ML18082A933
ML18082A933 | |
Person / Time | |
---|---|
Site: | Salem |
Issue date: | 08/07/1980 |
From: | Public Service Enterprise Group |
To: | |
Shared Package | |
ML18082A922 | List: |
References | |
90.1, NUDOCS 8008190533 | |
Download: ML18082A933 (24) | |
Text
- STARTUP_ PROCEDURE 90. *1 UNIT NO. 2 NATURAL CIRCULATION TEST SUP-90.l Salem Unit 2 Rev. 2
--1 STARTUP PROCEDURE 90.1
- l. 0 OBJECTIVES 1.1 UNIT NO. 2 NATURAL CIRCULATION TEST To demonstrate the capability to remove decay heat by natural circulation.
1.2 To verify that the pressurizer pressure control system can respond automatically to loss of forced circulation from all four reactor coolant pumps and maintain RCS pressure within acceptable limits, during the coastdown transient.
1.3 To verify that steam generator level and feedwater flow can be controlled under conditions of natural circulation to maintain adequate cooling of the reactor coolant system.
- l. 4 To verify natural circulation flow rates predicted in the FSAR are established, or exceeded after loss of forced RCS flow.
1.5 To document that each Salem Unit 2 licensed operator has operating experience on the unit in the natural circulation mode.
- SUP-90.1 Salem Unit 2 Rev. 2
2.0 REFERENCES
2.1 FSAR table 14 ... 1-3 (attached) 2.2 Salem Unit 2 final Technical Specifications 2.3 Station Operating Instructions EI I-4.0 "Safety Injection Initiation" Rev. 1 EI I-4.9 "Blackout" Rev. B OI II-1.3.1 "RCP operation" Rev. 1 OI II-3.3.1 "Establishing Charging, Letdown and Seal Injection Flow" Rev. 0 OI III-10.3.1 "Auxiliary Feedwater System Operation" Rev. 1 2.4 SUP 90.0, "Natural Circulation Tests Sequencing Document
- SUP-90.1 Salem Unit 2 Rev. 2
---~--,
.O PREREQUISITES 3.1 SUP's 70.4, 70.5, 70.11, 80.3, 80.4, 80.5, 80.6 have been completed. (low power physics testing) 3.2 Reactor Coolant System ambient heat loss has been measured (!AW SUP 90.0 or other estimate)
- 3.3 Preliminary calibration of the P-250 incore flux map short form program under forced circulation has been performed, !AW Appendix C of SUP 90.0 (ref. 2.4).
3.4 Heise guages have been installed on all four Main Stearn loops at any convenient instrument line, e.g. DT 514, 524 etc.
3.5 The NIS power range hi-level, low-range (normally 25%) trip setpoint have been reset to 0.583V. The intermediate range hi-level trips are reset to 28 µa.
(equivalent to 7% power) 3.6 A thermometer has been installed to measure 23 AFP room temperature.
3.7 Fluke DVM(s) have been connected to read the RCS flow transmitters, as outlined in section 7.0.
3.8 P-25~ computer is operational, with a dedicated analog recorder operating as a saturation meter.
3.9 P-250 routines for incore T/C maps and shortform, flux map are operational.
3.10 Reactivity computer operational per paragraph 8.4.
3;11 Brush recorders are set up to record the plant parameters outlined i~ paragraph 8.2. Plant instrumentation monitored by these recorders has been recently calibrated.
3.12 A trend block containing the address points shown in paragraph 8.3 h~s been established on the P-250.
3.13 Verify the input logic of safety injection on Hi steam line t::,.p has been blocked in accordance with A~pendix A, of SUP 90.0 (ref. 2.4).
3.14 Verify the Hi Stearn Flow coincident with Lo S/G pressure or Lo Tavg input to safety injection has been modified in accordance with Appendix A, of SUP 90.0 (ref. 2.4). - The high steam line flow bistables have all been placed in tripped status.
