ML19319D856

Startup Rept, Suppl 1

ML19319D856
Person / Time
Site:	Rancho Seco
Issue date:	06/30/1975
From:	SACRAMENTO MUNICIPAL UTILITY DISTRICT
To:
References
NUDOCS 8003260817
Download: ML19319D856 (16)

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SACRNEITO MJNICIPAL UTILITY DISTRICT RANCHO SEco NUCLEAR PbWER STATION UNIT 1 DOCKET fb.

50-3.12-LICENSE No. DPR l STARTUP REPORT l

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' INTRODUCTION

.'Th'is' report-has been prepared for submittal to the Nuclear Regulatory

. Commission in accordance with Regulatory Guide 1.16 Rev. 3 Section C.I.'a.

On March 1,.1975, the Startup Report for Ranchof Seco Nuclear Power

~ The Station, Unit'1, was submitted to the Nuclear Regulatory Commission.

report addressed unit startup and power escalation testing up to 92.6% through 2400 hours0.0278 days <br />0.667 hours <br />0.00397 weeks <br />9.132e-4 months <br /> February ~ 28,.1975 At ~that time, five tests invo'lving; " Shutdown.

from Outside the Control Room, 75.and 92% Load Rejection Tests, 100% Power Physics Testing and 100%' Load Rejection Test.

All tests.except.the later two have been--completed.

This supplement is prepared and submitted with regard to i

.the, tests completed since the original Startup Report and 2400 June 30, 1975 Following completion _of further testings additional supplementary infor-mation will be compiled and submitted concerning final results of testing.

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~S LOAD' REJECTION TEST FROM 75% FULL POWER 1.

PURPOSE 1The purposee of the load rejection test from 75% full power are to verify that the minimum allowable feedwater temperature entering

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the steam generators is maintained during a loss of load occurrence;-

~ to verify that the maximum allowable temperature dif ferentials for the feedwater and the steam generator shells are not exceeded following a loss of load occurrence; to verify.that the plant and all systems can safely withstand a 75% outside electrical load rejection without an overspeed tripout of the turbine generator unit; to verify a reactor trip does not occur during the subsequent runback; and to verify that during and af ter. a. loss of load occurrence, the ma).imum allowable temperature. rate change is not exceeded for the first point feedwater heaters.

2.

TEST HETHOD Load rejection test from 75% FP was successfully completed on March 17, 1975 A modification to the -ICS circuitry was made following. he unsuccessful load-rejection test attempted on February 18, 1975, as reported In'the startup report.

A "feedpump kicker" circuit consisting of a header pressure error signal was installed to increase feedpump speed wh'en turbine header-pressure increases greater than set point.

This modification was necessary to prevent an excessive drop in feed-water' flow which occurs immediately upon load rejection. The ICS time lag constant between neutron error and-feedwater demand was decreased from 6 seconds to I second and the etice* T-ave has on

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reactor demand was reduced.

These changes were necessary to prevent feedwater flow from remaining at too high of-flow thus producing an excessive cooldown rate during runback of the plant.

-The load rejection test is performed by opening the external power load' circuit breakers52-220 and 52-230.

Runback of the reactor 1to 15% FP is monitored along with other parameters of the plant including ICS response, turbine bypass valve operation, atmospheric dump valve

operation, turbine governor valve and intercept valve operation, and the operation of pegging steam valves' to the second and fourth point j

-heaters.

Figures I and 2 show the plant response during the transient.

-3 TEST RESULTS

-The test was ini tiated by opening two 220-KV _ ci rcui t breakers,52-220 and_52-230,-resulting in the loss of external power load. The reactor immediately began to' runback at a rate of 30%/ minute.

RCS T-ave began

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, TEST RESU'LTS (Continued) to increase due to the rapid decrease in OTSG feedwater flow which occurs immediately after load rejection.

RCS pressure also increased sharply in response to the increase in T-ave.

