ML19254F943

Responds to NRC Requesting Addl Info Re Lift Frequency of Power Operated Relief Valve & Safety Valve. Submits Data Compiled by B&W for All B&W Operating Plants

ML19254F943
Person / Time
Site:	Crystal River
Issue date:	11/14/1979
From:	Moore G FLORIDA POWER CORP.
To:	Reid R Office of Nuclear Reactor Regulation
References
3--3-A-3, 3-0-3-A-3, NUDOCS 7911190489
Download: ML19254F943 (24)

Text

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O 0o0 Florida Power CO R PO R A T IO N November 14, 1979 File:

3-0-3-a-3 Mr. Robert A. Reid Chief Operating Reactors Branch #4 Division of Operating Reactors U.S. Nuclear Regulatory Commission Washington, D.C. 20555

Subject:

Crystal River Unit 3 Docket No. 50-302 Operating License No. DPR-72

Dear Mr. Reid:

Enclosed is Florida Power Corporation's response to your letter of September 28, 1979 requesting additional information concerning the lift frequency of the PORV and safety valve at CR#3.

As indicated in our October 15, 1979 response, this requested data was being compiled by B&W for all of the B&W Operating Plants into a single data base. The enclosed response represents the results of this activity.

If you have any questions regarding our response, please contact us.

Very truly yours, FLORI,D,A POWER CORPORATION g

C. C. Moore Assistant Vice President Power Production GCMemhWO6 1344 135 7

7 911190 N

/

General Office 3201 Thirty-foe in street soutn. P O Box 14042. St Petersburg. Fionda 33733 e 813-866-5151

STATE OF FLORIDA COUNTY OF PINELLAS G.

C. Moore states that he is the Assistant Vice President, Power Production, of Florida Power Corporation; that he is authorized on the part of said company to sign and file with the Nuclear Regulatory Commission the information attached hereto; and that all such statements made and matters set forth therein are true and correct to the best of his knowledge, information and belief.

(h

, htD(.-

" ' G'.

C. Moore Subscribed and sworn to before me, a Notary Public in and for the State and County above named, this 14th day of November, 1979.

Notary Public Notary Public, State of Florida at Large, My Commission Expires: August 8, 1983 CameronNotary 3(D12) 1344 136

I-l ATTACHMENT I (12 PAGES)

Request i According to statements made by B&W, there are approximatel; 146 documented occasions where PORV actuation occurred at Ball f acilities prior to the accident at Three Mile. Island, Unit 2 (TMI-2).

For each of these events which have occurred at your facility (ies), provide the following information:

a.

The cause of the event; b.

the init'ial power level prior to the transient; c.

Indicate which of these transients caused the reactor to trip on hiah RCS pressure and/or caused the safety valves to lift; and, d.

If you assume that the present setpoints for high RCS pressure trip and PORV actuation were in effect at the time of each of these transients, estimate whether either of the followina would have taken place:

(1)

PORV actuation, and (2) lifting of the safety valves.

(For this item assume no credit for the anticipatory control-grade reactor trip on loss of feedwater or turbine trip.)

Response

The requested information has been compiled in the followina plant specific tables (Reactor trips with a PORV actuation).

In addition, there have been seven (7) instances when the PORV stuck open - three (3) when the plant was at power and four (4) when it was not producinq power.

a.

At power:

(1)

Oconee-3, June 13, 1975 (Feedwater oscillations while shutting down)

(2)

Davis-Besse 1, Sept. 24, 1977 (Loss of Feedwater)

(3). TMI-2, March 28, 1979 (Loss of Feedwater) 1344 137

I-2 ATTACHf1EllT I ('C o n t ' d )

b.

flot producinq power:

(1)

Oconee-2, August 15, 1973 (Pre-op Testing)

(2)

Oconee-2, flovember 6, 1973 (RCS'Heatup)

(3)

Davis-Besse 1, October 13, 1977 (Hot Standby)

(4)

TMI-2, March 29, 1978 (Zero Power Physics Testing)

}3kk kbb

y -

1-3 P^RY A0Telt.? ION 4 - ocr ?:rE-1 (" A c" 1)

PT. ACTOR TRIPS WITH A PORV ACTUATION Ir PRESENT SETPOINTS p.,

"^

INITI AI.

SAFETY TRANSIENT TRIP POWER VALVES PCRV LIFT S AFETY DATE CLASSITICATICN SICNAL CAL'SE Cr TRANSIENT LEVrl.

