NUREGAA-0030

Interational

Agreement Report

Assessment of RELAP5/MOD2

Code Using Loss of Offsite Power

Transient Data of KNU #1 Plant

Prepared by

Bud-Dong Chung, Hho-Jung Kim

Nuclear Safety Center

Korea Advanced Energy Research Institute

Young-Jin Lee

Department of Nuclear Engineering

Seoul National University

Office of Nuclear Regulatory Research

U.S. Nuclear Regulatory Commission

Washington, DC 20555

April 1990

Prepared as part of

The Agreement on Research Participation and Technical Exchange

under the International Thermal-Hydraulic Code Assessment

and Application Program (ICAP)

Published by

U.S. Nuclear Regulatory Commission
NOTICE

This report was prepared under an international cooperative

agreement for the exchange of technical information.; Neither

the United States Government nor any agency thereof, or any of

their employees, makes any warranty, expressed or implied, or

assumes any legal liability or responsibility for any third party's

use, or the results of such use, of any information, apparatus product or process disclosed in this report, or represents that its use

by such third party Would not infringe privately owned rights.

Available from

Superintendent of Documents

U.S. Government Printing Office

P.O. Box 37082

Washington, D.C. 20013-7082

and

National Technical Information Service

Springfield, VA 22161
NUREG/IA-0030

Intemational

'J Agreement Report

Assessment of RELAP5/MOD2

Code Using Loss of Offsite Power

Transient Data of KNU #1 Plant

Prepared by

Bud-Dong Chung, Hho-Jung Kim

Nuclear Safety Center

Korea Advanced Energy Research Institute

Young-Jin Lee

Department of Nuclear Engineering

Seoul National University

Office of Nuclear Regulatory Research

U.S. Nuclear Regulatory Commission

Washington, DC 20555

April 1990

Prepared as part of

The Agreement on Research Participation and Technical Exchange

under the International Thermal-Hydraulic Code Assessment

and Appllcation Program (ICAP)

Published by

U.S. Nuclear Regulatory Commission
NOTICE

This report is based on work performed.under the sponsorship of The Korea

Advanced Energy Institute of Korea. The information in this report has been

provided to the USNRC under the terms of an information exchange agreement

between the United States and Korea (Agreement on Thermal-Hydraulic Research

between the United States Nuclear Regulatory Commission and The Korea Advanced

Energy Research Institute, May 1, 1986). Korea has consented to the publication

of this report as a USNRC document in order that it may receive the widest

possible circulation among the reactor safety community. Neither the United

States Government nor Korea or any agency thereof, or any of their employees,

makes any warranty, expressed or implied, or assumes any legal liability of

responsibility for any third party's use, or the results of such use, or any

information, apparatus, product or process disclosed in this report or

represents that its use by such third party would not infringe privately

owned rights.
Acknowledgement

We would like to express our appreciations for the help of KNU #1

utility company (KEPCO) staffs in preparing the plant input deck. We

especially appriciate to Dr Sang Hoon Lee, president of the Nuclear

Safety Center, in organizing the project.. This assessment work was

sponsered by the Ministry of Science and Technology in Korea.

Abstract

This report presents a code assessment study based on a real plant

transient that occurred on June 9, 1981 at the KNU #1 ( Korea Nuclear

Unit Number 1 ). KNU #1 is a two-loop Westinghouse PWR plant of 587 Mwe.

The loss of offsite power transient occurred at the 77.5 X reactor power

with 0.5 %/hr power ramp. The real plant data were collected from

available on-line plant records and computer diagnostics.

The transient was simulated by RELAP5/MOD2/36.05 and the results were

compared with the plant data to assess the code weaknesses and

strengths. Some nodalizatlon studies were performed to contribute to

developing a guideline for PWR nodalization for the transient analysis.

i
Executive Summary

This report presents a code assessment study based on a real plant

transient that has occurred on June 9, 1981 at the KNU #1 (.Korea

Nuclear Unit Number 1 ). KNU #1 is a two-loop Westinghouse PWR plant of

587 Mwe. The loss of offsite power transient occurred at the 77.5 %

reactor power with 0.5 %/hr power ramp. The real plant data were

collected from available on-line plant recording and computer

diagnostics.

The transient was simulated by RELAP5/MOD2/36.05 and compared with

the plant data to assess the code weakness and strengths. Some

nodalization studies were performed to develop the guideline of PWR

nodalization for the transient analysis.

It was found that the'code gives stable steady-state results and

accurate predictions of the plant behavior for the transient,

indicating the excellent' capability'' of the code for this type

of transients. In 'particular, the calculated primary "thermal

behavior closely follows the'plant• data and 'th'is validates that the

relevant thermal-hydraulic and decay power model using previous

power history data in the RELAP5/MOD2 are correctly describing the

actual phenomena.

In the nodalization sensitivity study it was found that S/G noding

with junctions between bypass `plenum and Steam dome is preferred to

simulate the S/G water level decreasing and avoid the spurious level

peak at turbine trip.'

The pressurizer pressure increase is sensitive to the insurge flow.

It' is believed that :the interfaciail heat: transfer in a horizontal

stratified flow regime may be estimated low and the compression effect

due to insurge flow may be'high. '

,: .... i i
Contents

Executive Summary

Abstract

Acknowledgement

List of Tables

List of Figures

1. Introduction --------------------------------------------- 1

2. Plant Description --------------------------------------- 2

2.1 Reactor Coolant System ----------------------------------- 2

2.2 Configuration of Secondary System -------------------------- 3

2.3 Plant Diagnostics and Uncertainty Band ---------------------- 3

3. Plant Transient Description -------------------------------- 6

4. Code and Model Description for Plant Simulation----------------8

5. Base Case Result and Discussions ---------------------------- 13

6. Discussions on the Result of Nodalization Study ---------------- 22

7. Run Statistics ------------------------------------------- 30

8. Conclusion ---------------------------------------------- 33

9. References ---------------------------------------------- 34

Appendix. -------------------------------------------------- 35

iii
List of Tables

Table 1. Sequence of Events for Plant Transient Simulation ---------- 7

Table 2. Simulated Initial Condition for Full Load Condition -------- 9

Table 3. Simulated Initial Condition for 77.5 % Power Condition ----- 9

iv
List of Figures

Fig.1 Schematic Diagram of Reactor Coolant System for KNU #1 --------5

Fig.2 Nodalization of KNU #1 Power Plant ------------------------- 10

Fig.3 S/G Main Feedwater Flowrate and Simulated Boundary Condition- 11

Fig.4 Power History prior to Reactor Trip and Simulated Input ------ 12

Fig.5 S/G Narrow Range Water Level versus Time -------------------- 16

Fig.6 S/G Pressure versus Time ---------------------------------- 17

Fig.7 Loop Flowrate versus Time --------------------------------- 18

Fig.8 Loop Temperature versus Time ------------------------------- 19

Fig.9 Collapsed PZR Water Level versus Time ----------------------- 20

Fig.10 PZR Pressure versus Time ---------------------------------- 21

Fig.11 S/G Nodalization for Sensitivity Study ---------------------- 24

Fig.12 S/G Narrow Range Water Level ( case 2, case3, case4 ) -------- 25

Fig.13 S/G Narrow Range Water Level versus Time ( case2 ) ---------- 26

Fig.14 S/G Pressure versus Time ( case2 ) ----------------------- 27

Fig.16 PZR Pressure versus Time with Heat Loss through Wall --------- 29

Fig.17 Time Step Size and Courant Time Limit versus Real Time ------- 31

Fig.18 Total required CPU Time versus Real Time -------------------- 32

V

.1. Introduction

The plant transient following a loss of offsite power have a

relatively high probability of occurrence and many studies were

performed about the accident sequence initiated by loss of offsite

power. We have experience of this event in 1981 at KNU # I PWR plant.

The event was initiated by loss of feedwater in one of two steam

generators. During the transient, the major plant data was recorded by

on-line computer data logging system and by strip charts. Although the

collected data is very limited according to the frequency of data

processing during the accident, the plant data is very useful for code

assessments because the scaling problem would be eliminated.

The loss of offsite power transient was simulated by

RELAP5/MOD2/36.05. The main objectives of simulation are to check the

code capability for such event and to give the guideline of PWR

nodalization for transient analysis.

The plant characteristics and the event of transient are described in

Section 2 and 3. The plant simulation model and nodalization are

included in section 4. The base case results are discussed in section 5

and the nodalization studies are discussed in section 6. A run statics

are included in section 7.

1
2. Plant Description

This section provides a description of the plant and principal system

relevant to understanding KNU # 1 loss of offsite power transient. Kori

Unit 1 is a Westinghouse 2-loop PWR rated at 587 Mwe and commissioned in

1978, for which BECTHEL was the architect/engineer [1].

2.1 Reactor Coolant System

A flow schematic of. the reactor coolant system (RCS) is presented in

Fig. 1. As shown in Figure 1 the RCS is equipped with 2 reactor coolant

loops (A and B) composing each steam generator (PCSG1,PCSG2) and main

coolant pump (2P1A,2P1B). A 144 inches active core consists of 121 fuel

assembly with 179 fuel rods per assembly. The nominal core power is

1723.5 Mwt.

The reactor vessel has two inlet and outlet nozzles located in a

horizontal plane just below the reactor flange but above the top of the

core. Coolant enters the vessel through the inlet nozzles and flows

down the core barrel-vessel wall annulus, turns at bottom and flows

through the core to the outlet nozzles.

Two steam generators are vertical Westinghouse U-type Model 51. The

reactor coolant flows through the inverted U-tubes, entering and leaving

through the nozzle located in the hemispheric bottom head of the steam

generators. Steam is generated on the shell side and flows upward

through the moisture separators to the outlet nozzle at the top of the

vessel.

The reactor coolant pumps are identical single-speed centrifugal

units driven by air-cooled, three phase induction motors. The type of

pump is the Westinghouse Model W93-A. A flywheel the inertia of which

is 82,000 lb-ft 2 provides additional inertia to extend pump coast

down. The reactor coolant loop piping is specified in sizes

consistent with system requirements. The hot leg inside diameter is 29

inches and the the inside diameter of the cold leg return line to the

reactor vessel is 27.5 inches. The piping between the steam generator

and the pump suction is increased to 31 inches inside diameter to reduce

the pressure drop and improve flow conditions to the pump suction.

2
The pressurizer is a vertical, cylindrical vessel with hemispheric

top and bottom heads and it's total free volume is about 1000 ft?

Electrical heaters the maximum capacity of which capacity is 1,000

Kw,was installed through the bottom head of the vessel while the spray

nozzle, relief and safety valve connections are located in the top of

the vessel.

2.2 Configuration of Secondary System

The auxiliary feedwater system consists of two separate sections to

ensure delivery of auxiliary feedwater. One. section has two electric

motor-driven pumps and the other section a single steam turbine-driven

pump. The motor-driven pumps start automatically upon receipt of

two-out-of-three low-low water level signal in both steam generators.

The design flow of one pump is 215 gpm. The turbine-driven pump will be

operated upon the same logic of motor-driven pump, but only if one of

the motor-driven pumps does not operate. The design flow is about 410

gpm.

The steam supply line to the auxiliary feedwater pump turbine are

connected to the upstream of the main steam stop valves to provide a

dependable steam supply.

The steam dump system enables the nuclear supply system to follow

load changes which exceed 10 percent step or 5 percent per minute. The

steam dump system is designed to have a flow capacity of 40 percent of

the full load steam flow at full load steam pressure.

2.3. Plant Diagnostics and Uncertainty Bands.

There are three type of digital recordings from plant computer; the

computer daily logging sheet [2],pre-post trip review record [3]-and

sequence record of event [4]. Besides of these digital recording, there

are analog strip chart recordings the speed of which is 2 cm/hr. The

processing interval of daily logging'system is 1 hour. The trip review

record system keeps the data started from 2 minute before the reactor

trip to 3 minute after reactor trip. The processing frequency of the

3
trip review record is 10 seconds during the above period.

It is believed that the short time behavior is more useful for the

loss of offsite power transient. Therefore the available data for code

assessment are pre-post trip review record and sequence of event record.

Trip review record contains important thermal-hydraulics parameters

measured in primary and secondary systems. The recorded parameter of

primary system are the ; reactor neutronic power, loop averaged

temperature, loop temperature difference, hot leg temperature, cold leg

temperature, pressurizer pressure,pressurizer level, loop flowrate, and

system pressure. The recorded secondary system parameters are steam

flowrates, feedwater flowrates, steam pressure,. narrow and wide range

water level of steam generators, and feedwater temperatures.

The evaluation of measurement uncertainty is quite difficult because

it contains the calibration error caused by the human"error. But in the

rough precision of engineering sense, the uncertainty band of

temperature sensors is estimated as 2.22 deg-K and that of pressure

sensors is estimated as 2.1 bars.

4
4 II

1i4.: r Li

- ITnatafEbd SCCs

CA'

U '-

C-. ~

*-.S.C S

* - ~j pACt-S-Ca-4

~ l.a

Fig.1 schematic Diagram of Reactor Coolant System for KNU #1
3. Plant Transient Description

Plant transient sequence is based upon the sequence of events

record from digital plant computer records. At around 11:00 AM on June

9, 1981, while operating at 77.5% reactor power and 447 MWe generator

power, the I/I converter (LM-461A) of the S/G-A level control system

mal-functioned generating a spurious signal that indicated high S/G-A

water level. This signal activated the closure of the S/G-A main

feedwater control valve(IFV-466) which subsequently caused the

steam/water flow mismatch signal to be generated. The resulting S/G low

level signal brought about the reactor/turbine trip at 11:05.20 AM. The

turbine-generator continued to operate for 30 seconds, as designed, and

then tripped at 11:05.50 AM. At the moment the generator trips,

automatic transfer to the offsite power supply (154KV) should have

occurred.- However, both the automatic and the manual transfer of Bus-A

failed, whereas Bus-B succeeded in automatic transfer to the offsite

power initially but also failed after 31 seconds. Both buses were open

at 11:06.21 AM.

Failure of Bus-A caused the RCP-A totrip at 11:05.55 AM immediately

followed by the actuation of the diesel generator-A (D/G-A) which

provides emergency power to safeguard Bus-A.The failure of Bus-B after

the initial successful transfer caused a loss of offsite power transient

for about 6 minutes from 11:06.21 AM. The failure of Bus-B caused the

RCP-B to trip at 11:06.23 AM and the D/G-B to begin supplying power to

safeguard Bus-B. After 6 minutes into the loss of offsite power

transient, at 11:11.52 AM, Bus-B recovered the offsite power and

subsequently the D/G-B was manually tripped. Despite the recovery of

offsite power in Bus-B, the RCP-B continued to remain tripped until it

was manually activated at 11:32 AM. Recovery of offsite power to Bus-A

was achieved much later and the RCP-A was re-activated at 19:16.

In summary, from 11:06.23 to 11:32, both RCPs were not in operation

causing a complete loss of reactor coolant flow accident for 26 minutes,

and from 11:05.51 to 11:06.21 and also from 11:32 to 19:16, only one RCP

was operating causing a partial loss of reactor coolant flow accident.

Major sequence of events of the transient is summarized in Table 1.

6
Table 1. Sequence of Events for Plant Transient Simulation

Real Time Elapsed Time Recorded Events Remarks

(Hr.Min.Sec.) (sec)

0.0

50.0

11.05.20. 100.0

-77.5% Power Operation

(0.5% /hr increase)

-Hal-function of I/I

converter

-S/G-A MFWCV start to

close

-S/G-A Low Level &

Flow mismatch cause

Reactor/Tubine Trip

-Unit on line Breaker

52/MT-345 Open

-Safegard Bus-B

operation

-RCP #1 Trip

Due to Tansfer Fail

in Bus-A

-Safegard Bus-A

Operation

11.05.51.

11. 05. 52.

131.0

132.0

Steady State

Calculation

Accident

Starts

Simulation

as input time

Loss of Onsite

Power (345KV)

Transfer to

Offsite Power

(154KV)

Simulation

as input time

Start of

Station

Blackout

Sequence

Loading

Simulation

as input time

Calculation

Stop

11.05.55

11.05.57

135.0

137.0

11.06.23 163.0

300.0

392.0

-RCP #2 Trip

Due to Transfer Fail

in Bus-B

-Restore the failure of

Offsite Power Transfer

11.11.52

7
4. Code and Input Model Description for Plant Simulation

The Code used was RELAP5/MOD2/CY36.05 and was processed on a CDC

machine CYBER 170-875. The input deck was prepared by KAERI in

cooperation with a utility company of KNU #1. The nodalization

philosophy is based on the guideline of RELAP5 code manual [5] and the

detailed data for specific volumes and junctions are based on the design

or drawing values for KNU # 1.

The resulted nodalization is shown in Fig. 2. The nodalization

divides the whole system into 114 volumes including 11 boundary volumes,

124 junctions and 79 heat slabs. Each steam generator is modeled with 8

heat slabs for U-tubes and 13 volumes including a steam separator. The

outlets of both S/Gs are connected to form a single volume, 'steam

head', which is then connected to two time-dependent volumes that act as

the pressure boundary conditions for the steam generators.

The steady-state calculations were carried out to provide the initial

conditions for the transient analyses. The transient was occurred at

77.5 Z power condition. However plant conditions needed for starting a

calculation are not known. Meanwhile the design values based on the full

load condition are available. Thus it is necessary to calculate the

steady state for the full power condition first, and next for the 77.5

power condition by reducing the power from full load condition.

The simulated initial conditions along with the desired plant

steady-state data for both power cases are summarized in Table 2 and

Table 3. Generally the simulated values are in excellent agreement with

the desired values. In the process of obtaining the desired value, it

was necessary to adjust the total heat transfer area of steam

generators.

During the transient the most thermal hydraulic parameters were

determined by calculation but some parameters were taken from boundary

conditions.

One of these is the feedwater. In the initial stages of the plant

transient, the main feedwater flow rate was automatically controlled by

the MFWCV(Main Feed Water Control Valve) following the mal-function of

the S/G level indicator. Since the actual automatic operation of the

MFWCV is difficult to identify, the feedwater flowrate shown in Fig. 3

8
is assumed based on the plant data so as to correctly simulate the plant

thermal hydraulic behavior.

The decay power strongly depends on the history of power operation.

The transient occurred during the 'escalation of power after the

performance test. Thus the 4-day power history prior to reactor trip

was used as input values, shown in Fig. 4. The resulted decay power is

estimated as 94 % of decay power for infinite operation.

