ML20043G241
| ML20043G241 | |
| Person / Time | |
|---|---|
| Site: | Seabrook  |
| Issue date: | 06/13/1990 |
| From: | Feigenbaum T PUBLIC SERVICE CO. OF NEW HAMPSHIRE |
| To: | NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM) |
| References | |
| NYN-90126, NUDOCS 9006200083 | |
| Download: ML20043G241 (30) | |
Text
!
- o. O g j New Hampshire Tod C. F44r- ;
Senior Vice President and Chief Operating Officer i
NYN-90126 June 13, 1990 United States Nuclear Regulatory Commission Washington, DC 20555 Attention: Document Control Desk l
References:
(a) Facility Operating License No. NPF-67. Docket No. 50-443 (b) Facility Operating License No. NPF-86, Docket No. 50-443 (c) NHY Letter NYN-900070, ' Initial Startup Report', dated March 13, 1990, T. C. Feigenbaum to USNRC
Subject:
Supplement 1 to the Initial Startup Report Gentlemen:
In accordance with the requirements of Technical Specification 6.8.1.1, enclosed is Supplement 1 to the Initial Startup Report, submitted via reference (c), for Seabrook Station. This covers the period from July, 1989 through May, 1990, however, no testing took place between July, 1989 and February, 1990. This is the first of the Supplemental reports to be submitted every three months until comencement of commercial operation as
! required by this Technical Specification.
l Should you have any questions, please contact Mr. James M. Peschel, ,
Regulatory Compliance Manager, at (603) 474-9521, extension 3772.
Very truly yours.
W
-fd&hf Ted C. Feigentfaum Enclosure TCP:CLB/sel l6 cci Mr. Thomas T. Martin (n Regional Administrator g-on. United States Nuclear Regulatory Commission Region I
$$ 475 Allendale Road King of Prussia, PA 19406
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$U Mr. Noel Dudley NRC Senior Resident Inspector [ h O(I P.O. Box 1149 Seabrook, NH 03874
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$b New Hampshire Yankee Division of Public Service Company of New Hampshire l P.O. Box 3005 Seabrook, NH 03874
- Telephone (603) 474 9521
.. , - .~ - -. . . - -. .- .
a new nampshire nak:e j June 13, 1990 .
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ENCLOSURE 1 TO NYN-90126 !
-1 Sunnl-- nt 1 to the Initial Startuo Renort :
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, 3-NEW HAMPSHIRE YANKEE SEABROOK STATION i
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SUPPLEMENT 1
.19.
IEITIAL STARTUP REPORT i
to the UNITED STATES NUCLEAR REGULATORY COMMISSION ,
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OPERATING LICENSE: NPF 86 NRC DOCKET NO. 50-443 i
For the Period July. 1989 throuah May. 1990 D
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i TABLE OF CONTENTS Section Egge List of Tables 11 List of Acronyms iii 1.0 Introduction 1-1 2.0 Startup Test Program Overview, Supplement 1 2-1 3.0 Seabrook Startup Chronology, Supplement 1 31 4.0 Summary of Initial Startup Report, Supplement 1 41 5.0 Power Ascension Testing 5-1 5.1 ST-26 Thernal Power Measurement and Statepoint 5-2 Data Collection 5.2 ST-23 Dynamic Automatic Steam Dump Control 5-3 5.3 ST-25, Automatic Steam Generator Le'11 Control 5-6 5.4 ST-48 Turbine Generator Startup Test 5-8 5.5 ST-48.1. Turbine Generator Torsional Response Test 5-10 6.0 Instrument Calibration and Alignment 6-1 6.1 ST-13 Operational Alignment of Nuclear Instrumentation 6-2 6.2 ST-28, Calibration of Steam and Feedwater Flow 6-4 Instrumentation 7.0 General Plant Testing 7-1 7.1 ST-52 Thermal Expansion 7-2 i
l LIST 0F,1 G .Q ST-23 Table 1. Steam Dump Valve Timing Data ST-25 Table 1, Auto Steam Generator Level Control Test Data Sunnary en l
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l . l LIST OF ACRONYMS l
l ACOT - Analog Channel Operational Test AFD - Axial Flux Difference l
ARI - All Rods Inserted l
ARO - All Rods Out l
ASDV - Atmospheric Steam Dump Valve CB_ - Control Bank (A B.C. or D)
CIV. Combined Intermediate Valve CRD - Control Rod Drive i
CRDH - Control Rod Drive Mechanism CV - Control Valve l
CVCS - Chemical and Volume Control System DRPI - Digital Rod Position Indication l ECCS - Emergency Component Cooling System EFW - Emergency Feedwater EHC - Electrohydraulic Control FCFM - Full Core Flux Hap FSAR - Final Safety Analysis Report FTC - Fuel Temperature Coefficient GE - General Electric Company GETARS - General Electric Transient Analysis Recording System HFT - Hot Functional Test i HSB - Hot Standby l HZP - Hot Zero Power ICRR - Inverse Count Rate Ratio IV - Intercept Valve IR - Intermediate Range ITC - Isothermal Temperature Coefficient 1
l 111 l
LTST OF ACR0RYMS (Continued)
