NUREG/IA-0008

SIntenmational

([)Agreement Report

Assessment Study of

RELAP-5 MOD-2 Cycle 36.01:

Based on the DoeI-2 Steam Generator

Tube Rupture Incident of June 1979

Prepared by

E. J. Stubbe

Tractionel

Rue de la Science 31

B-1040 Brussels, Belgium

Office of Nuclear Regulatory Research

U.S. Nuclear Regulatory Commission

Washington, DC 20555

October 1986

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-0008

•••International Agreement Report

Assessment Study of

RELAP-5 MOD-2 Cycle 36.01:

Based on the Doel-2 Steam Generator

Tube Rupture Incident of June 1979

Prepared by

E. J. Stubbe

Tractionel

Rue de la Science 31

B-1040 Brussels, 'Belgium

Office of Nuclear Regulatory Research

U.S. Nuclear Regulatory Commission

Washington, DC 20555

October 1986

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 documents work performed under the sponsorship of the Tractionel of

Belgium. The information in this report has been provided to the USNRC under

the terms of an information exchange agreement between the United States and

Belgium (Technical Exchange and Cooperation Arrangement Between the United

States Nuclear Regulatory Commission and the Tractionel of Belgium in the field

of reactor safety research and development, April 1985). Belgium 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 Belgium 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.
iii

EXECUTIVE SUMMARY

Severe plant transients following a Steam Generator Tube

Rupture (SGTR) have a relative high probability of occurrence.

Such transients provide a direct release path of contaminated

coolant to the environment thereby breaching several barriers

built in the concept, and induce a rather complex asymmetric

plant behaviour.

Analyses of most of the reported SGTR events clearly show that

there is substantial operator involvement required to mitigate

the consequences of such events for which the operator could

rarely follow prescribed procedures. Therefore, the operators

had to rely on their skill and insight to bring the plant to a

cold shutdown.

All the reported events of this type clearly demonstrate

a need to have bettor emergency response guidelines;

a need to have a better manual control over safety systems

such as the high pressure safety injection;

a need to better understand the different phenomena which

may determine the sequence of events.

The SGTR accident that occurred at the DOEL-2 plant on June

25th 1979 clearly demonstrated above features and triggered a

need to acquire the tools and develop the needed skill to cope

with these problems.

The resulting data and recordings made during this transient

provide A valuable data base for assessing both code and code

users, as real plant data are scarcely available and eliminate

the scaling problems inherent in small scale test facility

data for code assessment.
iv

The code assessment work presented in this document was based

on all the available data (from plant computer and plant

recordings) from this incident. Although the initial plant

conditions were well known, it must be emphasized that the

quantity and the quality of the available data from real

plants are by nature inferior to well instrumented test

facility data. Furthermore, the timing and the intensity of

the operator involvement during such transient were not

readily available and had to be inferred from the available

data.

The objective of this study was to assess the code RELAP5 MOD-2 CYCLE 36.01 performance, preferentially based on the

comparison of trends rather than comparison of absolute

values.

The study revealed some important features of the code which

can be summarised as follows

1. The code is capable to simulate the observed phenomena

reasonably well and can be used to predict similar

transients. However, lack of precise boundary conditions

does not allow one to quantify the error margin from this

analysis.

2. The code performance is acceptable. The time step is

constant and Courant limited for 99 % of the transient, and

the execution time on a CYBER-176 is about 1.8 times the

transient time. The mass error ratio remains negligible.

3. Impressive improvements over RELAP-5 MOD-i CYCLE 19 have

been observed in the steady break flow rate, and the water

vapour flow slip (CCFL) in the pressuriser when pressuriser

spray is actuated.

4. Excessive water level swell observed in the intact S.G..

during cooldown may be at'tributed to excessive interphase

momentum transfer in the S.G. riser region when bulk

boiling is initiated.
V

5. Excessive interphase mass and heat transfer for

condensation and evaporation in quasi stagnant flow

conditions was observed in the vapour space of the isolated

affected steam generatbr.

6. Erratic natural circulation in the affected steam generator

leads to an anomalous cooldown capacity of the steam

generator. This behaviour can be suppressed by inserting

high form loss factors in the natural circulation flow

pý'a t h.

7. While some anomalies may be reduced by a judicious choice

of tWe nodalisation and/or code options, this study

suggests that further improvements in the constitutive

equation package, in function of the various flow regimes

is needed to take full benefit of the potential of a 6

equation code.

1

ABSTRACT

This report presents a code assessment study based on a real

plant transient that occurred at the DOEL 2 power plant in

Belgium on June 25th 1979.

DOEL 2 is a two-loop WESTINGHOUSE PWR plant of 392 Mwe. A

steam generator tube rupture occurred at the end of a heat-up

phase which initiated a plant transient which required

substantial operator involvement and presented many plant

phenomena which are of interest for code assessment.

While real plant transients are of special importance for code

validation because of the elimination of code scaling

uncertainties, they introduce however some uncertainties

related to the specifications of the exact initial and

boundary conditions which must be reconstructed from available

on-line plant recordings and on-line computer diagnostics.

Best estimate data have been reconstructed for an assessment

study by means of the code RELAP5/HOD2/CYCLE 36.01. Because of

inherent uncertainties in the plant data, the assessment work

is focussed on phenomena whereby the comparison between plant

data and computer data is based more on trends than on

absolute values. Such approach is able to uncover basic code

weaknesses and strengths which can contribute to a better

understanding of the code potential.

This work was performed by TRACTIONEL, being the ArchitectEngineer for all DOEL plants, in cooperation with the utility

EBES which owns and runs these plants.

3

TABLE OF CONTENTS

Page

1. INTRODUCTION .................................................... 5

2. DOEL-2 PLANT AND SYSTEM DESCRIPTION .............................. 7

2.1 Reactor coolant system .......................................... 7

2.2 High pressure safety injection .................................. 8

2.3 Doel-2 charging and letdown system .............................. 8

2.4 Steam generators - main steamlines - auxiliary feedwater

system ........................................................... 9

2.5 Plant diagnostics and uncertainty bands ......................... 10

3. ANATOMY OF THE PLANT TRANSIENT .................................. 23

3.1 Plant status prior to the SGTR .................................. 23

3.2 Initiating event ................................................ 24

3.3 Mitigation phase ................................................. 24

3.4 Safety injection cancelling phase ............................... 26

4. CODE AND MODEL DESCRIPTION FOR PLANT SIMULATION ................. 33

4.1 Nodalisation of the primary coolant system and S.G ............... 34

4.2 Special code models and options ................................. 40

5. BASE CASE RESULTS ............................................... 64

6. DISCUSSION OF THE.BASE CASE RESULTS ............................. 126

6.1 Water level discrepancy in intact S.G. at start of cooldown ..... 126

6.2 Excessive cooldown between 1500 and 2400 seconds ................ 127

6.3 Vapour condensation anomaly in affected S.G ...................... 130
4

TABLE OF CONTENTS (Continued)

Page

7. DISCUSSION OF THE RESULTS OF A SENSITIVITY STUDY ................ 135

7.1 Water level discrepancy in intact S.G. at start of cooldown ..... 135

7.2 Discussion of sensitivity study concerning the cooldown period .. 135

7.3 Vapour condensation phenomena in highly stratified conditions ... 136

8. RUN STATISTICS .................................................. 148

9. CONCLUSION .................................................... 152

10. REFERENCES ...................................................... 154

ANNEXES .............................................................. 155
5

1. INTRODUCTION

Severe plant transients following a Steam Generator Tube

Rupture (SGTR) have a relative high probability of occurrence

(ref. 1). Such transient provide a direct release path of

contaminated coolant to the environment thereby breaching

several barriers built in the concept, and induce a rather

complex asymmetric plant behaviour.

Analyses of most of the reported SGTR events clearly show that

there is substantial operator involvement required to mitigate

the consequences of such events for which the operator could

rarely follow prescribed procedures. Therefore the operators

had to rely on their skill and insight to bring the plant to a

cold shutdown.

All the reported events of this type clearly demonstrate

a need to have better emergency response guidelines;

a need to have a better manual control over safety systems

such as the high pressure safety injection;

a need to better understand the dieferent phenomena which

may determine the sequence of events.