Table. 2 Simulated Initial Conditions for Full Load Condition

Parameters Simulated Desired

Core Thermal Power (MW) 1,723.0 1,723.5

PZR Pressure (MPa) 15.51 15.50

PZR Level (%) 47.60 47.60

Hot Leg Temperature (K) 589.45 589.36

Cold Leg Temperature (K) 556.06 555.89

Loop Coolant Flowrate (kg/sec) 4,686.50 4,687.50

Main Feedwater Flowrate (kg/sec) 473.00 473.00

Feedwater Temperature (K) 496.30 496.30

Steam Flowrate (kg/sec) 472.64 473.10

S/G Pressure (MPa) 5.52 5.55

S/G Narrow Range Level' () 44.01 44.00

S/G Mass Inventory (kp) 44,612.3 44,776.7

U-tube Heat Transfer Area (m ) 5,214.4 4,784.5

U-tube Heat Transfer Rate (Mw) 1,728.8 1,728.5

Recirculation Ratio 2.50 2.50

Table. 3 Simulated Initial Conditions for 77.5.% Power Condition

Parameters 'Simulated Desired

Core Thermal Power (MW) 1,334.8 1,334.8

PZR Pressure (MPa) 15.51 15.41

PZR Level (W) 41.61 41.60

Hot Leg Temperature (K) 583.06 583.10

Cold Leg Temperature (K) 556.88 556.80

Loop Coolant Flowrate (kg/sec) 4,688.28 4,686.50

Main Feedwater Flowrate (kg/sec) 356.75 356.70

Feedwater Temperature (K) 484.80 484.80

Steam Flowrate (kg/sec) 357.00 356.70

S/G Pressure (MPa) 5.896 -

S/G Narrow Range Level (W) 44.02 44.00

S/G Mass Inventory (kg) 49,783.4 -

U-tube Heat Transfer Area (m ) 5,214.4 4,784.5

U-Tube Heat Transfer Rate (MW) 1,340.9 1,339.8

Recirculation Ratio 3.36 -

9
-L

Fig.2 Nodalizatlon of KNU #1 Power Plant
KNU #1 Loss of Offsite Power Transient

REALP5/MOD2/CY36.05 Simulation

500

400

-.- Simulated Input ( -- Simulated Input (

0 Plant Data ( Loop

A Plant Data ( Loop

Loop A )

Loop B )

A)

B)

0

0

a, N

0'

C

4 J

0

L

0

*0

0

C

Iz~

C, N

C,,

A A A A A A• A A

j

v -. v-,

300

200 -

A

100

0 -J I ~T I I I I I I I I

0

4 0 40 s o 80 1 2 T

120 160 200 240 280

Time ( seconds )

Fig.3 S/G Main Feedwater Flowrate and Simulated Boundary Conditiofl
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

1.7

1.6

1.5

V

0.

1.3

1.2

1.1

1

0.9

-110 -90 -70 -50 -30

Time ( Hours )

Fig.4 Power History prior to Reactor Trip and Simulated Input

-10
5. Base Case Results and Discussions

Analyses were performed following the sequence described in Table 1.

During the simulation time (300 seconds), the major events of sequence

were the reactor trip and reactor coolant pump trip, which are not related

to thermal hydraulic phenomena. Therefore the time of major events were

treated as input values. The simulated thermal-hydraulic parameters are

compared with the plant transient data, which are deduced from the

computer trip review sheet. The plant transient occurred during power

escalation, and hence most parameters were not in stabilized.condition

which led to difficulties in deciding the appropriate initial value.

Hence, the unreasonable plant data were ignored and the initial values

were chosen either by an averaging process, or in some cases, from the

design values-specified in the FSAR of KNU #1.

As can be seen in Fig. 3, the feedwater flow was decreased by

malfunction:of the level detector, and it result in the water level

decreasing. The S/G water level was obtained not by the pressure

difference method, as used in the actual plant measurement, but by

calculating the collapsed water volume deduced from the void fraction.

This is because the pressure difference method, when used in the

simulation, often gave rise to a doubtful level oscillation. The

calculated S/G water levels do not agree with the plant data as shown in

Fig. 5. Moreover the spurious level peak was calculated at the turbine

trip. This was caused by the nodalization of steam generator, and the

details are discussed in section 6.

Since the two loops of the S/G secondary side are connected .via a

single common head and because the main steam isolation valve (MSIV) does

not operate in these analyses, the pressure variations in S/G-A and B are

identical as shown in Fig. 6. Following the reactor/turbine trip, the S/G

pressure rapidly increases as the turbine stop valve closes. Normally,

the turbine trip causes the steam dump valve to open, but in this

transient, due to the loss of offsite power it remains closed. In the

plant transient analysis, the S/G pressure starts to decrease as the

supply of the auxiliary feedwater, actuated by the S/G low-low level

signal, reaches its maximum capacity (155.94 sec) so that the secondary

13
heat removal capability begins to overcome the reactor decay power; The

calculated S/G pressure variation up to the peak pressure agrees quite

well with the plant data. In the analyses, PORVs(Power Operated Relief

Valves) were simulated to open at 7.033 MPa (1020 psia). But the supply

of the auxiliary feedwater alone provides sufficient secondary heat

removal capability without the operation of the PORVs.

The primary loop coolant flowrate versus time is shown in Fig. 7, and

as shown in Table 1 and Table 2, the reactor coolant pump-A(RCP-A) was

tripped at 135sec and the RCP-B at 163sec. A rapid reduction in the

RCS flowrate in the loop-A due to the pump trip caused the frictional

resistance of the reactor vessel to decrease. Consequently the loop-B

coolant flowrate increased until the subsequent trip of the RCP-B

leading to the rapid reduction of loop-B flowrate. Meanwhile, the

loop-A flowrate increases, due to the same reason as described above,

just before flow reversal occurred and then decreased slowly. After 200

second, both loops showed an identical trend in the flow coastdown, and

the natural circulation began to be established due to the hot-cold leg

temperature difference. The overall trend in the calculated loop

flowrates is in excellent agreement with the plant data as can be seen

in Fig. 7.

Fig. 8 shows the RCS temperature variations and one can note that

the hot leg temperature variations for both loops are identical in

spite of different RCP trip times. This is reasonable since the

present simulation is based on a single channel model for the

core, allowing complete liquid mixing. Immediately after the

reactor/turbine trips the hot leg temperature decreases rapidly,

whereas the cold leg temperature increased due to the reduction in

the heat removal capability of the S/G secondary side. After the

RCP-A trip, loop-A hot leg temperature has little effect on the cold

leg temperature due to delay in fluid transport, and hence the cold

leg temperature stays at the saturation temperature corresponding

to the S/G-A pressure. Similarly, the loop-B cold leg temperature

also ceases its increase following the RCP-B trip. Afterwards, the cold

leg temperatures slowly decrease as the S/G pressure decreases.

The flow coastdown due to both ROP trips and the decay heat

increase the hot-cold leg temperature difference until the establishment

14
of the natural circulation in the primary side. As this hot-cold

temperature difference increases a driving force for heat transfer from

primary to the secondary side increases. Recognizing above trend in the

temperature variations, one can note that the hot leg temperature

increases until the stable natural circulation is fully

established, and afterwards it decreases along with the cold leg

temperature. The simulated cold leg temperature agrees well with the

plant data whereas the hot leg temperature behavior is rapid. It is

caused by the plant measurement method which use RTD system. The RTD

measurement depends strongly on the coolant flowrate, thus

measurement was delayed by the pump coastdown. For comparison

purpose the lag measure unit was simulated and the output from this

unit showed good agreements with the data. For a time constant of a lag

unit, it was estimated as 20 seconds.

The pressurizer level, shown in Fig. 9, is higher compared with the

plant data. One of the causes may be a difficulty with calculating

the accurate volume of the PZR bottom, in which the complex structures

and PZR heaters are located. Another cause is a difficulty with

predicting upper head temperature of reactor vessel. It is believed that

the upper head temperature is between the hot leg temperature and the

cold leg temperature due to 3 dimensional flow distribution in the upper

part of the core. Using one dimensional code such as RELAPS, It is

impossible to predict the upper head temperature correctly. If we

consider the bypass flow through upper head nozzles, the predicted

temperature should be same as the cold leg temperature. Thus the

contraction effect due to RCS cool down may be under predicted and it

results in the overprediction of pressurizer level.

The pressurizer pressure, shown in Fig. 10, has a similar trend as

the pressurizer level and is higher also as compared with plant data.

But the slope of pressure increase in the heatup phase is much higher.

It may be due to the treatment of pressurizer vessel wall. If we

consider the heat losses to atmosphere through the pressurizer vessel

wall, the improved result was obtained. The details will be discussed in

section 6.

15
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

0.7

0.6

0.5

0.4

at

0

0

z

0.3

0.2

0.1

0

0 40 80 120 160 200 240 280

Time ( seconds )

Ftg.5 S/G Narrow Range Water Level versus Time
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

"-J (0.2

U)

7

6.9

6.8

6.7

6.6

6.5

6.4

6.3

6.2

6.1.

6

5.9

5.8

0 40 80 120 160 200

Time ( seconds )

Ftg.6 S/G Pressure versus Time

240 280
KNU #1 Loss of Offsite Power Transient

6

5

OD

ale30.

Cj

0

LO

4

3

2

I.

0

0 40 80 120 160 200 240 280

Time ( Seconds )

Flg.7 Loop Flowrate versus Time
KNU #1 Loss of Offsite Power Transient

REALP5/MOD2/CY36.05 Simulation

WL

0

E

0

L

0

0.

0

0.

0

o,

586

584

582

580

578

576

574

572

570:

568

566

564

562

560

558

556

0 40 80 120 160 200 240 280

Time ( seconds )

Fig.8 Loop Temperature versus Time
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

0.5

0.4

0.3

00 13

0

-j

0.2

0.1

0

0 40 80 120 160 200 240

Time ( seconds )

Fig.9 Collapsed PZR Water Level versus Time

280
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

U)C

N.

U)y

(L

15.6

15.5

15.4

15.3

15.2

15.1

15

14.9

14.8

14.7

14.6

14.5

0 40 80 120 160 200

Time ( seconds )

Fig.10 PZR Pressure versus Time

240 280
6. Discussion on the result of nodalization study

As shown in Fig. 5, the calculated S/G water levels did not decrease

although the feedwater was decreasing. Moreover the spurious level peak

was calculated at the turbine trip. The calculation results may have

depended on the nodalization of steam generator, thus a study of

nodalization for steam generator was performed.

As shown in Fig. 11, there was no junctions between bypass plenum (

volume 172 ) and steam dome ( volume 180) in the base case ( Case 1). So

there was no steam pass for feedback of pressure spike at the turbine

trip, and the pressure buildup at steam dome (volume 180) drove the flow

of liquid into the volume 172 through separator (volume 171). This

resulted in a spurious level peak. The water level decrease following

decrease of feedwater flow was not simulated well because the flow

stagnation occurred in volume 172.

Three different nodalizations ( Case2, Case3, and Case4) were tested

to evaluate the effect of junction orientation. As shown in Fig. 12, the

effect of the junction orientation is negligible, and thus the

comparisons of case 2 with the base case were done in this paper.

As shown in Fig. 13, the level decreasing is well predicted and the

spurious level peak disappeared by connecting the cross flow junctions

between bypass plenum volume ( volume 187) and steam dome volume (

volume 180). The case 2 nodalization had a little effect on the pressure

of steam generators (Fig. 14), and no effect on the primary side

parameters.

As shown in Fig. 10, the pressurizer pressure was predicted high. The

main reason is the high prediction of pressurizer water level as

described in section 5. But the other reason is the treatment of the

heat losses through the pressurizer vessel wall. At the normal operating

condition, the proportional heaters are partially kept on to compensate

the heat losses. The amount is estimated as 167 KW. As shown in Fig. 15,

the pressurizer heater is simulated as heat slab and shut off at the

time of loss of offsite power. The heat loss through wall ia simulated

as boundary condition of the wall heat slab and remains constant during

the whole transient. As in Fig. 16 the pressure increase due to the

insurge flow is much higher than the plant data, although the improved

22
result was obtained compared with the base case. It is believed that the

interface heat transfer in horizontal stratified flow regime may be

estimated low, and thus the compression effect may be high.

23
( CASE 1 ) ( CASE 2 )

( CASE 3 ) ( CASE 4 )

Fig.11 S/G Nodalization for Sensitivity Study

24
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

0.5

0.4

0.3

(Il

-J

0.2

0.1

0

0 40 80 120 160 200 240 280

Time ( seconds )

Fig.12 S/G Narrow Range Water Level ( case 2, case3, case4 )
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

U,

-J

U,

0)

C

a

0

L

L.

0

z

N

C/)

0.7

0.6

0.5

0.4

0.3

0.2

0.1

0

0 40 80 120 160 200 240 280

Time ( seconds )

Fig.13 S/G Narrow Range Water Level versus Time ( case2 )
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

"-J

a.

L- C

a7

6.9

6.8

6.7

6.6

6.5

6.4

6.3

6.2

6.1

6

5.9

5.8

0 40 80 120 160 200

Time ( seconds )

Fig.14 S/G Pressure versus Time ( case2 )

240 280
SRV SRV

INSULATION

BOUNDARY

HEAT LOSS

BOUNDARY

PROPORTIONAL

HEATER Z

PZR MODEL WITHOUT HEATERS PZR MODEL WITH HEATERS

Fig.-15 Pressurizer Model with Heat Loss
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

(0

00

a-

..

U)

(L

15.6

15.5

15.4

15.3

15.2

15.1

15

14.9

14.8

14.7

14.6

14.5

0 40 80 120 160 200 240

Time ( seconds )

Fig.16 PZR Pressure versus Time with Heat Loss through Wall

280
7. Run Statistics

In order to compare the run times with other organization it should

be mentioned that the computer type used is CDC CYBER 170-875 which has

one unified extended memory unit. and the operating system is the NOS

2.6.1 level 700. As shown in Fig. 17 the time step size is mainly

governed by the minimum Courant limit time. The Courant limit time

increases due to the flow coastdown after the trip of reactor coolant

pumps. The requested maximum time step size is 1.0 second. Thus the

time step varies between the maximum time step and the Courant limit.

The total CPU time Is shown in Fig. 18. In the figure it runs faster

than the real time after the coastdown of flow. It is due to the

increase of Courant time limit resulting in an increase of time step

size as shown in Fig..17.

The total CPU time required for simulation of the whole transient 300

seconds is 455.276 seconds and the total number of time steps is 3095.

The input processing time is 7.87 second and the number of volumes is

118. Thus the grind time is 1.22 mili-second ; the grind time = (total

CPU time - Input processing time)/(Number of time step X Nunmer of

Volume) = (455.276-7.87)/(3095 X 118) = 0.00122.

30
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

0

U)

V)

0.

E

1.5

1.4

1.3

1.2

1..1

1

0.9

0.8

0.7

0.6

0.5

0.4

0.3

0.2

0.1

0

0 40 80 120 160 200 240 280

Real 'ime ( seconds )

Fig.17 Time Step Size and Courant Time Limit versus Real Time
KNU #1 Loss of Offsite Power Transient

RELAP5/MOD2/CY36.05 Simulation

500

400

CA)

0)

C

0

0

E

F0.

300

,o00

100

0

0 200 400

Real 'ime ( seconds )

Fig.18 Total required CPU Time versus-Real Time
8. Conclusion

An analysis of KNU #1 Loss of Offslte Power transient was carried out

using the RELAP5/MOD2. It was found that the code gives stable

steady-state results and accurate predictions for most of the plant

behavior associated with the transient, indicating the excellent

capability of the code for this type of transients. The

establishment of stable natural circulation due to the hot-cold leg

temperature difference after both reactor trips is confirmed.

In particular, the calculated primary thermal behavior closely

follows the plant data and this validates that the relevant

thermal-hydraulic and decay power model in the RELAP5/MOD2

correctly describes the actual phenomena.

In the nodalization sensitivity study it was found that S/G noding

with junctions between bypass plenum and steam dome is preferred. This

nodalization allowed the simulation of the S/G water level decrease and

avoided the spurious level peak at turbine trip.

The pressurizer pressure increase is sensitive to the insurge flow.

It is believed that the interfacial heat transfer in a horizontal

stratified flow regime may be estimated low and that the compression

effect due to insurge flow may be high.

33
9. Reference

1. "Final Safety Analysis Report, Kori Nuclear Power Plant Unit No.1",

Korea Electric Company.

2. Computed Daily Log Sheet of KNU1, on June 9, 1981.

3. Computed Post Trip Review Sheet of KNU1, 11:00 on June 9, 1981.

4. Computer Sequence of Events Record of KNU1, 11:00 on June 9, 1981.

5. Ransom, V.H., et al., "RELAP5/MOD2 Code Manual ; Volume 2 ",

NUREG/CR-4312, EGG-2396, December 1985.

34
Appendix

The input file for steady/transient run of KNU #1 Loss of Offsite

Power Transient is given. The geometric data and performance data was

prepared in cooperation with the utility company ( KEPCO ) of KNU #1

Plant. The input file is the CASE2 input which contains the

specific steam generator nodalization as discussed Th section 6. The

job control card at the top of input file is for KAERI computer system

(CDC CYBER-170, NOS operating system).

35
/JOB

BRUN,T777.

/USER

ATTACH,REL36KX.

ATTACH,STH2XT.

RFL,CM=350000,EC=200.

REDUCE(-)

FILE,RSTPLT,SBF=NO.

FILE,RSTIN,SBF= NO.

DEFINE,PLOTFL=BBASEP2.

REL36KX(,*PL=90000)

SKIP,JOB4.

EXIT.

ENDIF,JOB4.

DAYFILE,DAYLEE.

REPLACE,DAYLEE.