LPMS - Loose Parts Monitoring System MCB - Main Control Board MIDS - Movable Incore Detector System MSIV - Main Steam Isolation Valve MTC - Moderator Temperature Coefficient MWT - Megawatts Thermal NDR - Nuclear Design Repett NHY - New Hampshire Yankee NI - Nuclear' Instrumentation NRC - Nuclear Regulatory Commission NSSS - Nuclear Steam Supply System PAT - Power Ascension Test PATP - Power Ascension Test Program PCV - Pressure Control Valve PLS - Precautions. Limitations and Set points PORV - Power Operated Relief Valve RAT - Reserve Auxiliary Transformer RCCA - Rod Cluster Control Assembly RCS - Reactor Coolant System RDMS - Radiation Data Management System RHR - Reactor Heat Removal RTD - Resistance Temperature Detector SB_ - Shutdown Bank __ (A.B.C.D and E)
SORC - Station Operating Review Committee SSPS - Solid State Protective System UE&C - United Engineers and Constructors iv
1.0 INTRODUCTION
The Initial Startup Report was submitted to the Nuclear Regulatory Commission in March,1990 and covered startup activities through completion of low power physics testing in June 1989. Supplement 1 has been prepared to report on testing which has taken place in the three-month interval since the initial report, and is submitted as required by NRC Reg. Guide 1.16, Section C. Part la.
Approtimately eight months elapsed between completion of the low power physics tests and receipt of a full power licenset the full power license was received on March 15, 1990 and the power ascension test program was undertaken promptly thereaf ter. Supplement 1 covers the period from July 1989 through May 1990, but the actual testing reported herein took place from March 1990 through May 1990.
After completion of preparations to begin the ascension to the 302 power level test plateau, the first section of procedure ST-48 Turbine Generator Startup Test was run and ST-48.1 Turbine Generator Torsional Response Test started. An unsatisf actory resonance was detected by the latter t. e s t , and the PATP was temporarily suspended for approximately one month to allow GE turbine personnel to modify low pressure turbine rotor
'C'. Upon completion of the modifications, a retest of the turbine, using a revised ST-48.1, was conducted and satisfactory performance obtained.
Supplement 1 to the Initial Startup Report covers testing through ST-48.1. The turbine was synchronized onto the grid, but actual ascension to 302 power was not included.
The following tests are included in Supplement 1:
- ST-13 Operational Alignment of Nuclear Instrumentation ST-23, Dynamic Automatic Steam Dump Control i
- ST-25 Automatic Steam Generator Level Control ,
- ST-26 Thermal Power Measurement and Setpoint Data Collection
- ST-28 Calibration of Steam and Feedwater Flow Instrumentation
- ST-48, Turbine Generator Startup Test i ST-48.1. Turbine Generator Torsional Response Test j
- ST-52, Thermal Expansion
- Procedure requires additional testing later in PATP sequence.
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2,0 SUPPLDiENT 1. STARTUP. TEST PROGRAM OVERVIEW I l
The Initial Startup Report, submitted to the Nuclear Regulatory i Commission on March 13, 1990 covered that portion of the startup sequence through low pwer physics testing. Supplement 1 has been prepared to report testing which has taken place in the three months since submission of .
the initial report. j l
'A full power license was received on March 15, 1990. Portions of several startup tests involving alignments and setpoints were required in the startup sequence prior to increasing power to the 30! power level plateau.
These tests were completed and the Station Operating Review Conunittee ,
(SORC) authorized entry into the 301 test sequence on March 25, 1990.
During power ascension, the initial turbine generator tests were scheduled in the 81-201 power range. A turbine generator torsional response test had been reconsnended by General Electric (GE), the turbine vendor, and af ter turbine rolls to validate turbine protective systems and make adjustments to control systems, the torsional response test was undertaken.
The torsional response test disclosed an undesirable resonance, ,
requiring modification to the 'C' low pressure turbine. Power ascension testing was interrupted on April 27, 1990 for turbine modification and >
resumed on May 25, 1990. '
When the turbine was reassembled after modification, a revised torsional response test was performed to verify correction of the resonance problem. Testing through completion of ST-46.1, Turbine Generator Torsional i Response Test, is covered in this supplement to the Startup Test Report.
