
Core Exit Temperature (later) h.
Uncontrolled Rod Motion (later) 3.
Safety Injection must be manually initiated if any of the following limits are reached.
a.
Primary System subcooling (T Margin)
(later) sat b.
Steam Generator Water Level
<0 percent Narrow Range Span or Equivalvent Wide Range level c.
Containment Pressure (later) d.
Pressurirer Water Level
< 10 percent Span or an unex-plained decrease of more than 10 parcent not concurrent with a T"Y9 j
change.
e.
Pressuriser Pressure Decreases by 200 psi or more in an rnexplained manner.
NOTE Safety Injection termination will be in accordance with the termination criteria set forth in FNP-2-EOP-0.
~
501-7-002 Appcndix B Revision 0 Page 1 of 3 TEMPORARY RECORDERS Conncct temporary strip-chart recorders as indicated below.
1.0 Reactivity-Computer Recorder a.
Flux b.
Average wide range TCOLD c.
Average wide range TECT d.
Reactivity NOTE Set the chart speed on the following records to 125 mm/ min.
2.0 Strip-Chart Recorder No. 1 Channel Connection Monitoring 1
FP-414B, C1-432 RCS Flow, Loop 1 2
FP-424B, Cl-433 RCS Flow, Loop J 3
FP-4343, Cl-434 RCS Flow, Loop 3 4
??-455F, C1-428 Pressurizer Pressure 5
LP-459B, Cl-442 Pressuriser Level
l 501-7-002 Appendix B Revision 0 Page 2 of 3 9
3.0 Strip Chart Recorder No. 2 Channol 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-484B, C2-444 S/G No. 2 Pressure 5
LP-484B, C1-430 S/G No. 2 Level 6
F?-4843, C3-746 S/G No. 2 Steam Flow 4.0 Strip-Chart Recorder No. 3 Channel Connection Monitoring i
PP-494B, C2-445 S/G No. 3 Pressure 2
LP-4943, 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-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 l
5.0 Strip-Chart Recorder No. 4 Channel Connection Monitoring 1
FQY-122, C6-522 RCS Charging Flow 2
FQY-150, CS-433 RCS Letdown Flow 3
PP-403B, C4-433 Wide Range RCS Pressure 4
TD-454, C6-636 Pressurizer Steam Temp.
5 TD-453, C6-636 Pressurizer Liquid Temp
501-7-002 Appendix 3 Revision 0 Page 3 of 3 _
6.0 Strip-Chart Recorder No. 5 Channel Connection Menitorinc 1
T?-413A, C1-435 Wide Range T Loop i EOT 2
T?-410A, C2-435 Wide Range T cop 1 COLD 3
TP-423A, C1-436 Wide Range T L
p2 EOT 4
T?-420A, C2-436 Wide Range T bUOE COLD 5
TP-433A, C1-441 Wide Range T Loop 3 ECT 6
TP-430A, C2-441 Wide Range T Loop 3 COLD Tho above installation has been completed and check-out is satisfactory.
Ccmpleted by:
/
Signature Date Test Supervisor
/
Tha above installation has been removed.
Completed by:
/
Signature Date Test Supervisor
/
l Signature Date
501-?-002 i
Appsndix C RGvision 0 Page 1 of 3 APPENDIX C l
PROCESS CCMPUTER TREND BLOCK A COLUMNS ADDRESS PARAMETER UNITS 1
T0406A RCL A TCOLD 2
T0426A RCL B TCOLD 3
T0446A RCL C TCOLD 4
T0419A RCL A TECT 5
T0439A RCL 3 TECT 6
T0459A RCL C TECT 7
T0400A T
LOOP A
'F gyg 8
T0420A T
LCOP B F
gyg I
9 T0440A T
LCOP C
- F gyg 10 T0403A AT LOOP A 11 T0423A AT LOOP B 12 T0443A AT LCOP C 13 F0128A CHARGING FLOW GPM 14 F0134A LETDOWN FLCW GPM 15 U1250 EIGEEST REL FUEL ASSY PWR 16 LO480A PRESSURIZER LEVEL 17 LO112A VCT LEVEL 18 U1251 EIGEEST REL ASSY PWR INDENT
~-
501-7-002 a
AppOndix C Revision 0 Page 2 of 3,
PROCESS CCMPUTER TREND BLCCK B COLUMNS ADDRESS PARAME m 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 PSId 10 UO482 AVG PZR PRESS PSIG 1
11 UO483 AVG PZR T.IVEL 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 EOTTEST T/C (QUADRMT 2)
- F 16 AS REQUIRED EOTTEST T/C (QUADRANT 3)
- F 17 AS REQUIRED ECTTEST T/C (QUADRANT 4)
- F
6 501-7-002 Appendix C Revision 0 Page 3 of 3,
PROCESS CCMPUTER 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
- ?