LIrTED7 ACTUATICN7 VALVES 7 5-5 73 Loss of reedwater Manual operations Error Tripped 18 No No No MrW Pump 5-16-73 Loss of reedwater Hi RCP operator Frror 15 No No No 5-23-73 Loss of reedwater Hi RCP Operator and/or Procedure 25 No No No Error 5-26-73 Loss of reedwater Hi RCP Operator and/or Procedure 35 No No No Error 5-27-73 Loss of reedwater Hi RCP Began as CRDM rault 40 No No No 5-28-73 Loss of reedwater Hi RCP Atterpt to Transfer from 40 No No No 8 to A FWP 5-30-13 Loss of reedwater Ei RCP Cleaning Hotwell Purp 40 No No No Strainer 6-9-73 Loss of reedwater Hi RCP Switching Powdex Units 40 No No No 6-13-73 Turbine Trip Manual CRON rault rollowing 52 No No No Turbine Trip Test and ICS Runback Signal 6-14-73 Loss of reedwater Hi RCP Malatenance Work'on Hotwell 40 No No No (7)

Strainer

. 6-21-73 Loss of reedwater RCP/

Tripped Hotwell Pump 19 No No No Temp Initiated rWP Trip Ratio

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - P rio r to Comme r c ia l np e ra t io n - - - - - - - - = = = - - - - - - - -

7-15-73 Loss of reedwater Hi RCP raulty Speed Centro 11er on 75 No No No a Main rW Pump 8-11-13 Turbine Trip Loss Pwr Inadvertent closure of 85 No No No to Pumps Turbine Intercept Valves Ind.

9-16-73 Turbine Trip Hi Temp Manually Initiated Turbine 40 No No No Pressure Trip Decreased Closing Ratio Setpoint of Bypass Valves 3

10-12-73 Turbine Trip Hi RCP Main Steam Bypass Valves 20 No No No did not open: Operator put rods in manual 10-26-73 TurbLne Trip Hi RCP Loss of condensor vacuum 75 No No No 12-11-73 TurbLne TrLp EL RCP Spurious MWe Signal 90 No No No Detected by EHC System lead to Turbine Trip 8-23-74 Load Rejection El RCP Unit Loss of Electrical 95 No No yo Load Acceptance Test 3-12-75 Loss of reedwater Hi RCP Shorted Transistor in 25 No No No ATc Controller 4-22-75 Turbine Trip Hi RCP Loss of EHC Control Power 100 No No No 4-23-75 Lcss of reedwater Hi RCP Rapid reedwater Oscillations 46 No No No 6-8-73 Turbine Trip Hi RCP Low EHC Hydraulic Pressure 100 No No No T.T 6-9-75 Loss of reedwater Hi RCP rw Flow esci11ation 30 No No No 8-2-75 Instrument railure Hi RLT railure of Temperature 75 No No No Switch on Stator Coolant System 8-8-75 Turbine Trip Flux /

Positive Voltage Spike in 92 No No No riow Turbine Speed Error Circuit 1-22-16 Turbine Trip Hi RCP Loss of Excitation on 100 No No No Generator 5-31-76 Loss of reedwater Hi RCP rWP Turbine IH Speed s15 No 10 No Morentartly necretsed when Switching from Auat11ary to

14 PenV MT' AT t v = v' ' 'T-1 (r vr 21 REACTOR TR!f"*. WIT!! A t'0HV AC1'ATIrN Ir PPF9FNT SFTDO!NTS P2R

!;f!TI AL FArhTY

"^

TRANSIENT TRIP PPWFR VALVES PORV Lfr? SAFETY DATE CLASStrICATICN SICNAL CAUSE Cr TRANSIENT LFXEL LIFTED?

ACTUATIOM7 VALVES?

