ML20129E033
| ML20129E033 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 07/03/1984 |
| From: | TOLEDO EDISON CO. |
| To: | |
| References | |
| PROC-840703, NUDOCS 8507300226 | |
| Download: ML20129E033 (50) | |
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T POST TRIP REVIEW GUIDELINES July 3, 1984 Purpose The purpose of this booklet is to provide guidance on the performance of a review of a plant transient or trip. This is intended as generic guidance only and is not intended to cover every possible event. Each event should be reviewed on an individual basis with the scope of review determined by the type of event.
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8507300226 840703 hDR ADOCK 05000346 PDR
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e Transient analysis is basically divided into four phases:
- 1. Data Collection
- 2. Data Analysis
- 3. Support of Outside Organizations
- 4. Report Preparations and Review These guidelines will discuss each of the four phases.
- 1. DATA COLLECTION 1.1 Information Available The capability to record and recall the plant info rma tion necessary to assist in the determination of the cause or causes of unscheduled reactor trips currently exists at Davis-Besse Unit 1. Digital indications (e.g., on/off, open/close, etc.)
and key analog information are recorded by various transient monitoring systems during a reactor trip for subsequent analysis.
The Plant Process Computer records and displays both digital and analog information. The Data Acquisition and Display System (DADS) located in the Technical Support Center also provides a means for recording and displaying analog information. An additional source of analog information used to support post trip efforts comes from the Control Room strip chart recorders.
These systems provide the primary sources of information used for trip analysis at Davis-Besse Unit 1.
Plant Process Computer The Plant Process Computer monitors digital and analog informa-tion from all major plant systems. Approximately 2,500 digital points and 2,000 analog points are fed into the computer. Some of this information is manipulated and stored for plant performance monitoring purposes, and all of the information is available to the Control Room operator in various display formats. Three functions of the Plant Process Computer provide information useful for transient analysis ef forts. These functions include the Sequence of Events Monitor, the Post Trip Review, and the Alarm Printout.
The Sequence of Events (SOE) Monitor is designed to provide a sequential list of important plant events. All inputs to this function are digital. The list of monitored points is provided as Enclosure 1. A change of state of any of these digital points is recorded in the SOE file along with the time of occurrence. The time of occurrence listed with the event is based on computer clock time and recorded to the nearest five milliseconds. The SOE file can hold up to 256 records. Once the SOE file is filled, subsequent events replace the oldest recorded event in the file. The first event to be recorded in the file triggers an indicator to the operator that an SCE monitored event has occurred. This indication is cleared, and the SOE file is emptied when the operator requests a printout of
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the SOE file. Enclosure 2 illustrates the format of information presented in the SOE printout.
The Post Trip Review function is designed to record selected analog information for a period of time before and af ter a reactor trip. The list of parameters monitored by this function is provided in Enclosure 3. The most recent 15 minutes of historical values for these parameters is maintained in a rolling file. In the event of a reactor trip, this rolling file is frozen and data for the next 15 minutes is recorded. An indication that the Post Trip Review function has been initiated is provided to the operator. The opecator may then request the Post Trip Review printout which clears the file. The Post Trip Review printout provides parametric data in engineering units given at 15 second intervals f rom 15 minutes prior to the trip until 15 minutes after the trip. Enclosure 4 provides a sample 4
of one segment of a Post Trip Review prtntout. Note that some of the parameters monitored have scan intervals of more than 15 seconds. Consequently, some data may be repeated in successive
, 15 second records. The parameters monitored for the Post Trip Review function were chosen as a part of the original plant process computer design. The variables monitored are key parameters of the major primary and secondary systems which could indicate abnormal trends that may lead to, or result from, a reactor trip. Normally inoperative safety systems are not monitored by this function. The scan intervals selected for the parameters were based on the anticipated rates of change of the individual parameters, and multiplexing hardware and memory capacity limitations that existed at the time of the initial design.
The Alarm Printout function provides an historical listing of both digital and analog information recorded when the monitored parameters enter a predetermined alarm state. Essentially, all digital and analog input points are monitored for alarm status.
Alarm messages are recorded as they occur on the alarm printer along with the time of occurrence. No operator action is
' required to initiate the Alarm Printout. All digital points are scanned once per second, and a change of point status is identified on the alarm printer. Analog points are scanned at varying intervals (either 1, 5,15, 30, or 60 second intervals) and are compared at each scan to a predetermined alarm value. Each time the parameter exceeds the alarm limit or returns to within Ifmits, the event is recorded on the Alarm Printout. An example of a section of the Alarm Printout is provided in Enclosure 5.
. The Plant Process Computer consists of redundant MODCOMP Classic 7870 CPUs. The CPUs are powered from separate uninterruptable instrumentation buses YAU and YBU. The uninterruptable buses are supplied from the station battery backed 250 volt DC power supply system through an inverter. Power can also be supplied to the bus from a nonessential regulated instrumentation bus through a static transfer switch within the inverter. The redundant CPUs were installed during the 1982 Refueling Outage 2-
t as a part of the overall project to upgrade the Plant Process Computer system. The multiplexers providing inputs to the processors will be replaced in future outages. The multiplexers are currently supplied from YBU, consequently, a loss of YBU will interrupt all three transient monitor functions of the Plant Process Computer. The DADS will still be functional. As the multiplexers are replaced, they will be equipped with redundant power supplies.
Data Acquisition and Display System (DADS) a The DADS, located in the Technical Support Center, was designed as a part of the emergency response facilities at Davis-Besse Unit 1. The primary function of the system is to provide information to emergency response personnel in the Technical Support Center to assist in evaluating plant status in an l accident situation. Consequently, those variables important to determining the safety status of plant systems and the proper functioning of safety systems are inputs to the DADS.
While the DADS receives inputs from numerous sources, such as the Meteorological Tower and the Plant Process Computer, the inputs of _importance to the transient monitoring function are supplied through a separate multiplexer (the Validyne). The list of parameters supplied by this multiplexer is provided in Enclosure 6. The scan rate for these variables is approximately once per second. Data is recorded at that rate for a period of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> in a rolling file. Access to information in this data file is possible in several formats. Individual points or groups of points can be examined by a CRT or a line printer output. Additional output formats are being developed and will include the use of a printer / plotter to provide graphical trends.
The Prime Comupter stores information from both the MODCOMP and Validyne inputs. These values can be called up and printed out per Section 1.2. The power supply tor the multiplexer located in the station is YAU. The power supply for the DADS computer system is independent of the station electrical system. The Davis-Besse Administration Building (DBAB) which houses the Technical Support Center and the DADS, is supplied from a construction feeder independent of the three 345 KV lines
, connected to the station grid. The DBAB electrical system supplies an emergency response facilities bus which can also be fed by an emergency diesel generator through an automatic transfer switch. The emergency response facilities bus in turn feeds an uninterruptable distribution network. Power to the uninterruptable distribution network is backed up by a battery driven system through a static transfer switch which assures i continuous operation of the DADS computer system. The emergency battery system is charged from the emergency response facilities bus.
E Strip Chart Recorders In the event that the Plant Process Computer and the DADS are unable to perform their transient monitor functions, the Control Room strip chart recorders act as a backup source of information for transient analysis. Due to the compressed time scales of the strip chart recorders, the information cannot be used for sequence of events determination and the limited number of parameters recorded make determination of the cause of a tran-sient very difficult. However, the parameters that are recorded are important major system parameters such as pressurizer level, Reactor Coolant System (RCS) pressure, steam generator levels, feedwater flows, etc. The information available on the strip chart can be very useful in assuring that major system upsets did not occur as a result of the transient. Strip chart recorders are also useful in recognizing long term trends that may be indicative of problems leading to, or resulting from, a transient.
1.2 Technical Section Function It has become a Technical Section function to collect all the available plant data and have copies given as soon as possible to rue Assistant Station Superintendent (Steve Quenncz), Opera-ticns (Dale Miller), NRC Resident Inspector (Walt Rogers), and I&C (acting I&C Engineer). This job normally requires a trip to the Control Room to retrieve the alarms (at least 20 minutes prior to trip and for an hour after), the SOE printout and the Post Trip Review (may have to ask the operators to print out).
If possible, attempt to set up a post trip meeting which includes operators from the shift that was on. Copies of the Reactor Operator Log and Unit Log should also be obtained when completed (usually not until the day after the trip).
If possible, talk with the operators which are on shif t. The purpose of this interview is to record pertinent information as seen by the operator during a transient condition. The interview should be conducted as soon as possible af ter the event.
Typical questions are:
- 1. Briefly describe plant conditions prior to the trip.
(Include Integrated Control System (ICS) mode and pertinent testing, operations, or maintenance in progress or recently completed.)
- 2. What was the first indication or alarm which keyed you to a problem? What actions did you take as a result of these indications?
- 3. Were any alarms or indications out of service or did any fail during the course of the transient? Did any indications or alarms mislead you? Could the Control Room alarms or controls have been relocated in such a manner to have aided your actions on this transient?