8 T0023A INCORE T/C
- F 9
T0045A INCORE T/C F
10 T0033A INCORE T/C
- F 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 T004aA INCORE T/C
- F l
16 T0044A INCORE T/C
501-7-002 Appnndix D Rcvision 0 Page 1 of 12 APPENDIX D ENGINECED SAFETY FEATURES AND REACTOR PROTECTION MCDIFICATIONS 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.
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 b_e initiated manually by Phase A manual actuation or Safety Injection manual actuation.
6.
Phase 3 Isolation system will not be changed.
7.
Steam Line Isolation will result from any one of the following:
a.
Containment Pressure - High 2.
b.
Steam Line Pressure Low with Manual Unblock.
High 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 T ave'
501-7-002 Appcndix D Rcvision 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.
NOqE 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.
r s Primary Coolant Flow.
b.
Undervoltage c.
Underfrequency d.
Pressurizer Low Pressure e.
Pressurizer Eigh Level f.
Turbine Trip signal
501-7-002 Appendix D Rovision 0 Page 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 l
The following Reactor Trip signals will not be changed.
14.
a.
Pressurizer High Pressure b.
Low Feedwater Flow c.
Safety Injection input d.
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 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:
l 1.1.1 Place the Multiplexer Test switch for Train A in the INHIBIT position.
- Then, have tne Cperator close the SYPASS breaker which parallels the reactor trip breaker for Train A.
Confirm this action by verifying the following:
NOTE The Operator must rack-in the s
3Y? ASS breaker prior to closing.
501-7-002 AppGndix D Rcvicion 0 Page 4 of 12 1
1.1.1.1 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 MC3.
1.1.1.3 Annunciator E24, SS?S TR A TROUBLE actuates.
1.1.2 On the Cutput Relay Test Panel, place the Mode Selector switch in the TEST position and verify that the CPERATE 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 1.2.3 Using a Test Jumper, connect Universal Board A213 pin 42 to logic g-ound.
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 Jesper, 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.
u A313-4 to logic ground-Train A
501-7-002 Appendix D Rsvision 0 Page 5 of 12 1.3 Return Train A Solid State Protection System to service as follows:
1.3.1 Place the Mode Selector switch to 3PERATE.
1.3.2 Have the Operator placs the following manual block switches for Trains A and B in the BLCCK position.
NOTE f
Blocks will not be set unless their associated permissives are present.
1.3.2.1 Scurce 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 SI-A(B) Block and Reset ave 1.3.2.5 LO PRZ SI-A(B) Block and Reset 1.3 3 Place the Input Error Inhibit switch to NORMAL.
1.3.4 Verify that both Reactor Trip Breakers are closed.
1.3.5 Have the Operator open and rack out the BYPASS breaker which was closed in Step 1.1.1.
4 l
NOTE The General Warning lamp should go off.
CAUTICN Prior to performing Step 1.3.6, ensure that a General Warning does not exist for the opposite Train.
501-7-002 Appcndix D Rcvision 0 Page 6 of 12
]
1.3.6 Return the Multiplexer Test switch for Train A to the NCRMAL position.
1.3.7 Verify that MCS annunciator E24 for Train A is extinguished.
1.4 Place Train 3 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 SY? ASS breaker which parallels the reactor trip breaker for Train 3.
Confirm this action by verifying the following:
NOTE The Operator must rack-in the SY? ASS breaker prior to closing.
1.4.1.1 The General Warning lamp for Train 3 illuminates.
1.4.1.2 The red breaker position indicator BY3 (for Train 3 under test) is illuminated on the MC3.
1.4.1.3 Annunciator E25, SSPS TR 3 TROUBLE actuates.
1.4.2 On the output Relay Test Panel, place the Mode Selector switch in the TEST position and verify that the OPERATE lamp goes off.
1.4.3 On the Logic Test Panel place the Input Error Inhibit switch in the INEI3IT position.
1.5 Install Test Jumpers in Train 3 Solid. State Protection Cabinet as follows:
1.5.1 Using a Test Jumper, connect Universal Board A313 pin 36 to logic ground.
s A313-36 to logic ground-Train 3 i
L-
501-7-002 Appandix D acvicion 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 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 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 4
1.6.2.3 Power Range Block LO S.P.
1.6.2.4 LO T SI-A(B) Block and Rese&V*
1.6.2.5 LO PRZ SI-A(B) Block and Reset
~ B
~'v"
501-7-002 Apntndix D Rcvision 0 Page S of 12 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 Eave 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 porition.