RCS pressure and T-ave began to decrease as,0TSG feedwater flow sharply increased in response to the speed increase of the feedwater pumps.

During the load rejection transient, turbine speed increased to 1860 RPM.

This speed was well below the maximum turbine speed set point of 1998 RPM.

Turbine header pressure increased rapidly to 1030 psig where the code safety relief and atmospheric dump valves lifted. The turbine bypass valves opened and began diverting steam to the condenser.

Steam pressure began to decrease gradually from 1025 psig at time 28 seconds to 894 at time 200 seconds.

6 lb/hr at time OTSG feedwater flow began to decrease from 4.6 x 10 16 seconds in response to

.e decrease in reactor demand.

Feedwater flow continued to decrease in response to reactor demand and leveled

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out at 1 x 106 IL/hr at time 128 seconds.

Reactor runback leveled off at time 68 seconds and resumed the 30%/

minute runback at time 80 seconds.

This was due to the ICS correcting for T-ave which had decreased to 576 F.

As T-ave began to increase, reactor' runback was resumed.

In 200 seconds af ter. load rejection, all plant parameters had leveled off. The reactor had runback to 16% FP, T-ave was at 587'F, RCS pressure was at 2160 psig, turbine header pressure was at 894 psig, OTSG-A feedwater flow was at 1.8 x 106 lb/hr and OTSG-B feedwater flow was at 1.2 x 106 lb/hr.

4.

CONCLUSIONS The plant and 'all systems can safely withstand a 75% outside electrical load rejection without tripping the reactor or turbine-generator unit.

Minimum allowable feedwater temperature entering the steam generators was maintained throughout the transient. The maximum allowable tempera-ture rate change was not exceeded for the first point feedwater heaters.

During performance of this test, the Pegging Steam System was out of service resulting in higher than normal differential temperatures be-tween the OTSG downcomer outlet and feedwater inlet.

No Technical Specification limits were exceeded during the transient.

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LOAD REJECTION TEST FROM 92.6% FULL POWER 1.

PURPOSE' The purposes of the load rejection test from 92.6% FP are to verify that the minimum ' allowable feedwater temperature entering tiie Steam Generators is maintained during a loss of load occurrence; to verify that the maxi-mum allowable temperature differentials for the feedwater and the steam generator shells are not exceeded following a loss of load occurrence; to verify that the plant'and all systems can safely withstand a 92.6%

outside electrical load rejection without an overspeed trip of the

. turbine generator unit; to verify a reactor trip does not occur during the subsequent runback; and to verify that during and af ter a loss of load occurrence, the maximum allowable temperature rate change is not exceeded for the first point feedwater heaters.

2.

TEST METHOD Load rejection test f rom 92.6% FP was successfully completed on March 18, 1975 The load rejection test was perforned by opening the external power load circuit breakers,52-220 and 52-230.

Runback of the reactor to 15% _ FP was monitored along with other parameters of the plant including ICS response, turbine bypass valve operation, atmospheric dump valve operation, code safety valve operation, turbine governor valve and inter-

' cept valve operation and the operation of pegging steam valves to the second and fourth point heaters.

Figures ?. and 4 show the plant response during the transient.

3 TEST RESULTS

-The test was initiated by opening two 220-KV circuit breakers,52-220 and 52-230 resulting in the loss of external power load.

The reactor immediately began to runback at a rate of 30%/ minute.

RCS T-ave began to increase due to the rapid decrease i'n OTSG feedwatdr flow which occurs immediately after load rejection.

RCS pressure also increased sharply

.in response to the increase in T-ave.

RCS pressure and T-ave began to decrease as OTSG feedwater flow increased sharply in response to the speed increase of the feedwater pumps.

Turbine header pressure increased rapidly to 1034 psig where the code safety relief -and atmospheric dump valves lif ted.

The turbine bypass valves opened and began diverting steam to the condenser.

Steam pressure began to decrease gradually from 1030 psig at time 28 seconds

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to.936 psig.at time.200 seconds.