/EOR

=KORI UNIT 1 STATION BLACK-OUT AT 77.5% POWER TRANSIENT

(14/NOV/1981)

*------------------------------------------------------------------*

* FILENAME IS "BBASE2" (1985.DEC.10) - BASE CAL. BY LEE

* ORIGINAL LOSS COEFF. BUT MODIFICATION OF PUMP DATA

* ATTACH PZR PRESSURE, & CORE KINETIS DATA

* S/G NODALIZATION STUDY 2 (CASE 2)

----------------------------------------------------------------- 7-*

* STANDALONE REACTOR *

*------------------------------------------------------------------*

------------------------------------------------------------------- *

* ----------------------------------------------------------------

* MISCELANOUS CONTROL CARDS ----------------------------------------------------------------------

100

101

102

104

105

PROBLEM TYPE OPSTDY-ST/TRANSNT

NEW TRANSNT

INP-CHK/RUN

RUN

INP-UNIT OUT-UNIT OUTPUT-UNIT

BRITISH BRITISH

NOACTION

TIME 1 TIME 2

1.0 2.0

*------------------------------------------- ---------------------------

* TIME STEP CONTROL CARDS

-----------------------------------------------------------------------

* EDND.T MIN.DT MAX.DT CNTL MINOR.ED MAJOR.ED RESTRT

201 300.0 1.E-7 1.00 14003 1 050 4000

*202 800.0 1.E-7 .1.00 2 1 1 100 4000

*------------------------- 7 -------- 7-------------------- -----------------

* MINOR EDIT REQUEST.*

0----------------------------------------------------------------

301 P 301010000

36
302

303

304

305

306

307

308

309

310

311

312

313

314

315

316

317

318

319

320

321

322

323

324

325

326

327

328

329

330

331

332

333

334

335

336

337

338

339

340

341

342

343

TEMPF

P

TEMPF

P

TEMPF

P

TEMPF

P

TEMPF

P

TEMPF

TEMPF

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

301010000

356010000

356010000

335010000

335010000

335020000

335020000

335030000

335030000

620010000

220010000

201010000

300010000

300020000

325010000

325020000

355030000

345010000

355020000

220020000

120020000

621000000

RKTPOW

RKFIPOW

RKGAPOW

RKREAC

CNTRLVAR,051

CNTRLVAR,052

CNTRLVAR,057

CNTRLVAR,058

CNTRLVAR,061

CNTRLVAR,062

CNTRLVAR,067

CNTRLVAR,068

CNTRLVAR,060

CNTRLVAR,070

CNTRLVAR,122

CNTRLVAR,300

CNTRLVAR,401

CNTRLVAR,402

CNTRLVAR,403

CNTRLVAR,404

0

0

0

0

*------------------------------------------------------------

* TRIP DATA ------------------------------------------ w----------------

501

502

503

504

*588

TIME 0 GE NULL

TIME 0 GE NULL

TIME 0 GE NULL

TIME 0 GE NULL

CNTRLVAR 057 LE

0 9999.0 L * CPU LIMIT

0 0.0 L * INITIALIZATION

0 50.00 L * ACCIDENT.ACTUATION

0 9999.0 L * MSIV CLOSURE

NULL 0 0.25 L * RX/TBN TRIP

37
* REPLACE RX TRIP B

588 TIME,O GE

589 CNTRLVAR 05

590 CNTRLVAR 10

592 TIME 0 GE

601 588 AND

594 TIME 0 GE

595 TIME 0 GE

IY TIME 89.2.18

NULL,O 100.00 L * RX/TBN TRIP

7 LE NULL 0 0.11 L *S/G L-L (AUX. FEED)

)1 LE NULL 0 554. L *MAIN FEED ISOLATION

TIMEOF 589 9999.0 L *STEAM DUMP

503 L

TIMEOF 601 35. L * BROKEN LOOP P1

TIMEOF 601 63. L * INTACT LOOP P1

UMP TRIP

UMP TRIP

*=== CORE COMPONENTS ===

* ---------------------------------------------------------------

* HYDRODYNAMIC COMPONENT

*--------------------------------------------------------------------

* COMPONENT 300: REACTOR UPPER DOWNCOMER BRANCH

* ------------------------------------------------------

*

3000000

3000001

3000101

3000200

3001101

3002101

3001201

3002201

RX-U-DO BRANCH

2 1

21.559 1.965 0. 0. -90. -1.965 0. 1.347

3 2299.7 542.71

300000000 308000000 21.559 0.4 0.4 001

300010000 301000000 21.559 0.3 0.3 001

63.597 0.0 0.0

20611.0 0.0 0.0

00

O0

O0

-----------------------------------------------------------

* COMPONENT 301: REACTOR MID DOWNCOMER BRANCH

-----------------------------------------------------------

3010000 RX-M-DO BRANCH

3010001 1 1

3010101 18.6475 2.0 0. 0. -90. -2. 0. 0.591 00

3010200 3 2298.9 542.71

3011101 301010000 315000000 18.6475 0.3 0.3 0000

3011201 20611.0 0.0 0.0

------------------------------------------------------

*COMPONENT 315: REACTOR LOWER DOWNCOMER ANNULUS

*

*

3150000

3150001

3150101

3150201

3150301

3150302

3150303

3150601

3150701

3150702

3150703

3150801

3150901

3151001

RX-L-DO

5

17.934

17.934

1.08

4.0

3.239

-90.0

-1.08

-4.0

-3.239

0.0 0.568

0.3 0.3

00

PIPE

1

4

5

4

5

4

5

1

4

5

5

5

38
3151101

3151201

3151202

3151203

3151204

3151205

3151300

3151301

0000

3

3

3

3

3

1

2298.3

2298.1

2298.A

2298.(

2298.E

4

542.71

542.71

542.71

542.71

542.71

0.0 " 0.0

0.

0.

0.

0.

0.

0.

0.

0.

0.

0.

0.

0.

0.

0.

0.

1

2

3

4

5

20611.0 4 -----------------------------------------------------------

*COMPONENT 322: REACTOR MID LOWER PLENUM --------------------------------------------------------------------

*

3220000

3220001

3220101

3220200

3221101

3222101

3223101

3221201

3222201

3223201

RX-M-LP

3

BRANCH

1

79.639 2.8 0. 0. -90. -2.8 0. 0.

3 2297.8 542.71

315010000 322000000 17.934 1.3

322000000 325000000 46.684 3.2

322010000 321000000 31.118 0.0

20611.0 0.0 0.0

20611.0 0.0 0.0

0.0 0.0 0.0

00

2

00

1.32 0100

3.200 0100

0.0 0000

* COMPONENT 321: REACTOR BOTTOM LOWER PLENUM

-----------------------------------------------------------

*

3210000

3210101

3210200

RX-B-LP SNGLVOL

31.118 2.283 0. 0. -90. -2.283

3 2298.7 542.55

0. 1.219 00

* COMPONENT 325: REACTOR TOP LOWER PLENUM --------------------------------------------------------------------

*

3250000

3250001

3250101

3250200

3251101

3252101

3251201

3252201

RX-T-LP

2

BRANCH

1

46.684 3.239 0. 0.

3 2295.0 542.70

325010000 335000000

325010000 320000000

19995.0 0.0

616.65 0.0

90. 3.239 0. 1.753 00

26.938 4.1 5.4 0100

0.834 7.0970 7.0970 0100

0.0

0.0

X...........................................................................

* COMPONENT 335: ACTIVE CORE *

X ---------------------------------------------------- x

3350000

3350001

3350101

3350301

3350401

3350601

3350701

3350801

3350901

CORE

3

0.0

PIPE

4.0

108.092

90.0

4.0

5.E-5

2.0 2.0

3

3

3

3

3

0.0402 3.

2

39
3351001

3351101

3351201

3351202

3351203

3351300

3351301

3351302

00

0000

3

3

3

1

2286.2

2276.5

2272.7

559.49

575.63

591.04

3

2

0

0

0

0

0

0

0.

0.

0.

1

2

3

19995.0

19995.0

0.0 0.0 1

0.0 0.0 2

-----------------------------------------------------------

*COMPONENT 340: CORE TOP --------------------------------------------------------------------

*

3400000

3400001

3400101

3400200

3401101

3402101

3401201

3402201

CORE-TOP BRANCH

2 1

36.582 1.08 0. 0. 90.

3 2263.4 590.95

335010000 340000000 2

340010000 344000000 3

19995.0 0.0

19995.0 0.0

1.08 0. 0.0402 00

6.938

6.582

0.0

0.0

5.4

1.0

4.6 0100

1.0 0100

-----------------------------------------------

* COMPONENT 320: CORE BYPASS *

m ------------------------------------------------------

3200000

3200001

3200101

3200201

3200301

3200302

3200601

3200701

3200702

3200801

3200901

3201001

3201101

3201201

3201202

3201203

3201204

3201300

3201301

CORE-BY1

4

11. 9274

0.834

4.0

1.08

90.0

4.0

1.08

0.0

7.0970

00

0000

3 24

3 2,

3 2

3 2

PIPE

4

3

3

4

4

3

4

0.124

7.0970

4

3

4

3

~91.7

~83.0

274.2

?65.8

545.48

550.41

556.96

558.59

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

*0.0

0.0

0.0

0.0

1

2

3

4

1

616.65 0.0 0.0 3

* COMPONENT 344: BOTTOM UPPER PLENUM ---------------------------------------------------------------------------

*

3440000

3440001

3440101

3440200

3441101

3442101

RX-B-UP

3

BRANCH

1

49.7375 2.0 0. 0. 90. 2. 0. 0.7626

3 2262.3 589.97

320010000 344000000 0.834 7.0970

344010000 345000000 49.7345 0.0

00

7.0970 0100

0.0 0000

40
3443101

3441201

3442201

3443201

337010000

616.65

20675.0

63.574

344000000 1.267

0.0 0.0

0.0 0.0

0.0 0.0

0.86 0.86 0100

* COMPONENT 345: MID UPPER PLENUM ------------------------------------------------------

*

3450000

3450001

3450101

3450200

3451101

3452101

3453101

3451201

3452201

IAKionl

RX-M-UP

3 1

'BRANCH

54.657 1.965 0. 0. 90. 1.965

3 2261.8 589.97

345010000 310000000 54.657

345010000 101000000 4.587

345010000 201000000 4.587 (

0.0 .0,0 0.0

10334.0 0.0 0.0

1AnAlq n A Annn

0. 0.838 00

).0

).05 0.05

0.0

0.05

0.05

0000

0100

0100

---------------------------------------------------------------

* COMPONENT 310: REACTOR TOP UPPER PLENUM

---------------------------------------------------------------

3100000 RX-T-UP SNGLVOL

3100101 54.659 5.804 0. 0. 90. 5.804 0. 0.836 00

3100200 3 2260.9 575.19

* ------------------------------------------------------

*COMPONENT 308: REACTOR TOP DOWNOOMER ---------------------------------------------------------------------------

*

*

3080000

3080101

3080200

RX-T-DO SNGLVOL

26.004 6.146 0. 0. 90. 6.146 0. 1.625

3 2300.4 543.70

00

* COMPONENT 355: REACTOR UPPER HEAD *

X---------------------------------------------------------------

3550000

3550001

3550101

3550200

3551101

3552101

3553101

3551201

3552201

3553201

RX-U-HD

3 1

BRANCH

69.927 2.476 0.0 0.0 90.0

3 2259.4 543.89

308010000 355000000 0.0247

356010000 355010000 40.016

355010000 337000000 1.267

63.563 0.0 0.0

0.0 0.0 0.0

63.563 0.0 0.0

2.476 0.0 2.309 00

11.0

0.0

0.86

11.0

0.0

0.86

0100

0000

0100

* COMPONENT 337:REACTOR GUIDE TUBES

---------------------------------------------------------------

3370000 GID-TUB SNGLVOL

3370101 1.267 12.587 0. 0. -90. -12.587 0. 0.221

3370200 3 2261.0 545.90

* ------------------------------------------------------

* COMPONENT 356: REACTOR UPPER HEAD DOME

*

00

*

41
3560000 RX-UH-D SNGLVOL

3560101 40.016 2.804 0. 0. -90. -2.804 0. 7.1379 00

3560200 3 2258.5 588.09

---------------------------------------------------------------------

*HEAT STRUCTURE INPUT

---------------------------------------------------------------------

*--------------------------------------------------- -------

* HEAT STRUCTURE 301: REACTOR VESSEL WALL (DOWNCOMER) *

-----------------------------------------------------------

13010000 8 3 2 1 5.5

13010100 0 1

13010101 1 5.513

13010102 1 6.052

13010201 5 1

13010202 6 2

13010301 0.0 2

13010401 541.2 3

13010501 308010000 0 1 1 6.146 1

13010502 300010000 0 1 1 1.965 2

13010503 301010000 0 1 1 2.0 3

13010504 315010000 0 1 1 1.08 4

13010505 315020000 0 1 1 4.0 5

13010506 315030000 0 1 1 4.0 6

13010507 315040000 0 1 1 4.0 7

13010508 315050000 0 1 1 3.239 8

13010601 0 0 0 1 6.146 1

13010602 0 0 0 1 1.965 2

13010603 0 0 0 1 2.0 3

13010604 0 0 0 1 1.08 4

13010605 0 0 0 1 4.0 7

13010606 0 0 0 1 3.239 8

13010701 0 0.0 0.0 0.0 8

13010801 0 1.62 3.010 6.146 1

13010802 0 1.347 2.495 1.965 2

13010803 0 0.591 2.158 2.0 3

13010804 0 0.568 2.0758 1.08 4

13010805 0 0.568 2.0758 4.0 7

13010806 0 0.568 2.0758 3.239 8 -----------------------------------------------------------

* HEAT STRUCTURE 300: CORE BARREL *

-----------------------------------------------------------

13000000 8 2 2 1 4.5417

13000100 0 1

13000101 1 4.6875

13000201 5 1

13000301 0.0 1

13000401 541.26 2

13000501 310010000 0 1 1 6.146 1

13000502 345010000 0 1 1 1.965 2

42
13000503

13000504

13000505

13000506

13000507

13000508

13000601

13000602

13000603

13000604

13000605

13000606

13000607

13000608

13000701

13000801

13000802

13000803

13000804

13000805

13000806

13000901

13000902

13000903

13000904

13000905

13000906

344010000 0 1 1

-320040000 0 1 .1

320030000 0 1 1

320020000 0 1 1

320010000 0 1 1

325010000 0 1 1

308010000 0 1 1

300010000 0 1 1

301010000 0 1 1

315010000 0 1 1

315020000 0 1 1

315030000 0 1 1

315040000 0 1 1

315050000 0 1 1

0 0.0 0.0 0.0

0 0.836 7.662

0 0.838 7.661

0 0.763 6.971

0 0.028 0.321

0 0.028 0.321

0 1.753 6.544

0 1.62 3.532

0 1.347 2.928

0 0.591 2.533

0 0.568 2.436

0 0.568 2.436

0 0.568 2.436

2.0

1.08

4.0

4.0

4.0

3.239

6.146

1.965

2.0

1 .08

4.0

4.0

4.0

3.239

6.146

1.965

2.0

1.08

4.0

3.239

6.146

1.965

2.0

1.08

4.0

3.239

3

4

5

6

7

8

1

2

3

4

5

6

7

8

8

1

2

3

4

7

8

1

2

3

4

7.

8

* HEAT STRUCTURE 320: BYPASS (CORE BAFFLE AND GUIDE THIMBLES) *

X---------------------------------------------------------------

13200000

13200100

132001.01

13200201

13200301

13200401

13200501

13200502

13200503

13200504

13200601

13200602

13200603

13200604

13200701

13200801

13200802

13200803

13200804

13200901

42 2

0

1

5

0.0.

550.0

335010000

335020000

335030000

340010000

320010000

320020000

320030000

320040000

0 0.0

0 0.040

0 0.040

0 0.040

0 0.040

0 0.123

1 0.0910846

1

1.92

01 0

01 0

01 0

01 0

0 10

0 10

01 0

01 0

0.0 0.0

0.376,

0.376

0.376

0.376

0.157

2

1214.96

1214.96

1214.96

328.039

1283.86

1283.86

1283.86

346. 642

4.0

4.0

4.0

1.08

4.0

1

2

3

4

1

2

3

4

4

1

2

4

1

43
13200902

13200903

13200904

0

0

0

0.123

0.123

0.123

0.157

0.157

0.157

4.0

4.0

1.08

2

3

4

HEAT STRUCTURE 333: ACTIVE CORE *

13330000

13330100

13330101

13330102

13330103

13330201

13330202

13330203

13330301

13330302

13330303

13330304

13330401

13330402

13330403

13330404

13330405

13330406

13330501

13330601

13330602

13330603

13330701

13330702

13330703

13330901

3 8

0 1

3

1

3

1

2

3

0.955

1.085

1.275

0.0

2361.0

2159.0

1607.0

874.0

730.0

651.0

0 0

2 1 0.0

0.015246

0.015558

0.017583

3

4

7

1

2

3

7

1

2

3

4

5

8

0 0 0.0

335010000 0 1

335020000 0 1

335030000 0 1

1000 0.33333

1000 0.33334

1000 0.33333

0

0

0

9571.488

9571. 488

9571. 488

0.0 0.0

0.0 0.0

0.0 0.0

3

1

2

3

1

2

3

0 0.0402 0.04503 4.0 3

HEAT STRUCTURE 356: UPPER HEAD DOME

-----------------------------------------------------------

13560000 1 3 3 1 5.526

13560100 0 1

13560101 2 5.97396

13560201 5 1

13560202 6 2

13560301 0.0 2

13560401 590.0 3

13560501 356010000 0 1 1 0.27 1

13560601 0 0 0 1 0.27 1

13560701 0 0.0 0.0 0.0 1

13560801 0 7.1379 7.1379 2.804 1

------------------------------------------------------

*HEAT STRUCTURE 355: UPPER HEAD

-----------------------------------------------------------

*

*

13550000 1 3 2 1 5.00833

44
13550100

13550101

13550201

13550202

13550301

13550401

13550501

13550601

13550701

13550801

0 1

2

5

6

0.0

590.0

355010000 0 1 1

0 0 0 1

0 0.0 0.0 0.0

0 2.3089 10.454

5.5510

1

2

2

3

2.476

2.476

2.476

1

1

1

1

* HEAT STRUCTURE 310: UPPER CORE SUPPORT PLATE *1

13100000 1 2 1 1 0.0

13100100 0 1

13100101 1 0.3417

13100201 5 1

13100301 0.0 1

13100401 600.0 2

13100501 310010000 0 1 0 56.397 1

13100601 355010000 0 1 0 56.397 1

13100701 0 0.0 0.0 0.0 1

13100801 0 2.3089 2.8795 7.51 1

13100901 0 0.836 2.251 7.51 1

* ------------------------------------------------------

*HEAT STRUCTURE 337: GUIDE TUBES WALL -----------------------------------------------------------

*

13370000

13370100

13370101

13370201

13370301

13370401

13370501

13370502

13370503

13370504

13370601

13370602

13370603

13370604

13370701

13370801

13370802

13370803

13370804

13370901

13370902

13370903

13370904

4 2 2

0 1

1

5

0.0

590.0

337010000

337010000

337010000

337010000

355010000

310010000

345010000

344010000

0 0.0

0 0.2211

0 0.2211

0 0.2211

0 0.2211

0 2.3089

0 0.836

0 0.83806

0 0.7626

1 0.11055

0

0

0

0

0

0

0

0

0.0

1

1

1

1

1

1

1

1

0

0

0

0

0

0

0

0

0.0

0.3119437

1

1

2

64.594

133.039

45.042

45.844

182.268

375.402

127.097

129.36

2.818

5.804

1.965

2.0

2.818

5.804

1.965

2.0

1

2

3

4

1

2

3

4

4

1

2

3

4

1

2

3

4

0.2211

0.2211

0.2211

0.2211

4.3245

3.3803

3.3801

3.0757

45
* HEAT STRUCTURE 321: BOTTOM LOWER PLENUM

* (VESSEL WALL AND INTERNAL)

*-------------------------------------------------------- --

13210000 1 3 3 1 5.526

13210100 0 1

13210101 2 5.86979

13210201 5 1

13210202 6 2

13210301 0.0 2

13210401 543.667 3

13210501 321010000 0 1 1 0.265 1

13210601 0 0 0 1 0.265 1

13210701 0 0.0 0.0 0.0 1

13210801 0 1.219 1.219 2.283 1 ------------------------------------------------------

* HEAT STRUCTURE 322: TOP LOWER PLENUM

* ( VESSEL WALL AND INTERNAL ) --------------------------------------------------------------------

*

*

*

*

13220000

13220100

13220101

13220201

13220202

13220301

13220401

13220501

13220601

13220701

13220801

1

0

2

5

6

3 3 1 5.526

1

0.0

543.667

322010000

0

0 0.0

0 2.7!