The SGTR accident that occurred at the DOEL-2 plant on June

25th 1979 clearly demonstrated above features and triggered a

need to acquire the tools and develop the needed skill to cope

with these problems.

The resulting data and recordings made during this transient

provide a valuable data base for assessing both code and code

users, as real plant data are scarcely available and eliminate

the scaling prob4-.ms inherent in small scale test facility

data for code assessment.

The code assessment work presented in this document is based

on all the available data (from plant computer and plant

recordings) from this incident. Although the initial plant

conditions are well known, it must be emphasized that the
6

quantity and the quality of the available data from real

plants are by nature inferior to well instrumented test

facility data. Furthermore, .the timing and the intensity of

the operator involvement during such transient are not readily

available and have to be inferred from the available data.

Hence the objective of this study is to assess a code

performance preferentially based on the comparison of trends

rather than comparison of absolute values.

After a brief description of the plant characteristics

(chapter 2) and the anatomy of the SGTR transient (chapter 3),

the plant nodalisation for the code RELAP-5 HODý-2 is discussed

in chapter 4.

The base case results are described in chapter 5 followed by a

discussion of these base case results in chapter 6, and of the

sensitivity results in chapter 7. Chapter 8 briefly presents

some run statistics.
7

2. DOEL-2 PLANT AND SYSTEM DESCRIPTION

This section provides a description of the plant and principal

systems relevant to understanding the DOEL-2 steam generator

tube rupture event during the first hour following the tube

rupture. Principal plant components and systems associated

with the event include the reactor coolant system, the high

pressure safety injection system, portions of the charging and

letdown system, the secondary side steam and auxiliary

feedwater systems including the power operated atmospheric

steam dump valves.

DOEL-2 is a WESTINGHOUSE 2 loop pressurized water reactor

(PWR) rated at 392 MWe (NET) and commissioned in 1975, for

which TRACTIONEL was the architect/engineer. This plant is

part of the twin concept with DOEL-1, as they share some

common engineered safety system such as the high pressure

safety injection system (HPSI).

2.1. Reactor coolant system

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

presented in fig. 2.1. The reactor vessel (2R1) is equipped

with 2 reactor coolant loops (A and B) comprising each I steam

generator (2EIA, 2EIB) and 1 main coolant pump (2PIA, 2P1B).

DOEL-2 is equipped with a aft core consisting of 121 fuel

assemblies with 179 fuel rods per assembly (outside cladding

diameter is 10.79 mm). The nominal core power is 1187 MWth.

The primary coolant pumps, with a rated power of 2.44 MW each

maintain a loop flowrate of 3628 kg/s with a net pump head of

4.275 bar.

A 24 m3 pressuriser (2R2) is connected by a 10" surgeline to

the "B" loop hot leg.

Two pressuriser spray lines connect the pressuriser spray

nozzle with both cold legs, yielding a maximum total spray
8

flow of 1500 1/min under nominal conditions when spray valves

are fully open (2PROOI, 2PRO02 and 2PRO06).

The pressuriser is equipped with pressuriser heaters

(proportional + back-up) with a total maximum power of 850 kW.

The heaters are switched off automatically when the

pressuriser level drops below 20 % .

2.2. Hiah pressure safety iniection (SI)

The Doel 1-2 plants are equipped with a common HPSI systemconsisting of 4 motovdriven pumps, which through a system of

valves and interconnected piping can feed cold water from the

refueling water storage tanks into both cold legs of the RCS

and also directly into the downcomer of the reactor vessel.

Fig. 2.2 shows a flow schematic of the HPSI system.

Fig. 2.3 and 2.4 illustrate the flow delivery curves of the

HPSI system in function of the reactor backpressure for the

cases with and without DOWNCOMER injection respectively.

Fig. 2.5. gives the pump characteristic of the HPSI pumps.

The HPSI pumps are actuated on generation of a SI signal. For

this event, the SI signal was generated at low - low

pressuriser pressure (117 bar) and pumps start feeding cold

water when reactor pressure drops below the high head cut-off

pressure of the 14PSI pumps (108 bar).

2.3. Doel 2 eharoing and letdown system

The water inventory and primary water chemistry in the reactor

coolant system is maintained by the charging and letdown

system.

For the charging system, 3 positive displacement pumps take

suction from-4he volumetric control tank and feed cold borated
9

water via a regenerative heat exchanger into the cold leg of

loop B.

The flowrate is normally controlled by the programmed water

level in the pressuriser which controls the speed of the

pumps. Normally only I pump is in operation. The flowrate per

pump varies between 8.7 m3 /hr for lowest speed of 140 RPM to

14.7 m3 /hr at 234 RPM.

The charging system also provides the seal injection water for

both main coolant pumps. Part of the seal water goes into the

RCS and part returns to the charging system.

The letdown flow is controlled mainly by three orifices in a

letdown line connected to the intermediate leg between S.G.

and primary pump of loop B. The orifices are sized to

discharge respectively 10, 10 and 20 t/hr. The backpressure is

controlled by an automatic control valve.

The letdown is closed when the pressuriser water level

decreases below 20 %

Upon generation of a SI signal, phase A containment isolation

is initiated which cuts off the compressed - air supply in the

reactor building. The containment isolation valve in the

letdown line, being a fail close valve, remains closed as long

as the SI signal is not RESET.

2.4. Steam aenerators - Main steam lines - Auxiliary feedwater

zs:isim

A schematic drawing of the Doel-2 main steam and auxiliary

feedwater system is given in fig. 2. 6.

The Doel-2 steam generators are U-type Westinghouse series 44

models, with a nominal heat transfer area of 4130 m2

consisting of 3260 tubes (s out = 22.2 m~m) with average

length of 18.16 m.
10

The power-operated atmospheric steam dump valves are hydraulic

operated valves each-with a steam capacity of 5 % of the total

plant steam flow (or 33.3 kg/s at 72 bar).

These valves (one per S.G.) are used to relieve minor pressure

increases in the S.G., to avoid lifting the safety valves (6

per SG) and provide also a means of plant cooldown when the

condenser is unavailable.

The main steam isolation valves (MSIV) are HOPKINSON valves.

During the DOEL 2 event, both MSIV were closed during the

heat-up phase and accident.

Also the main feedwater pumps were not operational at the

moment the break occurred. The auxiliary feedwater system

supplies cold feedwater to the S.G. when the main feedwater

system in unavailable.

The system consists of 2 motor-driven auxiliary feedwater

pumps (MPA and MPB) and one steam turbine-driven auxiliary

pump (TP) (Fig. 2.6.). These pumps take suction from the

auxiliary feedwater storage tank and suppletion water storage

tank.

The auxiliary feedwater actuation logic is shown in fig. 2.7.

The pump characteristics are shown in fig. 2.8. for one motor

driven pump, and fig. 2.9 for the steam turbine driven

auxiliary feedwater pump.

2.5. Plant diacnostics and uncertainty bands2.5.1. Measured plant parameters

Fig. I and 2 of annexe I illustrate the recorded

temperatures

- hot leg loop A sensor TR/2RC5 (see fig. 2.1.)

- hot leg loop B sensor TR/2RC25

- cold leg loop A sensor TR/2RC09

- cold leg loop B sensor TR/2RC29
11

The precision of the temperature sensors is estimated at

about 1.5 %

Fig. 3 and 4 of annexe 1 illustrate the recorder pressures

- RCS pressure : sensor PRA/2RCI1 in hot leg A.

- pressuriser pressure : sensor PICA/2PR61 in pressuriser.

The precision of the pressure sensors is estimated at 1 2

bar at the nominal system pressure resulting in an

uncertainty of 1.3 %

Pressuriser level (fig. 5 of annexe 1) : sensor LRCA/2PRI1.

The uncertainty band for the level gauge is estimated at 5 %

Steam generator pressure

- intact SG (fig. 6 in annexe 1) : sensor HS4A

- affected SG (fig. 7 in annexe 1) : sensor MS4B. These

sensors are located just upstream of the main steam

isolation valves.

The tolerance on the S.G. pressure gauges is estimated at 3%

Steam generator water level (narrow gauge)

intact SG (fig. 6 in annexe 1) : sensor FW9A

affected SG (fig. 7 in annexe 1) : sensor FW9B.