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- 4. Did existing plant procedures provide adequate action for this transient? Was it necessary to take action beyond their scope.
- 5. What additional information or guidance do you feet ,
would have assisted you during the transient?
- 6. Summarize the transient including both indications and actions. Discuss any equipment problems observed.
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The data from the Prime Computer must be manually hard copied within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of the trip as follews:
- 1) Go to the Technical Support Center Computer Room and turn on the orange line printer (the "run" light should be "on", the "off" light should be lit unless the printer is in the act of printing).
- 2) Turn on a Technical Support Center Ramtek terminal and push reset button located at the rear of the keyboard.
- 3) At the Ramtek terminal: (NOTE: two runs, one of 35 minutes length and 30 seconds interval, and a second of 5 minutes at. I second interval provide the best data)
ENTER: LOGIN_TSC lilt: f function key (hard copy) 3 111T: f functica key (to obtain Validyne data) 3 OR f 2functi n key (for selected MODC0!!P points) l l ENTER: point number i
ENTER: P (to output to line printer) l l
ENTER: beginning hours and minutes IDIMM i ENTER: starting time using IlllMM format Run 1: use 5 minutes before trip l (normally use 5 minutes before trip) !
Run 2: use 1 minute before trip l 4 1 ENTER: number of minutes wanted to display l ENTER: how long in IfilMM i Run 1: use 30 minutes l (normally 31 minutes)
Run 2: use 5 minutes l 4 1 ENTER: interval desired in seconds l ENTER: interval in minutes or <CR> for 30 seconds Run 1: use 30 seconds l Run 2: use I second l l
ENTER: point number or "ALL" for all Validyne l points l
! l Data will now be printed
- l Data will now be printed *
- 4) To exit, enter LO
- If data does not print, do not repeatedly attempt to request printouts since all requests will be remembered and printed when the system returns to working order. Call for assistance f rom Computer personnel.
The Prime data can be displayed on the Ramtek terminal and a video copy of the display obtained on the Tektronix hard copy printer.
- 1) Go to the TSC, turn on Tektronix Video copy printer and let warm up.
- 2) Turn on a Ramtek terminal and press reset button located at the rear edge of the keyboard.
- 3) At the Ramtek
ENTER: LOGIN_ LARRY _SMARTI ENTER: DIS i ENTER: OB ENTER: SEG_9 DISPLAYS e
, EVTER: 4 (to plot data vs. time)
E HER: 1 (for CRT display)
ENTER: 2 (to access 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> circular file data)
ENTER: 1 (always) j HIT: Return if data displayed looks OK when presented for i
review
! ENTER: Point number (NOTE: If a Validyne point is
Data will now be displayed and updated on the terminal.
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- 4) To obtain a video copy of the Ramtek display:
With the display finished updating, press the black button beside the tenninal and the video copy will be automatically f
taken.
If it is desired to freeze the display during updating, the terminal can be frozen by hitting " control" "S" (simultaneously).
To resume updating:
HIT: " control" "Q"-(simultaneously)
- 5) To exit program:
HIT: " Break" key i ENTER: "Q" ENTER: LO 3
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The printer / plotter is being programmed to have a fixed set of plots (see Enclosure 10 for list) be printed by manual command.
l Presently, only Larry Konopka can use this feature. This will, l in the future, be the primary method of data retrieval. Details '
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of use will be added later.
- 2. DATA ANALYSIS Data analysis is the most difficult part of the post trip review process. Every analysis is different since every event is different.
Some points need to be checked for almost every event, and the i following provides an indication of the extent of the review required.
The SOE and Alarm Printcut must be reviewed to verify the safety systems operated as required. This means verifying not only why some channels tripped, but also verifying that all channels that should have tripped did trip. Enclosure 7 provides a list of all SOE points and what causes the SOE to initiate. Enclosure 8 has a list of specific points to be checked.
The plots must be reviewed to determine if the overall plant response was acceptable. After a trip, the main feedwater control valves are closed, the startup feedwater valves are targeted to approximately 20% open, and the main feed pump speed is increased to target (approxi-mately 4600 RPM) by the rapid feedwater reduction system. Steam generator levels should be maintained at 35 inches (and rapid feedwater reduction startup feedwater valve target released). The main steam safety valves should rescat at approximately 960 PSIG and Tave should tend towards 551*F. Pressurizer level should reach a minimum of 10-20 inches if originally at full power (higher if originally at lower power).
RCS pressure should not fall below 1800 PSIG unless problems occur with main steam safety valves (MSSV)s resetting or makeup flow is inadequate. Cold leg temperature will most likely rise for the first 10-20 seconds from the drastically increasing steam generator pressure, i but will then cend toward 550'F. Since 100% FP is 48'F AT (Th - Tc),
the post trip AT is approximately 2-3*F for the first 20 minutes (dependent on decay heat load).
The drastic changes in steam generator pressure will cause momentary glitches in the steam generator level t ransmitters. These ara to be expected since the level transmitters are just AP indicators.
l High deaerator levels have been a problem post trip. It appears the Deaerator Level Control Valve #2 fails to close and the equalizing valve caused both deaerator levels to increase. Monitor both deaerator levels ar.4 the time the condensate pumps are reduced to one operating.
All turbine bypass valves should normally open initially after the l trip and then close during the MSSV blowdown. The atmospheric vents I should open when steam generator pressure rises above 1025 PSIG (providing no Steam and Feedwater Rupture Control System (SFRCS) actuation),
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1 RCS pressure, pressurizer level, and RCS Tave should have nearly identical curve shapes until the makeup pumps have added significant volume (1-2 minutes). RCS pressure is the most sensitive indicator of RCS temperature; the RTDs and thermowells response time, as well as the loop transport time, adds a significant time delay (5-15 seconds) in the sensing of actual Tave during a rapid cooloat tempera-ture change.
One additional caution is necessary on using the out-of-core power range NIs. These detectors are monitoring core neutron Icakage, which is affected drastically by changes in cold leg temperature (approximately .5% FP per *F). If Te increases 6'F, indicated core power will increase 3% without any actual change in core power.
The analysis performed depends largely on the transient. A closure of one main steam isolation valve (MSIV) requires a much more detailed review than a " screwdriver" trip. An imbalance trip requires a detailed core physics review, while an electro-hydraulic control (EHC) induced transient may require a significant review of the secondary plant. Common sense and an inquisitive attitude must be maintained throughout the review. Murphy's Law definitely applies to nuclear power; Don't assume anything worked like it should.
- 3. SUPPORT OF OUTSIDE ORGANIZATIONS The Technical Section provides support to the TAP Team and places information on NETWORK to provide information to outside organizations.
The B&W Resident Engineer (Jim Albert) has his own method of communica-tion with other B&W plants (ELEX) which can also be used as the method of communication between B&W units.
Within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of the event, the Technical Section should make an entry on NETWORK to the other B&W units describing the event. If the event has significance beyond the B&W design (such as failure mechanism of MSSVs), an entry should also be made on NETWORK to all operating units.
The Technical Section is responsible for telling the B&W Resident Engineer if a TAP Team site visit is desired. A TAP Team should be called in for most involved transients, but no site visit is necessary for a well understood transient. When requesting a site team, ask for personnel qualified in the area of the equipment involved in the transient; i.e., if ICS operatton is an question, ask for an ICS
" expert".
The Technical Section representative acts as a liaison for the B&W TAP Team. The entrance interview should be well prepared with all information necessary to analyze the event provided to the team.
They should be provided with:
- 1) An oral review of the transient details known
- 2) All plots, alarms, SOE, post trip review, and operator logs 9
- 3) Names, work extension, and schedule of personnel who were on shift during transient
- 4) A work area - typically a conference area in the DBAB
- 5) Escorts as required into the protected area After the draft report is prepared, we have Duplicating make 10-12 copies. An exit interview is then set up with Steve Quennoz, Bernie Peyer, IEC Engineer, Dale Miller, Louis Simon, other available operators, Shift Technical Advisors, Jim Albert, and the Technical Section representative. The draft report is then reviewed and several days given to receive comments.
If the TAP Team was not called in, only the NETWORK entry need be completed. Section 4 describes the details of report preparation to be followed.
- 4. REPORT PREPARATION AND REVIEW A TAP report will be prepared for all unscheduled reactor trips at Davis-Besse. Reports may also be prepared for other significant events. The purpose of the report is to provide transient event inforniation for all members of the 177 FA Owners Group. The opera-tional experience shared in this program will lead to improved plant reliability and a better understanding of the plant's performance by all participants.
The format of the report should be as follows:
I. Executive Sununary A. Plant Name, Data, Time of Trip B. Brief Description C. Root Cause D. Performance Anomalies E. Lessons Learned II. Transient Assessment A. Sequence of Events B. Plant Performance
- 1. Pre-trip Review
- 2. Initiating Event
- 3. Plant Post-trip Response
- 4. Operator Actions / Procedural Adequacy C. Safety Considerations D. Assessment Conclusions E. Annotated Plots The " Executive Summary" section should be a single page containing the following information: plant name, date and time of trip, brief description of the event, including initial power level, root cause of the transient, any performance anomalies, and lessons learned.
