ML19338F564
| ML19338F564 | |
| Person / Time | |
|---|---|
| Site: | McGuire, Mcguire  |
| Issue date: | 10/10/1980 |
| From: | DUKE POWER CO. |
| To: | |
| Shared Package | |
| ML19338F555 | List: |
| References | |
| TP-1-A-2150-26, NUDOCS 8010200580 | |
| Download: ML19338F564 (10) | |
Text
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' DUKE POWER COMPANY McGUIRE NUCLEAR STATION 3 19 $ 3 E E !E N [A N
' SIMULATED LOSS OF ALL ONSITE AND-OFFSITE-AC POWER f
l'. 0 Puroose :
.1.1 To verify that hot standby conditions can be maintained by manual control of the auxiliary feedwater system.
1.2'.To demonstrate that auxiliary feedwater can be controlled by.
manual means to remove heat energy from the primary system following'a loss of 'all onsite and offsite AC power.
2.0 References 2.1-
' System Description - Safety Injection System, Addendum 1 (Upper Head Injection System), MC-1223-12, Rev. O.
2.2 Reactor Coolant System Flow Diagram - MC-1553-1.0, Rev. 9.
2.3 CVCS Flow Diagram - MC-1554-1.2, Rev. ~
_ 2.4 CVCS Flow Diagram - MC-1554-3.1, Rev. 4.
2.5 System Description - Auxiliary Feedwater System, MC-1223-42, Rev. 4.
2.6 Auxiliary Feedwater System Flow Diagram - MC-1592-1.0, Rev. 8.
3.0 Time Required 3.1 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 3.2 Manpower needed - 2 engineers 4.0 ~Prerecuisite Tests 4.1 TP/1/A/2150/23, Natural Circulation with Simulated Loss of Offsite Power.
5.0 Test Equipment 5.1 OAC - Transient Monitor Program 1
5.2 Reactivity Computer
-(flux, reactivity, vide range THOT' "
range TCOLD) 5.3 OAC - Thermocouple Map Program
-5.4
-0AC - Subcooling from Saturated Conditions Curve 6.0 ~ Limits and Precautions 6.1 Avoid'any sudden changes _in feedvater flow, steam generator llevel, or steam pressure.
- 6.2 Maintain pressurizar level greater than 20% level.
89.10200 NO
.6.3 Ensura ceal flow 10 maintaintdlto the rocctor-coolant. pumps during1the test.
'6.4-If primary. system pressure drops to a point where-it is obvious that saturation pressure -for the existing hot leg or incore T/C c'emperatures will soon be reached, the pressurizer
. heaters will have to be' energized cr-charging flow re-established
.to-increase system pressure.
6.5-A minimud of gallons of water is available in the
- upper surge ta:.k.
7.0 Recuired' Unit Status 7.1 The unit-is in Hot Standby (Mode 3) 8.0 Prerequisite System Descriptions 8.1 - All four reactor coolant pumps are in operation.
8.2 Reactor is shutdown with control rod driver de-energized.
8.3 Tavg is 557 F with sufficient shutdown margin for a 100 F cooldown.
~8.4 Steam pressure -1090 psig and being maintained by steam dump to the condenser.
8.5 NC pressure is 2235 psig and pressuriz level is -25%.
8.6 Pressurizer level controllers and pressurizer pressure controllers-
.are in AUTO.
8.7 Steam dumps are in the Steam Header Pressure Controller mode and are being operated in AUTO.
8.8 Steam Generator level being maintained at approximately 26* and the. auxiliary feedwater control valves are in MANUAL.
8.9 The steam generators are being fed by the 2 motor driven auxiliary feedwater-pumps.
8.10 Excess ler.down is available for service if required during the test.
8.11 The steam generator. power operated relief valves are in AUTO.
8.12 Reset the: low power range and low ' intermediate range trip setpoints to 7% F.P.
(current equivalent co-2.8'x'10-$ amps on the inter-mediate range.)
8.13. The steam generator blowdown system will automatically be isolatad on an automatic start of the auxiliary feedwater pumps.
Therefore, steam generator chemistry should be such that blowdown will not be required for a period of -3 hours.
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18.l N Verify all valvesL11sted on Enclosure 13;l hav'e been blocked.
8.15:l Verify 1all: input? logic-circuitry has been modified'per Enciosure.13.2.s -
(8'.161i charging' is be'ing' maintained by one centrifugal < charging pump.
'8.17. 'Theisteam generator power operated relief valves control switches are in AUTO.
5.19jThe auxiliary fe'edwater pumps are aligned.to take suction from the 8
upper surge tank.-
9.0:.: Test' Method-This ' testa is l designed to demonstrate,that heat can be - removed from the RCS in~ conjunction vich loss of all AC' power.
The initial condi-
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tions are:as follows:
(a) 3The reactor ~is in hot standby-(Mode 3).
(b). 'A111four reactor coolant pumps are running.