3.15 Verify the automatic actuation of safety injection has been blocked in accordance with Appendix A, of SUP 90.0 (ref. 2.4)
SUP 90.l Salem Unit 2 Rev. 2
3.16 The Test Engineer has conducted a* briefing with all personnel involved in the test. This briefing is conventional SUP briefing, and is in addition to the full-scope shift training mentioned in SUP 90.0.
3.17 The special operator instructions given in SUP 90.0, section 9.1.4 are conspicuously posted on the operator's console.
3.18 Station QA has been notified of the start of this test.
3.19 A temporary 5" chart recorder is installed in the control room, connected to any channel of loop ~T, and calibrated over 0-5% (0-3.1°F) for core power indication with pumps running.
3.20 The steam generator lo, and lo-lo reactor trip setpoints have been reset to 5%
narrow range.
3.21 The over-power and over-temperature ~T trips have been defeated per SUP 90.0 Appendix A.
3.22 The T/E has verified that the Auxiliary Feed Tank temperature instrument is accurate and representative of the feed temperature to the steam generator. This may be accomplished by checking the AF lines at several locations, usi~g a portable pyrometer.
SUP 90.1 Rev. 2 Salem Unit 2 4.0 INITIAL CONDITIONS 4.1 Reactor is critical and manually controlled (in D-Bank Select) at approximately 3% power with Control Bank D at ~ 160 steps as specified by Test Engineer (control by chemical shim as necessary) 4.2 All four Reactor Coolant Pumps are in operation.
4.3 Pressurizer pressure control is in automatic, maintaining RCS pressure at approximately 2235 psig. Pressurizer level control is in manual, maintaining approximately 25% level in the pressurizer .. Pressurizer heaters are all operable.
4.4 Systems required to allow steam dump to the condenser are operational.
4.5 Steam dump valyes are in the pressure control mode, maintaining steam generator pressure at approximately 1005 psig.
4.6 Steam Generator level is being maintained at approximately 33% on the narrow range indicators.
4.7 Auxiliary Feedwater System i'n accordance with OI III-10.3.l.
Put *controller for 2PR2 ~n Manual or turn off the rate and indegradtor circuits.
4.9 RCS temperature (Tavg) is being maintained at approximately 547°F.
4.10 A reasonable steady feed to the steam generators should be established to minimize temperature variation in the RCS.
4.11 The steam generator atmospheric steam dumps (21-24MS-10) are all operable
- SUP 90.l Salem Unit 2 Rev. 2
0 ENVIRONMENTAL CONDITIONS 5.1 Atmosphere steam dump may be required during the performance of this procedure.
6.0 ACCEPTANCE CRITERIA 6 .1 The maintenance "Operator action points" of SUP 9 O. 0, section 9 .1. 4 .. 1 are met throughout this test.
6.2 Delta-T established between wide range That and Tcold for each loop is stable and less than 65°F.
6.3 Tavg for any loop does not exceed 578°F.
6.4 Delta-T established between wide range Tcold and core exit T/C average temperature is stable and less than 65°F.
6.5 RCS flow on natural circulation is stable and meets or exceeds the value given in FSAR table 14.1-3 for the measured reactor thermal power.
6.6 Documentation of all licensed operators participation in the test is recorded on Appendix B.
SUP 90.l Salem Unit 2 Rev. 2
.0 SPECIAL EQUIPMENT 7.1 a) Heise Guage S/G 21 0-2000 psig range + 0.5%
Serial No. Calib. Date b) Heise Guage 5/G 22 0-2000 psig range + 0.5%
Serial No. Ca lib. Date c) Heise Guage S/G 23 0-2000 psig range + 0.5%
Serial No. Calib. Date d) Heise Guage S/G 24 o-aoo psig range + 0.5%
Serial No. Calib. Date NOTE: One Fluke may be used to monitor all 4 loop flows via connection to a suita.ble switching device.