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The " Sequence of Events" section should contain those major events or conditions which delineate the progressive course of the transient.
It normally contains a combination of the SOE, alarms, and Reactor Operator Log.
The " Pre-trip Review" section should contain a statement of the plant conditions prior to the transient. Examples to be included would be power level, ICS status, maintenance or testing in progress, and equipment deficiencies.
The " Initiating Event" section should describe the sequence of events and plant conditions leading up to transient initiation. Try not to be repetitive with other sections.
The " Plant Post-trip Response" section should include a discussion of the response of the NSS and BOP from a process point of view; i.e.,
Tave, reactor coolant pressure, pressurizer level, feedwater flow, OTTC level, and main steam pressure. These parameters should be plotted versus time and annotsted to indicate major events, departures, etc., to support the text of this section. Also, this section should include a discussion of performance of components and their departures from the expected. Proposed corrective actions and corrective actions previously completed should be included in the text of this section.
The " Operator Action / Procedural Adequacy" section should include information concerning specific operator actions taken during the transient which have not been included in any previous sections.
Additionally, procedures followed during the transient, and any information which would be beneficial to other operators should be included. This section is of major interest to other operators regarding the TAP report and should be as detailed as possible, Operator interviews, operator logs, computer printout and plant procedures provide good source material. This section should provide an evaluation of the shift operator's ability to use the procedures to mitigate a plant transient. Avoid repetition of earlier sections when possible.
The " Safety Considerations" section should include the basis for which safety, as it relates to the transient, has beea considered.
Those bases may include plant design requirements, Final Safety Analysis Report (FSAR) accident analysis, or other information.
The " Assessment Conclusions / Corrective Actions" section should be a summary of the significant aspects of the transient, including :
departures from expected component and plant performance, suggested /
actual corrective actions, and any preventative measures if not already discussed in the Plant Post-trip Response section. For component failures, list name, model and serial number, manufacturer name, date of installation, etc. Try to give this section a positive, "we're fixing it" tone instead of a "diak sheet".
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t The " Annotated Plots" section should consist of a number of parameter versus time plots annotated with trip times and other important cecurrences (pump starts / stops, emergency Safety Features Actuation System (SFAS) initiation, power operated relief valve (PORV) lif ts,
- main steam relief valve (MSRV) / MSSV lifts, etc.) The Abnormal Transient Operator Guidelines (ATOG) P-T plot should be included in this section.
After the report has been reviewed in the exit meeting and modified by the Technical Section, it is sent out for review (see Laura for distribution). After the date that the comments were due (usually two weeks), the report comments are incorporated, and it is then sent to the Station Review Board (SRB). After SRB review and comment incorporation,- the report will be sent to B&W with the cover letter signed by the Technical Section TAP representative. B&W will place the report in the booklets and distribute to all participating utilities.
The data is then stored in the trip files (along with the Attachment 3 to PP 1102.03 from Operations). Revisions are not normally made to TAP reports, but can be completed if serious errors exist.
This completes the post trip review guidelines - these are only guidelines and are not cast in concrete. Enclosure 9 includes a checklist for post trip review which may be used to ensure no items are missed.
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SEQUENCE OF EVENTS POINTS LIST Auxiliary Transformer 11 Trouble Bus A Electrical Fault Bus B Electrical Fault Bus A to Transformer AC Breaker Bus C2 Trouble Bus D2 Trouble Control Rod Drive (CRD) Trip Confirm CRD Channel AC Any Trip Device CRD Channel BD Any Trip Device Electro Hydraulic Control Emergency Trip System Low Pressure Emergency Diesel Generator 1 Trouble Emergency Diesel Generator 2 Trouble Essential Bus C1 Trouble Essential Bus D1 Trouble Essential Transformer CE 1-1 Trouble (typical CE 1-1, DF 1-1, CE 1-2),
DF 1-2)
Cenerator and Main Transformer Overall Differential Trip Generator Overcurrent Trip Generator Reverse Current Power Trip Generator Field Failure Generator Out of Step Generator Underfrequency Generator Differential Generator Ground Current Enclosure 1 Page 1 of 3 i
Main Feed Pump Turbine (MFPT) 1 Trip (typical MFPTs 1 and 2)
Main Transformer Sudden Pressure Change Moisture Separator Reheater 1 High Level Turbine Trip Moisture Separator Reheater 2 High Level Turbine Trip Reactor Protection System (RPS) Channel 1 Flux / Delta Flux / Flow Trip (typical Channels 1 through 4')
RPS Channel 1 High Flux / Number of Reactor Coolant Pumps (RCPs) Running Trip (typical Channels I through 4)
RPS Channel 1 Reactor Coolant (RC) Pressure / Temperature (typical Channels I through 4)
RPS Shutdown Bypass High Pressure Trip (typical Channels 1 through 4)
RPS Channel 1 Containment High Pressure Trip (typical Channels 1 through 4)
RPS Channel 1 RC High Pressure Trip (typical Channels I through 4)
RPS Channel 1 RC Low Pressure Trip (typical Channels 1 through 4)
RPS Channel 1 Channel Trip (typical Channels 1 through 4)
RPS Channel I High Flux Trip (typical Channels 1 through 4)
RPS Channel 1 RC High Temperature Trip (typical Channels 1 through 4)
RPS Startup Rate Rod Withdrawal Inhibit RC Pressurizer Low Level Heater Interlock RCP 1-1 Motor Trouble (typical RCPs 1-1, 1-2, 2-1, and 2-2)
Safety Features Actuation System (SFAS) Channel 1 E, rated Water Storage Tank (BWST) Level Low (typical Channels 1 through 4; SFAS Channel 1 Containment Pressure > 38.4 psia (typical Channels 1 through 4)
SFAS Channel 1 Containment Pressure > 18.4 psia (typical Channels 1 through 4)
SFAS Channel 1 RC Pressure < 1650 psig (typical Channels 1 through 4)
SFAS Channel 1 RC Pressure < 450 psig (typical Channels 1 through 4)
Enclosure 1 Page 2 of 3
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- I SFAS Channel 1 Contaisunent Radiation High (typical Channels 1 through 4)
Steam and Feedwater Rupture Control System (SFRCS) Full Trip SFRCS Differential Pressure Half / Full Trip Steam Generator (SG) 1 (typical SGs 1 and 2)
Startup Transformer 01 Trouble Startup Transforecc 02 Trouble i
Switchyard Oscillograph Started
, Switchyard Bus J Differential Switchyard Breaker 34563 Open/ Closed (typical five breakers) i
- Turbine Generator Mechanical Trip Solenoid Turbine Trip Turbine Generator Master Turbine Trip Turbine Generator Mechanical Trip Valve Trip Turbine Generator Master Trip Solenoid Trip Turbine Bypass Valve 1-1 Open/ Closed (typical six valves) i Unit Seismic Instrumentation Started 4
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4 Enclosure 1 Page 3 of 3 i
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j teUP 10 StuuENCE eF EvfNTS Nfvifa l 7 10/15/63 j-i:2o:13:170 2027-- S=YO ACB 34562 rWth l l 1: 2o:31: 495 P702 STRCS OP NALF/ FULL 1 RIP , SG ? Ik]P j :2o:31: sos P702 SFRCS OF HALF / FULL 1 Rip .SG 2 heke i
5: 20:41:e95-- 09o3 - SFRCS FULL TRIP iwl4
- 2o: 41:905 x038 T-G MASTFW TURS THIP Ik!P
, 8:2o: 41: 440 x030 T-G MASTER TRIP SuLENeluS Iw1P
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- 41: 445 - 41M1 -
191P -
1 i:2o: 41: 950 0180 CHD Cn A/C ANY TRIP DEVICE ik19 i i a:Pe: 42: 45 02bo CRD THIP CHNFJRm i4}p j -- 4 : 2o: 42:le5 - x033- 1-G *ECH TRIP SeLENelD iukh Th!P idlk ;
j 4: 2e: 42:165 x032 T-G MECH TRIP VLV TElp L 8: 2o: 44:420 P382 Enc EMEk TRIP SYS Lea PRESS TRIP ,
-- 4 : 27:11:540 - J428 - GEN-REVENSE par 1AIP 1: 27:11:5e5 x026 SaYD ACb 34561 coEN i I: 27:11:5e5 x025 SnVU ACd 34500 ePEN !