5.86979

1

2

2

3

0.317

0.317

0.0

2.80

0 1

0 0

0.0

95 2.795

1

1

1

1

1

1

------------------------------------------------------------------- *

------------------------------------------- ;--------- ---------------- *

* STANDALONE STEAM GENERATOR (BROKEN LOOP-A) *

--------------------------------------------------------- ---------- *

------------------------------------------------------------------- *

* -----------------------------------------------------------------

* MINOR EDIT REQUEST ------------------------------------------------------------------------------ ----

351

352

353

354

355

356

357

358

359

360

361

362

P

P

P

P

P

P

P

P

TEMPF

TEMPF

MFLOWJ

MFLOWJ

170010000

170050000

171010000

172010000

174010000

185010000

285010000

700010000

120010000

220010000

191000000

291000000

46
363 MFLOWJ 185010000

364 MFLOWJ 285010000

365 MFLOWJ 701000000

366 MFLOWJ 703000000

367 MFLOWJ 102030000

368 MFLOWJ 171010000

369 MFLOWJ 171020000

370 MFLOWJ 171030000

371 MFLOWJ 174010000

372 MFLOWJ 174020000

373 MFLOWJ 178000000

374 MFLOWJ 170020000

375 VOIDG 170010000

376 VOIDG 171010000

377 VOIDG 172010000

378 MFLOWJ 184000000

379 MFLOWJ 271010000

380 MFLOWJ 271020000

381 MFLOWJ 271030000

382 MFLOWJ 274010000

383 MFLOWJ 274020000

384 MFLOWJ 278000000

385 MFLOWJ 270020000

386 VOIDG 270010000

387 VOIDG 271010000

388 VOIDG 272010000

389 MFLOWJ 284000000

393 CNTRLVAR 121

394 CNTRLVAR 101

395 CNTRLVAR 102

396 MFLOWJ 182000000.

397 MFLOWJ 282000000

398 MFLOWJ 186000000

399 MFLOWJ 286000000 --------------------------------------------------------------------

* HYDRODYNAMIC COMPONENT

*-------------------------------------------------------------------------

-----------------------------------------------------------

* COMPONENT 105: BROKEN LOOP STEAM GENERATOR INLET PLENUM *

-----------------------------------------------------------

1050000 B-SG-IP SNGLVOL

1050101 24.0015 6.7417 0.0 0. 90. 1.704 0. 0.000 00

1050200 3 2239.9 589.85

-----------------------------------------------------------

* COMPONENT 106: BROKEN LOOP STEAM GENERATOR INLET PLENUM *

* TO PRIMARY TUBE JUNCTION *

-----------------------------------------------------------

1060000 B-IP-TUB SNGLJUN Vi. N

1060101 105010000 108000000 11.0988 0.69 0.69. 0100

1060201 1 10334.0 0.0 0.0

47
* COMPONENT 108: BROKEN LOOP STEAM GENERATOR TUBES

----------------------------------------------------------

1080000

1080001

1080101

1080201

1080301

1080302

1080303

1080401

1080601

1080602

1080603

1080604

1080701

1080702

1080703

1080704

1080801

1080901

1081001

1081101

1081102

1081103

1081201

1081202

1081203

1081204

1081205

1081206

1081207

1081208

1081300

1081301

B-SG-TUB

8

PIPE

11.0988

11.0988

9.91

3.449

9.91

0.0

90.0

40.0

-40.0

-90.0

9.91

2.196

-2.196

-9.91

0.0 0

0.0 0

00

0000

0000

0000

3 22:

3 22:

3 22

3 22

3 22

3 22

3 22

3 22'

1

10334.0

8

7

3

5

8

8

3

4

5

8

3

4

5

8

8

7

8

3

4

7

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

.0646

.0

32.4

25.5

18.7

14.3

13.0

12.5

12.1

11.7

576.83

567.20

559.91

557.48

555.25

550.29

545.96

542.22

0.0

0.0

0.0

0.0

0.0.

0.0

0.0

0.0

0.

0.

0.

0.

0.

0.

0.

0.

1

2

3

4

5

6

7

8

0.0 0.0 7

* COMPONENT 109: BROKEN LOOP STEAM

TO PRIMARY OUTLET

GENERATOR PRIMARY TUBES

PLENUM

*

*

X---------------------------------------------------------------

1090000

1090101

1090201

B-TU-OP SNGLJUN

108010000 110000000 11.0988.

1 10334.0 0.0 0.0

0.69 0.69 0100

I----------------------------------------------------------------------------

* COMPONENT 110: BROKEN LOOP STEAM GENERATOR OUTLET PLENUM *

A ------------------------------------------------------

1100000

1100101

1100200

B-SG-OP SNGLVOL

24.0015 6.7417

3 2211.4

0.0 0. -90. -1.704 0. 0. 00

542.22

w --------- T--- BOE-OO-TAMGNR------ATOR-OUTLET-PL--------- rCOMPONENT ill: BROKEN LOOP STEAM GENERATOR OUTLET PLENUM :*

48
TO PUMP SUCTION LEG

1110000 B-SG-O-P SNGLJUN

1110101 110010000 112000000 5.2414 0.000 0.000 0100

1110201 1 10334.0 0.0 0.0 -----------------------------------------------------------

COMPONENT 174: BROKEN LOOP STEAM GENERATOR MID DOWNCOMER

-----------------------------------------------------------

1740000 BSG-M-DO BRANCH

1740001 2

1740101 60.3 6.752 0. 0. -90. -6.752 2.42189E-5 0. 00

1740200 3 857.37 501.730

1741101 172000000 174000000 60.3 1.0 1.0 0000

1742101 174010000 176000000 19.352 0.1 0.1 0000

1741201 1.7223 -4.2282 0.0

1742201 3.6356 3.6356 0.0 ------------------------------------------------------

COMPONENT 176: BROKEN LOOP STEAM GENERATOR BOTTOM DOWNCOMER

-----------------------------------------------------------

1760000 BSG-B-DO PIPE

1760001 4

1760101 19.352 1

1760102 7.0965 4

1760201 7.0965 3

1760301 2.196 1

1760302 9.91 4

1760401 0.0 4

1760601 -90.0 4

1760701 -2.196 1

1760702 -9.91 4

1760801 5.E-5 0.0 4

1760901 0.1 0.1 3

1761001 00 4

1761101 0000 3

1761201 3 858.84 501.740 0 0 0 1

1761202 3 860.39 501.740 0 0 0 2

1761203 3 863.68 501.760 0 0 0 3

1761204 3 866.98 501.770 0 0 0 4

1761301 9.9140 9.9140 0.0 1

1761302 9.9139 9.9139 0.0 2

1761303 9.9139 9.9139 0.0 3

*-----------------------------------------------------------

*'COMPONENT 178: BROKEN LOOP STEAM GENERATOR BOTTOM DOWNCOMER

* TO RISER JUNCTION *

-----------------------------------------------------------

1780000 BSG-D-RI SNGLJUN

1780101 176010000 170000000 2.8700 1.000 1.000 0100

1780201 0 9.9146 11.069 0.0 ------------------------------------------------------

* COMPONENT 170: BROKEN LOOP STEAM GENERATOR EVAPORATOR RISER *

49
1700000 B-SG-RIS PIPE

1700001 5

1700101 54.893 3

1700102 47.164 4

1700103 77.79 5

1700201 54.893 2

1700202 47.164 4

1700301 9.91 3

1700302 2.196 4

1700303 6.752 5

1700401 0.0 5

1700601 90.0 5

1700801 5.E-5 0.0 5

1700901 2.5 2.5 3

1700902 1.0 1.0 4

1701001 00 5

1701101 0000 .4

1701201 0 860.41 512.17 1115.8 0.32765 0.0 1

1701202 0 858.74 516.09 1114.6 0.72765 0.0 2

1701203 0 857.84 516.37 1114.2 0.83908 0.0 3

1701204 0 857.26 516.30 1114.1 0.84332 0.0 4

1701205 0 856.94 516.25 1114.0 0.83804 0.0 5

1701301 1.8407 6.0283 0.0 1

1701302 4.1842 6.1268 0.0 2

1701303 7.5892 9.3246 0.0 3

1701304 7.5386 10.473 0.0 4

*---------------------------------------------------------

*COMPONENT 171: BROKEN LOOP STEAM GENERATOR SEPERATOFR -------------------------------------------------------------------

1710000 B-SG-SEP SEPARATR

1710001 3

1710101 97.070 6.937 0. 0. 90. 6.937 0.0 4.667 01

1710200 0 855.70 516.05 1113.9 .500

1711101 171010000 180000000 63.8 0.86410.864 1020

1712101 171000000 172000000 30.000 0.0 0.0 1000

1713101 170010000 171000000 77.790 21.0 21.0 1000

1711201 6.7470 6.7470 0.0

1712201 1.9472 7.5366 0.0

1713201 4.5731 6.6075 0.0

-----------------------------------------------------------

* COMPONENT 172: BROKEN LOOP STEAM GENERATOR TOP DOWNCOMER

-----------------------------------------------------------

1720000 BSG-T-DO SNGLVOL

1720101 88.87 6.937 0. 0. 90. 6.937 0. 4.014 01

1720200 0 855.70 516.05 1113.9 .500 -----------------------------------------------------------

* COMPONENT 180: BROKEN LOOP STEAM GENERATOR STEAM DOME

----------------------------- --------------------------

1800000 B-SG-DOt4 PIPE

0.00

0.00

*€

50
1800001

1800101

1800301

1800401

1800601

1800701

1800801

1801001

1801201

1

63.80000

7.2095

0.0

90.0

7.2095

0.0

00

2 855

1

1

1

1

1

1

1

0.0 0.0 0,0

0.0

.10 1.0000 1 ;9 ------------------------------------------------------

1870000

1870001

1870101

1870200

1871101

1872101

1871201

1872201

1880000

1880001

1880101

1880200

1881101

1881201

B-SG-DOM BRANCH

2 1

50.0 7.2095 0. 0.

2 855.10 1.0

172010000 187000000

187000000 180000000

0.0 0.0 0.0

0.0 0.0 0.0

90. 7.2095 0. 0. 00

50.0 0.

204.0 0.

0.

0.

0000

0003

B-SG-DOM BRANCH

63.8 7.2095 0. 0. 90.

2 855.00 1.0

180010000 188000000 63.8

0.0 786.65 0.0

7.2095 0. 0.

0.0 0.0 0000

00

COMPONENT 185: STEAM LINE

-----------------------------------------------------------

1850000 B-SG-SL BRANCH

1850001 1 1

1850101 5.585 137.0 0. 0. 0. 0. 0. 2.667 00

1850200 2 853.64 1.0000

1851101 188010000 185000000 5.585 0.0 0.0 0000

1851201 0.0000 786.65 0.0

------------------------------------------ :-----------------

COMPONENT 186: MAIN STEAM ISOLATION VALVE

-----------------------------------------------------------

1860000 B-MSIV VALVE

1860101 185010000 700000000 5.585 0.0 0.0 0100

1860201 1 0.0 786.65 0.0

1860300 MTRVLV

1860301 501 504 0.2 '1.0 0.0

------------------------ ---------------------------

*COMPONENT 191: PORV

-----------------------------------------------------------

*

*

*

1910000

1910101

1910200

1910201

1910202

B-PORV TMDPJUN

185000000 192000000

1 503 P 185010000

0.0 0.0 0.0

1019.0 0.0 0.0

1.0

0.0

0.0

51
1910203 1021.0 0.0 109.7 0.0 *

1920000 B-PORV TMDPVOL

1920101 1.0 0.0 100.0 0.0

1920200 3

1920201 0.0 14.7 100.0

0.0 0.0 0.0 0.0 00

*-------------------------------------------------------------*

* COMPONENT 193 SAFETY VALVES --------------------------------------------------------

1930000 B-SRV TMDPJUN

1930101 185000000 194000000

1930200

1930201

1930202

1930203

1930204

1930205

1930206

1930207

1930208

1930209

1930210

1930211

1 0

0.0

1089.0

1091.0

1102.0

1104.0

1116.0

1118.0

1129.0

1131.0

1143.0

1145.0

P 185010000

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

219.4

219.4

443.0

443.0

670.8

670.8

901.3

901.3

1134.7

1.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

1940000 B-SRV TMDPVOL

1940101

1940200

1940201

1.0 0.0 100.0 0.0

3

0.0 14.7 100.0

0.0 0.0 0.0 0.0 00

X ------------------------------------------------------

* COMPONENT 183: BROKEN LOOP MAIN FEEDWATER SOURCE VOLUME *

*-----------------------------------------------------------

1830000 B-MFW TMDPVOL

1830101 10.0 0.0 100.0 0. 0. 0. 0. 0. 00

1830200 3

1830201 0.0 500.0 413.0

--------------------------------------------------

*COMPONENT 184: BROKEN LOOP MAIN FEEDWATER JUNCTION *---------------------------------------------------------------------------

*

1840000

1840101

1840200

1840201

1840202

1840203

1840204

1840205

1840206

B-MFW-J

183000000

TMDPJUN

174000000

1 503

-1.0

0.000

10.0

20.0

30.0

40.0

786.65

786.65

630.00

391.20

340.00

290.70

0.0

0.0

0.0

0.0

0.0

0.0

5.0

0.0

0.0

0.0

0.0

0.0

0.0

52
1840207

1840208

1840209

1840210

1840211

50.0

60.0

70.0

81.10

10000.00

270.00

0.00

0.00

0.00

0.00

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

*----------------------------------------------------------

* COMPONENT 181:BROKEN LOOP AUXILIARY FEEDWATER

* SOURCE VOLUME

-----------------------------------------------------------

1810000 B-AFEED TMDPVOL

1810101 1.0 0.0 100.0 0. 0. 0. 0. 0. 00

1810200 3

1810201 0.0 500.0 100.0

-----------------------------------------------------------

* COMPONENT 182: BROKEN AUX-FEED WATER JUNCTION

* ------------------------------------------------------

*MOTOR DRIVEN + TBN DRIVEN

*

*

*

1820000

1820101

1820200

1820201

1820202

1820203

B-FEED-J

181000000

1

TMDPJUN

174000000

589

0.0 0.0

0.0 0.0

0.0 0.0

1.0

0.0

20.0

50.0

0.0

0.0

58.08

* .HEAT STRUCTURE INPUT

---------------------------------------------------------------------

---------------------------------------------------------------

* HEAT STRUCTURE 108: STEAM GENERATOR U-TUBES *

11081000

11081100

11081101

11081201

11081301

11081401

11081501

11081502

11081503

11081504

11081505

11081506

11081507

11081508

11081601

11081602

11081603

11081604

11081605

11081606

8 4 2 1 0.032292

0 1

3 0.036458

4 3

0.0 3

520.0 4

108010000 0

108020000 0

108030000 0

108040000 0

108050000 0

108060000 0

108070000 0

108080000 0

170010000 0

170020000 0

170030000 0

170040000 0

170040000 0

170030000 0

1

1

1

1

1

1

1

1

1

1

1

1

1

0'