6-27-76 Instrument railure ill RCP Short in Signal Arp for 100 No No No RPS r!cv Indications Secondary Flow Runback 7-7-76 Hi RCP Personnel Error 99 No No No 7-14-76 Loss of reedwater and Power Hi RCP ICS !!and Power circuit 100 No No No Supply railure Breaker Tripped when Circuit was overloaded with Calibration Equipment 8-14-76 Rod Drop HL RCP Heat and Moisture Affected 60 No No No Electrical Components in CRD System Cabinets 4-3-77 Instrument railure Hi RCP railure of ICS Component s15 No No No 4-24-77 Turbine Trip Hi RCP Misaligned Linkage Cauged 68 No No No High Moisture Separator Reheater Drain Tank Level 5-24-77 Turbine Trip H1 RCP Loss of Condenser vacuum 70 No No No 6-6-77 Turbine' Trip Hi RCP Personnel Error 99 No No No 10-18-77 Loss of reedwater Mi RCP Standby Condensate Pumps 15 No No No Off 12-10-77 Loss of reedwater Hi RCP Personnel Error - Inadver-100 No No No tent Closure of MFW Block Valve 8-1-78 Turbine Trip Hi RCP High Level in Motsture 95 No No No separator Tank Caused by railure of MSDT Dump valve and MSDT Level Control valve 8-2-78 Turbine Trip and Power Hi RCP EHC-DC Pewer Lost 100 No No No Supply railure 12-25-78 Power Supply railure Mi RCP Blown rutas Led to LorW 10 No No No 3-23-79 Instrument railure Mi RCP Startup FW Summer Module 100 No No No

' railed 9

3344 140

f.5 pery Ary m7? ^*pt re-apr-2 f e ve 1)

PEACTOR TRIPS w tT!! A PCHV ACTUATION Ir ePrtFNT SETPOINTS INITIAL SAFk*Y HAD BEEN USED TRAN9trNT TRIP POW"R VALV"3 PORV LIr? SAFETY DAfr CLASStr! CATION SICNAL CAUSE Or TRANSIrNT LEVEL LITTFD7 ACTUATION 7 VALVES?

12-2-73 Loss of reedwater Hi PCP Leak in l' Line Around 15 No No No one rWP. Operster Manipulation of rd SU Valves Led to LOfM 12-3-73 Loss of reedwater Hi RCP Control Red aroups 9

No No No 6 and 7 Lost Proper overlap 12-12-73 Loss of reedwater Hi RCP Too Large a Pressure Loss 30 No No No in Powdex Units. Conden-sate Sooster Pumps Tripned 1-4-74 Turbine Trip Hi RCP Erroneous Activation of 75 No No No Breaker railure Pelay System 5-30-74 Manual Rx Trip Manual Operator Mtstakenly Injected 75 No No No HP1 Water into RC System 6-13-74 Turbine Trip Hi RCP Turbine Intercept Valves 1

No No No Closed Due to raulty Pot

- - - - - = = - - - - - - - - - - - = = - - - - - - - - - - - - Prior to Commercial Operation - - - - - - = = = - - - - - - - -

9-17-74 Turbine Trip Hi RCP TT Curing Testing of Thrust 100 No No No Bearing Wear Detector 9-23-74 Power Supply railure and Hi RCP ICS Power Lost During 95 No No No Loss of reedwater Switching of reeds to Inverter. Main reed Pumps Tripped 3-27-75 Load pejection Hi RCP Logs of Electrical Load 100 No No No Test During startup 3-27-75 Instrument railure Manual Loss of Condensor Vacuum 15 No No No Led to rWP

• rip 4-1-75 Turbine Trip Hi RCP Manual Trip as Part of 100 No No No Turbine / Reactor Trip Test 8-5-75 Loss of reedwater Hi RCP 810wn Casket on rmergency 62 No No No Governor Lockout Valve in Hydraulic Control System 8-23-75 Loss of reedwater Manual Malfunction of Condensor 14 No No No Vacuum Switches Tripped rWPs. Reactor Manually Tripped 9-19-75 Loss of reedwater Manual TWP Trip on Low Vacuum.

10 No No No Manual Reactor Trip 7-12-76 Turbine Trip Hi RCP rw Oscillation ocurred 23 No No No While Taking Main Turbine off Line 7 27-76 Loss of reedwater Hi RCP Stean Leak on Main Turbine 20 No No No caused Load to Hold at 204.

ICS Caused rw Oset11ations 9-7-76 Turbine Trip Hi RCP Back-Up Speed Control System 100 No No No railed and Intercept Valves Closed During TT Test 5-4-78 Turbine Trip Hi RCP Moisture separator Level 100 No No No Controls railed to Function 10-17-78 Loss of reedwater M1 RCP Air Line 81ew Off Startup 100 No No No rw Valve 10-10-78 Loss of reedwater Hi RCP Welding Crew Ignited 011 55 No No No Around rW Pump with Sparks, causing fwP to Trip 10-10-78 Loss of reedwater Hi RCP FW Pump Leak.

Switching of 12 No No No Purps not Accomplisned e

1344 141

I-6 porv v -,..-ir c e<~ v. -3 REACTOR TRIPS WIT:t A POPV AC* RATION Ir PPEFENT *ETPOINTS P2R INITIAL SAthTT MAO OEIN U8EU TPANSIENT T3t?