4: 27:13: 030 - - J428- - GEN-REVERSE Pa4 New-l Y060 1: 27:32: 95 TURu uYPASS VLv 1-1 NC 4: 27:32: 445 Yueo TUR8 BYPASS VLV 1-1 CLeS I
4: 27:50: 630-- Yu63 - TURN eVPASS vLv P-1 NC -
, 2 i:.7:52: 5 Y003 TURU $YFASS VLV 2-1 (LeS I
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1: 33: 1:815 0903 SFRCS FULL IRio F.An*
1: 33:18:730 9641 WPS SU NATL NdD *IHuwel }qeIBIT jNne l I: 34: 3: 1o5 Do41 4PS Su wAIE hod nTHDRnt liesIBIT Nan =
i i:13:27:755 202e iaYD ACu 3a5 1 tLeS
{ - i:13:32:620 zu25 - SwYU ACH 3u560 LLes ;
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Enclosure 2 Page 1 of 1 1
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I POST TRIP REVIEW POINT LIST Auxiliary Feed Pump Turbine 1 Speed (typical Pumps I and 2)
Channel 1 Power Range Flux (typical Channels 1 through 4)
Channel 1 Power Range Delta Flux (typical Channels I through 4)
Condensate Pump Flow 1
Control Rod Drive Group 5 Position (typical Groups 5 through 8)
Deaerator 1 Storage Tank Level (typical Deaerators 1 and 2)
Generator Gross Megawatts l High Pressure Condenser Pressure i
High Pressure Condenser Hotwell Level l High Pressure Turbine First Stage Turbine End Pressure High Pressure Turbine first Stage Generator End Pressure ' -
i High Pressure Turbine Side 1 Inlet Temperature High Pressure Turbine Side 2 Inlet Temperature ,
l Low Pressure Condenser Pressure 4
Main Feedwater Average Flow Loop 1 (typical Loops 1 and 2) i Main Feedwater Temperature (typical Loops 1 and 2) '
i Main reedwater Compensated Flow (typical Loops 1 and 2)
Main Feedwater Pump Turbine 1 Speed (typical Pumps 1 and 2)
Pressurizer Average Level Pressurizer Pressure Reactor Coolant Makeup Tank Level Reactor Coolant Makeup Flow Reactor Coolant Pump (RCP) Seal Injection Flow Enclosure 3 Page 1 of 2
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RCP l-1 Discharge Cold Leg Narrow Range Temperature (typical RCPs 1-1 and 2-1)
Reactor Coolant System (RCS) Loop 1 Hot Leg Narrow Range Temperature (typical Loops 1 and 2)
RCS Average Temperature RCS Loop 1 Hot Leg Narrow Range Pressure (typical Loops 1 and 2)
RCS Average Hot Leg Total Flow RCS Letdown Boron Concentration Safety Features Actuation System (SFAS) Channel 1 Containment Pressure SFAS Channel 1 Containment Radiation Core Power, SFAS Channel 3 Borated Water Storage Tank Level Steam Generator (SG) 1 Full Range Level (typical SGs 1 and 2)
SG 1 Startup Level (typical SGs I and 2)
SG 1 Operate Level (typical SGs 1 and 2)
SG 1 Outlet Temperature (typical SGs 1 and 2)
SG 1 Outlet Pressure (typical SGs 1 and 2)'
SG 1 Feedwater Pressure (typical SGs 1 and 2)
Enclosure 3 Page 2 of 2
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Enclosure 4 Page 3 of 3
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I Enclosure 5 Page 1 of:1 t
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DATA ACQUISITION AND DISPLAY SYSTEM RECORDED POINTS Auxiliary Feedwater Flow to Steam Generator (SG) 1 (typical SGs 1 and 2)
Auxiliary Feed Pump 1 Discharge Pressure (typical Pumps 1 and 2)
Auxiliary Feed Pump Turbine 1 Speed (typical Pumps I and 2)
Containment flydrogen Concentration .
Containment Spray Pump 1 Discharge Flow (typical Pumps 1 and 2)
Containment Normal Sump Level Containment Wide Range Level Containment Wide Range Pressure Containment Atmosphere Particulate Radiation Containment Atmosphere Iodine Radiation Containment Atmosphere Noble Gas Radiation Containment Atmosphere Noble Gas Mid to liigh Range Radiation Containment Wide Range Radiation Pait Vent Particulate Radiation Uait Vent Iodine 131 Radiation Unit Vent Xenon 133 Radiation Generator Gross Megawatts High Pressure Injection 1-1 Flow (typical Lines 1-1, 1-2, 2-1, and 2-2)
Incore Outlet Temperature (typical 16 sensors)
Low Pressure Injection Pump 1 Flow (typical Pumps 1 and 2)
Main Feedwater Temperature to Integrated Control System Main Feedwater Control Valve Position Loop 1 (typical Loops I and 2)
Main Feedwater Startup Control Valve Position Loop 1 (typical Loops 1 and 2)
Enclosure 6 Page 1 of 2
~23-
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Main Feedwater Compensated Flow Loop 1 (typical Loops I and 2)
Reactor Coolant Makeup Tank Level Reactor Coolant System (RCS) Hot Leg Flow Loop 1 (Loops I and 2)
RCS Pressurizer Compensated Level RCS Pressurizer Quench Tank Level RCS Pressurizer Quench Tank Pressure RCS Hot Leg Wide Range Pressure Loop 1 (typical Loops I and 2)
RCS Average Narrow Range Temperature RCS Calculated Hot Leg Subcooled Margin Channel A RCS Calculated Hot Leg Subcooled Margin Channel B RCS Hot Leg Wide Range Temperature Loop 1 (typical Loops 1 and 2) i i RCS Pressurizer Temperature RCS Pressurizer Power Operated Relief Valve Position RCS Pressurizer Pressure Relief Valve Position (typical Valves 1 and 2)
Reactor Coolant Pump (RCP) 1-1 Discharge Cold Leg Wide Range Temperature (typical RCPs 1-1, 1-2, 2-1, and 2-2)
Reactor Protection System (RPS) Auctioneered Average Power RPS Channel 1 Power Range Flux (typical Channels I through 4)
RPS Channel 1 Source Range flux (typical Channels 1 and 2)
- RPS Channel 3 Intermediate Range Flux (typical Channels 3 and 4) 4 Safety Features Actuation System (SFAS) Channel 1 Borated Water Storage Tank Level Steam Generator (SG) 1 Outlet Steam Temperature (typical SGs 1 and 2)
SG 1 Operate Level (typical SGs 1 and 2)
SG 1 Startup Range Level (typical SGs 1 and 2)
SG 1 Outlet Pressure (typical SGs 1 and 2)
Enclosure 6 i Page 2 of 2 24-I
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- 9.
SOE POINT INI)EX POINT INSTR. Sf'T ALAR!!
NO. NO. DESCRIPTOR POINT CONDITION (S) l l A850 QS-RCl-1 RPS CH I Flux-DFlux-Flow BSTEL -32.25% 1 0.25% RPS Cll I $/AQ/ Flow Trip l
l A851 QS-NI6 RPS CH I HI Flux /No RCP ON BSTBL 1. One pump operating in RPS Cil 1 Power / Pumps Trip Bistables each loop i 54.25 1 .25% trips of RTP
- 2. Two pumps operating in one loop and no pump operating in other loop, no pumps operating, or only one piump operating 1
$ 0.0% of RTP .
A852 QS-RC2B2 RPS CH I RC Press-Temp BSTBL 12.6 T/Ilot -5644 PSIG RPS Cll 1 RC Press-Temp Trip ;
- i 4.0 PSI A856 QS-RCl-2 RPS CH 2 Flux-DFlux-Flow BSTBL -13.57% 1 0.12% RPS CH 2 $/A$/ Flow Trip A857 QS-NIS RPS CH 2 Ill Flux /No RCP ON BSTBL 1. One pump operating in RPS Cll 2 Power / Pumps Trip histables I cach loop 5 54.25 i .25% trips '
of RTP
- 2. Two pumps operating in one loop and no pump i operating in other loop, no pumps operating, or only one pump operating
$ 0.0% of RTP A858 QS-RC2A2 RPS CH 2 RC Press-Temp BSTBL 12.6 T/ Hot -5644 PSIG 1 RPS Cll 2 RC Press-Temp. Trip I 4.0 PSI A862 QS-RCI-3 RPS CH 3 Flux-DFlux-Flow BSTBL 7.86% 1 0.14% RPS Cil3 $/A9/ Flow Trip
( <
l Enclosure 7 Page 1 of 17
l POINT INSTR. SET ALA101 <
CD. NO. DESCRIPTOR PolNT CONDITION (S)
A863 QS-NI8 RPS CH 3 HI Flux /No RCP ON BSTBL 1. One pump operating in RPS Cl! 3 Power / Pumps Trip Bistables each loop i 54.25 1 .25% trips of RTP
- 2. Two pumps operating in one loop and no pump operating in other loop, no pumps operating, or only one pump operating 5 0.0% of RTP A865 QS-RC2RI RPS CH 3 RC Press-Temp BSTBL 12.6 T/ Hot - 5644 PSIG 1 RPS CH 3 RC Press-Temp Trip 4.0 PSI A869 QS-RCI-4 RPS CH 4 Flux-DFlux-Flow BSTBL 32.25% 1 0.25% RPS CH 4 $/A&/ Flow Trip A870 QS-NI7 RPS CH 4 HI Flux /No RCP ON BSTBL 1. One pump operating in RPS Cil 4 Power / Pumps Trip Bistables each loop i 54.25 1 .25% trips of RTP
- 2. Two pumps operating in one loop and no pump operating in other loop, no pumps operating, or only one pump operating 5 0.0% of RTP AS72 QS-RCAI RPS CH 4 RC Press-Temp BSTBL 12.6 T/ Hot -5644 PSIC i RPS CH 4 RC Press-Temp Trip 4.0 PSI 1061 IS-6500 Bus A Elec Fault N/A Over current condition on the 13.8 KV Bus A or a ground fault on the 13.8 KV Bus A 1069 1S-65001 Bus B Elec Fault N/A Over current on the 13.8 KV Bus B or a ground fault on the 13.8 KV Bus B Enclosure 7 Page 2 of 17 i
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I l POINT INSTR. SET ALARM ".