0

.0

0

0

0

0

0

0

0

0

0

0

0

8382.1469

8382.1469

8382.1469

2917.1839

2917.1839

8382.1469

8382.1469

8382.1469

9463.5300

9463.5300

9463.5300

3293.5306

3293.5306

9463. 5300

1

2

3

4

5

6

7

8

1

2

3

4

5

6

53
11081607

11081608

11081701

11081801

11081802

11081803

11081901

11081902

11081903

170020000 0

170010000 0

0 0.0 0.0 0.(

1 0 9463.5300

1 0 9463.5300

0

0

0

0

0

0

0.0646

0.0646

0.0646

0.12618

0.119

0.12618

0.0646 9.91

0.0646 3.449

0.0646 9.91

0.12618 9.91

0.1215 3.449

0.12618 9.91

7

8

8

3

5

8

3

5

8

------------------------------------------------------

* CONTROL VARIABLE 51 BROKEN LOOP STEAM GENERATOR

*SECONDARY SIDE MASS INVENTORY *---------------------------------------------------------------------------

*

*

20505100

20505101

20505102

20505103

20505104

20505105

20505106

20505107

BSG-MAS SUM

0.0 544.0 RHO

544.0 RHO

525.252 RHO

616.5 RHO

42.498 RHO

70.3265 RHO

1611.200 RHO

0.062428

170010000

170030000

170050000

172010000

176010000

176030000

180010000

0.0 1

544.0

103.572

608.83

407.145

70.3265

70.3265

RHO

RHO

RHO

RHO

RHO

RHO

170020000

170040000

171010000

174010000

176020000

176040000

---------------------------------------------------------------

--------------------------------------------------- --

CONTROL VARIABLE 52: BROKEN LOOP STEAM GENERATOR

SECONDARY SIDE WATER VOLUME INVENTORY *

*

20505200

20505201

20505202

20505203

20505204

20505205

20505206

20505207

IBG-VOF SUM 1.000000 0.0 1

0.0 544.0

544.0

525.252

616.5

42.498

70.3265

1611.200

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

170010000

170030000

170050000

172010000

176010000

176030000

180010000

544.0

103.572

608.83

407.145

70.3265

70.3265

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

170020000

170040000

171010000

174010000

176020000

176040000

* CONTROL VARIABLE 53: BROKEN LOOP STEAM GENERATOR

* WIDE RANGE SECONDARY SIDE WATER VOLUME INVENTORY.*

-----------------------------------------------------------

*

20505300

20505301

20505302

20505303

20505304

WBWRVOF SUM 1.000000

0.0 616.5 VOIDF 172010000

42.498 VOIDF 176010000

70.3265 VOIDF 176030000

1611.200 VOIDF 180010000

0.0 1

407.145

70.3265

70.3265

VOIDF

VOIDF

VOIDF

174010000

176020000

176040000

CONTROL VARIABLE 54: BROKEN LOOP STEAM GENERATOR

*NARROW RANGE SECONDARY SIDE WATER VOLUME INVENTORY

*

*

20505400

20505401

BNR-VOF

0.0 616.5

SUM 1.000000

VOIDF 172010000

0.0 1

108.178 VOIDF 174010000

54
20505500 XXC3 SUM 1.3797-03 0.8 1 3 0.0 1.0

20505501 -552.33 1.00 CNTRLVAR,53

*-------------------------------------------------------------------------

20505600 XXC4 SUM 1.3797-03 0.44 1 3 0.0. 1.0

20505601 0.000 1.00 CNTRLVAR,54

-------------------------------------------------------------------------

NARROW RANGE LEVEL REDUCED FROM WIDE RANGE WATER VOLUME

20505700 BWR-LEVL FUNCTION 1.0 0.44 1 3 0.0 1.0

20505701 CNTRLVAR,55 501

------------------------------------------------------------------------

NARROW RANGE LEVEL REDUCED FROM NARROW RANGE WATER VOLUME

20505800 BNR-LEVL FUNCTION 1.0 0.44 1 3 0.0 1.0

20505801 CNTRLVAR,56 501

---------------------------------------------------------------------

S/G FLUID VOLUME FROM BOTTOM

20505900 BSGVOL SUM 0.0003498 0.66 1

20505901 0.0 1.0 CNTRLVAR,52

*----------------------------- --------------------------------------- S/G WATER LEVEL FROM BOTTOM

20506000 BSGLVL FUNCTION 44.942 39.2 1

20506001 CNTRLVAR,59 502

*------------------------------------------------------------------------

* GENERAL TABLE DECK

------------------------------------------------------------------------

* NARROW RANGE WATER LEVEL VERSUS NR WATER VOLUME

20250100 NORMAREA

20250101 0.0 0.0

20250102 0.149 0.1500

20250103 1.00 0.730 ----------------------------------------------------------------

S/G VOLUME VS. LEVEL

20250200 NORMAREA

20250201 0.0 0.0

20250202 0.215 0.662

20250203 0.266 0.710

20250204 0.592 0.860

20250205 1.0 1.0

------------------------------------------------------------------- *

* STANDALONE STEAM GENERATOR (INTACT LOOP-B) *

------------------------------------------------------------------- *

------------------------------------------------------ -------------- *

*----------------------------------------------------------------

* MINOR EDIT REQUEST

55
---- H-----R NAM-----C---COMPONENT------- ------

---------------------------------------------------------------------

*---------------------------------------------------------------

* COMPONENT 205: INTACT LOOP STEAM GENERATOR INLET PLENUM

*-------------------------------------------------------- --

2050000 I-SG-IP SNGLVOL

2050101 24.0015 6.7417 0.0 0. 90. 1.704 0. 0.000

2050200 3 2239.9 589.85

*

00

* COMPONENT * 206: INTACT LOOP STEAM GENERATOR INLET PLENUM

TO PRIMARY TUBE JUNCTION

*

*

x..................................................-............

2060000

2060101

2060201

I-IP-TUB SNGLJUN

205010000 208000000 11.0988 0.69 0.69

1 10334.0 0.0 0.0

0100

-----------------------------------------------------------

* COMPONENT 208: INTACT LOOP STEAM GENERATOR TUBES --------------------------------------------------*

2080000

2080001

2080101

2080201

2080301

2080302

2080303

2080401

2080601

2080602

2080603

2080604

2080701

2080702

2080703

2080704

2080801

2080901

2081001

2081101

2081102

2081103

2081201

2081202

2081203

2081204

2081205

2081206

2081207

2081208

I-SG-TUB

8

11.0988

11.0988

9.91

3.449

9.91

0.0

90.0

40.0

-40.0

-90.0

9.91

2.196

-2.196

-9.91

0.0 0.(

0.0 OC

00

0000

0000

0000

3 2232

3 222.

3 2218

3 2214

3 2213

3 2212

3 2212

3 2211

PIPE

8

7

3

5

8

8

3

4

5

8

3

4

5

8

8

7

8

3

4

7

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

)646

2.4

5.5

3.7

4.3

.,0

2.5

. 1

1.7

576.83

567.20

559.91

557.48

555.25

550.29

545.96

542.22

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

1

2

3

4

5

6

7

8

56
2081300

2081301

1

10334.0 0.0 0.0 7 X---------------------------------------------------------------

* COMPONENT 209: INTACT LOOP STEAM GENERATOR PRIMARY TUBES

TO PRIMARY OUTLET PLENUM

*

*

A ------------------------------------------------------

2090000

2090101

2090201

I-TU-OP SNGLJUN

208010000 210000000 11.0988

1 10334.0 0.0 0.0

0.69 0.69 0100

X ------------------------------------------------------

COMPONENT 210: INTACT LOOP STEAM GENERATOR OUTLET PLENUM -----------------------------------------------------------

2100000 I-SG-OP SNGLVOL

2100101 24.0015 6.7417 0.0 0. -90. -1.704 0. 0. 00

2100200 3 2211.4 542.22

* COMPONENT 211: INTACT LOOP STEAM GENERATOR OUTLET PLENUM

TO PUMP SUCTION LEG

*€

2110000 I-SG-O-P SNGLJUN

2110101 210010000 212000000 5.2414 0.000 0.000 0100

2110201 1 10334.0 0.0 0.0

OC------------------------------------------------------

*COMPONENT 274: BROKEN LOOP STEAM GENERATOR MID DOWNCOMER *

X---------------------------------------------------------------

2740000

2740001

2740101

2740200

2741101

2742101

2741201

2742201

-----------

*COMPONENT

BSG-M-DO BRANCH

2

60.3 6.752 0. 0. -90. -6.752 2.42189E-5 0.

3 857.37 501.730

272000000 274000000 60.3 1.0 1.0 0000

274010000 276000000 19.352 0.1 0.1 0000

1.7223 -4.2282 0.0

3.6356 3.6356 0.0

00

276: BROKEN LOOP STEAM GENERATOR BOTTOM DOWNCOMER *

X...........................................................................

2760000

2760001

2760101

2760102

2760201

2760301

2760302

2760401

2760601

2760701

2760702

2760801

2760901

2761001

BSG-B-DO

4

PIPE

19.352

7.0965

7.0965

2.196

9.91

0.0

-90.0

-2.196

-9.91

5.E-5

0.1

00

1

4

3

1

4

4

4

4

3

4

1

4

0.0

0.1

57
2761101

2761201

2761202

2761203

2761204

2761301

2761302

2761303

0000

3 858.84 501.740

3 860.39 501.740

3 863.68 501.760

3 866.98 501.770

9.9140 9.9140 0.0

9.9139 9.9139 0.0

9.9139 9.9139 0.0

3

0

0

0

0

0

0

0

0

0

0

0

0

1

2

3

4

1

2

3

* COMPONENT 278: BROKEN LOOP STEAM

TO RISER JUNCTION

GENERATOR BOTTOM DOWNCOMER *

2780000 BSG-D-RI SNGLJUN

2780101 276010000 270000000 2.8700 1.000 1.000

2780201 0 9.9146 11.069 0.0

--------------------------------------------------- --

*COMPONENT 270: BROKEN LOOP STEAM GENERATOR EVAPORATOR

-----------------------------------------------------------

0100

RISER *

2700000

2700001

2700101

2700102

2700103

2700201

2700202

2700301

2700302

2700303

2700401

2700601

2700801

2700901

2700902

2701001

2701101

2701201

2701202

2701203

2701204

2701205

2701301

2701302

2701303

2701304

B-SG-RIS

5

54.893

47.164

77.79

54.893

47.164

9.91

2.196

6.752

0.0

90.0

5.E-5

2.5

1.0

00

0000

PIPE

3

4

5

2

4

3

4

5

5

5

5

3

4

5

4

1115.8

1114.6

1114.2

1114.1

1114.0

0.0

2.5

1.0

0 860.41 512.17

0 858.74 516.09

0 857.84 516.37

0 857.26 516.30

0 856.94 516.25

1.8407 6.0283 0.0

4.1842 6.1268 0.0

7.5892 9.3246 0.0

7.5386 10.473 0.0

0.32765

0.72765

0.83908

0.84332

0.83804

0.0

0.0

0.0

0.0

0.0

1

2

3

4

1

2

3

4

5

* --------------------------------------------------- --

* COMPONENT 271: BROKENLOOP STEAM GENERATOR SEPERATOR *

X...........................................................................

2710000

2710001

2710101

B-SG-SEP SEPARATR

3

97.070 6.937 0. 0. 90. 6.937 0.0 4.667 01

58
2710200

2711101

2712101

2713101

2711201

2712201

2713201

0 855.70 516.05 1113.9 .500

271010000 280000000 63.8 0.864 0.864

271000000 272000000 30.000 0.0 0.0

270010000 271000000 77.790 21.0 21.0

6.7470 6.7470 0.0

1.9472 7.5366 0.0

4.5731 6.6075 0.0

1020

1000

1000

0.00

0.00

COMPONENT 272: BROKEN LOOP STEAM GENERATOR TOP DOWNCOMER

-----------------------------------------------------------

2720000 BSG-T-DO SNGLVOL

2720101 88.87 6.937 0. 0. 90. 6.937 0. 4.014 01

2720200 0 855.70 516.05 1113.9 .500

*------------------------------------------ ----------------

* COMPONENT 280: BROKEN LOOP STEAM GENERATOR STEAM DOME

-----------------------------------------------------------

2800000 B-SG-DOM PIPE

2800001 1

2800101 63.80000 1

2800301 7.2095 1

2800401 0.0 1

2800601 90.0 1

2800701 7.2095 1

2800801 0.0 0.0 1

2801001 00 1

2801201 2 855.10 1.0000 0.0 0.0 0.0 1 *-------------------------------------------------------

*

*

2870000

2870001

2870101

2870200

2871101

2872101

2871201

2872201

2880000

2880001

2880101

2880200

2881101

2881201

B-SG-DOM BRANCH

2 1

50.0 7.2095 0. 0.

2 855.10 1.0

272010000 287000000

287000000 280000000

0.0 0.0 0.0

0.0 0.0 0.0

B-SG-DOM BRANCH

1 1.

63.8 7.2095 0. 0.

2 855.00 1.0

280010000 288000000

0.0 786.65 0.0

90. 7.2095 0. 0. 00

50.0 0. 0.

204.0 0. 0.

0000

0003

90. 7.2095 0. 0. 00

63.8 0.0 0.0 0000

* COMPONENT 285: STEAM LINE

-----------------------------------------------------------

*

2850000

2850001

2850101

2850200

2851101

I-SG-SL

1 1

BRANCH

5.585 137.0 0. 0. 0. 0. 0. 2.667 00

2 853.64 1.0000

288010000 285000000 5.585 0.0 0.0 0000

59
2851201 0.0000 786.65 0.0

COMPONENT 286: MAIN STEAM ISOLATION VALVE

-----------------------------------------------------------

2860000 I-MSIV VALVE

2860101 285010000 700000000 5.585 0.0 0.0 0100

2860201 1 0.00 786.65 0.0

2860300 MTRVLV

2860301 501 504 0.2 1.0 0.0

------------------------------------------------------

*COMPONENT 291: PORV --------------------------------------------------------------------

*

$

2910000

2910101

2910200

2910201

2910202

2910203

I-PORV TMDPJUN

185000000 292000000

1 503 P 185010000

0.0 0.0 0.0

1019.0 0.0 0.0

1021.0 0.0 109.7

1.0

0.0

0.0

0.0

----------------------------------------------------------------------------------

2920000

2920101

2920200

2920201

I-PORV TMDPVOL

1.0 0.0 100.0 0.0

3

0.0 14.7 100.0

0.0 0.0 0.0 0.0 00

COMPONENT 293 SAFETY VALVES

±----------------------------------------------------------------------

2930000 I-SRV TMDPJUN

2930101 185000000 294000000

2930200

2930201

2930202

2930203

2930204

2930205

2930206

2930207

2930208

2930209

2930210

2930211

1 0

0.0

1089.0

1091.0

1102.0

1104.0

1116.0

1118.0

1129.0

1131.0

1143.0

1145.0

P 185010000

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

219.4

219.4

443.0

443.0

670.8

670.8

901.3

901.3

1134.7

1.0

0.0

0.0

0.0

-0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

--------------------------------------------------------------------------

2940000

2940101

2940200

2940201

I-SRV TMDPVOL

1.0 0.0 100.0 0.0

3

0.0 14.7 100.0

0.0 0.0 0.0 0.0 00

* COMPONENT 283: INTACT LOOP MAIN FEEDWATER SOURCE VOLUME *

60
2830000 I-MFW TMDPVOL

2830101 10.0 0.0 100.0 0. 0. 0. 0. 0. 00

2830200 3

2830201 0.0 500.0 413.0

-----------------------------------------------------------

* COMPONENT 284: INTACT LOOP MAIN FEEDWATER JUNCTION

-----------------------------------------------------------

2840000 I-MFW-J TMDPJUN

2840101 283000000 274000000 5.0

2840200 1 590

2840201 -1.00 786.650 0.0 0.0

2840202 0.0 786.65 0.0 0.0

2840203 10.0 0.0 0.0 0.0

2840204 10000. 0.0 0.0 0.0

----------------------------------------------------------- *

* COMPONENT 281:INTACT LOOP AUXILIARY FEEDWATER

* SOURCE VOLUME

------------------------------------------------------

2810000 I-AFEED TMDPVOL

2810101 1.0 0.0 100.0 0. 0. 0. 0. 0. 00

2810200 3

2810201 0.0 500.0 100.0

-----------------------------------------------------------

* COMPONENT 282: INTACT AUX-FEED WATER JUNCTION

* ------------------------------------------------------

*MOTOR DRIVEN + TBN DRIVEN

*

*•

*

2820000

2820101

2820200

2820201

2820202

2820203

I-FEED-J TMDPJUN

281000000 274000000

1 589

0.0 0.0 0.0 0.0

20.0 0.0 0.0 0.0

50.0 58.08 0.0 0.0

1.0

---------------------------------------------------------------------

* HEAT STRUCTURE INPUT ---------------------------------------------------------------------

* HEAT STRUCTURE 208: STEAM GENERATOR U-TUBES *

12081000

12081100

12081101

12081201

12081301

12081401

12081501

12081502

12081503

12081504

8 4 2 1 0.032292

0 1

3 0.036458

4 3

0.0 3

520.0- 4

208010000 0 1

208020000 0 1

208030000 0 1

208040000 0 1

0

0

0

0

8382.1469

8382.1469

8382.1469

2917.1839

1

2

3

4

61
12081505

12081506

12081507

12081508

12081601

12081602

12081603

12081604

12081605

12081606

12081607

12081608

12081701

12081801

12081802

12081803

12081901

12081902

12081903

208050000 0

208060000 0

208070000 0

208080000 0

270010000 0

270020000 0

270030000 0

270040000 0

270040000 0

270030000 0

270020000 0

270010000 0

0 0.0 0.'

0 0.0646

0 0.0646

0 0.0646

0 0.12618

0 0.119

0 0.12618

. 1 

1.64

1.64

1.64

0

0

0

0

0

0

0

0

0

0

0

0

9.91

2917.1839

8382.1469

8382.1469

8382. 1469

9463. 5300

9463. 5300

9463. 5300

3293. 5306

3293. 5306

9463.5300

9463.5300

9463. 5300

5

6

7

8

1

2

3

4

5

6

7

8

8

3

5

8

3

5

8

3.449

9.91

0.12618 9.91

0.1215 3.449

0.12618 9.91

--------------------------------------------------------------------- *

*CONTROL VARIABLE 300 :U-TUBE HEAT TRANSFER RATE

--------------------------------------------------------------------- *

20530000 UT-HEAT sum 1.OE-6 0.0 1

20530001 0.0 1.0 Q 108010000

20530002 1.0 Q 108020000

20530003 1.0 Q 108030000

20530004 1.0 Q 108040000

20530005 1.0 Q 108050000

20530006 1.0 Q 108060000

20530007 1.0 Q 108070000

20530008 1.0 Q 108080000

20530009 1.0 Q 208010000

20530010 1.0 Q 208020000

20530011 1.0 Q 208030000

20530012 1.0 Q 208040000

20530013 1.0 Q 208050000

20530014 1.0 Q 208060000

20530015 1.0 Q 208070000

20530016 1.0 Q 208080000 ---------------------------------------------------------------------

---------------------------------------------------------------------

* LOOP A-B INTERCONNECTION

---------------------------------------------------------------------

*COMPONENT 700 ; STEAM HEAD

*---------------------------------------------------- I---------------

7000000 STHEAD SNGLVOL

7000101 5.585 0.0 100.0 0. 0. 0. 0. 0. 10

7000200 2 849.39 1.0

I--------------------------------------------------------------------------

62
* COMPONENT 701; TURBINE STOP VALVE

7010000 TBNSTOP VALVE

7010101 700010000 702000000 5.585 0. 0. 0100

7010201 1 0.0 1573.3 0.0

7010300 MTRVLV

7010301 501 601 0.2 1.0 0.0

----------------------------------------------------------------------

* COMPONENT 702; TBN

*---------------------------------------------------------------------

7020000 TBN TMDPVOL

7020101 5.585 0.0 100.0 0. 0. 0. 0. 0. 00

7020200 2

7020201 0.0 850.00 1.0

-----------------------------------------------------------------

* CONTROL SYSTEM INPUT DATA

---------------------------------------------------------------------

---------------------------------------------------------

* CONTROL VARIABLE 61: INTACT LOOP STEAM GENERATOR *

* SECONDARY SIDE MASS INVENTORY *

--------------------------------------------------

20506100 ISG-MAS SUM 0.062428 0.0 1

20506101 0.0 544.0 RHO 270010000 544.0 RHO 270020000

20506102 544.0 RHO 270030000 103.572 RHO 270040000

20506103 525.252 RHO 270050000 608.83 RHO 271010000

20506104 616.5 RHO 272010000 407.145 RHO 274010000

20506105 42.498 RHO 276010000 70.3265 RHO 276020000

20506106 70.3265 RHO 276030000 70.3265 RHO 276040000

20506107 1611.200 RHO 280010000 ---------------------------------------------------------------

CONTROL VARIABLE 62: INTACT LOOP STEAM GENERATOR

* -SECONDARY SIDE WATER VOLUME INVENTORY

*

*

20506200

20506201

20506202

20506203

20506204

20506205

20506206

20506207

ISG-VOF

0.0 544.0

544.0

525.252

616.5

42.498

70.3265

1611.200

SUM 1.000000 0.0 1

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

270010000

270030000

270050000

272010000

276010000

276030000

280010000

544.0

103.572

608.83

407.145

70.3265

70.3265

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

270020000

270040000

271010000

274010000

276020000

276040000

* CONTROL VARIABLE 63: INTACT LOOP STEAM GENERATOR *

* .WIDE RANGE SECONDARY SIDE WATER VOLUME INVENTORY *

-----------------------------------------------------------

20506300

20506301

20506302

20506303

IWR-VOF

0.0 616.5

42.498

70.3265

IUM

VOIDF

VOIDF

VOIDF

1.000000 0.0 1

* 272010000 407.145 VOIDF 274010000

* 276010000 70.3265 VOIDF 276020000

:276030000 70.3265 VOIDF 276040000

63
.20506304 1611.200 VOIDF 280010000!