Ascension to the 30! power level test plateau is not included.
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3.0 STABROOK STARTUP CHRONOLOGY. SUPPLEMENT 1 i
This chronology documents the Power Ascension Test Program (PAPT), from receipt of a full power license to May 30, 1990.
DALL E.1tnL 3/16/90 Commenced PAT program.
Initial NIS alignment (ST-13).
3/17/90 Calibration of steam and feedwater flow instrumentation (ST-28).
3/20/90 Reactor critical shutdown monitor verification (ST-13).
Thermal expansion measurements (ST-52).
3/21/90 Shutdown to replar.e noisy power supply (rod control) and correct main steam valve leak.
3/22/90 Steam dump testa underway (ST-23). ;
3/23/90 Steam dump tests completed.
3/24/90 Commenced steam generator level control tests (ST-25). i Test delay, main feedwater B valve problem.
Completed required SG 1evel control tests.
- 3/25/90 51- power level test plateau complete: SORC approves initiation of 302 power level test plateau.
Entered Mode li continued SG level control tests.
3/26/90 Completed SG level control tests: preparing for turbine tests.
3/28/90 Testing interrupted: GE representative evaluating turbine rotor position problem.
4/1/90 Testing underway feedwater pump transfer (ST-25).
4/2/90 Chest warming for turbine roll.
4/3/90 Turbine ralled contrcl system oscillations observed.
4/4/90 Loss of speed signal, turbine trip evaluation underway.
4/18-
-22/90 Turbine testing underway (ST-48): bearing vibrations noted.
4/23/90 Setting up for torsional testing (ST-48.1).
4/25/90 Commenced torsional testing.
4/27/90 Completed torsional testing did not attempt to synchronize ,
generator.
4/29/90 PATP interrupted GE turbine personnel enroute to start turbine modifications.
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l 3,0 SranR00K STARTUP CHRCI.*0LOOY. SUPPLEMENT 1 (Continued) !
5/25/90 Prerequisite checking begins prior to resumption of torsional I testing (ST-48.1 Revision 4). !
5/28/90 Turbine rolled to rated speed. Testing underway. t i
5/29/90 Data collection for torsional testing completed: GE declares i modification to turbine has correctad resonance problem. ;
Synchronization test not necessary.
5/30/90 - PAT activities to be included in Supplement 1. Startup Test Report coa.pleted.
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4.0 StHMARY OF INITIAL STARTUP REPORT. SUPPLEMENT 1 The Power Ascension Test phase of initial startup was initiated with 1
the receipt of a full power license on March 15, 1990. '
Low power physics testing was completed in June, 1989, and because of the elapsed time, a brief 52 test sequence was scheduled before testing moved to higher power levels. Instrument alignments and calibrations, and validation of automatic steam dump and S/G 1evel control functions were included.
Upon completion of the 52 test sequence, ascension to the 302 power level test plateau was authorized. In the 302 sequence, the reactor power is increased enough to bring the turbine on line (8-101), and after a detailed checkout, to allow synchroniaation of the generator to the grid, i Only af ter completion of the turbine generator qualification testing does actual ascension to and testing at 30! power begin.
The first section of ST-48 Turbine Generator Startup Test was completed, with some interruptions cue to turbine vibration, but generally satisfactory results. These tests validated turbine instrumentation and protective circuits. A turbine torsional test, recommended by the vendor, General Electric, was started next, and resonances were measured during turbine operation at speeds from 100 rpm to approximately 1900 rpm. The torsional tests revealed unacceptable resonance characteristics requiring modifications to the 'C' low pressure turbine.
Power ascension testing was interrupted on April 27, 1990 for turbine modification, and resumed on May 25, 1990. The tie wires on the buckets of the final low pressure stage were replaced and brated with a solid tie wire, stiffening the stage and shifting the resonance. Three damaged bucket covers were replaced on the thirteenth stage (turbine end) cf 'C' rotor.
When the turbine was reassembled, a revised torsional response test was performed to verify correction of the resonance problem. Testing through completion of ST-48.1. Turbine Generator Torsional Response Test, is covered in this supplement to the Startup Test Report. Ascension to the 302 power level test plateau is not included.
The following tests are included in Supplement 1:
- ST-13, Operational Alignment of Nuclear Instrumentation ST-23, Dynamic Automatic Steam Dump Control
- ST-25, Automatic Steam Generator Level Control
- ST-26 Thermal Power Measurement and Setpoint Data Collection
- ST-28, Calibration of Steam and Feedwater Flow Instrumentation
- ST-48, Turbine Generator Startup Test ST-48.1. Turbine Generator Torsional Response Test
- ST-52 Thermal Expansion
- Procedure requires additional testing later in PAT sequence.