(c) ;The-auxiliary'feedwater system is in service.
(d) 'NCS is at normal operating temperature and pressure.
The test will be' initiated by tripping the 2 motor driven auxiliary feedwater. pumps.and verifying the turbine driven auxiliary feedwater pump starts on-2 out'of'4 low-low level oignals in 2 steam generators.
After the level is restored in the steam generators, level vill be maintained by manually ec7 trolling the feedwater flew and by controlling stear d-mp through the Power Operated Relief Valves
$10.0 Data 1 1uired'
'10.1 Outputs of the OAC. Transient Monitor Program.
NOTE:.The. data-on the OAC Transient Monitor Program will have to be " frozen"'and: dumped to 2-floppy discs every 30 minutes.
from the beginning of the test.
10.2 Record' initial' conditions on Enclosure 13.3.
10.3. Output of the OAC Thermocouple Map Program.
10.4 Output of 'the'0AC Saturation Limit Graphic.
'11.0~ Acceptance Criteria-ll.lb Manual operation-of:the auxiliary feedwater system can be coordinated by the operators.
-11.2 Hot Standby conditions can be. maintained by manual control of the auxiliary feedwater system.
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Initicl/Dito 12.0 Procedure NOTE: ' Data acquisition steps'need not be repeated for multiple performances.. N/A signoffs for'these steps.
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12.1-Record data'on Enclosure 13.3.
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12.2' Place each pressurizer spray valve in MANUAL on the control board and adjust the SETPOINT to a pressure such that the valves will.
not open during the' test.
/
12.3 Reduce charging to the minimum required for seal. injection flow.
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12.4 1solate letdown flow by closing valves 1NVlA, 1NV2A, INV457A, 1NV458A and 1NV459A and isolate letdown by closing valve 1NV26B.
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12.5 Isolate' charging by closing INV238.
NOTE: The charging pump is now supplying only seal flow. If necessary open 1NV26B periodically to maintain pressurizer
' level.
12.6 As quickly as possible,. shut down the following equipment.
NOTE: Record this time in the test log.
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12.6.1 All pressurizer heaters.
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12.6.1.1 Place backup pressurizer heaters A, B, and D in MANUAL on-the AUTO-MANUAL switch and'in OFF on the MANUAL switch.
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12.6.1.2 Place heater group C SUPPLY BREARER switch to the OPEN position.
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12.6.2 Trip both =otor driven auxiliary feedvater pumps.
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12.6.3
-Disable the steam dumps (Place the OFF-RESET buttons to
'0FF).
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12.6.4' Close the main steam isolation valves (from the Control Room).
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12.6.5 Reset the main steam power operated relief valves (from the Control Room).
NOTE: The operators should continuously monitor the Saturation Limit Graphic on the OAC beginning
-at this point._
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y (Initial /Date ~
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c12.7 1 Verify that the, turbine-driven auxiliary feedwater pump starts
' automatically..
NOTE: LThe turbine ! driven auxiliary feedwater pump will start l
3 automatically when it ' receives a' low-low level signal-
.from the.two out of.four steam generators.
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12.8 As stcan generator levels return to approximattiy 26% operators
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1 E should assume manual local control of auxiliary feedwater control
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1 valves 1CA63, ICA51, ICA47 and lCA35.
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- NOTE: Communications vill"have to be established between the l
operators;at these valves and the Control Room.
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12.9 Begin taking THERMOCOUPLE MAPS on.the OAC'every 30 minutes and' dumping the output of TRANSIENT MONITOR on the OAC to floppy disc every 30 minutes starting at the time recorded in Step 12.6.
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12.10 Begin taking an output of 'the Saturation Limit Graphic once every
.10~ minutes starting at the1 time recorded in Step 12.6.
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12.11 Maintain steam generator level"at approximately 26% and steam pressure at approximately 1090 psig for a two hour period.
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12.12 At the end of the two hours resume automatic control of the auxiliary feedwater control valves.
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12.13 Start the motor driven. auxiliary feedwater pumps-and shutdown the turbine driven auxiliary-feedwater pump.
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~12.14 Set the Main Steam Header Pressure AUT0/ MANUAL CONTROL STATION setpoint to 1090 psig and engage the ON switch on the OFF-RESET.
on BYPASS INTERLOCK switch.
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' 12.15. Restore; the-NC pressure 2235_ psig and return the pressuri:er heaters and spray to' AUTO.
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12.16 Resume normal letdown and charging and return pressuriser level-
~ control to AUTO.
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12.17 Reset the intermediate. range trip setpoint to 1 x.10 amps and.
- the low power range trip setpoint to 25
- F.P. unless the next L
. test alos ' requires. this adj ustment. If this is the case, N/A
.this. step.
d s
_Initicl/Date
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12.18 Remove the blocks from the valves listed in Enclosure 13.1
- unless the next test to be performed requires'the valves to
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be' blocked. - Iftthis is the case,;N/A this signoff and sign-offs on Enclosure 13.1.