* CONTROL VARIABLE 64: INTACT LOOP STEAM GENERATOR

* NARROW RANGE SECONDARY SIDE WATER VOLUME INVENTORY -- - - - - - - - - - -- - - - - - - - - -----------

*

*

20506400

20506401

INR-VOF

0.0 616.5

SUm 1.000000

VOIDF 272010000

0.0 1

108.178 VOIDF 274010000

--------------------------- 7 --------- 7 ---------- -------------------- ------

20506500 XXC3 SUM 1.3797-03 0.8 1 '3 0.0 1.0

20506501 -552.33 1.00 CNTRLVAR,63

*-------------------------------------------------------------------------

20506600 *XXC4 SUM 1.3797-03 0.44 1 3' 0.0 1.0'

20506601 0.000 1.00 CNTRLVAR,64

--------------------------------------------------- 7----------------------

* NARROW RANGE LEVEL REDUCED FROM WIDE RANGE WATER VOLUME

20506700 IWR-LEVL FUNCTION 1.0 0.44 1 3 0.0 1.0

20506701 CNTRLVAR,65 501

------------------------------------------------ :------------------------

* NARROW RANGE LEVEL REDUCED FROM NARROW RANGE WATER VOLUME

20506800 INR-LEVL FUNCTION' 1.0 0.44 1 3 0.0 1.0

20506801 CNTRLVAR,66 501 *

-----------------------------------------------------------------------

* S/G LIQUID VOLUME FROM BOTTOM

20506900 ISGVOL SUM 0.0003498 0.66 1

20506901 0.0 1.0 CNTRLVAR,62

---------------------------------------------------------- --------- --

S/G WATER LEVEL FROM BOTTOM

20507000 ISGLVL FUNCTION 44.942 39.2 1

20507001 CNTRLVAR,69 502

* -----------------------------------------------------------------

------------------------------------------------------------------- *

*-------------------------------------------------------- -----------*

* ~REACTOR COOLANT SYSTEM*

---------------------------------------- ------------------ 7---------*

------------------------------------------------------ -------- *

*COMPONENT 101; BROKEN LOOP HOT LEG #1 VOLUME

----------------------------------------- --------------- *

*

IU IuuuU

1010101

1010200

D--L--I QULVUL

4.587 0.0 39.6824

3 2244.0 589.86

0. 0." 0. 0.' 2.417 00

* COMPONENT 102; BROKEN LOOP HOT LEG #2 VOLUME

--- ------------ - - ----------- ---------------------

1020000

1020001

B-HL;-2 BRANCH

3 1

'64
1020101

1020200

1021101

1022101

1023101

1021201

1022201

1023201

4.587 0.

3 2243,

10101000( S1020 1000(

63001000(

10334.0

10334.0

0.0000

.0 40.0 0.

.7 589.87

) 102000000

0 103000000

102000000

0.0 0.0

0.0 0.0

0.0 0.0

0. 0. 0. 2.417

4.587

4.587

0.7854

0.0

0.2 1.92

0.0

0.2

1.70

00

0000

0000

0100

--------------------------------------------------------- *

* COMPONENT 103; BROKEN LOOP HOT LEG,#3 VOLUME

----------------------------------------------------

00

1030000

1030101

1030200

B-HL-3 SNGLVOL

4.587 0.0 31.8933

3 2240.3 589.85

0. .90.0 5.144 0. 2.417

*COMPONENT 104; BROKEN LOOP HOT LEG 3 TO INLET PLENUM -------------------------------------------------------- *

*

1040000

1040101

1040201

B-HL-IP SNGLJUN

103010000 105000000

1 10334.0 0.0

4.587 0.25 0.25

0.0

0100

--------------------------------------------------------- *

* COMPONENT 112; BROKEN LOOP PUMP SUCTION LEG

. . . .. ...------------------------------------------------------ *

1120000 B-P-SUC PIPE

1120001 3

1120101 5.2414 3

1120201 5.2414 2

1120301 15.456 1

1120302 11.886 2

1120303 4.5 3

1120401 0.0 3

1120601 -90.0 1

S1120602 0.0. 2,

1120603 90.0 3

1120701 -15.456 1

1120702 0.0 2

1120703 4.5 3

1120801 0.0 2.583 3

1120901 0.0 0.0. 2

1121001 00 3

1121101 0000 2..

1121201 3 2202.4 542.18 0.0 0.0 0.0 1.

1121202 3 2204.7 542.20 0.0 0.0 0.0 2

1121203 3 2203.8 542.19 0.0 0.0 0.0 3

1121300 1

1121301 10334.0 0.0 0.0 2..

*- -----------------------------------------------------

*COMPONENT 114; BROKEN LOOP REACTOR COOLANT PUMP.VOLUME

*

*

1140000 B-PUMP PUMP

65
1140101

1140102

1140103

1140108

1140109

1140200

1140201

1140202

1140301

1140302

1140303

1140310

0.0 5.812 57.0

0.0 90.0 5.812

00

112010000 5.2414 0.0

116000000 .4.1247 0.0

3 2258.3 542.53

1 10334.0 0.0 0.0

1 10334.0 0.0 0.0

0 0 0 -1 -1-594 0

1190.0 1.0 98214.00 31

0.0 0.0 1925.0 0.

1.0E6 1190.0 -1.0

0.0 0100

0.0 0100

4.93 32668.85 82000.0

0 0.0 0.0

COMPONENT 116; BROKEN LOOP COLD LEG PIPIG 1 *-----------------------------------------------------------------

*

1160000

1160101

1160200

B-CL-1 SNGLVOL

4.1247 0.0 19.6843

3 2293.2 542.68

0. 0. 0. 0. 2.292 00

--------------------------------------------------------- *

*COMPONENT 120; BROKEN LOOP COLD LEG PIPING 2

*-----------------------------------------------------------------±

*

1200000

1200001

1200101

1200200

1201101

1202101

1201201

1202201

B-CL-2 BRANCH

2 1

4.1247 0.0 56.4362 0. 0. 0. 0. 2.292 00

3 2292.8 542.68

116010000 120000000 4.1247 0.0 0.0 0000

120010000 300000000 4.1247 0.0044 0.0044

10334.0 0.0 0.0

10334.0 0.0 0.0

0100

COMPONENT 201; INTACT LOOP HOT LEG #1 VOLUME

--------------------------------------------------------- *

*

2010000

2010101

2010200

I-HL-1 SNGLVOL

4.587 0.0 39.6824

3 2244.0 589.86

0. 0. 0. 0. 2.417. 00

* COMPONENT 202; INTACT LOOP HOT LEG #2 VOLUME ------------------------------------------------------------------ *

*

2020000

2020001

2020101

2020200

2021101

2022101

2021201

2022201

I-HL-2 BRANCH

2 1

4.587 0.0 40.0 0.

3 2243.7 589.87

201010000 202000000

202010000 203000000

10334.0 0.0 0.0

10334.0 0.0 0.0

0. 0. 0. 2.417 00

4.587 0.0 0.0 0000

4.587 0.2 0.2 0000

* COMPONENT 203; INTACT LOOP, HOT LEG #3 VOLUME

--------------------------------------------------------- *

:*

2030000 I-HL-3 SNGLVOL

66
2030101

2030200

4.587 0.0 31.8933 0.

3 2240.3 589.85

90.0 5.144 0. 2.417 00

--------------------------------------------------------- *

* COMPONENT 204; INTACT LOOP HOT LEG-3 TO INLET PLENUM ---------------------------------------------------- *

2040000

2040101

2040201

I-HL-IP SNGLJUN

203010000 205000000 4.587

1 10334.0 0.0 0.0

0.25 0.25 0100

--------------------------------------------------------- *

* COMPONENT 212; INTACT LOOP PUMP SUCTION LEG

--------------------------------------------------------- *

2120000 I-P-SUC PIPE

2120001 3

2120101 5.2414 3

2120201 5.2414 2

2120301 15.456 1

2120302 11.886 2

2120303 4.5 3

2120401 0.0 3

2120601 -90.0 1

2120602 0.0 2

2120603 90.0 3

2120701 -15.456 1

2120702 0.0 2

2120703 4.5 3

2120801 0.0 2.583 3

2120901 0.0 0.0 2

2121001 00 3

2121101 0000 2

2121201 3 2202.4 542.18 0.0 0.0 0.0 1

2121202 3 2204.7 542.20 0.0 0.0 0.0 2

2121203 3 2203.8 542.19 0.0 0.0 0.0 3

2121300 1

2121301 10334.0 0.0 0.0 2

*------------------------------------------------------------------±

"*1

* COMPONENT 214; INTACT LOOP REACTOR COOLANT PUMP VOLUME *

X ----------------------------------------------------- A

2140000

2140101

2140102

2140103

2140108

2140109

2140200

2140201

2140202

2140301

2140302

2140303

2140310

I-PUMP PUMP

0.0 5.812 57.0

0.0 90.0 5.812

00

212010000 5.2414 0.01 0.0

216000000 4.1247 0.0' 0.0

3 2258.3 542.53

1 10334.0 0.0 0.0

1 10334.0 0.0 0.0

114 114 114 -1 -1 ý595 0

1190.0 1.0 98214.00 314.93

0.0 0.0 1925.0 0.0

1.0E6 1190.0 -1.0

0100

0100

32668.85

0.0 0.0

82000.0

67
--------------- --------------

*COMPONENT 216; INTACT LOOP COLD LEG PIPIG 1 -------------------- m-------------------------------------*

*

2160000

2160101

•16Nl•Af

I-CL-1

4.1247

SNGLVOL

0.0 19.6843. .0. 0. 0. 0. 2.292 00

---------------------------------------------------------*

*COMPONENT 220; INTACT LOOP COLD LEG PIPING 2 ------------------------------------------------------------------------

*

2200000

2200001

2200101

2200200

2201101

2202101

2201201

2202201

I-CL-2

2 1

BRANCH

4.1247 0.0 56.4362 0. 0.

3 2292.8 542.68

216010000 220000000 4.1247

220010000 300000000 4.1247

10334.0 0.0 0.0

10334.0 0.0 0.0

). 0. 2.292 00

0.0 0.0 0000

0.0044 0.0044 0100

---------------------------------------------------------*

* COMPONENT 620; PRESSURIZER (LOCATED AT BROKEN LOOP)

* CHECK #1023101 .

- - - - - - - - - - - - - - - - - - - - - - - - - - -

*

6200000

6200001

6200101

6200102

6200103

6200301

6200302

6200303

6200401

6200601

6200801

6200901

6201001

6201101

6201201

6201202

6201203

6201204

6201205

6201206

6201207

6201208

6201300

6201301

PREZ PiI

8

24.926

36.794

24.926

3.94

3.64 7

3.94 8

0.0

-90.0

0.0 0.000

0.0 ,0.0

00

0000

2 2250.

2 2250.

2 2250.

2 2250.

2 2250.

2 2251.

2 2252.

2 2253.

PE

7

8'

1

1

8

8

87.

7

1

3

4

6

9

7

6

6

8

7

1.0

1.0

1.0

1.0

0.1484

0.0

:0.0

0.0

0.0

0.0

0.0

0.0

0.0,

0.0

0.0 0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0,

0.0

0.0

0.0

0.0

0.0

0.0

0.0

*1

2

3

4

5

6..

7

8

1

0.0 0.0 0.0 7

---------------------------------------------------------*

* COMPONENT 621; PRESSURIZER TO SURGELINE JUNCTION

----------------------------------------------------

*

6210000

6210101

PRZ-SUR

620010000

SNGLJUN

630000000 0.7854 6.19 7.655 0100

68
6210201 1 0.0 0. 0 0. 0.

6 2 1 0 2 0 1-1-0. 0-0. 0-0. 0

C CMPONENT 630; PRESSURIZER SURGE LINE

----------------------------------------------------

6300000 PRZ-SUR PIPE

6300001 3

6300101 0.7854 3

6300301 8.125 1

6300302 22.567 3

6300401 0.0 3

6300601 -90.0 1

6300602 0.0 3

6300701 -8.125 1

6300702 0.0 3

6300801 0.0 1.0 3

6301001 00 3

6301101 0000 2

6301201 3 2255.2 636.66 0.0 0.0 0.0 1

6301202 3 2256.3 624.03 0.0 0.0 0.0 2

6301203 3 2256.3 609.74 0.0 0.0 0.0 3

6301300 1

6301301 0.0 0.0 0.0 2

I ------------------------------------------ ±

*

* TIME DEPENDENT VOLUME FOR PRESSURIZER SAFETY VALVE *

6400000 PZRSRV TMDPVOL

6400101 1.0 0.0 100.0 0. 0. 0. 0. 0. 00

6400200 3

6400201 0.0 14.700 100.0

----------------------------------------------------

* TIME DEPENDENT JUNCTION FOR PZR SAFETY VALVES ------------------------------------------------------------------ *

=

6410000

6410101

6410200

6410201

6410202

6410203

PZRSRV TMDPJUN

640000000 620000000 1.0

1 0 P 620010000

0.0 0.0 0.0 0.0

2499.0 0.0 0.0 0.0

2501.0 211.2 0.0 0.0

*6400000 SS-VOL TMDPVOL

*6400101 1.0 0.0 100.0 0. 0. 0. 0. O. 00

*6400200 2

*6400201 0.0 2250.0 1.000

**---------------------------------------------------------------------

*6410000 SS-JUN SNGLJUN

*6410101 640000000 620000000 1.0 0.0 0.0 0000

*6410201 1 0.0 0.0 0.0

-----------------------------------------------------------

*----------------------------------------------------- ------------------------

= HEAT STRUCTURE INPUT

69
---------------- ----------------

* HEAT STRUCTURE 101: INTACT LOOP HOT LEG

----------------------------------------------------------- *

11010000 1 2 2 1 2.417

11010100 0 1

11010101 1 3.2833

11010201 5 1

11010301 0.0 1

11010401 601.45 2

11010501 101010000 0 1 1 8.6506 1

11010601 0 0 0 1 8.6506 1

11010701 0 0.0 0.0 0.0 1

11010801 0 2.417 2.417 8.6506 1

----------------------------------------------------------- *

* HEAT STRUCTURE 102: INTACT LOOP HOT LEG 2

--------------------------------------------------------------- *

11020000 1 2 2 1 2.417

11020100 0 1

11020101 1 2.8854

11020201 5 1

11020301 0.0 1

11020401 601.45 2

11020501 102010000 0 1 1 8.7203 1

11020601 0 0 0 1 8.7203 1

11020701 0 0.0 0.0 0.0 1

11020801 0 2.417 2.417 8.7203 1

--------------------------------------------------------------- *

HEAT STRUCTURE 103: INTACT LOOP HOT LEG 3

--------------------------------------------------------------- *

11030000 1 2 2 1 2.417

11030100 0 1

11030101 1 2.8524

11030201 5 1

11030301 0.0 1

11030401 601.45 2

11030501 103010000 0 1 1 6.953 1

11030601 0 0 0 1 6.953 1

11030701 0 0.0 0.0 0.0 1

11030801 0 2.417 2.417 6.953 1

* --------------------------------------------------------

*HEAT STRUCTURE 105: INTACT LOOP S/G INLET PLENUM *-----------------------------------------------------------------

*

*

*

*

11050000

11050100

11050101

11050201

11050301

11050401

11050501

1 2 3 1

0, 1

1 5.731

5 1

0.0 1

601.41 2

105010000 0

5.2342

12

1 1 0.25 1

70
11050601

11050701

11050801

0

0

0

0 0 1 0.25 1

0.0 0.0 0.0 1

5.5281 5.5281 6.7417 1

HEAT STRUCTURE 110: INTACT LOOP S/G OUTLET PLENUM

-------------------------------------------------------------

11100000 1 2 3 1 5.2342

11100100 0 1

11100101 1 5.7342

11100201 5 1

11100301 0.0 1

11100401 540.99 2

11100501 110010000 0 1 1 0.25 1

11100601 0 0 0 1 0.25 1

11100701 0 0.0 0.0 0,0 1

11100801 0 5.5281 5.5281 6.7417 1

*---------------------------------------------------------------

HEAT STRUCTURE 112: INTACT-LOOP PUMP SUCTION LEG

*---------------------------------------------------------------

11120000 3 2 2 1 2.583

11120100 0 1

11120101 1 3.038

11120201 5 1

11120301 0.0 1

11120401 541.0 2

11120501 112010000 0 1 1 15.456 1

11120502 112020000 0 1 1 11.886 2

11120503 112030000 0 1 1 4.5 3

11120601 0 0 0 1 15.456 1

11120602 0 0 0 1 11.886 2

11120603 0 0 0 1 4.5 3

11120701 0 0.0 0.0 0.0 3

11120801 0 2.583 2.583 15.456 1

11120802 0 2.583 2.583 11.886 2

11120803 0 2.583 2.583 4.5 3

*-------------------------------------------------------------*

HEAT STRUCTURE 116: INTACT LOOP COLD LEG 1

*-------------------------------------------------------------*

11160000 1 2 2 1 2.2917

11160100 0 1

11160101 1 2.7396

11160201 5 1

11160301 0.0 1

11160401 541.2 2

11160501 116010000 0 1 1 4.7723 1

11160601 0 0 0 1 4.7723 1

11160701 0 0.0 0.0 0.0 1

11160801 0 2.292 2.292 4.7723 1

--------------------------------------------------------

* HEAT STRUCTURE 120: INTACT LOOP COLD LEG 2

*

*

*

*

71
11200000 1 2 2 1 2.2917

11200100 0 1

11200101 1 3.0006

11200201 5 1

11200301 0.0 1

11200401 541.2 2

11200501 120010000 0 1 1 13.6825 1

11200601 0 0 0 1 13.6825 1

11200701 0 0.0 0.0 0.0 1

11200801 0 2.292 2.292 13.6825 1

*-------------------------------- ;---------------------------*

* HEAT STRUCTURE 201: BROKEN LOOP HOT LEG 1

----------------------------------------------------------- *

12010000 1 2 2 1 2.417

12010100 0 1

12010101 1 3.2833

12010201 5 1

12010301 0.0 1

12010401 601.45 2

12010501 201010000 0 1 1 8.6506 1

12010601 0 0 0 1 8.6506 1

12010701 0 0.0 0.0 0.0 1

12010801 0 2.417 2.417 8.6506 1

*----------------------------------------------------------*

* HEAT STRUCTURE 202: BROKEN LOOP HOT LEG 2

----------------------------------------------------------- *

12020000 1 2 2 1 2.417

12020100 0 1

12020101 1 2.8854

12020201 5 1

12020301 0.0 1

12020401 601.45 2

12020501 202010000 0 1 1 8.7203 1

12020601 0 0 0 1 8.7203 1

12020701 0 0.0 0.0 0.0 1

12020801 0 2.417 2.417 8.7203 1 ,-------------------------------------------------------------