PnwrA VALVES POPV LIFT SAFF" CATE CLASS!FICATION SICN AL CAUSE Cr TRANS!rNT LEVEL LITTED7 ACTUATION 7 VALVES?

10-13-74 Loss of teetwater Power to Debris obstructed Hotwell

'5 No No No Purpe Pump Straicer 10-17-74 Loss of reedwater Hi RCP Dehris Cbstructed Hotwell 16 No No No Pump Strainer

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - P ri o r to Cnmee r c ia l ope r a tio n - - - - - - - - - - - - --- - - - -

4-7-75 Loss of readwater Hi RCP Servicing Powdex Tripped 75 No No No Condensate Booster Purp 4-30-75 Load Rejection Hi RCP Loss of Electrical Load 100 Yes No*

No Test Low RCP while Shutting Down, Turbine 19 No No No 6-13-75 Switched to Manual at 194, Bypass Valves Opened, ULD Increased FW Demnd M FWP and OTSG Level oscillations 7-1-76 Turbine Trip Power to TT on Low Turbine Shaf t 011 98 No No No Pumps Pressure 4-6-77 Turbine Trip Power to TT on Momentary Loss of 100 No No No Pumps DC Power to EHC 8-21-77 Loss of reedwater Hi RCP Manual Adjustments to rW 15 No No No by CPerators 11-3-78 Loss of reedwater Hi RCP TT Due to Low rwP Discharge 44 No No No Pressure 2-21-79 Instrument railure Mi RCP Noise Spike on ICS Cable 99 No No No After CROM Testing

• SETPOINT wCUI.D MAVE BEEN PEACHED, SUT BLOCR VALVE WAS CLOSED.

1344 142

!7 PM V A & AT?m:

" Art -tT W -1 REACTOR T. TIPS WITil A PORY ACTt'ATICN IF PPF9ENT SFTPOINT9 pf,

"^ O IO INITIAL FAFETY 1RANSICNT TRIP POWrR VALVES PORV LIFT MAFETY DATE CLASSIFICATION SION AL CAUSE OF TRANSIENT LEVEL LIFTED?

ACTUATICN7 VALVES?

982-77 Turbine Trip Lo RCP CTSC Overfed by cperator s t3 No No No 9-24-77 Loss of reedwater Manual

" Half-Trip

• of SFRCS 9

No No No Isolated OTSca 10-23-77 Loss of Teodwater Lo PCP SFRCS Caused Isolation of 16 No No No 1 OTSC, Later Both

................................... Prior to Conmercial Operation - - - = = - - - - - - - - -

12-16-77 ICS in Manual Lo RCP Ove-fel

• B' OTSC. Operator 11 No No No had MFM Pump in Hand 12-30-77 Loss of Feedwater Lo PCP FWP Tripped on High Exhaust 72 No No No Casing Water Level 1-31-78 Loss of Feedwater Hi RCP Spurious SFRCS Trip After 67 No No No Performing SFRCS Monthly Test 3-1-78 Loss of Feedwater Hi RCP SFRCS Actuated on FW/STM 49 No No ho Pressure AF Demerator Level Cont. Valve Failed Shut 4-2-79 Turbine Trip Lo RCP TT Test - During Runback, 75 No No No Rx Tripped, Overfed OTSG's 9 10-78 Turbine Trip Lo RCP Tripped Turbine for Test

%75 No No No TP-400-14 9-28-78 Instrument Failure Lo RCP Loop 2 RCS Flow KM7R Failed 90 No No No Low, Runb'ack 9 204/ Min Initiated. Operator Lost Control 10-3-78 Turbine Trip Lo RCP TT Caused by Starting 2nd 68 No No No EHC Pump. ICS Oversupplied FW 10-29-78 Loss of Feedwater Lo RCP EM Relief Cycled and Stuck 4

No No No Open Too Long 11-13-78 Power Supply Failure Power to Fuse for RC Purp Control gg No No No Pumps Circuitry Blew 1-12-79 Loss of Feedwater Hi RCP Technician Shorted Inverter 100 No No No Causino Losa of Vital Bus Y2s SFRCS Trip 2-22-79 Lose of Feedwater Nf RCP

?alfunction fn Turbine epeed 87 No No No Control System Led to SFRCS Actuation 1344 143

18 mov Ae-r 3?mnt

-rs:rm mn REACTOR TR'PG WITH A PCRV ACT'7TTON Ir PREFf'NT SETPOINT INIT!AL hTY TRANSirNT TRtP POWrR VALVIS PCRV LIFT SArETY DATE CLASSIr!CATICN S ION AL CAUSE Cr TRANSIT!!T LC'ft:L LIFTED 7 ACTUATION 7 VatVES?