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.. i 5.0 POWER ASCEN110N_ TIE 11MG j contentsi 5.1 $7 26 Thermal Power Measurement and Statepoint Data Collection I 5.2 ST 25 Dynamic Automatic Steam Dump Control 5.3 S7 25 r Automatic Steam Generator Level Control ,
5.4 ST-48 Turbine G&nerator Startup Test 5.5 $7 48.1. Turbine Generator Torsional Response Test t
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5.1 ST-26. THEP. MAL P0kTR MEASUREHENT AND STATEPOINT DATA COLLECTION Obiective The objective of this procedure is a calorimetric determination of reactor power, and verification of main steam and feedwater performance from various primary and secondary process data.
The procedure is described in FSAR. Section 14. Table 14.2-5. Sheet 29.
Discussion Primary and secondary process parameters are measured, using station procedures, and from these data a calorimetric determination of power is made. Calorimetric determinations of thermal power are made at the 302, 502, 752, 902, and 100! power level test plateaus.
ST-26 specifies the following stability requirements for a calorimetric -
power level determination:
- 1. RCS temperature (T A yg) changing less than_l'F/ hour,
- 2. Core power changing < 0.52/ hour.
- 3. Steam generator water level at 502 (48-522).
- 4. Pressurizer pressure at 2235 psig (2210-2260 psig).
- 5. Pressurizer level
- 22 of programmed level.
- 6. Blowdown secured.
- 7. Charging and letdown flow constant.
At hot zero power (HZP) an initial set of process data was taken using GETARS.
Results The acceptance criterion for HIP measurements in this procedure requires only that an initial set of process data using GETARS be taken.
The criterion was met.
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.i 5.2 ST-23. DYNAMIC AUTOMATIC STEAM DUMP CONTROL l
Obiective !
l Procedure ST-23 demonstrated proper operation of the Automatic Steam I Dump System by means of valve and controller teste performed at I approximately 2-32 reactor power.
1 The procedure is described in FSAR Section 14 Table 14.2-5, Sheet 26.
Discussion The twelve condenser steam dump valves were each stroke timed while SG pressure was controlled by ASDV's. The air supply to all but one of the valves was isolated, and a test signal injected into the load rejection .
bistable circuitry to simulate an actuation of the steam dump system. The process was repeated until all valves were stroked.
Following stroke time verification, steam dump control was transferred, under steady state conditions, from the ASDV's to the steam dump pressure controller in the automatic steam pressure mode. A test of its transient response was made by increasing reactor power by control rod withdrawal, and verifying that steam pressure remained constant during the transient.
In the T Ayo mode, controller response to a load rejection was verified by simulating a trip of the loss of load interlock, and to a plant trip by simulating the plant trip and increasing reactor power by control rod :
withdrawal. In each case, steam dump action maintained the appropriate '
TAVG' This section of Supplement 1. Startup Test Report, covers all sections of ST-23 Revision 4. In conjunction with the performance of larger transient tests such as ST-35, Large Load Reduction Test, and ST-38 Unit Trip from 1002 Power, further steam dump system actuation and multiple bank actuation will be demonstrated.
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.c 9.2 ST-23. DYNAM?C AUTCMATIC CTEAM DUKP CONTROL fContinued) j Rtsults All acceptance criteria were met Dump Valve Opening Time, s 5 seconds
- Dump Valve Closing Time, s 5 seconds *
- See Table 1.
Steam Header Pressure Controller maintains setpoint. 1092 1 26 psig:
Measured Variation. 1079.1 1082.9 psig over a 14 minute period.
Load Reduction Controller maintains stable TA yg. 556 1 2'F Measured Variation, 555.15 555.54'F over a 7.5 minute period.
Plant Trip Controller maintains stable TAyo, 560 1 2'F:
Measured Variation, 559.00-558.03*F over a 12 minute period.
Eleven of the 12 steam dump valves were stroke tested satisfactorily on the initial measurement. A defective solenoid was repaired and a switch positioner was readjusted on MS-PV-3020 before the valve could be successfully tested. In addition, steam line vibration was observed when MS-PV-3013 was tested, and this valve was stroked a second time after vibration instrumentation had been installed. The measured vibration was found to be acceptable.
During transfer of steam pressure control from the ASDV's to the steam dumps in the pressure control mode, the dump valves modulated due to a slight mismatch. The mismatch was within the tolerance of the controllers and steam header pressure change was less than 6 psig during the transfer.