The tolerance on the S.G. level gauges is estimated at 16 X.

2.5.2. Recorder uncertainties

For the parameter values, a global recorder uncertainty of 3 %

should be added to the instrument uncertainty.

For the timing, an estimated off-set of 2 min should be

acounted for, from comparing time values in the computer

listing to recorded times on figures I to 6 of annexe 1.

Furthermore, by comparing fig. 1 and fig. 2 of annexe 1, a

large horizontal time shift (about 20 min) is evident due to
12

improper adjustement of timing. Hence, some engineering

judgment is required to synchronise the recorder data which

can be done on the basis of some important events (time of

break) and on the basis of the timing listed in the plant

computer listing.


FIr 2.2 - FLOW DIAGRAMI OF HIGH PRESSURE SAFETY INJECTION/ SYSTEt"I

21~tO97 osrool

COLD LEG. A

2 RC 073 2sr0oil

2 sfool

2 S 002

2RC 072 2S 009

COLD LEG B U.,"' H2 $1oo6

2 St 128 25I 125T

2RC017 29tI2G
16

FIG.: 2 - 3 - DOEL 2 HPSr ZCCS FLOW DELIVERY CURVES FOR

F-OUP LINES CONNECTING TO 0T0I4 CL AND HL OP TO

SOTH COLD LEGS AND VESSEL DOWNCOMER. `\

K

(WAC TOR BACK

PRESSURE

(8AR)

C.L.A

K

C,L. B

KLIPN = 0.03772 bar/(kg/S) 2

AVG

75

so

25

3

t4U?18( OF PUMIPS : I 2

TOTAL 14PSI FLOW (kg/s)

0 25 50
17

FIG 2.4 - DOEL 2 ,.J5.t ECCS FLOW DELIVERY c;,;VES FOR

TWO LINES TO SOTH COLD LEG5 OPEN.

REACTOR BACK

PPESSURE

(SAP) K

C. L. A -v,^-

K

C.L.8

100 K 1. =1- 0.03772 bar/(l

AVG.

75

25NUMBER OF PUMPS "

25

/T%

~9/s) 2

TOTAL HPSt PLOW (kq/$s)

0

so 7S
18

FIG 2. 5- HPs PUINlI C14APACTEPISTIC (-EST ESTIMATE)

P(bar)

110 - 107.91

100 -

90

80-

70

60-

so -

40 -

30 -

20 -

10 -

0

0 10 20 3 0 W ( 1491s)
19

FIG 2.G: FLOW DIAGPAM OF THE AUXILIARY FEED'dATER

SYTEfvl

FW Fw

MSIV" B" M $IV "A"
20

FiG 2.7 : AUXILIARY FEEDWATCP ACTUATION TRIP

( For power levels > 20 % )

PEF: DOEL 1708/95 PEV. B (20.01.77). VOL. 1-CHAP10

IF rwp\%

THEN MRP

MID

TP ~ MPA

MPB/

TP/

MPA/

MPB/

DECIZEASING INCRC

WATER LEVEL WATER

IN £6 IN

NARROW LEVEL- RANGE : 3.G32 -M = 100%

, - 75%(2.7Z4m) (1.724,n) 75% ---

8/

52'4 NOPMAL SG WATRP LEVEL

('1434m) 45%1

,1 T1 (0.908m)

:ASING

LEVEL

SG 4

TP

MPA

MP5

'-4

V

rJ

/

FWP /

IF ALSO FW TEM'PERATUPE < 450"C

714EN FWP\ý,FW VALVES%%. FOP BOT14 SG.

'IFSI"ORQDIE15ELS` TRIP

IS SEQUENCED BY VITAL

BUS LOADING LOGIC

SYMBOLS : FWP

MPA

rlPB

Feedwaterpumps

friotopump A

Motopump B

Turbopump

/ Automatc start

/€ / : Can't stop manually

Automatic TPIP

• \ : Can't start manually

I , Cari start manually '• : Can TPID manually
21

FIG. 2. 8

MEN

Pill

~f* rB~i r- FZ V

400

90

8o

Toi

E! _F

40

30

20

0
22

lp

SO

F/G 2.9

17

0
23

3. ANATOMY OF THE PLANT TRANSIENT

Part of the material presented in this chapter, and chapters

5, 6 and 7 has been presented before at two meetings in the

U.S.A. (References 2 and 3). Information presented in these

references and essential for code assessment is repeated in

this document for completeness sake.

A report on the incident was issued on October 25th, 1979 (see

annexe 1). From the raw plant recordings (figures 1 to 7 of

the annexe), figure 3.1 was reconstructed for the most

important plant variables.

From the original plant computer records, relevant computer

diagnostics were retrieved and shown in table 3.1.

From this information, the best estimate sequence of events

and operator interventions, as shown in fig. 3.2, was

reconstructed, and is used as the basis for the event

simulation.

3.1. Plant status prior to the SGTR (fig. 3.1 prior to point

A)

At the moment the event occurred on June 25th 1979, the

primary-system was being heated up after a 24 hour stop for

repair work on the main steam isolation valves.

The pressure had reached the rated value of 155 bar, with a

RCS temperature of about 255 0 C.

The water level in the pressuriser was kept constant at 25 %

by the automatic control of the charging flow. For the

letdown, two orifices of about 10t/hr each were available.

The reactor was subcritical with all control rods down.. Both

primary pumps were running and the pressuriser heaters were

ON. On the secondary side, the steamlines were both isolated

by the main steam isolation valves and no condenser vacuum was
24

present. The main feedwater pumps were not operational and

water level in both S.G.'s was manually controlled around 29 %

level narrow band by means of the blowdown. The auxiliary

feedwater pumps were not running.

The total heating power'was about 11 MWth (2.5 MWth per

primary coolant pump and 6 MWth decay heat).

3.2. Tnitiatina event : [fig. 3. 1, between points A and D)

At 19.20 hr C = to) a quick level decrease in the pressuriser

and a pressure decrease (z 2.5 bar/min) in the RCS was

observed followed by a demand for increased charging capacity,

and closure of the letdown line when the pressuriser level

dropped below 20 %

While the pressuriser level recording went off scale (point B)

a quick level increase in the B loop steam generator was

observed (point C).

When the radiation monitoring channels of the SG blowdown

recorded a maximum activity level, the operator diagnosed

within a couple of minutes the cause of the event to be a leak

in the B steam generator.

Post examination of the failed tube revealed a longitudinal

crack of about 7 cm long located in the U bend and most

probably caused by stress corrosion cracking. The initial

break flowrate was about 15 kg/s (300 gpm).

3.3. Mitigation phase (fig. 3.1., between points D and L)..

The faulted S.G. was completely isolated on the steam side,

but the isolation of the steam discharge to the turbo-pump

was omitted.

The atmospheric steam dump valve setpoint of the affected

S.G. was set at maximum pressure to avoid steam release from

this S.G.
25

A third charging pump was started in an attempt to

compensate the leak rate.

By steam discharge to the atmosphere from the intact S.G.

(point D), the operator started to cool down the plant,

causing a decrease in temperature and a faster

depressurization rate at t. + 15 min, in the RCS.

At t. + 18 min, the operator tripped the primary pump of the

affected loop to reduce the RCS heat input.

At t. + 20 min, the safety injection signal was generated on

low RCS pressure (117 bar) (point E) which caused the

emergency diesels to start, initiated the containment

isolation phase A, and caused ventilation isolation of the

reactor building.

When reaching a pressure of 107 bar in the RCS (point F) all

four HPSI pump injection started and stabilized the RCS

pressure.

Steam discharge from the intact S.G. caused a water level

drop below the low setpoint of 0.9 m on the narrow band

level gauge (point G) and opened both steam discharge lines

to'the turbine driven auxiliary feedwater pump. This

resulted in a quick pressure decrease of both S.G.'s (point

H) followed by a rapid increase in the SG.-A water level. The

steam discharge from the affected S.G. through the turbine

driven auxiliary feedwater pump was stopped about 8 min.

later (POINT I) during which time about I ton of steam was

released.

In an attempt to reduce the leak rate by equilibrating the

RCS pressure to the affected S.. the operator started the

primary pump B and used the full pressuriser spray capacity

(point J) which caused a rapid drop of the RCS pressure.