11-19-74 Loss of reedwater Manual rcw Des 1112tions During 25 No No No ICS *uning 11-22-74 Loss of reedwater and Hi RCP

• echnician Mtsop ration.

32 No No No Power Supoly railure Power Lost to "Y" and "2"

NNI Busses 12-4-74 Loss of reedwater HL RCP Inadvertent Actuation of 40 No No No Reheater Intercept Valve 12-15-74 Rod Drop (cRP. 66 7)

La RCP CRDM Motor raults Programmer 39.5 No No No Assenbly 12-17-74 Rod Drop (GRP. 7)

Lo CRP Same as Preceding Transient 41.3 No No No 12-26-74 Loss of reedwater and Hi RCP railure of 2 SCR's in "C" 39.5 No No No Power Supply railure Invertir 17-31-74 Power Supply railure Pressure / Operator Error in Paral-40 No No No Temp.

leling Inverters 2 12-75 Turbine Trip Hi HCP Spurious Overspeed Trip 92 No No No Signal 2 18-75 nanual Load Pajection La RCP Poor ICS Tuning 75 No No No for Trip 4-14-75 Loss of reedwater Hi RCP Startup Valve in Auto 15 No No No (Closed), but "A" OTSC Blew Down

................................... Prior to Commercial Operation - - - - - - - - - - - -

6-15-75 Loss of reedwater Hi RCP Transferring Steam Supp1v 13 No No No for FWP f rcm Aux. to F.ain Steam 10-10-76 Loss of reedwater Hi RCP rwP Speed Control Logt.

13.6 No No No rwP Covernor was Dirty 10-10-76 Loss of reedwater Hi RCP Same as Preceding Transient

?

No No No 1-13-77 Loss of ree1 water Hi RCP Technician Shorted out rwP 98 No No No Thrust Searing Indicator 1-5-78 Unknown Hi PCP Unknown 100 No No No (7) 3-20-78 Loss of reedwater Hi RCP Dropped Light Bulb Shorted 72 Yes No No NNI Cabinet 12-31-78 Loss of reedwater Hi RCP Condensate Valve railure 100 No No No 1-2-79 Loss of reedwater Hi RCP Loss of Vital Bus 1A 100 No No No 1-5-79 Lose of reedwater El RCP Technician Shorted Wires 100 No No No in ICS Cabinets 1 M 4 144

!.9 Pm,V ACTt**.T y m - A_No-1 REACTOR TR1r1 WITtt A PCPV ACTUA*'ON Ir PPE$ENT 9ETPOINTS pg,h?Y HAD RFTN L3CD S AT INITIAL POWF9 VALVES PORV

. LIFT SAFETY TRANSICNT TRIP DATE CLAS$1rICATION

$1CNAL CAUSE Cr TRANSirNT LEVEL LIFTED 7 ACTUATION 7 VALVEg?

10-15-74 Loss of reedwater H1 RCP

• A*

rwP Tripoed on fligh 45 No No No Vibration 12-6-74 Loss of reedwater Pressure / Loss of vacuum Due to *5*

90 No No No Temp Main Chiller Cettina Wet and Shorting

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Prior to Comrercial Operation - - = = - - - - - - - - - -

1-6-75 Load Rejection Hi RCP Cenerator Tripped on 98.5 No No No Differential Current Due to Loss of Buss Cooling 5-15-75 7

Pwr/

Flow Oscillations occurred 100 No No No Imbalance During Maneuvering riow 6-6-75 Instrument railure Pwr/

Loose Connection on Loop 99 No No No Imbalance "B" Te Signal Flow 7-3-75 Instrument railure Pwr/

Technician Grounded TH 95 No No No Imbalance Signal to ICS Flow Pressure / Cperator Lost Htr. Drain 50 No No No 7-23-75 Lese of reedweeer Temp Pump which Tripped FWP 7-8-76 Loss of reedwater/ Power Hi RCP Inst. Techs Shorted NNI 94 No No No Supply railure Power Supply 9-23-76 Turbine Trip Hi RCP Turbine Tripped when Vibra-99 No No No tion Trip Module was ReLnserted by Technician 12-20-76 Rod Drop / Power Supply Hi RCP Rod 8 in Grouo 4 Dropped.