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12.19~ Verify all: input logic circuitry has been placed back in its norma 1' status per. Enclosure 13.2 unless the next test to be performed requires the. logic circuitry to be modified. If this is the case, disregard this step and N/A.this signoff and signoffs on~ Enclosure 13.2.
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'12.20 All Acceptance Criteria has been met.
13.0 Enclosures 13.1 Valves to be Blocked 13.2 Modifications to Input Logic Circuitry 13.3 Initial-Conditions 4
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Enclosure =13.1 Valves to be. Blocked TP/1/A/2150/26
' Natural Circulation with Staulated Loss of All Onsite and Offsite AC-Power
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The following UHI Isolation Valves shall be blocked for the performance of this test.
(1) INI2423
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-(2) 1NI243A
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. (3) INI244B
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(4) INI245A'
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The following UHI Isolation Valve Blocks shall be removed after the performance of this test, unless the next test to be performed requires these valves to be blocked.
If this is the case, N/A the signoff steps.
(1) 1NI242B
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(2): 1NI243A
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(3) INI244B
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(4).lNI245A
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1 3.2 Modifications to Input Logic Circuitry-TP/1/A/2150/26
- Natural Circulation 'with Simulated Loss of All Onsite and
. l Offsite AC Power'
- l Th's.following modificat1ons to input logic circuitry-shall be made for the-
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performance of this test..
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(1) Block safety injection from low pressuriter-pressure.
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i (2) Block safety' inject:1on-initiated' by low steam line l
pressure.
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-(3): Block ~ safety injec tion initiated by negative rate on the steam line pressure.'
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1 NOTE: The safety injection alarm, manual safety injection hand switch, and
. the reactor trip portion of the protection logic will remain in oper-ation... If, truly, the conditions exist that would normally initiate a safety injection the operator shall manually initiate the safety injection. The operator shall be alert as to the conditions that would iniciate.a safety injection and shall be able to differentiate between the actual test conditions and the conditions that would initiate safety injection.
The fo' 1o' wing mo' ifications to input lo;.c circuitry shall.be removed after 1
d the performance of this test unless the next test-to be' performed requires these modifications. If this is the case, N/A theLsignoff~ steps, j
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(1) Remove' the block of safety injection from low rcessurizer pressure.
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(2) Remove the block of safety injection initiated by' low steam
.line pressure.
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1(3) Remove 'the block;of ~ safety injection initiated by negative 1
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rate on the steam line pressure.
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Paga-1 of 2-Enclosura 13.3
. Initial Conditions TP/1/A/2150/26 Natural Circulation with Simulated Loss of All Onsite and Offsite AC Power Point ID#
Point.
Value j
l A1118 Pressurizer Pressure 1 l
A1124 Pressurirer Level'1 A1061 Loop A Cold Leg Temp.
A1067
_ Loop B Cold Leg. Temp.
A1073
-Loop C Cold Leg _ Temp.
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A1079 -
Loop D Cold Leg Temp.
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A0965 Loop A Hot Leg Temp.
A0971 Loop B. Hot Leg Temp.
A0977
. Loop C Hot Leg Temp.-
1 A0983 Loop D Hot' Leg Temp.
A1059 Steam Generator A Level i
'A1065 Steam Generator B Level A10,71 Steam Generator C Level A1077 Steam Generator'D Level I
A1107 Steam Generator A Pressure l
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A1113 Steam-Generator B Pressure A1119 Steam Generator C Pressure A1125 -
Steam' Generator D Pressure A0890 Steam Generator A Aux. Feedwater Flow I
l A0884 Steam Generator 3 Aux. Feedwater-Flow l
A0878 Steam Generator C Aux.-Feedwater Flow A0872 Steam' Generator D Aux. Feedwater Flow.
I A1060' Steam Generator A Steam Flow
-A1066 Steam Generstor'B Steam Flow A1072 Steam Generator-C Steam Flow A1078
-Steam Generator D Steam Flow
'Alll2 NC Loop Highest Avg. Temp.
=A0555-Steam Generator A Aux. Feedwater Temp.
A0561<
Steam Generator 3 Aux.' Feedwater Temp.
A0567
' Steam Generator.C Aux. Feedwater Temp.
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~l 1 3.3 Initial Conditions 4
TP/1/A/2150/26 Nat! ural Circulation with Simulated Loss of All Onsite and
- i Offsite AC Power Point ID#-
Point' Value
.A0573 Steam Generator D. Aux.-Feedwater Temp.
A1058 Loop A AT A1070.
Loop 3 AT A1082:
Loop C AT
-A1094-Loop D AT A0628' Power Range Avg. Level Quad. 1 l
A0627~
Power Range Avg. Level Quad. 2 A0629 Power Range Avg. Level Quad. 3 A0626-Power Range Avg. Level' Quad. 4 l
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