Vapour condensation in the pressuriser, combined with the

full HPSI capacity caused a rapid increase in the water
26

inventory such that the pressuriser water level went off

scale high (point K) at which time the operator stopped the

pressuriser spray. This caused the pressure to increase from

75 bar to the cutt-off head of the HPSI pumps and stabilized

at 107 bar (Point L).

3.4. Safety injection cancellina phase (fig. 3.1 between L and

R)

A further primary pressure decrease was mandatory to

reduce the break mass flow rate and avoid flooding of the

SG-B main steam lines;

avoid the opening of the safety valves of the faulted S.G;

start as soon as possible the shutdown cooling system (28

bar).

Therefore the operator first tried to cancel the S.I. signal

in order to be able to trip the HPSI pumps. A circuit fault

however did regenerate the S.I. signal on low RCS pressure

after reset, each time requiring about 5 min before resetting.

After about 20 min, the concerned bistables were flicked over

manually which cancelled definitively the SI signal.

Three HPSI pumps were tripped (point M) and soon after (point

N) the remaining pump was stopped after checking the

subcooling margin. The RCS pressure dropped to about 65 bar

(point 0), for which pressure the charging system compensated

the leak rate.

An attempt to open the letdown line failed as the isolation

phase A also eliminated the compressed air supply in the

reactor building.

It took the operator about 20 min to restore the air supply

and to open the pneumatic isolation valves of the letdown line

(POINT P).
27

After stopping a charging pump (point Q) the pressure

decreased to the point where the residual heat removal system

could be coupled to the reactor coolant system (point R).
28

TABLE 3.1.

SGTR : CHRONOLOGY OF EVENTS (PLANT COMPUTER)

Actual time Elapsed time (s) Computer diagnostic Comment or set point

19.20.00.00

19.22.50.47

19.23.15.67

19.23.30.67

19.23.32.17

19.23.32.77

19.23.36.37

19.23.37.57

19.23.41.77

19.25.42.37

19.26.14.05

19.30.29.77

19.30.30.07

19.30.31.28

19.35.37.87

19.37.19.57

19.38.31.65

19.38.59

19.40.17.88

19.40.19.18

19.40.19.18

19.40.19.27

0.0

170.47

195.67

210.7

212.2

212.8

216.4

217.6

221.7

342.4

374.0

629.8

630.1

631.3

937.9

1039.6

1111.7

1139.0

1217.9

1219.2

1219.2

1219.3

(rupture assumed)

demand for higher charging

flow

pressure in pressuriser

below reference

PR heaters OFF

1st letdown orifice

(closed/2CV024)

2nd letdown orifice

(closed/2CV025)

Pressuriser low level

alarm

Letdown valve 2CV022 closed

Pressuriser block valve

2PR008 closed

Spray valve PRO08 closing

Low RCS pressure alarm

Low-low pressuriser pressure alarm

High level SGB (1/3)

High level SGB (2/3)

(L >65 %)

Computer saturation starts

start 3rd charging pump

start cooldown with SG

Computer saturation stops

Reactor coolant pump B

tripped

Low pressure in SGA

Pressuriser pressure <

118.5 kg/cm2

SCRAM (from SI generation)

Diesels start

High flow. in MSB (at

venturi)

LPR = 25 %

LPR < 25 %

PREF = 155 bar

LPR

LPR

20

220

LPR e 20 %

LPR <(20 %

LPR< 20 %

P .145 bar

P\<145 bar

p C155 - 1.8 bar

p .147 bar

LSGB )65 % (= 2,36m)

LSGB V65 %

assumed

normal

PPR 117 bar
29

TABLE 3.1.

(continued)

SGTR : CHRONOLOGY OF EVENTS (PLANT COMPUTER)

Actual time Elapsed time (s) Computer diagnostic Comment or set point

19.40.19.27

19.40.19.57

19.40.23.49

19.40.23.61

19.40.23.66

19.40.23.75

19.40.23.77

19.40.24.19

19.40.24.20

19.40.24.31

19.40.24.45

19.40.24.49

19.40.24.60

19.40.33.07

19.40.33.37

19.40.33.67

19.40.34.87

19.42.04.27

19.42.55.87

19.43.48.32

19.44.02.47

19.44.39.14

19.44.42.37

19.44.50.77

1219.8

1219.6

1223.5

1223.6

1223.7

1223.8

1223.8

1224.2

1224.2

1224.3

1224.5

1224.5

1224.6

1233.1

1233.4

1233.7

1234.9

1324.4

1375.9

1428.3

1442.5

1479

1482

1490.8

1609.2

Ventilation isolation in

containment

Containment isolation

(phase A)

Start command SI pump D

SI pump D started

Start command SI pump A

SI pump A started

Isolation of compressed aiz

Safety injection alarm

Start command SI pump C

SI pump C started

High MS flow B stopped

Start command SI pump B

SI pump B started

Valve 2SI011 open

Valve 2S1009 open

Valve 2SI127 open

Valve 2SI125 closed

Computer saturation starts

Computer saturation stops

Very high AFW flow

(2FW-51) to SGA

Low level in SGA

Very high AFW flow to SGB

Steam admission valve (SGB)

to turbopump open

Steam admission valve (SGA)

to turbopump open

Very high AFW to SGB

SI

SI

SI

SI

SI

SI

SI

SI

Cold leg A

Cold leg B

Downcomer

Downcomer

L ý<25 % (0,9 m)

TP starts

TP starts

19.46.49.24
30

TABLE 3.1.

(continued)

SGTR : CHRONOLOGY OF EVENTS (PLANT COMPUTER)

Actual time

Elapsed time (s) Computer diagnostic Comment or set point

7 1 1-

19.46.22.70

19.46.28.87

19.46.40.05

19.48.01.15

19.48.02.00

19.53.12.00

19.53.12.44

19.55.05.72

19.56.33.67

19.57.10.87

19.57.28.57

19.58.09.67

19.58.12.97

19.58.33.07

19.58.33.67

19.58.47.77

19.59.37.17

20.00.15.15

20.00.15.16

20.00.21.05

20.03.20.77

20.03.24.07

20.03.52.57

20.05.05.00

1582.7

1588.9

1600.0

1681.1

1682.0

1992

1992.4

2105.7

2193.7

2231

2249

2287

2293

2313

2314

2328

2377

2415

2415

2421

2601

2604

2633

2705

Low pressure in SGB

Low level in SGA

Low pressure in SGB

High AFW to SGB stopped

Computer saturation starts

Computer saturation stops

Motopump B disarmed

Start of primary coolant

pump B

Reduce charging pump speed

Pressuriser level normal

PR heaters on

Spray valve 2PRO01 closed

Spray valve 2PR002 closed

Spray valve 2PRO01 not

closed

Spray valve 2PR002 not

closed

High pressuriser level

Very high pressuriser level

LSGA <25 %

Trip turbopump

Trip motopump B

manual

PR level normal

LPR >25%

spray stopped

spray on

I

I1

L >130

PR 7

LPR Ž.71

Reset command all SI pumps

SI cancelled

SI generated

Spray valve 2PR001 closed

Spray valve 2PR002 closed

High level SGA

High level SGA (2/3)

L >65 %

SGA ;00

LSGA > 65 %
31

FIG 3.1

EVOLUTION OF SOME IMPORTANT SYSTEM PARAMETERS DURING TRANSIENT

a)

HOT LEG

TEMPERATURE

b)

REACTOR

COOLANT

PRESSURE

250 18 19 A 0 20 21 22 23 t(hrj • l &,•

I I .1 .c

150 "---O

A

ISO A___ ISO

12S ___IL M ___~

120 1

RECORDERS

TR / RCOS

PRA / RC'I 75

_ 

P0_ I _:Nf - 75

:-- 25

So

2S

25

c) 100 I I.- -.4 --

IlevelI

A

PRESSUHIRZER

WATER

LEVEL

_- IJ.._

LRCA/PRII

0

B i

SO

d) bar

30 STEAM

GiENERATOR

PRESSURES 20

10

PRIMS4A

PR/ MS4

LR I FW9A

LR / FW9B

e)

STEAM

GENERATOR

WATER

LEVELS

DOEL 2 - SGTR INCIDENT 25 JUNE 1979
FIG 3.2 SEQUENCE OF EVENTS ( D OEL 2 - SGTrI? 4)

0 6?0 1200 f800 .2400 t (Sj 3000

BREAK

1

cv 2

3

LETDOWN

HPSi

RcP A

B

MI/A .3 pa/ I//

938 1040 11342- 1354 f681 2000

0171S

900S

LpR c2011

PpI < f17 bor

1~X.