7.2 a) Fluke - RCS loop 21 flow Serial No. Calib. Date b) Fluke - RCS loop 22 flow Serial No. Calib. Date c) Fluke - RCS loop 23 .flow
- Serial No. Calib. Date d) Fluke - RCS loop 24 flow Serial No. Calib. Date NOTE: If desired, one Fluke may be used together with a switbh box.
7.3 Thermometer - Turbine Driven Auxiliary Feed Pump Room Serial No. Calib. Date 7.4 Brush Recorders (3) - connected per paragraph 8.
U Serial No. Calib. Date
- 2 Serial No. Calib. Date
- 3 Serial No.
Calib. Date 7.5 .~ reactivity computer SN Cal. Date 7.6.l Chart Recorder #1 7.6.2 Chart Recorder i2 7.6.3 Chart Recorder #3 7.6.4 Chart Recorder #4 7.6.5 Chart Recorder #5 7.6 Temporary 5". chart recorder for 6T measurement from narrow range RTD's during RCP operation.
Salem Unit 2 SUP 90 .1 Rev. 2
- 8.0 DATA COLLECTION 8.1 All data acquired as a result of performance of this procedure shall be recorded at the appropriate step, on the check-off sheets or affixed as appropriate.
8.2 Three Brush recorders will be utilized and connected as shown to monitor the following test parameters. Channels monitored may be changed at the direction of the test engineer.
Brush Recorder No. l Transmitter Monitoring Parameter Range Channel No. 1 FT414 RCS Flow Loop 21 0-10% flow Channel No. 2 FT424 RCS Flow Loop 22 0-10% flow Channel* No. 3 FT434 RCS Flow Loop 23 0-10% flow Channel No. 4 FT444 RCS Flow Loop 24 0-10% flow Channel No. 5 PT474 Pressurizer Pressure 1600-2400 psig Channel No. 6 LT461 Pressurizer Level 0% - 100%
Brush Recorder No. 2 Transmitter Monitoring Parameter Range Channel No. l FA-1087 Aux. Feed flow 0-300 gpm to S/G 21 Channel No. 2 LT-517 S/G 21 Level 0-100%
Channel No. 3 PT-516 S/G 21 Pressure 700-1200 psig Channel No. 4 FA-1091 Aux. Feed flow 0-300 gpm to S/G 22 Channel No. 5 LT-527 S/G 22 Level 0-100%
Channel No. 6 PT-526 S/G 22 Pressure 700-1200 psig Brush Recorder No. 3 Transmitter Monitoring Parameter Range Channel No. l FA-1095 Aux. Feed flow 0-300 gpm to S/G 23 Channel No. 2 LT-537 S/G 23 Level 0-100%
Channel No. 3 PT-536 S/G 23 Pressure 700-1200 psig Channel No. 4 FA-1097 Aux. Feed flow 0-300 gpm to S/G 24 Channel No. .5 LT-547 S/G 24 Level 0-100%
Channel No. 6 PT-546 S/G 24 Pressure 700-1200 psig 8.3 Two P-250 trend blocks will be set up to monitor the following computer points.
(Additional points may be added as required by the test engineer)
- Address P0480A L0480A Parameter Pressurizer Pressure Pressurizer Level (PT-455)
(PT-459)
SUP 90.l Salem Unit 2 Rev. 2
- Address T0419A T0406A T0439A Parameter RCS Loop 21 Hot Leg Temperature RCS Loop 21 Cold Leg Temperature RCS Loop 22 Hot Leg Temperature T0426A RCS Loop 22 Cold Leg Temperature T0459A RCS Loop 23 Hot Leg Temperature T0446A RCS Loop 23 Cold Leg Temperature T0479A RCS Loop 24 Hot Leg Temperature T0466A RCS Loop 24 Cold Leg Temperature P0400A Steam Generator 21 Pressure (PT-514)
L0400A Steam Generator 21 Narrow Range Level (LT-519)
P0420A Steam Generator 22 Pressure (PT-524)
L0420A Steam Generator 22 Narrow Range Level (LT-829)
P0440A Steam Generator 23 Pressure (PT-534)
L0440A Steam Generator 23 Narrow Range Level (LT-539)
P0460A Steam Generator 24 Pressure (PT-544)
L0460A Steam Generator 24 Narrow Range Level (LT-549)
N0049A Power Range Channel N41 (Loop 24)
N0050A Power Range Channel N42 (Loop 21)
N005lA Power Range Channel N43 (Loop 22)
N0052A Power Range Channel N44 (Loop 23)
Selected TOOOlA thru T0065A Hottest T/C quadrant 1 Selected T0001A thru T0065A Hottest T/C quadrant 2 Selected TOOOlA thru T0065A Hottest T/C quadrant 3 Selected TOOOlA thru T0065A Hottest T/C quadrant 4 U0090A Hottest Incore T/C T0482A Pressurizer Surge Line temperature
<, As required As *required As required 8.4 Reactivity Computer Chart Recorders.