~
l NO. NO. DESCRIPIOR PolNT CONDITION (S) 1844 15-6108 ShTD Bus J Diff N/A Bus J Elect Fault J428 JS-6400A CEN Reverse Pwr At 25,200 KW in, relay times tiotoring occurs as a result of a out for 25 seconds and then deficiency in the prime snover input initiates trip to the a-c generator. When this input cannot supply all the losses, then the deficiency is supplied by absorbing real power from the system. Trips turbine and main generator breakers 34560 and 34561.
L680 LSH-140 MSR I HI Lvl Trub Trip Lvl increases to 3"-5" from increasing level in MSR drain line i bottom of tank l
L690 LSH-164 MSR 2 HI Lvl Turb Trip Lvl increases t o 3"-5" f rom lacreasing lesel in HSR drain line bottom of tank L770 LSLL-RCl4 RC PRZR Lo Lvl Htr 40 inches Low pressurizer level L862 QS-7640 SFAS Sump Recire Logic L511 8 feet water "ihis alarm is generated when any two of the four SFAS BWST low level r bistables trip. The alarm is pro-vided to tell when SFAS level 5 allows the transfer to the emergency sump to occur. l L864 QS-7641 SFAS Sump Recire Logic L512 8 feet water This alarm is generated when any two of the four SFAS BWST low level bistables i trip. The alarm is provided to tell
. when SFAS level 5 allows the transfer to the emergency sump to occur.
Enclosure 7 Page 4 of 17 t
L
_ - . . - .. . _ _ . - . - - . . - - - - - _ _ ~ _ - - - _ . _ - - _ . . - - . . . - . _ _ . _ - . _ - . - - . . . .
I PolNT INSTR. SET ALARM ,,
NO. NO. DESCRIPIOR POINT CONDITION (S)
- L866 QS-7642 SFAS Sump Recirc Logic L513 8 feet water This alarm is generate! hen any two of the four STAS BWST low level bistables trip. The alarm is pro-
- vided to tell when SFAS level 5 allows the transfer to the emergency sump to occur.
i L868 QS-7642 SFAS Sump Recire Logic L514 8 feet water This alarm is generated when any two of the four SFAS BWST low level i
histables trip. The alarm is pro-
] vided to tell when SFAS level 5 allows i j the transfer to the emergency sump to occur.
P683 PSH-6405 MN XFMR 1 Sudden Press N/A The alarm is cause.1 by a sudden change in XHIR Tank pressure, possibly accom-panied by an arc in the XR1R. The '
turbine generator and reactor may trip.
P701 QS-2686 SFRCS DP Half / Full Trip, SG 1 177 PSIG High steam to feedwater DP t P702 QS-2685 SFRCS DP Half / Full Trip, SG 2 177 PSIG High steam to feedwater DP j PS57 PS-NI15-2 RPS CH 1 CTNT HI Press 3.175 PSIG 1 0.2 PSIG RPS CH 1 CTNT Press HI Trip P858 PSh-RC2B2 RPS CH I RC HI Press 2285.0 PSIG 1 4.0 PSIG RPS CH I RC Press ill Trip I i
PS59 PSL-RC2B2 RPS CH I RC ID Press BSTBL 1998.4 PSIG i 4.0 PSIG RPS CH I RC Press Low Trip PS62 PS-N115-1 RPS CH 2 CTMT HI Press 3.175 PSIG 1 0.2 PSIG RPS CH 2 CTiff Press ll! Trip P863 PSL-RC2A2 RPS CH 2 RC ID Press BSTBL 1998.4 PSIG i 4.0 PSIG RPS CH 2 RC Press Low Trip 1
j P864 PSH-RC2A2 RPS CH 2 RC HI Press 2285.0 PSIG 1 4.0 PSIG RPS CH 2 RC Press 11I Trip Enclosure 7 l
Page 5 of 17 l ! :
i I
POINT INSTR. SET ALARM .
CD. NO. DESCRIl40R POINT CONDITION (S) 1 P867 PS-nil 5-4 RPS CH 3 CTNT HI Press 3.175 PSIG 1 0.2 PSIG RPS Cil 3 CTttr Press til Trip P868 PSH-RC2B1 RPS CH 3 RC HI Press 2285.0 PSIG 1 4.0 PSIG Ris CH 3 HC Press til Trip '
P869 PSL-RC2B1 RPS Cl 3 RC to Press BSTBL 1998.4 PSIG 1 4.0 PSIG HPS Cil 3 RC Press Low Trip PS72 PS-nil 5-3 RPS CH 4 CTMT Ill Press 3.175 PSIG 1 0.2 PSIG Els Cil 4 CT!!T Press III Trip P873 PSH-RC2Al RPS CH 4 RC 111 Press 2285.0 PSIG 1 4.0 PSIG RPS Cil 4 HC Press Hi Trip P874 PSL-RC2Al RPS CH 4 RC ID Press BSTBL 1998.4 PSIG 1 4.0 PSIG RPS Cil 4 RC Press Low Trip r P895 PSHH-2000A SFAS CH 1 CTMT Press > 38.4 PSIA 23.6 PSIG 1 0.4 PSIG SFAS Cil I CTitT Press til III Trip P896 PSH-2000A SFAS CH I CTNT Press > 18.4 PSIA 3.5 PSIG 1 0.5 PSIG SFAS Cil I CTtfT Press ill Trip -
P898 PSHH-2001A SFAS CH 2 CTNT Press > 38.4 PSIA 23.6 PSIG 1 0.4 PSIG SFAS Cil 2 CTt!T Press lil III Trip ;
P899 PSH-2001A SFAS CH 2 CTNT Press > 18.4 PSIA 3.5 PSIG 1 0.5 PSIG SFAS Cil 2 CTirr Press 111 Trip P901 PSIDI-2002A SFAS CH 3 CTMT Press > 38.4 PSIA 23.6 PSIG 1 0.4 PSIG SFAS CH 3 CTtIT Press ill 111 Trip P902 PSH-2002A SFAS CH 3 CTNT Press > 18.4 PSIA 3.5 PSIG 1 0.5 PSIG SFAS Cll 3 CTMT Press 111 Trip P904 PSHH-2003A SFAS CH 4 CTMT Press > 38.4 PSIA 23.6 PSIG 1 0.4 l$1G SFAS Cll 4 CT!!T Press HI til Trip '
P905 PSH-2003A SFAS CH 4 CTNT Press > 18.4 PSIA 3.5 PSIG 1 0.5 PSIG SFAS Cil 4 CTtfr Press HI Trip
P912 PSLL-RC2B4 SFAS CH I RC < 400$ 450 PSIG i 25 PSIG SFAS Cil I RC Press Low Trip t
P914 PSL-RC2A4 SFAS CH 2 RC < 1650# 1650.0 PSIG 1 25 PSIG SFAS Cil 2 RC Press low Trip P91S PSLL-RC2A4 SFAS CH 2 RC < 4008 450 PSIG 1 25 PSIG SFAS Cll 2 kC Press Low Trip i
Enclosure 7 Page 6 of 17
_, __ - _ _ _ _ - - . . ~ . , ,_ -_ _
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! PolNT INSTR. SET ALARf1 NO. NO. DESCRIPTOR POINT l CONDITION (S)
P917 PSL-RC2B3 SFAS CH 3 RC < 1650J 1650 PSIG 1 25 PSIC SFAS Cil 3 RC Press Low Trip t
P918 PSLL-RC2B3 SFAS CH 3 RC < 400# 450 PSIG 1 25 PSIG SFAS Cil 3 RC Press Low Trip P920 PSL-RC2A3 SFAS CH 4 RC < 1650# 1650 PSIG 1 25 PSIG SFAS Cll 4 RC Press Low Trip P921 PSLL-RC2A3 SFAS Cll 4 RC < 400# 450 PSIG 1 25 PSIG SFAS Cll 4 RC Press Low Trip l QOIS QS-6411 Aux XFt1R 11 TRBL N/A 1. A sudden pressure in the XFl!R l due to a fault
- 2. A ground fault on the XFMR secondary, or in backup pro-tection breakers !!X11A and HXilB
- 3. A phase overcurrent on the XHIR primary, or in backup protection breakers HXI]B and ilXilB
- 4. A differential relay operation caused by a fault in the trans-former or its connections to the 13.8 KV buses QO37 15-6503 Bus A to XRIR AC BRKR N/A 1. A bus lockout on Bus A.