111 S 21055

LPR <20 % 22483 K, 2108S •--22117S

900S

X PLANr COMPUTER r'lm 1482S 1900,S

.0 ESTIM7ATED TlINE 1R4ORDIA3 1/28 X

I 479, (-- 1992 S

I1 TRIP SET POINT

-l/l PLAmT CO NPUTER SATURAT 4f82 S goOs

, I I _ _ _ _ _ _ _

cJJ

HEATERS

SPRAY

STEArI A

DISC14ARGEJ13

AFW -

TP

0

to = 19.20 h

1'o zo 30 40 t (rmin) 50
33

4. CODE AND MODEL DESCRTPTTON FOR PLANT SIMULATION

The code used was RELAP-5 MOD-2 cycle 36.01 and was processed

on a CDC machine CYBER 176.

The simulation was performed over a period of 2700 s, starting

at the estimated time of rupture at t. w 19hr 20 min. (Point A

on fig. 3.1) This period covers the most interesting plant

transient phenomena.

The input data deck for the base case is joined in annexe 2.

In order to understand and interpret the main parameters of

the input data deck, the general and special nodalisation

features are described in this chapter.

The general nodalisation philosophy is a compromise between

precision and economy. For the primary system, a minimum

transport time of 0.15 s was selected, at nominal conditions,

'leading to a four volume representation of the core. The

minimum length of the loops was taken to correspond to the

length of the horizontal section of the cross over legs. In

the U tube bundle, the number of axial nodes is based on a

rule of thumb of about 20 AT per volume, in order to obtain an

acceptable heat transfer and temperature drop between primary

and secondary. This resulted in 10 axial nodes in the upgoing

leg, and 5 axial nodes in the descending leg of' the U tube

bundle. This also sets the volume length in the riser of the

S. G.

The simulation of the S.G. separator and dryer region was

principally based on the RELAP-5 requirements for the

mechanistic separator model, as recommended inithe manual

(Ref. 4).

The pressuriser nodalisation was chosen fine enough to

accommodate large insurges and outsurges. All important

structures were modeled as heat slabs in order to properly

account for the important structural heat exchange between
34

structures and fluid during important temperature (or

pressure) changes in the system.

For completeness, also the heat release to the containment was

accounted for.

This resulted in the nodalisation scheme as shown in fig.

4.1., consisting of 154 volumes, 158 junctions and 164 heat

slabs (563 mesh points).

The remainder of this chapter explains the detailed

nodalisation features for the

reactor vessel

primary loops

S.G.

pressuriser.

Furthermore, special nodalisation features are described for

the leak simulation

the high pressure safety injection system

the charging and letdown system

the pressuriser spray and heaters

the S.G. atmospheric steam dump valve

the auxiliary feedwater system.

4.1. Nodalisation of the primarv coolant system and S-G_

The numbering logic for the RCS system is as follows

a. reactor vessel components 010 - 099

b. B loop components 100 - 199

c. A loop components 200 - 299

d. pressuriser components 300 - 399

e. Steam generator (secondary components) : 600 - 699 (SGB)

700 - 799 (SGA)
35

Table 4.1. compares the calculated steady state conditions at

100 % power with the nominal plant values for most relevant

parameters.

Table 4.2. summarises the geometrical data, in terms of free

volume, coolant mass inventory at 100 % power and the

structural mass inventory which are compared to nominal plant

data (where available).

4.1.1. Reactor vessel nodalisation (volumes 011 - 099)

Table 4.3. summarises the dimensions of the hydrodynamic

components corresponding to the volume arrangement shown in

fig. 4.2.

Table 4.4. summarises the individual pressure losses in the

reactor vessel from which the junction form loss factors are

derived.

4.1.2. Nodalisation of the primary loops (volume numbers 111 -

153, 211 - 253)

Tables 4.5 and 4.6 summarize respectively the dimensions of

the hydrodynamic components for the loops B and A.

The nominal pressure losses in primary loops (hot leg,

intermediate legs and cold legs) amount to 0.31 bar.

Additional form loss factors have been added in the junctions

of the intermediate legs, such that the frictional plus form

losses in the primary piping add up to this nominal value.

4.1.3. Nodalisation of S.G. U tube bundle (volumes 121 - 125,

221 - 225).

The detailed nodalisation for I SG is shown in fig. 4.3. and

table 4.7 summarizes the dimensions of the hydrodynamic

components on primary and secondary side.
36

As seen in table 4.7, all U tubes have been globalised into

one pipe with 10 volumes on the hot side (122/01 - 122/10) and

5 volumes on the cold side (124/01 - 124/05) with a total area

of about 1 M2 . For the simulation of the leak, the volumes

122/09 and 122/10 have been replaced by I branch 123 in order

to accommodate the leak junction.

The frictional pressure losses in the U tube bundle are based

on a drawn tubing roughness of 0.1 micron and a hydraulic

diameter 19.66 mm (inside diameter of 1 tube).

Additional form-n loss factors for contraction and expansidn are

added for the hemispherical bottom of the SG primary sides, in

order to obtain a total pressure loss of 1.56 bar between

inlet and outlet of a steam generator.

4.1.4. Simulation of the primary pumps (Vol. 140, 240).

The .pump geometrical data are summarised in table 4.5.

Inlet-outlet form losses :

The pump inlet and outlet form losses are chosen to obtain the

nominal loop pressure drop corresponding to the nominal pump

head.

Apf

pressure vessel

steam generator

primary loops

pump inlet-outlet

2.16 bar

1.56 bar

0.31 bar

0.295 bar

4.325 bar

Buoyancy head - 0.050 bar

Nominal net pump head : 4.275 bar

Pump hydraulic data :
37

Since not enough data are available, the built-in

WESTINGHOUSE PUMP model was selected as a best guess.

The pump hydraulic torque, the motor torque and the

frictional torque at nominal speed (990 RPM) are based on

the nominal pump head (58 m), the volumetric flowrate (4.826

m3 /s) and the pump gross power (2.44 MW).

The frictional torque at zero was taken from the measured

value for cold water and adjusted to hot water conditions.

4.1.5. Pressuriser nodalisation

Table 4.8. summarises the geometrical data for the

hydrodynamic components of the pressuriser and the surgeline.

The pressuriser spray is taken from volumes 152 and 252 in the

cold legs and forced in volume 317 of the pressurizer, by

means of 2 time dependent junctions (J345, J346) to correspond

to a nominal maximum spray flow rate of 1500 1/min when spray

valves are fully opened.

Fig. 4.4 provides pressuriser level data.

The pressuriser level taps are connected to a 'P cell which

effectively compares the weight of a reference water column to

the weight of the water (and steam) in the pressuriser.

The electrical signal, corresponding to a pressure difference

varies between 0 and 100 % for water level varying between

lower tap and upper tap. Hence, one can write.

Level 100= AP1- = 100 x H

SP1oo -APo I H -e H
38

wherein : g = earth gravity

= density

H = distance between level taps (= 8.243 m)

h = height of hydrodynamic volume

subscript i - index of hydrodynamic volumes in pressuriser

z = water level

v = vapour at saturated conditions

1 = liquid at saturated conditions

o=0%

100 = 100 %

The pressuriser is equipped with various level measurement

cells which are of two types

a. cold calibrated at atmospheric pressure and 600 C.

In this case the values of the densities of water and

vapour are constant at I bar and 600C.

Ze s6e- C- I

Hence Lc (%) 100 x

superscript c cold calibrated conditions

b. Hot calibrated conditions at nominal power

p - 155 bar (saturation)

Hence Lm - 100 x W()

superscript h - hot calibrated conditions

Since there is no adjustment for different fluid temperatures

in the pressuriser, there can be a strong difference between

the real (collapsed) water level and the measured level with

the hot or the cold calibrated cells. This relationship is
39

shown in fig. 4.5 for different fluid conditions in the

pressuriser.