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TEST RESULTS (Continued).

During the load rejection transient,. turbine speed increased to 1880 RPM. This speed is well halow'the maximum turbine speed set point 4

'of.~1998 RPM.

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-0TSG feedwater flow began to decrease from 5 0 x 106 lb/hr at time 16 i

seconds in response to the decrease in reactor demand.

Feedwater flow continued to decrease in response to reactor demand until time 75 seconds where feedwater control was'placed in manual.

The operator placed feed-water control in manual as~ it was felt that RCS. pressure was approaching 3

the RPS. low pressure set point and a further reduction in feedwater flow -

was'necessary to compensate.

Feedwater control was returned to automatic lCS control at time 112 seconds since RCS pressure had focreased to 2240 6 lb/hr at ps i g.-

Feedwater the-resumed a gradual decrease from 2.2 x 10 time 116 seconds to

.l.x 106 lb/hr at time 200 seconds.

-Reactor _ runback leveled off-at 50% FP at time 68 seconds and resumed the 30%/ minute runback at time 88 seconds.

This was due to the ICS correcting for T-ave.which had decreased to 575*F.

As T-ave began to increase, reactor' runback was resumed, in 200 seconds af ter load rejection, all plant parameters had leveled off.

l The reactor had-runback to 15% FP, T-ave was at 588*F, RCS pressure was at 2080 psig, turbine header pressure was at 936 psig, OTSG-A feedwater flow was at 1.1Lx 106 lb/hr_ and 0TSG-B feedwater flow was at 1.2 x 106 Ib/hr.

' 4.

CONCLUSIONS i

The plant'and all systems can safely withstand a 92.6% outside electrical load rejection wihtout trloping the reactor or turbine generator unit.

Minimum allowable feedwater tempe.ature entering the steam generators was maintained throughout.the transient.

During performance of this test, the Pegging Steam System was oct' of service resul ting in higher than normal differential temperatures between the OTSG downcomer outlet and feedwater inlet.

No-Technical Specification limits were' exceeded during the transient.

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SHUTOOWN ' FROM 0UTSIDE THE CONTROL ROOM l..

PURPOSE

-The purposes.of..the shutdown from outside the control room' test are

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to prove the capability of: maintaining.the plant in a safe hot shut-

- down' condi tion - f rom the Jemergency shutdown panel upon loss of access to the control room and to verify' Emergency Procedure D-17 " Evacuation of Control Room".

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3 2.

TEST METHOD Test procedure TP 800-40,-Shutdown from Outside the Control Room, estabitshes the requirements for performing the test including test equipment' required,-data required and plant limits and precautions.

4 The test is to be performed with offsite power available.

Prior to starting the test, reactor power must be equalEto or greater than 15_ percent FP with ICS stations, pressurizer level control, and reactor coolant pressure control in automatic.

The auxiliary boilers

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shall be operating as required.

Prcrequisite system conditions include the following:

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A11' reactor. coolant. pumps in operation.

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Pressurizer level control in automatic at 180 + 12 inches.-

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RC' pressure control in automatic at :2155 + 20 psig.

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RC average - temperature at 582 + 2*F.

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All'lCS stations in automatic.

6.. Makeup tank level'and pressure in normal operating range, 70 + 5 inches, and 20 + 5 psig.

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All lndicators on the hutdown auxi'llary panel have been verified to agree with Indications of the same parameters in the Control Room.

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Auxiliary Boller Steam Pressure.

9. - Operators have been briefed on their assignments and on the

-conduct of the test.

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.The acceptance criteria for the test include the following:

- 1.. Technica1' Specification Limits are not' exceeded.

2.; 'The plant was controlled in a safe manner and can be

-maintained in hot: shutdown lper D-17. Emergency-Procedure.

. A backup shif t! crew consistinglof'a Shif t Supervisor, Senior' Control 3

' Room '0perator,- Control.. Room Operator, ' Auxiliary ~ Operator, Equipment 1 Attendant-and Power:PlantfHelper are available and standing by ready-

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to assist iand -take' control of the plant.should any parameter. exceed t

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TEST METHOD (Continued) the Process Standards limits.