* HEAT STRUCTURE 203: BROKEN LOOP HOT LEG 3

----------------------------------------------------------- *

*

*

*

12030000

12030100

12030101

12030201

12030301

12030401

12030501

12030601

12030701

12030801

1 2 2 1 2.417

0 1

1

5

2.8524

1

0.0 1

601.45 2

203010000

0

0 0.0

0 2.417

0 1 1 6.953

0 0 1 6.953

0.0 0.0

2.417 6.953

1

1

1

1

72
* HEAT STRUCTURE 205: BROKEN LOOP S/G INLET PLENUM

*-------------------------------------------------------------

12050000 1 2 3 1 5.2342

12050100 0 1

12050101 1 5.7342

12050201 5 1

12050301 0.0 1.

12050401 606.41 2

12050501 205010000 0 1 1-. 0.25 1

12050601 0 0 0 .1 0.25 1

12050701 0 0.0 0.0 0.0 .1

12050801 0 5.5281 5.5281 6.7417 1

---------------------------------------------- 7 ------------

HEAT STRUCTURE 210: BROKEN LOOP S/G OUTLET PLENUM

*-------------------------------------------------------------

12100000 1 2 3 1 5.2342

12100100 0 1

12100101 1 5.7342

12100201 5 1

12100301 0.0 1

12100401 540.99 2

12100501 210010000 0 1-.1 0.25. 1

12100601 0 0 0 1 0.25 1

12100701 0 0.0 0.0 :0.0. 1

12100801 0 5.5281 5.5281 6.7417 1

---------------------------------------------------------------

HEAT STRUCTURE 212: BROKEN LOOP PUMP SUCTION LEG

- -----------------------------------------------------------

12120000 3 2 2 1 2.583

12120100 0 1

12120101 1 3.038

12120201 5 1

12120301 0.0 1

12120401 541.0 2

12120501 212010000 0 1 1 15.456 1

12120502 212020000 0 1 1 11.886 2

12120503 212030000 0 1 1 4.5 " 3

12120601 0 .0 0 1 -15.456 1

12120602 0 0 0 1 11.886 2

12120603 0 0 0 1 4.5 3

12120701 0 0.0 0.0 0.0 3

12120801 0 2.583 2.583 15.456 1

12120802 0 2.583 2.583 11.886 2

12120803 0 2.583 2.583 4.5 3

--------------------------------------------------------

*HEAT STRUCTURE 216: BROKEN LOOP COLD LEG 1

*-------------------------------------------------------------

*

*

*

*

12160000

12160100

1 2 2 1

0 1

2.2917

73
12160101 1 2.7396

12160201 5 1

12160301 0.0 1

12160401 541.2 2

12160501 216010000 0 1 1 4.7723 1

12160601 0 0 0 1 4.7723 1

12160701 0 0.0 0.0 0.0 1

12160801 0 2.292 2.292 4.7723 1 -------------------------------------------------------------

*HEAT STRUCTURE 220: BROKEN LOOP COLD LEG 2

*---------------------------------------------------------

12200000 1 2 2 1 2.2917

12200100 0 1

12200101 1 3.0006

12200201 5 1

12200301 0.0 1

12200401 541.2 2

12200501 220010000 0 1 1 13.6825 1

12200601 .0 0 0 1 13.6825 1

12200701 0 0.0 0.0 0.0 1

12200801 0 2.292 2.292 13.6825 1 ------------------------------------------------ *

*HEAT STRUCTURE 620: PRESSURIZER*

------------------------------------------------ *

16200000 8 2 2 1 7.625

16200100 0 1

16200101 1 8.0

16200201 5 1

16200301 0.0 1

16200401 652.5 2

16200501 620010000 0 1 1 3.94 1

16200502 620020000 0 1 1 3.64 2

16200503 620030000 0 1 1 3.64 3

16200504 620040000 0 1 1 3.64 4

16200505 620050000 0 1 1 3.64 5

16200506 620060000 0 1 1 3 .64 6

16200507 620070000 0 *1 1 3.64 7

16200508 620080000 0 1 1 3.94 8

16200601 0 0 0 1 3.94 1

16200602 0 0 0 1 3.64 2

16200603 0 0 0 1 3.64 3

16200604 0 0 0 1 3.64 4

16200605 0 0 0 1 3.64 5

16200606 0 0 0 1 3.64 6

16200607 0 0 0 1 3.64 7

16200608 0 0 0 1 3.94 8

16200701 0 .0.0 0.0 0.0 8

16200801 0 0.000 0.000 3.94 1

16200802 0 0.0 0.0 3.64 7

16200803 0 0.0 0.0 3.94 8

74
-- - - - - - - - - - -- - - - - - - - - - ---

*HEAT STRUCTURE 630: PRESSURIZER SURGE LINE

*--------------------------------------------------

*

16300000

16300100

16300101

16300201

16300301

16300401

16300501

16300502

16300503

16300601

16300602

16300603

16300701

16300801

16300802

16300803

3

0

1

5

2 2 1 1.0

1

1.1

1

0.0 1

635.0 2

630010000 0

630020000 0

630030000 0

0 0

0 0

0 0

0 0.0 0.0

0 1.0 1.0

0 1.0 1.0

0 1.0 1.0

1 1 .

1 1

1 1 0 1 0 1

0 1

0.0

8.125

22.567

22.567

3.125-

22.567 22. 567

3.125

?2.567

?2.567

2

3

1

2

3

3

1

2

3

*------------------------------------------------------------------

* CALCULATING TIME STEP INTERVAL

*------------------------------------------------------------------

20500100 Ti MULT 1.0 0.0 0

20500101 TIME 0

20500200 DELT SUM 1.0 0.0 0

20500201 0.0 1.0 CNTRLVAR 001 -1.0 CNTRLVAR 999

20599900 TO MULT 1.0 0.0 0

20599901 CNTRLVAR 001

* --------------------------------------------------------------

* TRIP DATAý

591 CNTRLVAR 103 GE NULL 0 -1.OE-6 N

* MEASURED PZR LEVEL - BASED ON VOID FRACTION

x....................................................-....................................

20512100

20512101

20512102

20512103

PZRLVL SUM 0.166667

0.0 1.0 VOIDF

1.0 VOIDF

1.0 VOIDF

0.4762 0

620020000

620040000

620060000

3

1.0

1.0

1.0

0. 1.

VOIDF

VOIDF

VOIDF

620030000

620050000

620070000

X --------------------------------------------------------------

* MEASURED

20512200

20512201

20512202

20512203

20512204

PZR WATER VOLUME.

PZRVOF SUM i 1.0

0.0 98.2084

133.93

133.93

133.93

YOIDF

VOIDF

VOIDF

VOIDF

476.2 0

S.620010000

* 620030000

* 620050000

* 620070000

133.93

133.93

133.93

98.2084

VOIDF

VOIDF

VOIDF

VOIDF

620020000

620040000

620060000

620080000

* TO CALCULATE AUCTIONEERED T AVERAGE,

75
v --------------------------------------------------------------

20510100

20510101

20510102

20510200

20510201

20510202

20510300

20510301 20510302

20510400

20510401

.20510500

20510501

20510600

20510601

20510700

20510701

20510800

20510801

20510802

20510900

20510901

TAVG-A SUM

-459.67

TAVG-B SUM

-459.67

1.0 574.0

0.9 TEMPF

0.9 TEMPF

1.0 574.0

0.9 TEMPF

0.9 TEMPF

0

101010000

116010000

0

201010000

216010000"

HTX1

0.0

SUM 1.0

1.0

-1.0

0.0 0

CNTRLVAR

CNTRLVAR

101

102

HTX2

591

TRIPUNIT. 1.0 1.0 0

HTX3 SUM 1.0 0.0 0

1.0 -1.0 CNTRLVAR 104

HTX4 MULT 1.0 0.0 0

CNTRLVAR 104 CNTRLVAR 101

HTX5 MULT 1.0 574.0 0

CNTRLVAR 105 CNTRLVAR 102

TAVG-H SUM 1.0 574.0 0

0.0 1.0 CNTRLVAR 106 1.0 CNTRLVAR 107

DELTEM SUM 1.0 0.0 0

-574.0 1.0 CNTRLVAR 108

---------------------------------------------------------------------

* STEAM DUMP CONTROL

------------------------------------------------------------

* TURBINE TRIP

------------------------------------------- ---------------------------

* STEAM DUMP SIGNAL BY TURBINE TRIP

* ------------------------------------------------------------- --

*AUCTIONEERED TEMPERATURE LEAD LAG UNIT ---------------------------------------------------------------------

20531100

20531101

DENOM SUM

1.0 0.5

1.0 1.0 0

.CNTRLVAR 002

20531200 DT/2A SUM 1.0 0.0 0

20531201 0.0 0.5 CNTRLVAR 002

20531300

20531301

VV SUM 1.0 0.0 0

0.0 3.0 CNTRLVAR 109• 1.0 CNTRLVAR 326

76
20531400 Wi SUm 1.0 0.0 0

20531401 0.0 1.0 CNTRLVAR 324 1.0 CNTRLVAR 109

20531500 V-YO SUm 1.0 0.0 0

20531501 0.0 1.0 CNTRLVAR 314 -1.0 CNTRLVAR 325

20531600 NUMER MULT 1.0 0.0 0

20531601 CNTRLVAR 312 CNTRLVAR 315 *

20531700 NUMERT SUM 1.0 0.0. 0

20531701 0.0 1.0 CNTRLVAR 313 1.0 CNTRLVAR 316 *

20531800 LEADLAG DIV 1.0 0.0 0

20531801 CNTRLVAR 311 CNTRLVAR 317

20531900 WV SUm 1.0 0.0 0

20531901 0.0 1.0 CNTRLVAR 324 1.0 CNTRLVAR 109

20532000 YY SUm 1.0 0.0 0

20532001 0.0 -1.0 CNTRLVAR 318 -1.0 CNTRLVAR 325

20532100 DEL SUM 1.0 0.0 0

20532101 0.0 1.0 CNTRLVAR 319' 1.0 CNTRLVAR 320

20532200 DELI MULT 1.0 0.0 0

20532201 CNTRLVAR 321 CNTRLVAR 312 *

20532300 I1 SUm 1.0 0.0 0

20532301 0.0 1.0 CNTRLVAR 326 1.0 CNTRLVAR 322

20532400 VO MULT 1.0 0.0 0

20532401 CNTRLVAR 109

20532500 YO MULT 1.0 0.0 0

20532501 CNTRLVAR 318

20532600 10 MULT 1.0 0.0 0

20532601 CNTRLVAR 323

20532700 LEADAUC SUM 1.0 574.0 0

20532701 574.0 1.0 CNTRLVAR 318

*------------- ---------------------------------------------------------

REFERNCE AVERAGE TEMPERATURE.

*---------------------------------------- ----------------------------

20533100 TAV TRIPUNIT 1.0 0.0 0

20533101 588

20533200 TAVER SUM 1.0 574.0 0

20533201 574.0 -27.0 CNTRLVAR 331-, -------------------------------------------- ------------------- --------------

77
* TEMPERATURE ERROR (BROKEN LOOP)

20534100

20534101

* FACTOR

20534200

20534201

20534300

20534301

20534400

20534401

20534500

20534501

TEMERR SUM 0.037037 0.0 0 3 0.0

0.0 1.0 CNTRLVAR 327 -1.0 CNTRLVAR 332

TO DETERMINE STEAM DUMP FLOWRATE

STM-P MULT 1.45037E-4 805.0 0

P 700010000

1.0

DELP SUM 1.26534E-3 1.0 0

-14.7 1.0 CNTRLVAR 342

DELPFNC STDFNCTN 1.0 1.0

SQRT CNTRLVAR 343

0

FACTOR MULT

CNTRLVAR 341

1.0 0.0 0 3

CNTRLVAR 344

0.0 1.0

* LAG= 20.0 SEC OF T-COLD OR T-HOT / LOOP A AND B

20540100

20540101

20540200

20540201

20540300

20540301

20540400

20540401

TCOLDA

20.00

TCOLDB

20.00

THOT-A

20.00

THOT-B

20.00

LAG 1.0 557.0 1

TEMPF 120010000

LAG 1.0 557.0 1

TEMPF 220010000

LAG 1.0 583.0 1

TEMPF 101010000

LAG 1.0 583.0 1

TEMPF 201010000

* COMPONENT 703: STEAM DUMP VALVE

-----------------------------------------------------------

7030000 DUMP-V TMDPJUN

7030101 700010000 704000000 5.585

7030200 1 592 CNTRLVAR 345

7030201 0.0 0.0 0.0 0.0

7030202 .1.0 0.0 834.56 0.0

* --------------------------------------- ---------------

*COMPONENT 704: CONDENSER -----------------------------------------------------------

*

*

7040000

7040101

7040200

7040201

CONDEN TMDPVOL

1.0 0.0 100.0

2

1.0 14.7 1.0

0. 0. 0. 0. 0. 00

* REACTIVITY DATA ---------------------------------------------------------------------

---------------------------------------------------------------------

* TOTAL POWER VS. TIME

---------------------------------------------------------------------

---------------------------------------------------------------

* SCRAM TABLE *

78
20210100 REAC-T 601

* TIME DOLLAR

20210101 0.0 0.0

20210102 0.2 -0.1205

20210103 0.4 -0.4567

20210104 0.6 -1.5978

20210105 0.8 -7.48546

20210106 1.0 -9.6304

20210107 1.2 -10.6992

20210108 1.4 -11.2282

20210109 1.6 -11.5210

20210110 1.8 -11.7130

20210111 2.0 -11.8670

20210112 2.2 -11.9295

20210113 2.4 -11.9898

20210114 2.6 -12.0500

20210115 2.E20 -12.0500

* REACTOR KINETICS TYPE CARD

30000000 POINT

30000001 GAMMA-AC 1335.7E6 0.0 321.0000 1.0

30000002 ANS79-1

30000011 101

30000401 0.0 50.0 HR

30000402 2.6714+8 40.0 HR

30000403 5.3428+8 30.0 HR

30000404 8.0142+8 20.0 HR

30000405 1.0186+9 10.0 HR

30000406 1.3357+9 0.00 HR

30000401 1.6378+9 50.0 HR

30000402 1.3012+9 6.00 HR

30000403 9.5657+8 12.0 HR

30000404 9.6425+8 2.00 HR

30000405 9.9680+8 2.00 HR

30000406 1.0293+9 2.00 HR

30000407 1.0619+9 2.00 HR

30000408 1.0944+9 2.00 HR

30000409 1.1270+9 2.00 HR

30000410 1.1595+9 2.00 HR

30000411 1.1921+9 2.00 HR

30000412 1.2246+9 2.00 HR

30000413 1.2237+9 6.00 HR

30000414 1.2339+9 2.00 HR

30000415 1.2542+9 2.00 HR

30000416 1.2746+9 2.00 HR

30000417 1.2950+9 2.00 HR

30000418 1.3153+9 2.00 HR

30000419 1.3357+9 1.00 HR *----------------------------------------------------------------------------

79
*DENSITY REACTIVITY TABLE ----------------------------------------------------------------------

*

30000

30000501

30000502

30000503

30000504

30000505

30000506

30000507

30000508

300005109

30000510

30000511

30000512

30000513

30000514

30000515

30000516

30000517

30000518

30000519

30000520

30000521

30000522

*30000523

*30000502

*30000503

30000701

30000702

30000703

*DOPPLER

30000601

30000602

30000603

30000604

30000605

30000606

30000607

30000608

30000609

30000610

30000611

30000612

30000613

44.4981 0.0

DENSITY

42. 2817

42.9136

43. 7370

44.5070

44.6939

44.7028

45. 0544

45. 2325

45. 4060

45. 5796

45. 7532

45. 9179

46. 0870

46. 2517

46. 4119

46. 5721

46.7324

46. 8881

49. 4517

53. 9692

57. 4496

60.1601

62. 0116

0.95

1.00

1.39

335010000

335020000

335030000

REACTIVITY (DOLLAR)

-1.700

-1.198

-0.599

0.000 44.5159 0.0

0.150

0.291

0.3§6.