By means of the control variables, the various water levels

are calculated in the program :

CNTRLVAR 900 : calculates the collapsed water level

CNTRLVAR 901 : calculates Li (expression (b) above)

CNTRLVAR 902 : calculates Lc (expression (a) above)

using the summation control variable with

HOT' COLD

gain = 2.515 10-5 1.2459 10-5

&gH - CvgH

Lconstant - e, gH - 8248 Pa 0

4.1.6. Nodalisation of the S.G secondary side.

Fig. 4.3. illustrates the correspondence between real S.G.

volumes and RELAP-5 nodalisation.

Table 4.7. summarises the geometrical data for the various

hydrodynamic components of the S.G. and the main steamlines up

to the MSIV valves.

The single junction forward form loss factors are chosen in

order to obtain a nominal recirculation of 6. This is mainly

controlled by the junctions 617 (K, - 3.3), 6231 (Kr - 20.4),

6232 (Kr - 1.0), and 623,33 (K, - 1.81) around the separator.

Since strong reversed natural circulation was observed during

some calculation, very large reverse form loss (Kr - 1000)

factors were introduced in the downcomer, the junctions into

the feedwater inlet plenum and the separator.
40

The S.G. outlet venturi was modelled in the outlet junction

630/01 with effective venturi area of 0.13 m2 (KM = 0.2269, Ki

= 0. 4969).

4.2. Special code models and options

This paragraph deals with some code models which were

incorporated especially for simulating the .SGTR event.

4.2.1. Steam generator B tube leak model.

The break junction is modelled as a single junction (3618)

connecting the outlet of a pipe component (V 122) on the

primary side to a branch component (V 621) on the secondiary

side. The cross flow junction option (S = 3) was used with an

orifice type form loss (K, = KR = 2.6). With these options,

the area of the junction was adjusted to a final value of

1.724 cm2 for which the calculated water level rise in the

affected S.G. matched the recorded data (fig. 3.1 - e). Since

the plant was close to a hot shutdown condition without any

normal feedwater addition, the resulting water level signal

demonstrated almost a straight line from which the leak rate

could be determined a posteriori with acceptable precision.

The initial break flowrate determined in this way amounts to

14.9 kg/s (= 300 gpm), and the adjusted area of 1.724 cm2

corresponds to about 57 % of the croassectional area of I S.G.

tube.

4. 2. 2. High pressure safety injection

From the plant computer information, it turned out that I SI

valve for downcomer injection closed at t = 19.40.34.87.

Shortly afterwards the plant computer was satured during 12

seconds and it is not known if the valve was opened manually.

However, since the RCS pressure during the SI period stays

close to the cut-off pressure of the HPSI pumps, one should

infer that downcomer injection did take place with 4 SI lines

to the primary.
41

Hence the programmed HPSI delivery curve used corresponds most

likely to the configuration of figure 2.3. Owing to the

uncertainty of direct downcomer injection, only two SI

injection points were modelled in both cold legs. Hence,

coldwater taken from TDV (170, 270) at 15 0 C, is injected for

50 % in cold leg A (TDJ 271) and 50 % in cold leg B (TDJ 171)

with a RCS pressure flowrate dependance corresponding to the

flow delivery curve of fig. 2.3 (4 pumps). The table trip

number 571 simulates the generation of a SI signal when

pressure in pressuriser drops below 117bar. The SI flowrate

look-up table consists of a compensated RCS pressure (CNTRLVAR

070) and SI flowrate.

Instead of taking the local pressure at the injection points,

for controlling the SI flow, the upper plenum pressure was

taken (V043) combined with a numerical smoothing as follows

PCuz) - 0.9 POLD + 0.1 Po4'3MEW)

This technique may introduce a lag time (7.5 seconds to 96 %)

but avoids strong fluctuations in the SI flow due to strong

pressure feedback between injection volume pressure and

corresponding SI flow.

4.2.3. Steam generator A atmospheric steam dump valve

The steam relief capacity of this valve corresponds to 5 % of

the total plant steam flowrate of 666 kg/s. The valve (V791)

was modelled as a motorvalve for which the flow area was

adjusted to yield the nominal relief capacity at nominal

pressure (i.e. 33.3 kg/s at 72 bar) with Kr = KP = 1.0.

The valve was programmed to open with a constant rate between

900 and 1200 s. The exact actuation of this valve is not

recorded. In order to reduce excessive water level swell by

sudden opening of this valve, a duration of 300 s was selected

(see also chapter 7).
42

4.2.4. RCS charging and letdown system.

The charging and letdown flowrate were not monitored during

the event, hence a best estimate reconstruction has been

implemented, based on the plant conditions at the time of the

break, and the plant computer data.

The plant is equipped with three volumetric charging pumps.

Per pump, the minimum charging flow is 8.7 m3 /hr (= 2.42 kg/s)

at 140 RPM

the maximum charging flow is 14.7 m3 /hr (= 4.08

kg/s) at 234 RPM

One assumes that at the moment of the tube rupture, one

charging pump was operational at 50 % flow capacity or 3.2

kg/s.

At on elapsed time of 170 s, the plant computer signals a need

to start an additional charging pump, from which is inferred

that the maximum charging capacity of 4.08 kg/s is reached in

170 s, and that a second charging pump is actuated at full

speed (additional 4,08 kg/s). A third charging pump is added

around 900 a (estimated time, since computer was saturated

between 938 s and 1 040 a), for which again full speed was

assumed in order to cope with the primary coolant inventory

loss.

From the computer information, it is known that 2 letdown

orifices of each 10 t/hr in nominal conditions, were open at

time of the tube rupture. Furthermore, there exists also a

leak path via the primary pump seals back to the CV tank.

The initial letdown flow was estimated from the required

charging - letdown flow mismatch during the heat-up phase in

order to maintain a constant water level in the pressuriser.

A total thermal heat input of 11.85 MWth (decay heat + 2

primary coolant pumps + pressuriser heaters) at a RCS pressure

of 155 bar and 2550, would lead to an isobaric volumetric

expansion of 4.38 10-3 m3 /s, which can be compensated by an

excess letdown of 3.6 kg/s (density = 804 kg/m3 ). Hence the
43

initial letdown flow was taken at 3.6 + 3.2 = 6.8 kg/s and

maintained constant until the letdown closes at 170 s.

It should be recognised that a maximum net charging flowrate

of max. 12.24 kg/s is not much smaller than the initial

estimated leak flow of 14.9 kg/s. The resulting pressuriser

level evolution could hence be affected by a very large

uncertainty.

4.2.5. Pressuriser spray and heaters

The pressuriser heaters are incorporated as a heat source of

850 kW in the heat slab bounding pressuriser volume 312. The

actuation logic for the heaters is such that the heaters are

switched off when the water level drops below 20 % (variable

trip 580) and are switched on at an elapsed time of 2248 s

(variable trip 542) conform to the plant computer data (fig.

3.2).

The pressuriser spray lines are simulated explicity, except

for the spray flowrate which is controlled, not by the

pressure head of the primary coolant pumps, but by 2 time

dependent junctions (J 345, 346) in order to force a nominal

spray flow of 1500 I/min when the spray valve is opened (see

nodalisation on fig. 4.1.). The spray flow is injected in

volume 317 which corresponds roughly to the elevation of the

pressuriser spray nozzle.

From the computer data, there is no trace for the opening time

of the spray. However, since the operator started the second

primary coolant pump (at an elapsed time of 2106 s) in order

to use full spray, it is assumed that the spray was initiated

a few seconds after starting the primary pump (variable trip

529) and stopped at an elapsed time of 2287 s (variable trip

530) as registered by the plant computer.
44

4. 2.6. Auxiliary feedwater system

The auxiliary feedwater motordriveu pumps (one for each SG)

are modelled by a TDV (605, 705) and a TDJ (607, 707) which

inject cold water (35 0 C) in the SG's, at a rate controlled by

the SG pressure (volumes 630, 730) conform to the delivery

curves for each motordriven pump (fig. 2.7).