The Backup Shift Supervisor is respons-ible for. observation of all plant parameters and takes control i f any parameter exceeds the Process Standa.eds limits.

The Backup Senior Control Room Operator remains at the reactor console and is ready to take over cor.crol if requested by the Backup Shift Supervisor.

The Backup Control Room Operator is responsible for communications with each control station and monitors the communications from the shutdown panei, relaying important messages to his Shift Supervisor.

The Backup Auxiliary Operator, Equipment Attendant and Power Plant Helper are stationed in the Control Room and are immediately avail-able to assist any operator at the remote stations.

The Test Coordinator and Shift Supervisor verify that all system pre-requisites and procedure requirements have been met prior to initiating the test.

The Shift Supervisor then directs the Senior Control Room Operator to manually trip the reactor and implements Emergency Pro-cedure D-17.

Prior to abandoning the control room, the following actions are accomplished:

1.

Confirm all rods in.

2.

Close the letdown valve SFV-22009 3

Trip both Main Feedpumps and verify Auxiliary Feedpumps start.

Open HPl injection valves to either RCS Loop A or B from the HPl pump not connected to the makeup pump.

4.

Open the BWST suction valves.

5 Announce the reactor trip and Control Room Evacuation throughout the plant.

The control room is evacuated.

The Shift Supervisor is available to take action to restrict damage due to the casualty and to assist where necessary.

The Senior Control Room Operator reports to the Emergency Shutdown Panel, verifies available reactor coolant pumps running (4 pumps are desirable) and assumes the same responsibilities for the plant as held in the Control Room.

He also verifies operation of the Emergency Shutdown Panel instrumentation and equipment which includes the following:

1.

Pressurizer level indication.

2.

Reactor coolant pressure.

3.

Reactor coolant Th and Tc.

4.

Source range indication.

5 Paging system.

6.

Offsite telephones.

The-Control ' Room Operator verifies that auxiliary busses 4C, 4D, and 4E

' have transferred to their standby sources and verifies the 2nd point 51-7

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TEST METHOD (Continued) heater drain pumps have tripped.

He then reports to the Emergency Shutdown Panel for further assignment.

i The Auxiliary Operator verifies the makeup pump is running and that HPl injection valves to RCS Loop A or. B are open.

He then establishes connunications with the Emergency Shutdown Panel and stands by the HPl injection valves.

The Equipment Attendant verifies one condensate pump running, verifies both auxiliary feedpumps are running, and that at least one CCW pump is running.

He then reports to the "B" OTSG Auxiliary Feed Control

-Valves complex, establishes sound powered communications with the Emergency Shutdown Panel and controls steam generator feed as directed.

The Power Plant Helper reports to the "A" O'TSG Auxiliary Feed Control Valve complex, establishes sound powered communications with the Emergency Shutdown Panel and controls steam generator feed as directed.

The plant is brought to hot shutdown conditions and maintained there until the Test Coordinator determines that conditions have stabilized.

3 TEST RESULTS A briefing and dry.run walk-through was conducted with both the normal shift and backup shift crews on March 21, 1975 The test was performed successfully on March 22, 1975 The plant and all systems responded satisfactorily.

Evacuation of the Control Room was completed within 35 seconds after the reactor trip. Then, the plant was brought to a hot shutdowa condition and was maintained there using equipment located at various locations in the plant for 21 minutes prior to ending the test.

No Technical Specification or Process Standards limits were exceeded during performance of the test.

Refer to Figures 5, 6, and 7 for the plant response during the transient.

4.

' CONCLUSIONS The reactor can be maintained in a safe hot shutdown condition from locations outside the control room by the minimum shif t compliment.

The Emergency Shutdown Panel contains sufficient instrumentation and communications to permit satisfactory monitoring and direction of shutdown: operations.

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