1.6.7 Verify that MCB annunciator E25 for Train 3 is extinguished.
Test Supervisor
/
S 2.gnature Date
501-7-002 Appandix D Ravicion 0 Page 9 of 12 2.0 The following Instrumentation Setpoint changes will be made for perforning Natural Circulation Testing.
2.1 Change 17% Steam Generator Lo Lo trip to by adjust:ing the signal comparator card to VDC trip and VDC reset per the following Procedure.
Signal Comoarator Card Procedure No.
LT 474A ENP-2-STP-213.1 LT 475A FNP-2-STP-213.2 LT 476A FNP-2-STP-213.3 LT 484A FNP-2-ST?-213.4 LT 485A EMP-2-STP-213.5 LT 486A FNP-2-STP-213.6 l
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 at parcent 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 FNP-2-STP-228.3 anc 228.4.
i Test Supervisor
/
S 2.gnature Date
501-7-002 App ndix D Rovision 0 Page 10 of 12 e
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 i,n 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 B Solid State Protection Cabinet that were installed in Section 1.5.
3.5.1 Test Jumpers removed:
A313-36 to logic ground-Train B A213-36 to logic ground-Train B A213-42 to logic ground-Train B A216-36 to logic ground-Train B A312-4 to logic ground-Train B A313-4 to logic ground-Train B
]
501-7-002 Appandix D Rcvision 0 Page 11 of 12 c.
3.6 Return Train 3 Solid State Protection System to service in accordance with Section 1.6.
Test Supervisor
/
Signature Date i
.. _, _. -. _ _, _l
501-7-002 Appandix D RGvision 0 Page 12 of 12 O
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 F.4P-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
501-7-002 i
AppOndix E RGvision 0 l
Page 1 of 1,,
APPENDIX E CORE AT WITH NATURAL CIRCULATION (Estimated Range)
POWER LEVEL (%)
(2) OPERATING LCOPS (3) OPERATING LOOPS 1
(later)
(later) 1 (later)
(later) 3 (later)
NOTE These values of AT reflect an uncertainty of 0.5% core power.
s
501-7-002
..i-Appendix F j
Rsvision 0 Page 1 of 2 APPENDIX F c
AUXILIARY SPRAY TEST 1.0 Verify steady state Pressurizer conditions by observing a straight-line trace of Pressurizer pressure on Pressure Recorder PR-444.
1.1 Record Pressurizer pressure as indicated on PI-444.
Pressure psig 2.0 Place Spray Valve controllers PK-444C and D in j
Manual and open Spray Valves 2-RC-PCV-444C and D.
i CAUTION The following steps place the plant in a condition for the establishment of initial baseline data.
A sufficient degree of uncertainty exists such that spray flow may be initiated upon the execution of any step.
Observe ALL available indica-i tions of RCS pressure.
j 1
Do not allow RCS pressure to fall below 2135 psig.
1 Immediately upon any sudden or uncontrol-able pressure decrease, shut Auxiliary Spray Valve 2-CVC-EV-8145 and open Normal l
Charging Line Valve 2-CVC-EV-8146.
If system pressure response becomes unduly sensitive to changes in valve position under these conditions, establish minimum Letdown, balance the Charging Flow for constant Pressurizer level, and reattempt this Test.
1 l
3.0 Open Auxiliary Spray Valve 2-CVC-EV-8145 and i
observe system pressure response.
1 4.0 Close Normal Charging Line Valve 2-CVC-EV-8146 and observe the system pressure response.
l
- P[ *.'
501-7-002 Appondix F Revision 0 Page 2 of 2 m
l l~
2-RC-PCV-444C and then, if necessary, slowly 5.0 Begin slowly closing Pressurizer Spray valve close 2-RC-PCV-444D, while continously observing i
RCS pressure indications.
5.1 Record the following data:
5.1.1 Spray Valves 2-RC-PCV-444C and D positions at which system pressure decrease is first obtained.
2-RC-PCV-444C position 2-RC-PCV-444D position 5.1.2 Charging (Aux. Spray) Flow.
FI-122 gpm 5.1.3 Charging (Aux. Spray) temperature TI-123
- F 5.2 Under the direction of the Shift Supervisor, establish the optimum Spray Valve position operating range for pressure control under these conditions.
i CAUTION During the following step, observe the Margin to Saturation Meters and do not allow the T
system to fall below a 20 F Saturation Margin.
6.0 Reposition Spray Valves 2-RC-PCV-444C and D to the positions established in step 5 above, to maintain minimum Auxiliary Spray flow and observe restoration of system pressure by Automatic Pressurizer Heater Operation.
7.0 Re-establish Charging ud Letdown to the conditions existing prior te step 4.14 in the body of the procedure.
.o 501-7-002 NOTE The Training Attendance Sheet will be provided in the Control Room by the Training Department, prior to the performance of this procedure.
l