Dynamic testing of the steam dump system in the pressure control mode, testing the plant trip controller and the load rejection controller completed ST-23. The systems performed as expected.
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o 5.2 ST-23. DYNAMIC AUTOMATIC STEAM DUMP CONTROL (Continued)
Table 1. Steam Dume Valve Timina Data Steam Hdr Valve Valve Pressure Opening Closing per MCB Time Time Valve No. MS-P1-507 (seconds) (seconds)
MS-PV-3009 1070 psig 3.3 1.1 MS-PV-3010 1070 psig 3.75 1.1 MS-PV-3011 1070 psig 3.4 1.25 l
MS-PV-3012 1060 psig 3.45 1.2 MS-PV-3013 1075 psig 3.7 1.15 MS-PV-3014 1060 psig 3.4 1.0
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MS-PV-3015 1060 psig 3.2 1.15 j MS-PV-3016 1060 psig 3.4 1.0 MS-PV-3017 1070 peig 2.95 1.0 i
MS-PV-3018 1060 psig 2.8 0.9 HS-PV-3019 1070 psig 3.4 1.18 MS-PV-3020 1075 psig 3.85 1.4 Acceptance Criteria:
Opening Time s 5 seconds Closing Time s 5 seconds l
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5.3 ST-25, STEAM GENERATOR AUTOMATIC LEVEL CONTROL Obiective This procedure demonstrated the stability of the Automatic Steam Generator Level Control System under simulated transient conditions, and proper operation of the main feedwater pump speed control. System stability during transfer from bypass feedwater regulating valves to main feedwater regulating valves was included.
The steam generator automatic level control tests are described in FSAR Section 14, Table 14.2-5. Sheet 28.
Discussion Level control of the steam generators and speed control of feedwater pumps is validated in ST-25 by testing at reactor power levels of 12-42,82-102, 82-202, 302, 502, 752, and 1002.
At a power level of approximately 32, each feedwater bypass valve automatic controller was tested, using station operating procedures, to demonstrate stability during a steady state manual to automatic transfer, as I
well as stability during steady state operations. The changeover from startup feedwater pump to one main feedwater pump was next demonstrated using station procedures. Again, stability during a steady state manual to automatic transfer, and steady state operation in automatic control was verified for main feedwater pump operation. The changeover from startup i feedwater pump to the opposite main feedwater pump, and the stability l
verifications was demenstrated at the end of the test, by repeating Section l 6.2.
After the feedwater regulating block ' valves were opened, and stable level control demonstrated with feedwater regulating bypass valves in autenatic, the ability of each of these valves to restore and maintain steam generator narrow range level was demonstrated when the narrow range level was successively raised and lowered.
This section of Supplement 1. Startup Test Report, covers Sections 6.1 l through 6.7 of ST-25. Rev. 03.
Results All acceptance criteria were met for the sections covered:
- No manual intervention was required after initiating automatic control.
- Steam generator level returned to and remained within 122 of the reference level, within 3 times the level controller time constant, following transfers and simulated level transients.
- Steam generator level overshoot (undershoot) was less than 42 following a level increase (decrease). .
- Feedwater pump discharge pressure oscillations were less than 132 of the final value.
l Table 1 is a tabulation of the results.
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5,3 ST-25. STEAM CENERATOR AUTOMATIC LEVEL CONTROL (Continued) l l
TABLE 1. ST-25 TEST DATA
SUMMARY
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Section 6.1 Feedwater regulation bypass valves in automatic, maintaining S/G 1evel at 502:
Controllers (2 Open) - Maximum 392 Minimum 362 Acceptance Criterion - No manual intervention None required.
Section 6.2 Main Feedwater Pump A operating in automatic, I Hain Feedwater Pump B operating in automatic. '
Acceptance Criterion - No manual intervention .
None required.
Section 6.3 Feedwater regulation block valve open, and feedwater regulation bypass valves in automatic maintaining S/G 1evel 4 l at 502:
( Controllers (2 Open) - Maximum 722 l Minimum 66Z f
Acceptance Criterion - No manual intervention None required.
Sections 6.4, 6.5, 6.6, 6.7:
Level Level (!) Recovery Level FW Pump Change Initial Time Overshoot- Discharge
, / Final (Seconds) Undershoot Pressure i
Osc.
Valve, FW-LK-4210 Raised 48.6 49.1 1326 None None l Lowered 48.9 48.8 1620 None None 4220 Raised 49.0 49.2 1380 None None Lowered 49.1 49.0 948 None None 4230 Raised 48.7 48.8 1104 None- None Lowered 48.8 49.3 1344 None None l
l 4240 Raised 48.8 48.8 1140 None None Lowered 48.8 48.8 1116 None None Acceptance Max. Min. .