For the turbine driven pump, the auxiliary feedwater flow to

both SG's and the steam flow to the turbine is evaluated by

means of a complex turbine driven auxiliary feedwater pump

control block (Fig. 4. 6) conform to the flow schematic of fig.

2. 6.

The turbine driven auxiliary feedwater pump flow to each SG

depends on the SG back pressure (PA, Ps) the pump head (P.)

and the flow resistances in the common branch, (Kp, c) and both

individual branches (Kp, a and Kp, b) as follows

P, - PA - Kp,cW2 p

W p,a = ------------------ (a)

Kp, a

P, - Ps - Kp, c W2 p W2 p,b = ------------- (b)

Kp, b

Assuming a known turbine driven auxiliary feedwater pump head

(Pp) and a total pump flow (Wp) from former cycle, the

individual flows can be evaluated by means of control blocks

865,866 and 868 conform to eq. (a), and by means of control

blocks 865,867 and 869 conform to eq (b). The total turbine

driven auxiliary feedwater pump flow is then obtained in the

adder 872.

Knowing the total pump flow, one then can evaluate the pump

head (Pp) from the known pump characteristic

n 2 n t

Pp = (--) Pp,o - Kp IWp - (--) Wp, o (c)

no no

wherein Pp,o is the maximum pump head

Wp,o is the net pump flowrate at max. pump head

Kp is the pump loss factor
45

n/no is the speed ratio of the turbine driven

auxiliary feedwater pump

The expression (c) is evaluated in control blocks 880, 881 and

882. Knowing the total pump flow (Wp in block 872), one can

also calculate the required pump power in blocks 874 and 875

conform to the expression (d)

n 3 no

Vp = (-- ) Vp, f + d (--) Wp] d)

no n

Wherein Vp,f is the power required at zero flow (friction)

d is the power coefficient for given pump flow.

At this point one has to verify if the required pump power

does not exceed the maximum turbine power which is controlled

by the available steam flow to the turbine. Since such turbine

is supposed to yield full power for a large range of steam

pressures, the available steam from the SG is throttled down

to 9 bar at the turbine inlet valve and one can reasonably

assume that down to 9 bar in the SG' s, the turbine can provide

full power, which is rated at 368 kW.

Based on the general Rateau laws, one assumes that the power

varies with the third power of the speed, and for required

pump power above 368 kW (from d), the new speed ratio becomes:

368 n

--. = (C--) with limit : n s no

Vp no

The actual speed radio is evaluated in control blocks 876, 877

and 878.

Finally, knowing the turbine power Vp, one can calculate the

gross steamflowrate extracted from the SG at the highest

pressure; according to the turbine power-flowrate

characteristic (e)

Vp

Wv.T = W .* + -- (e)

t=A

Wherein : WY.T = Vapour f'lowrate to turbine
46

Wv~o = Vapour flow not producing work (dissipation)

AH = enthalpy drop of steam expanding from 9 bar

to atmosphere.

This is evaluated in control block 883 which gives the

steamflow extracted from I SG (at highest pressure).

Direct feedback from outlet to inlet is applied for

stabilisation purposes of some vital parameters such as Wp

(872), Pp (882) and Vp (875), whereby the new value at the

actual time step is based for 50 % on the output value of the

preceeding step and for 50% on the new input parameters.

The actuation control logic for the auxiliary feedwater motor

driven. pumps and turbine driven auxiliary feedwater pump was

not based on the water level program of fig. 2.6, for 2

reasons

First, the operator has taken over the auxiliary feedwater

system in the manual mode for some periods in the transients,

and secondly, to avoid the feedback of discrepancies in the

calculation of the water level into the operation of the

auxiliary feedwater system (see also chapter 7).

Hence, the actuation logic for this system was based on the

recorded timing for the start ?f the auxiliary feedwater

system, and on a best estimate timing for the trip of the

turbine driven auxiliary feedwater pump (logical trip 661

which goes into trip units 862 and 863 of the turbine driven

auxiliary feedwater pump control logic).
1/2

Table 4.1 : Comparison between systern nominal parameters and

(after stabilization )

cakulated steady state conditions

Component Variable Units Nominal Calculated Commrents I I I-.- .i=- -

GO3/02 , 03

C 140, C 240

C 140, C 240

C s3, C ill

Co2S C041

C I3s/oI, C131/1o

(GoIl/02)/(GoL3o2+03)

(G02S/02)/1(Go23/01)

T043

T043 - Tol3

Pf172

CV 6fO + CY71D

Primary coolant flow

Pump head

Pump speed

AP reactor vessel

AP core

A P steam cgenerator

Vessel head bypass flow

Core bypass flow

Vessel inlet temperalure

Vessel outlet temperature

At core

System nominal pressure

Total heat output

kg/s

ral / S

bar

bar

bar

0/0

O/0

Oc

ec

°c

bar

MtvW

3628.

58.

103.67

2.f6

1.

1.56

0.24

4.5

287.3

317.1

29.8

155.1

1192.

362G.7

58.

103.67

2.156

0.992

1.51

0.25

4.52

287.3

3 16.8

29. G

15.1

1iS2.

P 751.72

fixed input

-4

J. ~. .L I L... L _______________ I _________________________________________
2/2

Table 4.1: Comparison between system nominal parameters and calculated steady state conditions

(after stabilization)

Component variable Units Nominal Calculated Comments

J609, J709 Feedwater flowrale kg/s 333. 333. fixed input

J 63401 , 73401 Steam flowra(e Ic9/s 333. 332.G

T 610 Feedwater temperature 0 C 230. 230. fixed input

P630 SG steorn pressure bar SB.8 59.

CV GIl , 711 .SG dow.ncorrer water level M 11 .GG2 11.69

recirculahion ratio (6) 5. 7

CVe001 700 3G water mass kq 36220 3G030
TA8LE 4. Z

FRCC VOLUME• (;n) WATER -ASS (0t) SrUCTURAL NASS LEAT lO/PoWER 00- I

R.LAP AOHIMAL 6/.

RELAP NlOtiIJAL RrLAP NIONIMA L

I +

1

2

3

4

S

7

8

Reactor vessel

Hot legs

Cold legs

Pump suction legs

Pump caslriq

SG primary

Pressurtser

,5urge line

54. 3.?.

3.o015"

14.4r"

*. £ro

r',tall s-t ,

t.4133

3.27'

3 .1I

1.lxt

t.11.01

-i.3

,L .*

... ?

40.453

4.1 .1

1007

43IJ$

300, 94

1.10

9.16

lt1-t %

1.

-14

..........

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

I61. + -.. Total for primary coolantsyst. 0.1 ________ 4SU1., f _,_

10 SG secondary side . 13.S- C .- 3 _ __._"_ 59.94 if Steam tines _._____ oO,. .__. __t

f2 Cottector 3A.At 0.41,

13 Total 'or secondary side ___. ___,_ 694.31 (o o 11 -I 12)

14 Total for S.G componen.

(G 4 10)__ _ __ _ _ __ _ ___ __-

Grand totol M.13t -1 1-3-S S is
50

TABLE 4.3 Summary of reactor vessel nodalisotion (volumes)

( SED 'cl• TT-44/85)

Component AreQ Lerg1h Volume Watermarss Nlame Type.

rrLZ 6 n rn.3 k?9-

ot4 2.1 G9 1. 584 (3 .436) 2583 VDCO1;ER BRANJCH(2,

0!3 2.0874 0.872 (1.8 202) 1366 INOZZLE BRA 4CW (3)

015 1 , 41 4.083 (5.758) 4328 DOWNCOM ANNULUS(3)

021 (4.499) 0.638 2.679 2014 VtSBOT SNGLVOL

023 (8.4 )- 0.638 5.359 14029 LMIXPL BRANCW(3)

025 (3.52.8) 1.0j3 3.574 2;87 CQRINPL 5RANCH(2)

031 2.5 £4( 6o095] (G.095) 4333 CORE PIPE (4)

035 (0.808) 2.4-38 1. S706 1481 CORBYPS SNG.LVOL

0z9 (3.821) 0.rG085 2.5252 1t00 COREX BRANC1!(3)

041 (S,99Z) 0.8965 5.103 3512 CORPLEN SWG-LVOL

043 (5.902-) 1.584 9.349 6435" UPPLEN DRAWC4(3)

045 (5.901) 4.49G 8.833 6083 DOME.... BACH(1)

5C. 302 4 04513

) t data in brachets are riot enrered in input daora , but are

calculared by program from other inlered darc.
51

TABLE 4.4-:5Ut"11VAJY OF REACTOR VESSEL PRE.SSUQE DROP

Component numbersI Description I Nominal Calculated

V153 - Vill

W 02f02 1W 2,302

Wo 11o0/ Wf 1302 #03

V153 - V013

VO13 - V01503

V01503- V025

Y025 - V03101

V3Oio, 02, 034 04

J3fof ,02,03

V3104 - V041

V25 - V041

V041 - Viff

AP vessel (bar)

Core bypass 01v

Upper head bypass s/

Inlet nozzle AP(bar)

Downcorner AP(bar)

Lower plenum AiP(bcr)

Core support plate ,AP(bar)

Core rod frictiond AP(bar)

Core rod grids AP (bar)

Upper core plate AP(bar)

Total core AP (bar)

Outlet nozzle AP(bar)

2. 165

4.5-

0.24

0.372

0 .f2 4

0.524

0.2

0.19

0.4

0.2

1.