- 2. A primary or secondary ground fault on XFHR AC.
- 3. A dif ferential or overcurrent on XHIR AC.
Q041 IS-6504 Bus B to XFMR BD BRKR N/A 1. A bus lockout on Bus B.
- 2. A primary or secondary ground fault on XFRM BD.
- 3. A dif ferential or overcurrent on XRtR BD.
Q050 IS-6521 Bas C2 TRBL N/A Bus overcurrent sensed by the partial differential overcurrent or ground relay scheme I
i Enclosure 7 i Page 7 of 17
_33
- ,, , - -_- - - - . ~
POINT INSTR. SET ALAkfl .
, ,'I NO. NO. DESCRIPTOR POINT CONDITION (S)
Q058 15-6522 Bus D2 TRBL N/A Bus overcurrent sensed by the partial differential overcurrent or ground relay scheme Q180 CRD-SW9 CRD CH A/C Any Trip Device N/A 1. Breakers A or C Trip
- 2. Electronic Trip C
- 3. WYE Current Sensor A
- 2. Electronic Trip D
- 3. WYE Current Sensor B
- 4. Return SCR ' trip D Q266 CRD-SW4 CRD Trip Confira N/A Any reactor trip Q396 QS-6221A EMER DG 1 Locked Out or TRBL N/A 1. Lockout Relay 86-1 operation (will trip AC 101 breaker and short the field for No. 1-1 DG)
- 2. Lockout Relay 86-2 operation (will trip AC 101 breaker and shutdown the engine)
- 3. Emergency Diesel Generator Voltage Regulatur Switch in the OFF position Q401 QS-6231A EMER DG 2 Locked out or TRBL N/A 1. Lockout Relay 86-1 operation
. (will trip AD 101 breaker and short the field for No. 1-2 DG)
- 2. Lockout Relay 86-2 operation 3 (will trip AD 101 breaker and shutdown the engine)
, 3. Emergency Diesel Cenerator Voltage Regulator Switch in the off position.
4 1
Enclosure 7
) Page 8 of 17 I
_ . . _ . _7 m,, .
7 _ _. ., . .-. -
POINT INSTR. SET ALARM ,
NO. NO. DESCRIPTOR POINT 4 CONDITION (S)
Q414 IS-6519 ESSEN Bus Cl TRBL N/A 1. Phase overcurrent on Bus C1
- 2. l'round overcurrent on Bus Cl Q417 IS-6520 ESSEN Bus D1 TRBL N/A 1. Phase overcurrent on Bus DI
- 2. Ground overrurrent on Bus D1 Q430 IS-6529 ESSEN KFMR CEl-1 TRBL N/A Automatic tripping of 4.16 KV Feeder Breaker ACICEll for the following:
- 1. Transformer Ground (SIN / ICE)
- 2. Bus Overcurrent (94-1)
- 3. Feeder Overcurrent (50-51)
- 4. Feeder Ground (50GS)
Q432 IS-6530 ESSEN XFMR DFI-I TRBL N/A Automatic tripping of 4.16 KV Feeder Breaker ADIDFil for essential Unit Substation F1 and 480V breaker BDFil for the following:
- 1. Transformer Ground (SIN /lDF)
- 2. Bus Overcurrent (94-1)
- 3. Feeder Overcurrent (50-51)
- 4. Feeder Ground (50GS)
Q435 IS-6532 ESSEN KFMR CEl-2 TRBL N/A Automatic tripping of 4.16 KV Feeder Breaker ACICE12 for essential Unit Substation F1 and 480V breaker BCE12 for the following:
- 1. Transformer Ground (51N/2CE)
- 2. Bus Gver c > (?? -1)
. 3. Feeder Overcurrent (50-51)
- 4. Feeder Ground (50GS) 4 Enclosure 7 Page 9 of 17 J
t
POINT INSTR. SET ALARtl -
NO. NO. DESCRIPTOR POINT CONDITION (S)
Q437 IS-6532 ESSEN XFMR DF1-2 TRBL N/A Automatic tripping of 4.16 KV Feeder Breaker ADIDF12 for essential Unit Substation F1 and 480V breaker BDF12 for the following:
, 1. Transformer Ground (51N/2DF) *
- 2. Bus Overcurrent (94-1)
- 3. Feeder Overcurrent (50-51)
- 4. Feeder Ground (50GS)
Q448 ES-6400A GEN Field Failure A typical alarm point is Loss of excitation by an abnor-632,310 KVA power flow mally low value or failure of into the generator generator field current, which ,
causes reactive power flow from the system into the machine.
Trips turbine and main generator breakers 34560 and 34561.
Q451 KS-6400A GEN Out-of-Step Cen. Out of step relay: A phase angle measuring device that Alarms at a pickup of 0.162 functions between two voltages, two primary cluns and 30,000 currents or between voltage and primary amperes (main current. Trips generator main transformer high side breakers 34560 and 34561 for gener-ampers), ator loss of synchronism.
Q613 QS-2731 MFPT I 1. 5925 RPfl 1. MFIT l-1 Over Speed Trip
- 2. 40 PSIG 2. MFPT l-1 Thrust Brg Wear Trip
- 5. 12.5" HgA 5. MFPT l-1 Exhaust til Press Trip
- 6. N/A 6. MFPT l-1 Manual Trip ;
- 7. 1500 PSIG 7. MFPT l-1 Disch lil Press Trip ;
1 i l
l Enclosure 7 Page 10 of 17
-~
POINT NO.
INSTR. SET ALAkti "
.~
NO. DESCRIPTOR PolNT CONDITION (S)
Q634 QS-2732 -MFPT 2 1. 5925 RPil 1. MFPT l-2 Over Speed Trip
- 2. 40 PSIG 2. MFIT 1-2 Thrust Brg Wear Trip
- 3. 4 PSIG 3. MFPT l-2 Lube 011 Low Press Trip
- 5. 12.5" HgA 5. FIFPT l-2 Exhaust til Press Trip
- 6. N/A 6. MFIT 1-2 flanual Trip
- 7. 1500 PSIG 7. !!FPT l-2 Disch III Press Trip Q783 QS-6515A RCP l-1 MTR TREL N/A 1. Motor Overcurrent
- a. Phase, Time and Instantaneous l
- b. Phase, Extremely Inverse Time i
- 2. Instantaneous Ground Fault
- 3. Phase Imbalance
- 4. Bus Protection Lockout Q789 QS-6516A RCP 1-2 MTR TRBL N/A 1. Motor Overcurrents l a. Phase, Time and Instantaneous l b. Phase, Extremely Inverse Time l 2. Instantaneous Ground Fault l 3. Phase lubalance
- 4. Bus Protection Lockout l
Q795 QS-6517A RCP 2-1 MTR TRBL -
N/A 1. Motor Overcurrents
- 4. Phase, Time and Instantaneous
- b. Phase, Extremely Inverse Time
- 2. Instantaneous Ground Fault
- 3. Phase Imbalance
- 4. Bus Protection Lockout Enclosure 7 Page 11 of 17 l
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I j FOINT INSTR. SET AI/.R*I +
l th0. MO. DESCRIPIOR luthT Cb'sDITION(S)
Q%3 QS-SFRCS SFRCS Full Trip 1. High or low current indi- 1. Loss of 4 Reu tor Coolant Pumps.
cation on all 4 RCP's.
- 3. Creater than 177 PSIC. 3. High steam to fee.! water DP due to loss of feedwater.
- 4. Less than 2t. 5" 4. Low steam generator level.