Criteria 52 48 1800 <4! < 132 5-7 l
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5.4 ST-48. TURBINE GENERATOR STARTUP TEST Obiective The objective of the turbine generator startup test was acquisition of baseline operating parameters for the turbine generator and associated components, and operational data at each of the power level test plateaus for evaluating unit performance.
This procedure is described in FSAR, Chapter 14 Table 14.2-5, Sheet 51.
Discussion The turbine generator startup test, when completed, will demonstrate the following: '
The loss of primary or backup speed signals will not trip the turbine, but loss of both speed signals causes a turbine trip.
The Backup Overspeed Trip and Emergency Trip qircuits function as designed.
A power level at which valve testing can be performed without excessive load swing is identified.
The turbine-generator is capable of operating at various loads without exceeding any manufacturers' design limitations.
This section of Supplement 1 Startup Test Report, covers Section 6.1 of ST-46, Rev. 03, and demonstrated the first two functions. Additional sections of ST-48 will be performed at the 302, 502, 752, 902, and 1002 power level test plateaus.
GE Startup Engineers assisted PAT personnel throughout the test, and on occasion requested that additional measurements be made, or extended the time for gathering data.
No-load data was recorded for the following:
Turbine Steam Conditions Lube 011 System and Bearings Moisture Separator Reheaters Turbine Supervisory Unit Generator Generator Temperature RTDs Generator Temperature Thermocouples Alterrex Temperature RTDs !
MSR Cross-around Relief Valve Tail Pipe Temperature Test points yielding Control Valve (CV) and Intercept Valve (IV)
- positions, and additional turbine operating parameters, were monitored at )
hold points. Control and excitation systems were fine tuned, and on completion, the turbine generator was ready for testing at the 302 power l 1evel test plateau. '
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5.4 ST-48. TURBINE GENERATOR STARTUP TEST (Continued)
Results The acceptance criteria apply to test sections after Sec. 6.1. Since the result of the torsional tests did not allow synchronizing the turbine generator to the grid, no acceptance criterion has been met during this reporting period.
The test to validate loss of primary and backup speed signals was conducted at a reactor power of approximately 81, and a turbine speed of 800 rpm. Loss of backup speed signal was simulated by inserting a ground, and, when the ground was lif ted and turbine speed had recovered, the primary speed signal was similarly interrupted. Finally, both signals were grounded, and a turbine trip observed.
Adjustment of EHC to correct a speed control error signal and fine tuning of the system were conducted by the vendor with the unit operating at various speeds. The test was interrupted several times due to excessive bearing vibration, and on one occasion, when a large power fluctuation l external to the site disrupted site power momentarily, the turbine tripped. i IV oscillations were detected and adequate voltage to fully backseat the I valves determined to reduce the oscillations.
Four test exceptions were taken: nine RTDs embedded in generator windings are defective, but additional operational RTDs assure adequate monitoring of winding temperatures: three exceptions were written against inoperative instruments or readouts which were subsequently repaired.
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5.5 ST-48,1. TURBINE GENERATOR TORSIONAL RESPONSE TEST Obiective The turbine generator torsional response test determined torsional natural frequencies that occur near 120 Hz, and the location of turbine generator rotor system torsional resonant frequencies. The test was intended to measure adequate separation between resonant frequencies occurring near 120 Hz, and dynamic torques in the same frequency range, to prevent excessive torsional response stress of the rotor system.
Evaluation of turbine generator torsional response is not described in FSAR Section 14. General Electric recommended the test based on investigations at other sites which suggest that resonance excitation may '
induce sufficient vibrational energy (torque) to initiate cracks in the rotor structure.
Discussion Torsional oscillations of turbine generator rotors are detected with telemetry torque collars (to measure torsional dynamic strains on selected shaft journal bearings), and station instrumentation installed on the front and middle standard (to measure speed and phase angle).
A generator unbalance short circuit current, produced by placing a solid line-to-neutral short circuit on one phase in the high voltage switchyard, was utilized to measure torsional natural frequencies. The unit was completely disconnected from the power grid, and turbine generator speed control and field excitation used as test variables.