64 No No No railure Coupled with Loss of Y-11 Inverter 6-19-78 Turbine Trip Hi RCP Technician or Operator 7

No No No Error in Opening Wrong reeder Breaker 9-16-78

==

ni riux surned out control Air

?

No No No Solenoid On KSIV 10-13-78 Instrueent railure Pressure / RPS Channel *B*

RC 7

No No No Temp riow Signal railed 12-20-78 Instrument railure Pressure / Low Steam Pressure 99 No No No caused by LVDT Lankage Teme Breating 1 H 4 145

1 13 F0pv A & -ton. Twe-1 SEACTOR TRIP 5 WITH A PORV ACTVATION IF PRESENT 9tTFotNT F2R.

MAD SEEN CSED INITIAL SAFFTY POUFR VALVES P0kV LIFT SAFF; TRAN$ TENT TRif DATE CLASSIFICATION

$1CNAL CAUSE OF TRAN$ TENT LEVEL LIFTFDT ACTUAft0N?

VALVE 5?

4-18-74 Lees of Feedwater M1 RCP "A" toetrument Ntt 7

No No No Compresser Tripped en Thermal overload 7-13-74 Lese of Feedwater Freasure/ LOFW Noticed Feier to 15 No No Me Temp 3-set. Red Withdrawal F-14-74 Lees of Feedwater Pressure / TechatcLan Grounded 76 We We No temp T3yg $1gnal 4-13-74 Lead aejecties (Test)

Ei RCP Cenerater Trip Test 98 No No No 8-30-74 Turttee Trip Ri RCP Turbine Bearing Failure FS Ne No Ne

.................................. P r i o r t o C o mm e r c i a l op e r a t i e s = = = = - - - - = = * - - - -

3-30-75 Tertime Trip El RCP Ernesseue Signal from 100 No No No Faulty 701 Relay tadicated Lose of 125-V Supply to Turbine, ENC Systems S-9-75 Turbine Trip R1 RCP "3" Meisture separater 100 No We No Desta Tank High Level Trip Device Shefted 4-18-75 Turbine Trip N1 RCP vettage spikes Transmitted 100 No No Ne late Terbine ENC Systes 11-14-77 ICs Campement Failure Flus /Flev ICs signal-Convertar "L" 100 Ne No No Embalance Module Failed to Midrange 1744 146

!.11 Pney AcTU4Ttogs - Twe-2 REACTOR TatPS WIT!t A P0AV ACTUATION 17 PRESENT SETPo!NTC p.g INITIAL

$AF TT TRANSIENT TRIP POWER VALVE $

PORV LIFT SAFETY DATE CLA$$1FICAT105 SICNAL CAUSE OF TRAN517.NT LEVEL LIFTED 7 ACTUATION 7 VALVE $7 No Pumps in Loop "A" 11saal. Fuse 11ew in 2*IV.

RCP-2A Already Out 4-19-78 Lees of Feedwater 81 RCP Operator Blev Dawn 15 No No NO Condensate Strainere 9-20-78 Lees of Feedwater N1 ECF Valving Error Tripped Condensate Beester Pump 24 No No No 9-21-78 Lev Feedwater R1 RCP Feed Pump and Feed Reg.

19 Ne Ne No Valve Probleme 9-23-78 Lead Rejectise Normal Ni RCP Migh Pressure Due to 17 No Me No Redustag Lead on Turbine.

Incorrect Section Pressure Switch or Logia Error en C.B.

Pumpa Caused FWP Trip 10-14-78 Lees of Feedwater Le RCP FWP-1A Lost 26 No No No 11-7-78 Lees of Feedwater Pressure / TP-800-05 (Peactivity 92 No No No Temp Coefficients) was being performed at TAVE

• 588F.

Nester Drain Tank Low Level Alere Tripped FWP-13.

=

1-15-79

!astruneat Failure Le RCP Atmospheric Relief Se11ews S

No No No Failed

'l I ti E

l

1-14 POPV tc* m T'es

- tmV iT

• f.

eP/TP-1 RIACTOR TRIPS WIT 14 A PORV ACTUATION Ir PPE?rNT SETPOINTS pg,bTY HAD BEEN USED SAr INITIAL TRANPIENT TRIP PONER VALVES PORY LIr? SAFETY DATE CLASSIr!CATICN SICNAL CAUSE Cr TRANSIENT LEVFL LIFTED 7 ACTUATION 7 VALVE 37 1-30-77 Instrument railure/rurbine Lo RCP Manaal TT Due to Low 15 No No No Trip Turbine Header Pressurn Coupled with Inoperable MW Peter 3-2-77 Power Supply railure Loss of 120 VAC-3 Vital Bus was 40 No No No CRD Pwr Lost Due to ra11ure of Diode in *B*