Q981 QS-6401 SU XDSt 01 TRBL 1. Sudden Pressure 8 PSIG !. A sudden pressure in the XDIR
- 2. Phase overcurrent 144.3 A due to a fault (AP3101.07)
(86.2 11VA) 2. A ground fault on the XHIR secondary or backup protection for breakers HX01A and HXolB
- 3. A phase overcurrent on the XRIR primary or backup protection for breakers HX0IA and HXOlB
- 4. A differential relay operation caused by a lault in the trans-former or its connections to j the 13.8 KV Busses Q984 QS-6402 SU M 02 TRRL 1. Sudden Pressure 8 PSIG 1. A sudden pressure in the XDIR
- 2. Phase overcurrent 144.3 A due to a fault (AP3101.07) l (86.2 ?fVA) '
- 2. A ground fault co the XDIR l secondary or b.sckup protection
( for breakers IIXO2A and liXO2B
- 3. A phase overcurrent on the XHtR primary or backup protection for breakers HXO2A and HXO2B i
- 4. A differential relay operation caused by a fault in the trans-former or its connections to the 13.8 KV Busses Enclosure 7 Page 13 of 17
.w PO!NT INSTR. SET
~
AI.AP!! +
CD. NO. DESCRIPTUR lolNT CONDITI6N(S)
R793 NSH-NI5 RPS CH I HI Flux 1. 104.75 + 0 - .5% of Rated khen any one of the four RPS Over-Thermal Power with tour power Trip histables Trip pua,*s operating
- 2. 79 + 0 - .5% of Rated Thermal Power with three pumps operating RSO2 NSH-NIS RPS CH 2 Hi Flux 1. 104.75 + 0 - .5% of Hated When any one of the f ou r RPS Ove r-T;.crual Power with four power Trip bistables Trip pumps operating
- 2. 79 + 0 - .5% of Rated The rma l Powe r wi t h t h ree pumps operating R811 NSH-NIS RPS CH 3 Hi Flux 1. 104.75 + 0 - .5% of Rated When any one of the f our El"i over-Thermal Power with f our power Trip histables Trip pumps operating
- 2. 79 + 0 - .5% of kate.1 Thermal Power with three pumps operating RS17 NSH-N17 RPS CH 4 Hi Flux 1. 104.75 + 0 .5% of Rated When any one of the lour RPS over-Thermal Power with four power Trip Bistat.les Trip pumps operating
- 2. 79 + 0 .5% of Rated The rma l Powe r w i t h t h ree pumps operating RS32 RSHH-2004 SFAS CH I CT!!T RAD til 1. Modes I, 2, 3, 4: SFAS Cll 1 CT!!T RAD 111 Trip 15 ?!R/HR or 1.8 x bKGND 1 10% BKGND
- 2. l lode 6: 2 MR/liR E834 RSliH-2005 SFAS CH 2 CTMT RAD !!I 1. Mo.les I, 2, 3, 4: SFAS Cll 2 CTtlT RAD til Trip 25 !!R/IIR or 1.8 x BKGND 1 101 EKGND
- 2. Mode 6: 2 t1R/HR Enclosure 7 Page 14 of 17
+-
POINT INSTR. SET AI. ARM NO. No. DESCRIPTOR POINT CONDITION (S)
R836 RSHH-2006 SFAS Cll 3 CTtIT RAD 111 1. tiodes I, 2, 3, 4: SFAS Cli 3 CTt!T RAD Hi Trip 25 ilR/ilR or 1.8 x BKGNI) i 101 bKGND
- 2. Mode 6: 2 !!R/lik R838 RSHH-2007 SFAS Cil 4 CTNT RAD lil 1. Modes 1, 2, 3, 4: SFAS Cil 4 C1MT RAD 111 Trip 15 t1H/liR or 1.8 x BKGND 1 101 BKGND
- 2. Mode 6: 2 !!R/liR S426 SSL-6400 GEN Under Frequency Under irequency relay Blut & khen the system load excecils system 8102 are set for 58.2 Ilz and generation. Trips generator main 0.5 seconds. Both contacts breakers 34560 anil 34561 for gener-are in series so that both ator under f requency protection.
under irequency relays must operate to trip.
T856 TSH-RC3B2 RPS CH I RC HI Temp 616.8 *F 1 0.2 *F RPS CH 1 RC Temp til Trip T857 TSil-RC3A4 RPS Cll 2 RC HI Temp 616.8 *F 1 0.2 *F RPS CH 2 RC Temp III Trip T858 TSil-RC3B4 RPS CH 3 RC 111 Temp 616.8 *F 1 0.2 *F RPS CH 3 RC Temp 111 Trip T859 TSH-RC3A2 RPS Cll 4 RC HI Temp 616.8 *F 1 0.2 *F RPS Cli 4 RC Temp !!! Trip X014 QS-6044 SkTD ACB 34563 N/A SkTU ACB 34563 Trip X015 QS-6045 SkTD ACB 34564 N/A SWYD ACB 34564 Trip X024 QS-6117B SkTD Oscillograph Started N/A Electrical fault on 345 KV lines (may also be caused by operating 345 KV breakers).
X025 QS-6041 SkTD ACB 34561 N/A ACB 34560 Trip X026 QS-6042 SkTD ACB 34561 N/A ACB 34561 Trip X027 QS-6043 SkTD ACB 34562 N/A SWYD ACB Trip Enclosure 7 Page 15 of 17 7
. 1 s 7 f
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) i a a dl p t i i i i i na S r r i l i d s s s s s EP
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ne E sM( M gab r e b ns ns ns ns ns el el r eo eo eo eo eo ho . . .
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I S V l T l l l 2 2 R L o C p V S b V V V V V S i r L L L L L E r p p u V V V V V D T i i T r r s s s s s r T T r s s s s s e e a a a a a t h h t p p p p p s c c s y y y y y a e e a B B B B B M M l t H b b b b b G G G G r r r r r
- - - - u u u u u T T T T T T T T T 1 2 3 l 2 A B B 8 A A R 0 3 1 3 3 3 3 3 3 T . 1 1 1 9 1 1 1 1 1 SO 2 2 2 2 P P P P P NN 2 2 2 2 S S S S S I - - - - - - - - -
S S S S S S S S S Q Q Z Q Z Z Z Z Z T 0 2 3 8 0 1 2 3 4 N . 3 3 3 3 6 6 6 6 6 l O 0 0 0 0 O O O O O oN X X X X Y Y Y Y Y P
e POINT INSTR. SET AI.Akt! -
NO. NO. DESCRIPTOR POINT CONDITION (S)
YO65 ZS-SP13A3 Turb Bypass VLV 2-3 N/A When the valve changes position Clos /NC 2980 ZS-2957 Unit Seismic Instr 0.1 g 1. Seismic Event.
- 2. Blasting Enclosure 7 Page 17 of 17 r
o 4
SOE/ ALARM ANALYSIS If Reactor Protection System (RPS) Trip:
(1) Each channel has SOE points on both the trip parameter and the verification of a channel trip. Check both.
(2) Verify on SOE, when second channel tripped, the following was received indicating trip occurred:
Q180 "CRD Cll A/C ANT TRIP DEVICE" " TRIP" Q181 "CRD Cl! B/D ANY TRIP DEVICE" " TRIP" Q266 "CRD TRIP CONFIRM" " TRIP" (3) Verify the trip parameter makes sense; for example, you should not get a pressure temperature trip when T g is less than 606*F.
(4) On SOE after the trip depressurizes the primary, all four RPS channels should receive low pressure trips. This is the time to confirm which RPS channels had not tripped (the channel trip only comes in once on SOE).
(5) On alarms, verify:
Q185 "CRD MTR PWR" "0FF" Q186 "CRD PROGRAMMER LAMP FAULT" "YES" Check Turbine Generator:
(1) On SOE verify:
X030 "T/G MASTER TRIP SOLEN 0 IDS" " TRIP" ]
J428 " GEN REVERSE POWER" " TRIP" } aftar X025 "SWYD ACB 34560" "0 PEN" ] 'l a
X026 "S'wYD ACB 34561" "0 PEN" l seconds (2) On alarm printout verify:
Z498 - 2501 "HPT GOV VLV 1-4" " CLOSED" Z506, Z508 "HPT STOP VLV l-4" " CLOSED" Z510, 2512,]
Z591, 2576,l "LPT 1, 2 RIIT STOP VLVS 1-4" " CLOSED" Z578, Z593 )
"LPT 1, 2 RIV l-4" " CLOSED" f55 X070 "TURB EXT ATR DUMP RELAY VLV" " TRIP" Q379 "EllC ELECTR'. CAL" "TRBL" Enclosure 8 Page 1 of 4 o
s.
Primary (1) On alarms, check time of second makeup pump on Q754 or Q759 "RC MU PMP 1 (2)" "0N" (2) On alarms, check high makeup F741 "RC MU FLOW" "lII Gli" (3) On SOE, check pressurizer heater cutof f if < 40" L770 "RC PRZR L0 LVL liTR" " TRIP" Then return to normal Miscellaneous (1) On alarms, check atmospheric vent positions Z961 and 2969 "SG 1, 2 ATM STil VENT VLV" "Ol'EN" when > 1025 l'SIG (2) On SOE or alarms, check TBV positions YO60, YO65 "TURii BYPASS VALVE 1, 2 3" "NC" when > 1015 PSIG (3) On alarms, check for deaerator hi level trips L'59, L360 " DEAR STRG TK 1, 2 !!! LVL" " TRIP" (4) On alarms, check condenuate pumps reduction Q168, Q171, Ql74 "CNI)S PMP 1, 2, 3" "0FF" SFRCS Prescatly, only three STRCS inputs are connected to the SOE monitort these are:
Point 40 SFRCS Full Trip Point 62 SFRCS DP llalf/ Full Trip SG 1 Point 63 SFRCS DP llatf/ Full Trip SG 2 The only way to tell the input parameter on which SFliCS tripped is to review the alarm printout. Notet khen it references Channel 1 or 2, it is Actuation Channel 1 or 2, not Logic Channel 1, 2, 3, or 4.