In the initial test, the machine was ramped from 100 rpm up to 1900 rpm, and then the speed was held at selected frequencies to verify and better define the torsional modes. Additional ramp tests were used to improve the signal in this range and determine background noise (excitation !
removec).
a GE test engineers reviewed the results and concluded that an unacceptable resonance required turbine modifications. '
f A turbine modification package was submitted by GE on April 30, 1990 which required removal of the 'C' low pressure turbine rotor. The modification package was completed and testing under ST-48.1 resumed on May 25, 1990. During the outage, a Revision 4 of ST-48.1 was prepared for the necessary retests, and these were completed on May 29, 1990.
Upon completion of the torsional response test. GE reviewed the results and indicated that the modifications had corrected the problem.
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TURBINE GENERATOR TORSIONAL RESPONSE TEST.(Continued)
Results The acceptance criteria acquisition of the required data, and analysis l to ensure that no corrective action was necessary, were met. There were no test exceptions.
In preparation for the tests, station loads were transferred to the Reserve Auxiliary Transformers (RATS) and the Scobie 345 Ky transmission line isolated. A generator unbalance short circuit current, produced by placing a solid line-to-neutral short circuit on the C phase of the Scobie line, was utilized to measure torsional natural frequencies. The turbine generator speed control and field excitation were used as test variables.
The turbine was brought up to 1800 rpm, in steps, to establish i excitation limits for the tests. Field currents producing 52 and 72 '
excitation (of the maximum C phase ground current. 485 amperes) were used.
The unit was then rampen Gwly from 100 to 1950 rpm and from the data, GE test engineers establii W the specific speeds at which more detailed evaluations were to be made.
Measurements were made by the GE test team at a number of speed hold points. Data evaluation followed, and upon completion, an unacceptable resonance had been identified. ST-48.1 was terminated, and turbine 7 modifications. undertaken by GE.
To shift the resonance frequency, alterations were made to the 'C' low pressure turbine rotor. The tie wires on the buckets of the final low pressure stage was replaced and brazed which had the effect of changing the rotor frequency response.
While the rotor was removed from its housing, some rub marks, noted when the rotor waw lifted from the housing, were eliminated by shroud replacement on the thirteenth stage.
When the turbine was reassembled, a revised torsional response test was performed to verify correction of the resonance problem. GE engineers reviewed the results and concluded that there was no longer a problem. A synchronization test, included in the revised torsional test sequence, to be performed if necessary, was omitted.
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6.0 INSTRtMENT CALIBRATION AND ALIGNMENT Contents 6 .1 ' ST-13. Operational Alignment of Nuclear Instrumentation 6.2 ST-28, Calibration of Steam and Feedwater Flov Instrumentation 4
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- 6.1 ST-13. OPERATIONAL ALIGNMENT OF RUCLEAR INSTRUMENTATION Obiective The objective of this procedure was determination of various voltage, trip, alarm, operational and overlap settings for the source, intermediate and power range instrumentation. Portions of ST-13 will be performed at a number of power levels and at each of the power level test plateaus in Power Ascension Testing.
The procedure is described in FSAR, Section 14, Table 14.2-5 Sheet 16.
Discussion Calibration of nuclear instrumentation, including alarm settinge, trip points, and operational ryntjes cannot be properly completed until the system is functioning on 1;ns. in its intended operational ranges. At each test condition, the nucleh ins ts"gaent s are adjusted, using the best available conservative infe'rmit ton , Initially. setpoint data furnished by Westinghouse was ated, und, as higher naa;4cb fluxes became available, these values were superseded by actual measured data.
the sections of ST-13 completed and included are:
- 1. Prior to Criticality (Hot Standby) 1.1 Adjustment of Intermediate Range (IR) rod stop and trip setpoints based on Ic5 power physics test data.
1.2 Scaling of each Power Range channel based on full power currents and Axial Flux Difference (AFD) values obtained from Reactor Engineering.
- 2. Initial Criticality During PAT Program 2.1 Initial adjustment and verification of operability of Trains A and B. Shutdown Monitor, during approach to criticality. The shutdown monitor continuously measures and displays a countrate from neutron detectors (Train A and Train B) installed in spare excore detector wells, and alarms when the countrate exceeds the alarm setpoint.
This section of Supplement 1, Startup Test Report, covers Sections 6.1 and 6.2 of ST-13 Rev. 05.
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Results The adjustments and scaling required in the precritical portion of ST-I 13 were satisfactory. There were no acceptance criteria.
The shutdown monitor operability test was conducted during initial PAT criticality av the countrate increased. The shutdown monitor establishes the alarm setpoint as a fixed multiple of the lowest measured countrate, and a higher current value of measured countrate can be established as the setpoint reference by depressing the alarm setpoint reset. The shutdown monitor was set up to alarm at a value 1.5 times the reference value.