Inverter Manual Reactor - Turbine Trin 40 No No No 3-9-77 Test TP-800-14

• • -*--**---- ----------==--===-- Prior to Commercial Operation - - - - - = * - - - - - - - - -

4-21-77 Fower Supply railure Power /

• X* Power supply to ICS 46 tio No No t pumps Lost cue to olown rune 4-23-77 Manual Part of Test (outside 20 No No No Control Room) 10-26-77 Power Supply railure/

Hi RCP Inverter *A* Tripped 100 No No No Turbine Trip / Loss of CausLng a Loss of Power reedwater to Vital Bus "A" 1-6-79 Turbine Trip Manual TT rollowed by rw Block 71 No No No Valve rwv-30 Sticking open or Partially Open 1-17-79 Loss of readwater Manual Solenoid railure on Inlet 100 No No No Seawater Block valve to Secondary Services Heat Exchanger "A".

1-30-79 Loss of reedwater Lo RCP Reason for Dacrease in 100 No No No FW Not S tated 7-17-77 Rod crop Manual Grp.1 Dropped During 90 No No No Surveillance Test 11-13-77 Loss of reedwater Pressure / FW Upset while Passing 57 No No No Temp Block Valve.Foint.

Cause is Operator Control and Pocr Control System Operation / Performance 1344 148

11-1 ATTACHMENT II (7 PAGES)

Request 2 Provide a complete listing of reactor trips for your facility (ies) which have occurred subsequent to the revised setpoints for PORV actuation and high RCS pressure trip.

This listing should include the followina items:

The cause of each event; a..

b.

The initial power level prior to the transient; Indicate which of these transients caused the PORV and/or c.

safety valves to open; and, d.

If the old (pre-TMI-2) setpoints for high RCS pressure and PORV actuation were in effect at the time of these transients, estimate whether any or all of the following would have taken place:

(1)

PORV actuation; (2)

Reactor trip on high RCS pressure, and (3)

Lifting of the safety valves.

Response

This information has been compiled and is presented in the attached tables.

The hypothetical actuation of the PORV and/or safety valves and high pressure trip assuming the old setpoints had been in effect is not based on any analytical technique.

Rather, Engineerina judgement, coupled with past operating history led to these results.

O 1344 149

6 11-2 REACTOR TRIPS SINCE THI OCONEE 1 If Old Setpe,ints ited hen U<ed Initial PCRV P7R PORV 1 rip or,liigh Lift Safety Date Transient Classificaticn Cause of Transient For.cr Lifted?

Safety Actuation?

Pressure?

Valves?

Level Valves t

Lifted I

6-11-79 l'as of feedwater Ei!C Card Failure 99 No No No No No l

6-11-79 Hanual Reactor Trip Low OTSG Level 1

No No No Na No 6-17-79 Two RC Pumps Tripped 97 No No No No No j

8-6-79 Turbine Trip Valving-out of 40 No No No No No i

Pressure Switch i

e i

i e

i 4

I l

t 6

i 0

e 1.-a

=

l

-@Db i

s C' )

---. 4 11-3 REACTOR TRIPS SINCE TMI-2-OCONEE-2

!f Old Setpoir.ts liad Ecen Used Initial PCRV PIR PCRV 1 rip on liigh Lift Safety Date Transient Classification Cause of Transier.t Po6:cr Lifted?

Safety Actuattor.?

Pressure?

Valves?

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Safety Actuation?

Pressure?

Valves?

Level Valves Lifted 9-18-79 Turbine Trip Perturbation in 99.8 No No Yes No No EllC Fluid Pressure 9-26-79 Turbine Trip Failure of Power 100 No No Yes No No Supply For Turbine Throttle Pressure Limiter XMTR e

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Safety Actuation?

Pressure?

Valves?

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8-17-79 Loss Of Feedwater IW Valve Actuator 47 No No Yes No No l'a ilure 8-17-79 Loss Of Feedwater FW Coing From One To 48 No No Yes No No Two-Pump Operations; "A" Pump Speed 1.ower And "B" liigher Than Required 8-17-79 Loss Of Feedwater Operator Went From 24 No No Yes No No Manual To Auto With ICS With Off Normal Plant Conditions 9-18-79 Loss Of Feedwater FWP Regulator Failed 72 No No Yes No No 9

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Safety Actuation?