8.4.l Recorder U Channel A p-computer output Channel B N-41 excore detector current 8.4.2 Recorder #2 Channel A Loop 21 Tc TE 413 B 510-610°F Channel B Loop 21 Th TE 413 A 510-610°F 8.4.3 Recorder #3 Channel A Loop 22 Tc TE 423 B 510-610°F Channel B Loop 22 Th TE 423 A 510-610°F 8.4.4 Recorder i4 Channel A Loop 23 Tc TE 433 B 510-610°F Channel B Loop 23 Th TE 433 A 510-610°F 8.4.5 Recorder ts Channel A Loop 24'Tc TE 443 B 510-610°F Channel B Loop 24 Th TE 443 A 510-610°F SUP 90.1 Salem Unit 2 Rev. 2
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- 8.5 Reactivity computer - recorder will be used to monitor core reactivity and flux.
Tavg and Tref will not be used - see precaution 9.7.
8.6 The following data (as applicable) shall be recorded on each strip chart and computer printout.
a) Unit number b) Date c) Procedure number, *step number, and run number if appropriate d) Parameter scale and range e) Chart speed f) Name of person recording data g) Recorder ID number hl Time mark for start of test 8.7 Record operator participation in the test on Appendix B
- a.a Appendix C and D of SUP 90.0 (ref. 2.4) will be used to record data and calculation when called for as follows:
Appendix C - P-250 Short form flux map, "Core Power Determinationn Appendix D - P-250 Incore T/C map "Incore Thermocouples" SUP 90.1 Salem Unit 2 Rev. 2
.O PRECAUTIONS 9.1 Do not exceed 5% nuclear power 9.2 Do not exceed any of the following temperature limits, observe the special operator instructions given in section 9.0 of SUP 90.0 (ref. 2.4), which should be posted conveniently in the control room.
9.2.1 610°F for any core outlet thermocouple 9.2.2 65°F for any loop Delta-T 9.2.3 578°F for any loop Tavg 9.3 Do not exceed primary to secondary differential pressure of 1600 psi 9.4 Avoid sudden changes in steam pressure, steam generator level, and feedwater flow to prevent rapid cooling of the reactor coolant.
9.5 Maintain Reactor Coolant Pump and.seal and thermal barrier differential requirements as given in OI-II-3.3.2. Do not allow Seal Injection flow to drop below about 6 gpm per pump, unless absolutely necessary to control Auxiliary Spray Flow.
9.6 After the Reactor Coolant Pumps are tripped, the normal Tavg and ~T indications will become unreliable, due to low or zero flow in the RTD bypass line. ~T and Tavg should be ca+culated by taking t~e difference and the average of the hot and cold leg wide-range temperatures indications, for each loop, periodically or at the request of the Test Engineer.
9.7 Do not start Reactor coolant Pumps while the reactor is critical. For the purposes of these procedures, subcritical is defined as D-bank rods at zero steps.