Thus, in ST-13, by recording the alarm value and resetting the alarm-setpoint at each alarm level, operation of the shutdown monitor was validated over a range of approximately four decades. Acceptance criteria for the shutdown monitor:
- 1. Recorded alarm setpoints were within
- 102 of 1.5 times the previously recorded countrate for a train, and
- 2. Countrates recorded at alarm were equal to the train's previously recorded alarm setpoint,
- 102, were not met in 15 of 22 values on Train A, and in 13 of 22 values on Train B. However, since the shutdown monitor was designed to detect a slow increase in counts from an undetected dilution, the test method was more of a challenge to the device than vould be encountered in normal service.
With one exception on Train A, all values which failed the criteria were outside the limits on the low sides the system performance was more conservative than required. The acceptance criteria were established as a performance guide, without recognition that the test did not simulate actual plant conditions for the device in normal service. A test exception was.
prepared to address the failure to meet acceptance criteria.
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.. 4 6.2 ST-28. CALIBRATION OF STEAM AND FEEDWATER FLOV INSTRUMENTATION Obiective .
The objective of this test was calibration of the main steam flow transmitters based on feedwater flow measurements.
This procedure is described in FSAR Section 14. Figure 14.2-5, Sheet 31.
Discussion The calibration of steam and feedwater flow instrumentation is an ongoing startup test, where data is collected at each test plateau.
At hot zero power -
Main steam flow transmitter calibrations were performed to monitor any zero shift changes from cold conditions.
At each power level test plateau - Steam and feed flow data will be collected at 302, 502, 75%, 90% and 1002 power.
At the 100% power level test plateau -
Steam flow and feed flow transmitter outputs will be comparodi steam flow output will .be.
corrected to agree with feed flow within the required accuracy.
Feed flow data is obtained from ST-26 Thermal Power Measurement and Statepoint Data Collection, test results. The feed flow data is the basis for determining feed flow.
This section of Supplement 1 Startup Test Report, covers Section 6.1 of ST-28 Rev. 04.
Results In the hot zero power check, all points were within the specified tolerance. One value, close to being out of tolerance, was adjusted.
There was no acceptance criteria for this portion of ST-28. I l
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7.0 GENERAL PLANT TESTING I l
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l 7.1 ST-52. Thermal Expansion 4
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e 7.1 ST-52. POWER ASCENSION THERMAL EXPANSION TEST l
Obiective l The objective of this test was a demonstration that piping systems were free to thermally expand consistent with design. These measurements. j confirmed that associated restraints and supports allow the required thermal I movement.
1 The test is described in FSAR, Section 3.9.3.4.d. and Section 14, l Table 14.2-3, . sheet 6.
I Discussion The rmal expansion data was obtained from displacement measuring transducers and by visual observation of. spring hangers, snubbers, and pipe whip restraints. Walkdowns were performed to identify areas of potential restraint to free movement.
The following systems were monitored at the Hot No-Load (555-559'F) condition:
- 1. Snubbers:
Auxiliary Steam Condensate Primary Component Cooling Chemical and Volume Control Diesel Generator Feedwater Main Steam Main Steam Drains Nitrogen Gas Reactor Coolant Residual Heat Removal Steam Generator Blowdown Spent Fuel Pool Cooling Safety Injection Service Water Waste Processing Liquid Drains
- 2. Spring Hangers:
Condensate Extraction Steam Feedwater Heater Drains Main Steam Main Steam Drains Moisture Separator & Reheater Drains / Sampling System Adjustments were made, during the test sequence, to spring hangers which were not within their hot and cold settings.
This section of Supplement 1 Startup Test Report, covers Section 6.2, of ST-52, Rev. 02 7-2
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7.1 ST-52. POWER ASCENSION THERMAL EXPANSION TEST (Continued)
Adjustments were made, during the test sequence, to spring hangers which were not within their hot and cold settings.
The following system was monitored during a turbine driven EW pump runt
- 1. Snubbers:
Main Steam (associated with EW pump)
This section of Supplement 1. Startup Test Report, covers Sections 6.2 and 6.7 of ST-52, Rev. 02.
Results Acceptance criteria for thermal movements were specified for Westinghouse (NSSS) scope, for UE&C scope, and for completion of NHY Engineering review. The results met all acceptance criteria.
Nine problem log sheets were developed during measurements at Hot No-Load. One problem identified deletion of a spring hanger by design change.
Another identified shipping lugs installed on a spring hanger (subsequently removed). The remaining seven problems related to pipe movement not within tolerance. These conditions have been evaluated by Design Engineering and were determined to be acceptable for the next power level test plateau.
No problems were encountered in the EW pump measurements.
There were no test exceptions.
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