Pressure?

Valves?

Level Valves lifted 4-22-79 Loss of Feedwater Loss of"A" inverter 100 No No Yes Yes No 7-1-79 Loss of Feedwater Test of STP-070 13 No No Yes No No 8-12-79 Turbine Trip Spurious Activity 100 No No No No No In Overspeed Protection Circuit 9-12'79 Turbine Trip Spurious Activity 100 No No No No No In Overspeed Protection Circuit 9-13-79 Unspecified Imbalance on Restart 30 No No No No No e

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Safety Actuation?

Pressure?

Vahes?

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III-l ATTACHMENT III (3 PAGES)

Request 3':

Provide an estimate of the increase in reactor trip frequency since lowering the high pressure trip setpoint and adding the anticipatory reactor trip.

Include a review of the design criteria for the number of reactor trips over the plant life and evaluate the effect of the increase in trip frequency on these criteria.

Also provide the basis for the acceptable number of reactor trips in terms of the limiting component (s).

Response

A.

An increase in reactor trip frequency will result from a lowering of the high pressure trip setpoint and the addition of the anticipatory reactor trip.

To estinate the ef fect of these changes, total reactor trips were divided into two (2) categories:

1.

Category 1 - Trips that should not be affected by the above changes (e.g., total loss of feedwater, since this led almost invariably to a reactor trip with the old setpoints; power to flow trips; test trips; etc.)

2.

Category 2 - Trips that are affected by the above changes (e.g., high pressure trips, feedwater upsets, and turbine trips).

Category 2 trips are listed in the following table (Table 1) in the "A" columns while total trips (Category 1 plus Category 2) are listed in the "B" columns.

The number of trips and frequencies in Table 1 are based on commercial calendar time. The post-TMI-2 frequencies should be viewed with caution as they are based on only a short operating history following the setpoint changes.

Ideally (i.e., wi th a la rge.enough. da ta base), the Ca tegory 1 trip frequency ("B" column minus the "A" column) should be similar for the pre-and post-TMI-2' periods.

The fact that this is

~

not the case can be attributed to the difference in calendar time and also statistical variations of the pre-and post-TMI-2 samples.

However, on the average, it can be observed that the trip frequency in Category 2 (i.e., " A" column) has increased by approxima tely a factor of 3 (0.23 to 0.71); which would almost double the total trip frequency.

Thus, although the data indicate approximately a doubling of the average trip frequency, the following must be considered:

1.

There has been a relatively short period of operation since the changes.

2.

There have been many startups and shutdowns during the pos44 4 156 TMI-2 period.

1

III-2 ATTACHMENT III (Cont'd) 3.

As operators become familiar with the revised setpoints and operating conditions, it is reasonable to assume the trip frequencies may-decrease.

B.

The structural design criterion for the number of reactor trips over the life of the plant is to keep the fatigue usage factors of all RCS components below 1.0 as supported by the component stress analysis.

In general, this usage factor is made up of contributions due to all specified transients.

Since the largest contribution to the fatigue usage factor is attributable to heatup and cooldown transients, with reactor trips producing only a small effect, the increase in trip frequency (indicated by the average data to date) should only have a small effect relative to plant life.

As a part of the total allowable transient picture, 400 reactor trips are specified.

Assuming a 40-year life, this translates into 10 trips per year or.83 per month.

With the pre-TMI-2 setpoints, only the most recent plants to come on line (Davis Besse-1, Crystal River-3, and TMI-2) exceed this figure.

As these plants accumulate operating experience, their trip frequencies would be expected to decline under the pre-TMI-2 setpoints.

With the new setpoints, three plants exceed 0.83; however, for the reasons discussed in A above, it is premature to draw'any conclusions over the life of the plant based on the little data available with.these setpoints.

C.

To determine the acceptable number of reactor trips in terms of the limiting component (s), it is necessary to review the stress report for each component and plant and evaluate the fatigue usage factor.

If the number of trips were to exceed 400 on any plant, that plant would have to be reanalyzed based on actual transients and the limiting component would be a function of these actual transients plus those that would be expected throughout the remainder of the plant's life.

It is important to recognize that usage f actors below 1.0 represent design margin in the plant design.

Any change that increases the frequency of transients causes a decrease in this margin whether the actual limit is reached or not.

Therefore, steps (such as raising the high pressure trip setpoint, etc.) should be considered to reduce the trip frequency thereby improving desian and safety mar ~ gins.

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