9.8 Maintain pressurizer pressure at about 2235 psig. Pressure control may be left in automatic but spray will be ineffective without pumps, Auxiliary Spray or relief valves may be needed during temperature changes. See SUP 90.0 (ref 2.4) for recommendations regarding the use of Auxiliary Spray. Avoid lifting PORV's.
9.9 If atmospheric steam dumps are used, avoid allowing large AP's to develop between the Steam generator's pressures. Attempt to maintain ~P .::_ 100 psid.
9.10 If a reactor trip should occur during Natural Circulation testing, at least one RCP (i23 or #21) must be restarted prior to reclosing the reactor trip breakers *
- SUP 90.1 Salem Unit 2 Rev. 2
.O INSTRUCTIONS 10.1 Mark all charts and computer printouts per the requirements of paragraph 8.6.
10.2 Start P-250 trend blocks as described in para. 8.3.
10.3 Start the brush recorders at 2 in/min chart speed, and start the reactivity comp.
recorders (TH & Tc) at 0.5 in/min.
CAUTION: Following Reactor Coolant Pump trip. Tavg and ~T indication will be unreliable. Continuously monitor main-steam line pressures and care-fully control feedwater addition during the transient.
NOTE: Steam Generator pressure, level, and flow conditions should be held as closely as possible to pre-transient conditions through the duration of the transient. Reactor Coolant System cold leg temperatures should be maintained within + 5°F of the initial values.
At the initiation of natural circulation (RCP trip) the following tempera-ture respo.nse is expected. See attached curves showing transient* times.
a) Wide Range Thot' 34.°F increase b) Wide Range Tcold' slight decrease 5-10°F c) Core exit ~hermocouple, increase 35-40°F d) Tavg indication, unreliable, decreasing e) Delta-T indications, unreliable f) Pressurizer level is expected to increase about 1% for each °F increase in' Tav, ie to about 39%.
g) Subcooling at about 75°F margin 10.4 Place the pressurizer relief valve 2PR2 in Manual, or manually reduce plant pressure about 100 psi to allow for an expected pressure increase transient of about that magnitude.
NOTE: 2PR2's compensation circuit would cause it to lift below the normal 2335 #
setpoint.
10.5 Verify that the green P-7 permissive light on RP-4 is lit, and simultaneously trip all four Reactor coolant Pumps. Keep oil lift pumps running.
10.6 Maintain RCP seal flow at a minimum of 6 gpm to each pump.
CAUTION: Spray will be ineffective without Reactor Coolant Pumps. Auxiliary Spray or relief valves may be needed during temperature changes. Refer to SUP 90.0 for general instructions or use of Auxiliary Spary
- SUP 90.1 Salem Unit 2 Rev. 2
10.7 Maintain pressurizer pressure control in automatic and manually adjust charging flow to match letdown and maintain a constant RCS water mass. Pressurizer level is expected to vary according to Tavg, following the relationship of 1% level change for 1°F change in Tavg.
10.8 Adjust height to maintain.power constant as indicated by the reactivity computer.
Use the steam dwnp controller to maintain Tc between 540 and 546°F.
10.9 Carefully control additions of feedwater to the Steam Generators to maintain levels at approximately 33%. Do not allow Steam Generator level to drop below 10% on narrow range indicators. (the reactor trip setpoint has been reset to 5%).
NOTE: Natural Circulation Flow will be stable when:
a) llT between Wide Range Thot and Tcold is constant.
b) llT :Ce tween Wide Range Tcold and core exit T/C average temperature is constant c) Wide Range Thot ~ core exit T/C average temperature d) Steam Generator level~ are steady, or varying slowly with constant feed.
10.10 After steady state conditions have been reached mark each recorder chart to indicate equilibrium has been reached and continue recording data. Restore relief valve 2PR2 to AUTO
- 10.11 Perf<)rm an incore flux m~p, incore T/C map, and core power determination using Appendix A, of SUP 90. 0 (ref. 2. 4).
10.9.l Estimate the average feed flows for each Steam Generator, from the data recorded on the Brush Recorders, and log on data sheet 1 in the spaces*provided.