Q847 SFRCS SG 1 Isol Q848 STRCS SG 2 Isol Q963 SFRCS Full Trip Q692 SFRCS Mn Stm Low Press Trip, Ch 2 Q693 SFRCS Mn Stm Low Press Trip, Ch 1 L886 SFRCS SG Lvl llatf/ Full Trip, Ch I L896 SFRCS SG Lvl llalf/ Full Trip, Ch 2 P671 SFRCS DP llalf/ Full Trip, Ch !
P680 SFRCS Mn Stm Line Low Press, Ch 2 P681 SERCS Mn Stm Line Low Press, Ch !
Enclosure 8 Page 2 of 4 l
O 4
Q847 SFRCS SG 1 1801 Q848 SFRCS SG 2 18o1 Q963 SFRCS Full Trip Qb92 SFRCS Mn Stm Low Press Trtp, Ch 2
- Qo93 SFRCS Mn Stm Low Press Trip, Ch 1 L886 SFRCS SG Lvl llatf/ Full Trip, Ch I L89n SFRCS SG Lvl llatf/ Full Trip, Ch 2 P671 SFRCS DP lialf/ Full Trip, Ch 1 Po80 SFRCS Mn Stm Line Low Press, Ch 2 P681 SFRCS Mn Stm Line 1.ow Press, Ch 1 0684 SFRCS Mn Stm Low Press lilk, Ch 2
. P685 SFRCS Mn Stm Line Low Press illk, Ch !
P691 SFRCS DP llatf/ Full Trip, Ch I Pb92 SFRCS DP llatf/ Full Trip, Ch 2 The SFRCS alarms have several flaws: (1) They only tell the status at actuation channels, not individual logic chan icts. As Sappens all too often, a power supply is lost to one logic ch.innel, initiating all the alarms for that actuation channel which prevent 4 proper analysis of the trip. (2) Not enough indication is ptovided of a full trip. Only Q693 is provided to vertly a full trip, and it does not tell which channel.
The stroking of the SFRCS valves shotild be vert t tcd within the proper time interval. The following is a 11st of the SFRCS valves, the computer points, and the stroke timcu.
CPT RESPONSr. TIME ICSilD *" 2961 10 seconds
- ICSilA -
- Z969 10 seconds 1 MS101 1 Z6 8', 10 seconds
- MS100-1 2688 10 seconds MS394 Z684 10 seroniis MS375 Z/ a7 to seconils
.SP7A 2680 lune plots) 12 seconds *
- SP78 s' 2675 lose plots l 12 seconds
- FW612 - Z674 15 neronds*
Fv601 -
2619 15 neton.ls'<
MS106 *-
2003 36 acrond*,
L MS107 2006 40 neronds
" i MS106A 2004 38 seconds
- MS107A ZOO 7 34 acconds
. MS101 2681 *a acconds
, 8 MS100 Z686 's act onds TtIRDINE TRIP SF.I. SOF, i -
AF3872 e - 2010 34 acconds
. ' AF3870 a - ' 2008 34 seconda r Ar3871 : 2011 33 scronds F.nclosurc 8 Page 3 of 4
-44 e
o 4
- AF3',b9 <- 2009 34 seconds F1.779 NONI N/A
}N780 SONt N/A AT599 Z9/0 10.5 seconds
+
Af608 2962 13.5 seconds SPtB !.678 [use plots]
SP6A 2073 luse plots!
Per USAR 7.4.1.3.10-9, auxiliary tcrdwater pumps will be at full speed within 40 seconr;s from the time of signal initiation.
There are prese'itly no ARTS SOE pointa.
The ARTS computer alarma presently .svatlable are:
Q)01 ARTS In From ?!FpT*
y003 ARTS In from T-G6 QOO4 ARTS Test Trip
- l Q777 ARTS Trip
- Q778 Rx Pwr > 15% and Rx T 0 Trip
- Q779 Rx T-G Trip *
- Note that thenc come in when any ppg channel trips on the parameter.
I Thtretore, if a channel was tripped hours before, no new alarm will l b? received when the ha.:end channel trips the plant.
tica,os have been writter to F.ngineering reipicating 6cparate ARTS channel al.orms and SOE points.
l l
l l
l Enclosure 8 Page 4 of 4 4 's -
\
\
9
{' ,
l 6 t
POST TRIP REVIEW CllECKLIST 1Lem Comments ,
1.0 SOE, Post Trip Review, alarms reviewed, operators interviewed, post trip meeting 1.1 Prime printout delogged 1.2 Plots completed 1.3 Copies of data distributed 2.0 Data Analysis {
f 2.1 SOE describes sequence RPS trip sequence delineated Q180, Q181, .ind Q266 came in when second channel tripped RPS trip makes sense All four RPS channels tripped on low pressure after trip (
i
_, Verify turbine trip (X030) t After 30 seconds, verify auto trans (J428, X025, X026) i
, Check pressurizer heater cutoff (L770) ;
Check TBV positions (YO60 - YO65) :
Check STRCS, SFAS, ARTS operation, including valve i operation time i i
2.2 Ala nse Read over all alarms (approximately 20 minutes prior to ,
and approximately I hour af ter) l Verify Ql85, Q186 for reactor trip Verify turbine operationt !
COV VLVS 2498-Z501 '
CLOSED STOP VLVS Z506, 2508, Z510, 2512 CLOSED RHT STOP VLYS 2591, 2576, 2578, 2593 CLOSED '
RHT VLV 2580, 2581, 2594, 2596 CLOSED AIR DUMP RELAY X070 TRIPPED EHC ELECT Q379 TRBL 2nd Haseup Pump on Time (Q754 or Q759)
F741 RC HU FLOW "HIGH" Check atmospheric vents (Z961, 2969)
Check deserator hiah level trips (L359, L360) i Check condensate pump reduction time (Ql68, Ql11 Ql74)
Time Enclosure 9 Page 1 of 3 l j
,o 4
Check alarms for SFRCS and ARTS 2.3 Data Analysis RFR operated properly Tave near $52*F Pressurizer level not lost (not < 8")
!!SSV reset > 960 psig I
RCS pressure minimum > 1800 psig Review deaerator level after trip Safety systems operated as designed ICS operated as expected 3.0 Support of Outside Organizations NEWORK ent ry made TAP Teim called in/not called in Entrance meeting data complete (if rc<luired) 4.0 Report Preparation Report out for comments Comments incorporated and sent to SRB Final report sent to B&W TRANS IENT__ Cort!ENTS :
Enclosure 9 Page 2 of 3
-47
~
f 0 l
< 1 l
l 4
Enclosure 9 Page 3 of 3
-48 e
L, e
n POST TRIP PLOTS PLOT NO.
1 F674 t1N FW 1 FLOW 0-7000 KPPH L883 SG 1 SU LVL 0-250" Z673 MN FW 1 CU POSITION 0-100%
2675 SU FW l CU POSITION 0-100%
P932 SG 1 STEAM PRESS 600-1100 2 F679 tin FW 2 FLOW 0-7000 KPPil L893 SG 2 SU LVL 0-250" 2678 MN FW 2 SU POSITION 0-100%
Z680 MN FW 2 CU POSITION 0-100%
P936 SG 2 OUT PRESS 600-1100 3 J427 GEN GROSS PokIR 0-1000 MWe R790 RPS AUCT AVE PhR 0-110%
R795 RPS Cll 1 PWR RANGE 0-110%
R804 RPS CH 2 PWR RANGE 0-110%
4 T782 RC LOOP 2 HLG WR TEMP 520-620 F T753 RC LOOP 1 HLG WR TEMP 520-620 F T781 RCP l-1 DISCH WR TEMP 520-620 F T821 RCP 2-1 DISCH WR TEMP 520-620*F 5 F874 AFW FLOW TO SG #1 0-1000 GPM S008 AFP #1 SPEED 0-5000 RPM F875 AFW FLOW TO SG #2 0-1000 GPM S018 AFP #2 SPEED 0-5000 RPM 6 P725 RC LOOP 1 HLG PRESS 1400-2400 PSIG L768 PRESS COMP LEVEL 0-300" T709 RCS AVE NR TEMP 520-620*F MODCOMP 7 S657 HFP #1 SPEED 0-6000 RPM S667 MFP #2 SPEED 0-6000 RPM L352 DEAR 1 STR TK LVL 6-16' L356 DEAR 2 STR TK LVL 6-16' MODCOMP 8 Q190 GROUP 7 R0D POSITION 0-100%
R794 NI6 D FLUX -25 to +25 R803 NI 5 D FLUX -25 TO +25 R813 NI 8 D FLUX -25 TO +25 R819 NI 7 D FLUX -25 TO +25 SNB/003 Enclosure 10 Page 1 of 1