0.484

0.564

0.643

0.722

0.802

0.8 72

0.942

1.013

1.075'

1.127

1.145

.2.037

3.358

4.018

4.415

4.767

0.000

0.000

0.000

0

0

0. 3333

0. 3334

0.3333

0.

0.

0!.

- --------------------------------- ---- --- -- -- ---- ---

REACTIVITY TABLE ----------------------------------------

*

TEMPERATURE

545.

58.6.5

628.0

669.5

711.0

752.5

794.0

835.5

877.0

918.5

960.0

1001.0

1043.0

(FUEL) REACTIVITY (DOLLAR)

2.13

2.00

1.95

1.74

1.62

1 .48

1.37

1.25

1.13

1.02

0.92

0.82

0.72

80
30000614

30000615

30000616

30000617

30000618

30000619

30000620

30000621

30000622

30000623

30000624

*30000601

*30000602

*30000603

30000801

30000802

30000803

1084.5

1126.0

1167.5

1209.0

1250.5

1292.0

1333.5

1375.0

1400.0

1500.0

1600.0

545.0

1375.0

1600.0

3330001

3330002

3330003

0.62

0.53

0.43

0.33

0.19

0.16

0.07

0.00

-0.04

-0.21

-0.69

0.00

0.00

0.00

0

0

0

0.3333

0.3334

0.3333

0.

0.

0. ---------------------------------------------------------------------

* HEAT STRUCTURE THERMAL PROPERTY DATA

---------------------------------------------------------------------

------------------------------------------------------

* COMPOSITION TYPE AND DATA FORMAT

------------------------------------------------------

20100100 TBL/FCTN 1 1 * CORE FUEL

20100200 TBL/FCTN 1 1 * CORE FUEL GAP

20100300 TBL/FCTN .1 1 *CORE FUEL CLADDING

20100400 TBL/FCTN 1- 1 INCONEL

20100500 TBL/FCTN 1 1 * STAINLESS STEEL

20100600 TBL/FCTN 1 1 * CARBON STEEL - -----------------------------------------------------------

* THERMAL CONDUCTIVITY DATA (BTU/SEC-FT/DEG F) AND

* . VOLUMETRIC HEAT CAPACITY DATA (BTU/FT**3-DEG F) *-------------------------------------------------------------------------------

*--------- -------------------------------------------------

* **.CORE FUEL.. --------------------------------------------------------------------

*

20100101

20100102

20100103

20100104

20100105

20100106

20100107

20100108

20100109

20100110

20100111

20100112

TEMP

188.6

332.6

440.6

500.0

650.0

800.0

950.0

1100.0

1250.0

1400.0

1500.0

1700.0

THERMAL CONDUCTIVITY

1.284E-3

1.1235E-3

9.951E-4

9.2806E-4

7.4194E-4

7.4361E-4

6.7750E-4

6.2278E-4

5.7722E-4

5.3889E-4

5.0639E-4

4.7889E-4

81
20100113

20100114

20100115

20100116

20100117

20100118

20100119

20100120

20100121

20100122

20100123

20100151

20100152

20100153

20100154

20100155

20100156

20100157

20100158

20100159

20100160

20100161

20100162

20100163

20100164

20100165

20100166

1850.0

2000.0

2150.0

2300.0

2450.0

2600.0ý

3100.0>

3600.0

4100.0

4600.0

5100.0

TEMP

32.0

122.0

212.0

392.0

752.0

2012.0

2732.0

3092.0

3452.0

3812.0

4352.0

4532.0

4712.0

4892.0

5144.0

8000.0

4.5528E-4

4.3556E-4

4.1861E-4

4.0472E-4

3.9306E-4

3.8389E-4

3.6750E-4

3.7028E-4

3.9056E-4

4.2722E-4

4.8056E-4

HEAT CAPACITY

34.45

38.35

40.95

43.55

46.80

51.35

52.65

56.55

63.05

72.80

89.70

94.25

98.15

100.10

101.40

101.40

* CORE FUEL GAP

-----------------------------------------------------------

*

20100201

20100202

20100251

20100252

TEMP

32.0

5400.0

TEMP

32.0

5400.0

THERMAL CONDUCTIVITY

3.0487788E-4

3.0487788E-4

HEAT CAPACITY

0.000075

0.000075

-----------------------------------------------------------

* FUEL CLADDING

-----------------------------------------------------------

*

20100301

20100302

TEMP

32.0

392.0

THERMAL CONDUCTIVITY

1.9267E-3

1.9267E-3

82
20100303

20100304

20100305

20100306

20100307

20100308

20100309

20100310

20100311

20100312

*

20100351

20100352

20100353

20100354

20100355

752.0

1112.0

1472.0

1832.0

2192.0

2552.0

2912.0

3272.0

3632.0

3992.0

TEMP

0.0

1480.3

1675.0

1787.5

3500.0

2.2478E-3

2.7297E-3

3.0508E-3

3.5325E-3

4.0142E-3

4.8169E-3

5.7803E-3

7.0647E-3

8.8311E-3

1.0918E-3

HEAT CAPACITY

28.392

34.476

85.176

34.370

34.476

* INCONEL ---------------------------------------------------------------------------

*

* TEMP THERMAL CONDUCTIVITY

20100401

20100402

20100451

20100452

20100453

20100454

32.0

1050.0

TEMP

100.0

400.0

600.0

800.0

2.1167E-3

4.0394E-3

HEAT CAPACITY

57.180

61.140

63.770

66.410

* STAINLESS STEEL

-----------------------------------------------------------

*

20100501

20100502

20100503

*

20100551

20100552

20100553

20100554

20100555

TEMP

32.0

1700.0

10000.0

TEMP

200.0

300.0

400.0

500.0

600.0

THERMAL CONDUCTIVITY

2.0833E-3

4.0294E-3

4.0294E-3

HEAT CAPACITY

57.114

59.118

61.122

63.126

64.629

83
20100556

20100557

20100558

20100559

20100560

700.0

800.0

1000.0

2000.0

10000.0

66.130

67.134

69.138

80.160

80.160

* CARBON STEEL --------------------------------------------------------------------

*

20100601

20100602

20100603

20100604

20100605

20100606

20100607

20100608

20100609

20100651

20100652

20100653

20100654

20100655

TEMP

80.0

440.33;

800.33.

1160.33.

1520.33

1880.33

2240.33

2600.33

2960.33.•

TEMP

80. 0.

200.03

1600.07:

2600.33.

2960.33.

THERMAL CONDUCTIVITY

0.01126.

0.01009

0.00908

0.00824

0.00756

0.00705

0.00670

0.00652

0.00649

HEAT CAPACITY

57.29

57.29

82.04

104.71

112.49!

*---------------------------- ;;----------------------------------------

*PUMP INPUT DATA

*--------------------------------------------------------------------

1141100

1

1141101

1141102

1141103

1141104

1141105

1141106

1141107

1141201

1141200

1141203

1141201

1141202

1141205

CURVE TYPE

1

V/A

0.0

0.05

0.2

0.4

0.6

0.8

1.0

TYPE

V/A

0.0

0.05

0.2

0.4

0.6

CURVE REGIME 1

H/A2

1.75

1.71

1.61

1.36

1.27

1.24

1.00

REGIME

B/A2

0.95

0.95

0.95

0.95

0.97

HAN

BAN

84
1141206 0.8 1.02

1141207 1.0 1.0

* TYPE REGIME HVN

1141300 1 

2

* A/V H/V2

1141301 0.0 -1.55

1141302 0.05 -1.46

1141303 0.1 -1.37

1141304 0.2 -1.13

1141305 0.4 -0.65

1141306 0.54 -0.3

1141307 0.58 -0.2

1141308 0.64 -0.05

1141309 0.66 0.0

1141310 0.68 0.05

1141311 0.8 0.35

1141312 0.9 0.65

1141313 1.0 1.0

* TYPE REGIME BVN

1141400 2 

2

* A/V B/V2

1141401 0.0 -1.46

1141402 0.05 -1.3

1141403 0.1 -1.15

1141404 0.2 -0.87

1141405 0.4 -0.4

1141406. 0.54 -0.05

1141407 0.58 0.03

1141408 0.64 0.15

1141409 0.66 0.2

1141410 0.68 0.25

1141411 0.8 0.54

1141412 0.9 0.75

1141413 1.0

TYPE REGIME HAD

1141500 1 

3

* V/A H/A2

1141501 -1.0 4.25

1141502 -0.8 3.58

1141503 -0.6 3.02

1141504 -0.4 2.50

1141505 -0.2 2.05

1141506 -0.05 1.8

1141507 0.0 1.75

TYPE REGIME BAD

1141600 2 

3

* V/A B/A2

1141601 -1.0 3.10

1141602 -0.8 2.5

1141603 -0.6 1.92

85
1141604

1141605

1141606

1141607

1141700

1141701

1141702

1141703

1141704

1141705

1141706

1141707

1141800

1141800

1141802

1141801

1141802

1141803

1141804

1141805

1141807

1143000

1143001

1143002 1143003

1143004

1143005

1143006

1143007

1143008

1143100

1143100

1143100

1143103

1143104 1143105

1143106

1143107

1144100

-0.4

-0.2

-0.05

0.0

TYPE 1

A/V

-0.8

-0.6

-0.4

-0.2

-0.1

-0.05

0.0

TYPE 2

A/V

-0.8

-0.6

-0.4

.'0.2

-0.1

-0.05

0.0

EXTRAP INDIC 0

VOID FRACTION

0.0

0.15

0.2

0.4

0.45

0.8

0.9

1.0

1.38

1.16

0.95

0.95

REGIME 4

H/V2

3.58

2.95

2.4

1.95

1.75

1.70

1.65

REGIME 4

B/V2

2.55

2.09

1.75

1.55

1.5

1.49

1.48

HEAD MULT.

0.0

0.0

0.3

0.8

1.0

1.0

0.8

0.0

HVD

BVD

EXTRAP. INDIC

0

VOID

0.0

0.3

0.4

0.5

0.8

0.9

1.0

TYPE 1

V/A

TORQUE MULT.

0.0

0.0

0.4

1.0

1.0

0.8

0.0

REGIME 1

H/A2

HAN

86
1144101

1144102

1144103

1144104

1144105

1144106

1144107

1144200

1144201

1144202

1144203

1144204

1144205

1144206

1144207

1144208

1144209

1144300

1144301

1144302

1144303

1144304

1144305

1144400

1144401

1144402

1144403

1144404

1144405

1144406

1144407

0.0

0.03

0.2

0.4

0.6

0.8

1.0

TYPE

1

A/V

0.0

0.1

0.2

0.4

0.6

0.66

0.8

0.9

1.0

TYPE

2

V/A

0.0

0.4

0.6

0.8

1.0

TYPE

2

A/V

0.0

0.2

0.4

0.6

0.66

0.8

1.0

1.0

1.0

1.11

1.06

1.07

1.08

0.9

REGIME

2

H/V2

0.0

0.05

0.17

0.25

0.25

0.26

0.3

0.58

0.9

REGIME

1

B/A2

0.55

0.55

0.52

0.52

0.45

REGIME

2

B/V2

0.0

0.03

0.04

0.07

0.08

0.14

0.45

HVN

BAN

BVN

* SEMISCALE TWO PHASE DIFFERENCE CURVES FOR HAD HVD BAD BND *

X---------------------------------------------------------------

1144500

1144501

1144502

1144503

1144504

1144505

1144506

1144507

TYPE

1

V/A

-1.0

-0.9

-0.8

-0.7

-0.6

-0.5

-0.4

REGIME

3

V/A2

-1.16

-1.24

-1.77

-2.36

-2.79

-2.91

-2.67

HAD

87
1144508 -0.25

1144509 -0.1

1144510 0.0

* TYPE

1144600 1

* A/V

1144601 -1.0

1144602 -0.9

1144603 -0.8

1144604 -0.7

1144605 -0.6

1144606 ý-0.5

1144607 -0.35

1144608 -0.2

1144609 -0.1

1144610 0.0

* TYPE

1144700 2

* V/A

1144701 -1.0

1144702 -0.8

1144703 -0.6

1144704 -0.4

1144705 -0.2

1144706 0.0

* TYPE

1144800 2

* A/V

1144801 -1.0

1144802 -0.8

1144803 -0.6

1144804 -0.4

1144805 -0.2

1144806 0.0

* TERMINATION CARD

.-1.69

-0.5

0.0

REGIME

4

H/V2

-1.16

-0.78

-0.5

-0.31

-0.17

-0.08

0.0

0.05

0.08

0.11

REGIME

3

B/A2

0.62

0.68

0.53

0.46

0.49

0.54

REGIME

4

B/V2

0.62

0.53

0.46

0.42

0.39

0.36

HVD

BAD

BVD

* PLOT DATA ---------------------------------------------------------------------------------------------

20300100

20300200

20300300

20300400

20300500

20300600

20300700

20300800

20300900

20301000

20301100

P 185010000

P 285010000

CNTRLVAR 57

CNTRLVAR 67

CNTRLVAR 58

CNTRLVAR 68

MFLOWJ 184000000

MFLOWJ 284000000

MFLOWJ 185010000

MFLOWJ 285010000

P 620010000

*

*

*

*

*

*

*

*

*

*

*

S/G

S/G

S/G

S/G

S/G

S/G

S/G

S/G

S/G

S/G

PZR

A PRESS.

B PRESS.

A WIDE RANGE LEVEL

B WIDE RANGE LEVEL

A NARROW RANGE LEVEL

B NARROW RANGE LEVEL

A FEED FLOW

B FEED FLOW

A STEAM FLOW

B STEAM FLOW

PRESS.

88
20301200

20301300

20301400

20301500

20301600

CNTRLVAR 121

TEMPF 120010000

TEMPF 220010000

CNTRLVAR 101

CNTRLVAR 102

20301700 RKTPOW

20301800 MFLOWJ 1

20301900 P 7

20302000 MFLOWJ 7(

20302100 MFLOWJ 7

20302200 MFLOWJ 1

20302300 MFLOWJ 2!

20302400 MFLOWJ 1

20302500 MFLOWJ 2;

20302600 TEMPF 1(

20302700 TEMPF 2(

20302800 CNTRLVAR

20302900 CNTRLVAR

20303000 CNTRLVAR

20303100 CNTRLVAR

* TERMINATION CARD

0

82000000

)0010000

01000000

03000000

91000000,

91000000

20020000,

?0020000

)1010000

)1010000

401

402

403

404.

* PZR LEVEL (W)

* LOOP-A T-COLD

* LOOP-B T-COLD

* LOOP-A T-AVG

* LOOP-B T-AVG.

* POWER

* AUX. FEEDWATER FLOW

* STEAM HEADER PRESSURE

* STEAM FLOW TO TURBINE

* STEAM DUMP, FLOW

* S/G A PORVý

* S/G B PORV

* * LOOP-A RCS FLOW

* LOOP-B RCS FLOW

* LOOP-A T-HOT

* LOOP-B T-HOT

* LOOP-A T-COLD.

* LOOP-B T-COLD

* LOOP-A T-HOT

* LOOP-B T-HOT.

89

NRC FORM 335 U.S. NUCLEAR REGULATORY COMMISSION 1. REPORT NUMBER

12.89) (Aured by NRC. Add Vol.. Suo. Rw., 1. NRCM 11|02. aind Addendm Numtorl. if any.) N320.3202 BIBLIOGRAPHIC DATA SHEET

(See instructions on tie reverse)

2. TITLE AND SUBTITLE NUREG/1A-0030

3 DATE REPORT IUESHED Assessment of RELAP5/MOD2 Code Using Loss of Offsite ,,ON .. . .=

Power Transient Data of KNU #1 Plant April 1 1990 4. FIN OR GRANT NUMBER

5. AUTHOR(S) 6 TYPE OF REPORT

Bub-Dong Chung Young-Jin Lee Technical

Hho-Jung Kim 7. PER!'D COVERED ... ,

8. PERFORMING ORGANIZATION - NAME AND ADDRESS III NRC, Ptow•v,d, -oh Olhce orR*9,oh. U.S. Nuclear Reguloror Comm,ss,On. ana mashog sootesi io cont-atol Oorvw,

nrnfe and mailing #dde'siI)

Korea Nuclear Safety Center (KNSC) Department of Nuclear Eng.

Korea Advanced Energy Research Institute (KAERI) Seoul National University

P.O. Box 7, Daeduk-Danji

Daejon - Korea

9. SPONSOR ING ORGAN IZATION - NAME AND ADDA ESS III NRC. fy00 Sjne a, above . .1 contraC for. pwede NRC Oeuon. Of hce or Regon. U & Nuclear Aveularory Conrns.,oy,

9. SPONSOR ING ORGAN IZATION - NAME AND ADDR ESS fit NVRC. tkae "3~ as &Dove". ,o cont,•ro,. Provide NRC D,vi,,o,. Office o, Re~i,. U.S. Nuckfteg Rulrory Comis,on.

and Mailing addesiI

Office of Nuclear Regulatory Research

U.S. Nuclear Regulatory Commission

Washington, DC 20555

10. SUPPLEMENTARY NOTES

11. ABSTRACT 120 .oo,os or to".

This report presents a code assessment study based on a r

transient that occurred on June 9, 1981 at the KNU #1 (Ko

Unit Number 1). KNU #1 is a two-loop Westinghouse PWR pl

The Loss of offsite power transient occurred at the 77.5%

with 0.5 %/hr power ramp. The real plant data were colle

available on-line plant records and computer diagnostics.

eal plant

rea Nuclear

ant of 587 Mwe.

reactor power

cted from

The transient was simulated by RELAP5/MOD2/36.05 and the results were

compared with the plant data to assess the code weaknesses and

strengths. Some nodalization studies were performed to contribute to

developing a guideline for PWR nodalization for the transient analysis.

12. KEY WORDS;DESCRIPTORS List *ows orOhrses that willasistnea•rhers on locating thereoort. I 13 AVAILABILITV STATEMENT

CODE ASSESSMENT STUDY OF RELAP5/MOD2 Unlimited

14. SECURITY CLASSIFICATION

( Ta#s PagelU

Unclassified

(This Report)

Uncl assified

15. NUMBER OF PAGES

16 PRICE

NRC FORM 335 12419•




UNITED STATES

NUCLEAR REGULATORY COMMISSION

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PENALTY FOR PRIVATE USE, $300

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1

PERMIT No. G-67