'* 10.9.2 Using the steam tables for saturated steam, calculate the specific enthalpy and record on data sheet 1, with the unit conversions indicated.
NOTE: If it is desired to proceed directly into another natural circulation test (90 .. 3, .5, or .4), steps 10.10-10.19 may all be skipped in this case, proceed to step 10.5 of SUP 90.3 or 90.5.
CAUTION: Step 10.12 should follow performance at step 10.10 within 30 minutes to prevent accumulation of colder seal injection water, and to minimize the time period at no flow, with control rods deeply inserted.
10.12 Shutdown the reactor (insert Bank D to zero steps using Bank D Select.)
NOTE: Pressurizer level will return to the pretest level of about 26%, as a result of reducing T avg SUP 90.1 Salem Unit 2 . Rev. 2
CAUTION: Stop feeding and steaming of steam generators in conjunction with shutdown of reactor, to avoid unwanted cooldown of the plant.
10.13 Ensure pressurizer spray valves are closed (if open, place pressure control in Manual and close the valves). Refer to SUP 90.0, para. 9.1.1 if Auxiliary Spray is in use.
10.14 Start No. 23 Reactor Coolant Pump 10.15 Establish stable conditions: Pressurizer level and pressure, primary system temperature and steam generator level and pressure.
10.16 Return pressurizer level control and pressure control to automatic.
10.17 Start the remaining Reactor Coolant Pumps one at a time.
10.18 Stop brush recOTders and terminate trend recording on the P-250 and attach the charts and printouts to the procedure, making sure that all material is adequately marked with the information required in paraqraph 8.5.
10.19 Remove modifications to Hi steam flow coincident with Lo S/G pressure or Lo Tavg input to saf~ty injection I/A/W SUP 90.0 Appendix A, unless the next test to be performed requires the modification to be made. If this is the case, disregard this
- stop, place N/A in signature line and initial.
10.20 Remove block of automatic initiation of safety injection in accordance with SUP 90.0 Appendix A, unless the next test to be performed requires the modification to be made.
If this is. the case, disregard this step, place N/A in signature line and initial.
10.21 Remove the block of input logic of safety injection on Hi steam line ~P I/A/W SUP 90.0 Appendix A, unless the next test to be performed requires the block to be installed.
If this is the case, disregard this step, place N/A in the signature line and initial.
10.22 Compare the flow data recorded to the acceptance criterion 6.5 and ensure that the design values were achieved.
10.23 Verify that all names of participating and observing licensed operators have been recorded in Appendix B *
- SUP 90 .1 Salem Unit 2 Rev. 2
- -~---*.:*-.-~*
11.0 P~ocedure Completion and Comments 11.l Note here any changes to normal plant procedure in the plant manual that should be made as a result of this test.
11.* 2 Comments Date 11.2 Senior Shift.Supervisor/Shift Supervisor Test Engineer --~~~~~~~~.......~~~~
Date Q.A.Surveillance Date 11.4 Changes in SPM required as a result of this test have been noted and necessary corrections initiated.
'* Operating Engineer Date SUP-90.1 Salem Unit 2 ~ev. 2
APPENDIX A P-250 Digital Trend Parameters Computer Point Parameter P04BOA Pressurizer Pressure Channel l L04BOA Pressurizer Level Channel 1 T04l9A RCS : ..cop 21 Hot Leg Temperature T0406A RCS Loop 21 Cold Leg Temperature T0439A RCS Loop 22 Hot Leg Temperature T-0426A RCS Loop 22 Cold Leg Temperature T0459A RCS Loop 23 Hot Leg Temperature T0446A RCS Loop 23 Col'd Leg Temperature T0479A RCS Loop 24 Hot Leg Temperature .
T0466A RCS Loop 24 Cold Leg Temperature P0400A Steam Generator 21 Pressure L0400A Ste~ Generator 21 Narrow Range Level P0420A Stearn Generator 22 Pressure L0420A Stearn Generator 22 Narrow Range Level P0440A Steam Generator 23 Pressure L0440A Steam Generator 23 Narrow Range Level P0460A Steam Generator 24 Pressure L0460A Steam Generator 24 Narrow Range Level N0049A Power Range Channel 1 (Quadrant ll NOOSOA Power Range Channel 2 (Quadrant 2)
NOOSlA Power Ran9e Channel 3 (Quadrant 3)
N0052A Power Range Channel 4 (Quadrant 4)
U0090A ...
Hottest Incore Thermocouple Pressurizer surge line temperature T0482A SUP 90.1 Rev. 2 Salem Unit 2 APPENDIX B (cont.)
RO's Participating In Test RO's. Observing Test SUP 90.l
-1.7- Rev. 2 Salem Unit 2
APPENDIX B SRO's Participating In Test SRO's.Observing Test SUP 90-1 Salem Unit 2 -18.;.. Rev. 2
SQNP SPECIAL TEST 1 Page 1 of 1 Rev. 1 TABLE 1 Loop Flow and Core AT for Various Power Levels and Isolation Configurations (Computer Estimates)
No. of Loops Operating (Nat. Circ.)
Power Level 4 3 2 1
.5% WL = 3.7 WL = 3.6 WL = 4.1 WL =. 5.2 AT = 10.3 llT = 12.5 llT = 16.4 llT = 26
.75% WL = 3.7 WL = 4.1 WL = 4.7 WL = 5.9 llT = 13.5 AT = 16.3 AT = 21.4 t:.T = 34 1% WL = 4.1 WL = 4.5 WL = 5.2 WL = 6.5 t:.T = 16.3 t:.T = 19.8 tlT = 26 tlT = 41 -
1.5% WL = 4.7 WL = 5.2 WL = 5.9 WL = 7.5 t:.T =21.4 tlT = 26 t:lT = 34 t:.T = 54 2% WL = 5.2 WL = 5.t WL = 6.5 WL = 8.2 t:lT =26 t:.T = 31.4 t:.T = 41 AT = 65.4 2.5% WL = 5.6 WL = 6.2 WL = 7.1 WL = 8.9 llT = 30.1 AT = 36.5 t:lT = 47.1 AT = 75.9 3% WL = 5.9 WL = 6.5 WL = 7.5 WL = 9.7
- . AT = 34 AT = 41.2 AT =54 llT = 85.7
- NOTE:
wL .
is% of 97,000 gpm flow through operable loop.
AT= Loop llT in °F.
sup 90.1 Salem Unit 2 Rev. 2
TABLE 14.1-3 NATURAL CIRCULATION FLOW Reactor Power Reactor Coolant Flow
% Full Power % Nominal Flow 4.0 5.32 3,5 5.06 29 3.0 4.79 2,5 4.44 2.0 4 .16 1.5 3.78 1.0 3.28
- SNGS-FSAR Table 14.1-3 Amendment 29 Uni ts l &2
a *,aemnrews r
- NATURAL CIRCULATION" SUP 90.1 Data Sheet 1 (step 10. 9)
Power level %.
i21 RCL flow FT 415 gpm
- 22 RCL flow FT 425 gpm
- 23 RCL flow FT 435 gpm
- 24 RCL flow FT 445 gpm psig Btu/lbm i21 S/G pressure (Heise gage)
II
- 22 S/G pressure II psig II
- 23 S/G pressure*
II psig II
- 24 S/G pressure II psig op Btu/lbm
- 2 Aux. Feed Tk Temperature gpm lbm/hr
- 21 Average aux. feed flow gpm lbm/hr
- 22 Average aux. feed flow gpm lbm/hr
- 23 Average aux. feed flow gpm lbm/hr
- 24 Average aux. feed flow l
~ #21 S/G steaming rate (l-2)x3 Btu/hr I
r I #22 S/G steaming rate ff #23 S/G steaming rate
[
- 24 S/G steaming rate I
- sul' 90.1 Rev. 2 Salem Unit 2
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