0.124

2.156

4.52

0,248

0.3623

0.1265

0.,538

0.197

0.195

0.398

0.207

0.992

0.127

A-I. &
52

TABLE 4.5 Summary oF primary [oop nodalisation vo[ume.s

-rIPST PRIMARY LOOP- (LOOP B)

14 OT LEG

Component Area Lcnq•h Volkrne , oftermQss Nome Type

r m2- mn rrt -

t1t 0.583 2. 4 7L (0.9/45o8) e-563 HTLGr 41 SNGLVOL

112 0.383 2.4"K ( 0.9403o8) G53 4TL&, f2 BRANCH

113 - 01 0.383 2..4 G (0.94.3o8) r•53 1rTLG t3 ;I-LVoL

7.4.28 2.844924 1959

PUMP SUCTION LEG

131- 01 0.487 1.806 (0.87952 £61 LSEALSi •BrZAwcif

412.- 0-1 0.487 1.806 (0.87552 ;GI b4l 2•. AtQc4

431-0o 0.487 1.633 (0.79527 596 L EAL3 B 2 ?tPF433-602 0.467 1.413 (0.9641 523

6.675 3.25072 2443 _

PUMP

440 1( 6.2927.) 1.232 7.757 5830 PUMP. PUMP

7.757 5 830

COLD LEG

151- 01 0.383 1.966 (0.754 ) 567 CLDLG&BI PIPE

02. 0.383 1.968 (0.754) 567

152. 0.S83 1.968 (0.754 ) 567 CLDLG.52- BRZPgcq

153 0.383 1.968 (0.754 ) 567 CLDLGB3 SWGLVOL

I 7.872 3 015 2268

( : dat'a in brochets are not entered In input dot , but are

calculated by prograrm From otlher inererd data.
53

TABLE 4.6 : Summary of primary loop nodalisation volumes

- SECOND PQIMARY LOOP - (LOOP A)

hOT LEG

Component Area Lerlncf Volume. raternmass Name Typeri M2 m rn,3 3 9

211- 01 0.353 2,4-K (0.946uc8) G T5 jTLGAI PIPE

02 0.33B 2. t'71 (0.1J6$cb) 65"3

03 0.sss Z.7-f; (0. 9LC) 46-c53

7.42S 2.64.492- 4959

PUMP SuCTION LEG

231 -01 0.467 4. 806 (0.87952Z)f 661 PIPE

02 0.487 1.806 (o0879522)• 661

03 0.487 4.633 (0,795271) 598

o4-, 0.4 87 4.43 (o.69G410)j 523

6.675 S.250725I 2443

PUMP

240o 6.2962G71 1.1212. 7.7S7 58z1 PV1t-lP jPumIp

7.757 5 831

COLD LEG-

'251- 01 0.383 1 .66 (0.754, ) 567 CLDLGAI PIPE

02 0.353 1.968 (0.754 ) 567

252 0.363 1.968 (0.754 ) 567 CLDLG A2. BRAWC'

1253 0.383 1.968 (0.754 ) 567 CLDLG-Al SNGLV

_ _ 1_ 7.872 3.015 2268

( )clra in. 6racI~ebs a~re nct ertered ih in~put d4~rc. hut Wt

c~.okulatec by prolrcrt1 Fý-ro orIhei inrerectd orc,
54

TABLE 4.7: Summary of steam cjeneratter nodalization (Vokrnes)

PRIMARY SIDE

lComponent Arecq Lenqth Votume Water mass Warne. Ty p en"m 2 m*71 t 3

124 - 221 (2.G 07) 1. C B /..392. 30Z4 INBOX BRAWCH (1)

125- 225 (2.607) 4.68 5 4.392 3301 OUBOX BRANCH (1)

422/01-,i0 0.99- ios0.908 (8.9B0) G436 OUTUB I PIPG (10)

222 /0 1aI0

124/014-V0 0.99 FA 4. 6 ( 8.989) 6697 DUTUB PIPE (5)

2G.762 49458

SECONDARY SIDE

(.42•- 712. S. 0,."f3-5 L S.315) 40,3 B 2, 12.- L•,•;ctGil - "11 C 8.02.9) O.697: S. g56 4318 rEED IX 1Y NG.LVOL

t15/01-715hi 2.589 1.938 (5.015) 3 8"5 SGLDCOW-i ANNULUS(4)

G15/oz--o4 0.o.81-5 3•2.550 (3x1.235) 2 8 IZ

715/0Z--04

620/01-0.04 4.432 4 1.816 (4x8.0485) 11 ZZS SG PIPE PIPE

720/01o- 04

Gzi - 7I 4,432 2.324 (10.300) 1 7CG s& RiSEr TdPRAkiCw

6?zz - ?2zz 4. 1 ,4.2 (5."1z') 0j 1Z "T)p Ri ID re-z, QCN

r..4 - 714 8.0146 Z. 4274 ( 59.'oe, 5-o75T -'ZPfSSS tZA~k•cq

6z3-723 4. 21.42 z4 9.654) 1-84 S EPARAT&R 'EPAP-ATR

G?-i-.7 $.s-& d, C 8.-' ) Zco PL5PJUtH8 9BP-WJC4

61o-11i 4 2. SC. 2.o3 2..2.6 se-7 S p4c1. 'bPZA&JCI

ST EAM LINJS

64c c4 c, Ise 2-Z.7471 (G;.s42) 2 CL. pIP

A O 04 c .*1 7- 12-________2- p P

S ©o o C..2 •.6 '/.. "4~ -L32

O2. ,,,c B

Oi , t " ) 2.SZ. _ _ _ _ _ _ _ _ _

03 #1 o " . .o

8s0o 01 a, 7.92 z .446 C 77.c. 2-.1 "SrGu A2. P I i;c

02. t It ( f 1t,3ao

01 IfI I It' 4

Soo 0.12.9 1 o 1(3 .82401 -113 )lCOLLEC-70~ I~ W

I 49-o.1 S44ý ý 5,9r.
55

TABLE 4.8 : Summary of pressurizer nodotisatiori (volumes)

Component] Area Length VoIu rr, e. IaermQss Nam e 7 ype.

no m2 m m 3--

310 1.6964 0.3 (0.509 ) 302. PRES3MO BRNCR

S11 1,6964 0.G (4.018 ) Go4 pES 3 BRANCH

312 2.51 ;4 4,.76 (. C)(.4 2417- P;,F S 312 5RAVHN

3 13 2.s614 4,.76G6 (4.444 2 c 28 143 'B RL AW

314 2.5144 1.539 (.&672.7 ) 2299 114 F•CLAC

315' 2,s164 4.545" (3. B123 $89 1,5 - .UCH

5 1 2. 5*1 G4 0.8 (2.0111 ) 2O 0 5 ! .AJCA317 2 .51G4 0.G (4.509S ) j5'4 3j7 BIcA

320-01 2.,S4 G4 0.4 ( i.OOGZ ) 103 PRES 32o PIPE"

02 4 .9C4 0.3 (0.50892) 52

03 1 .6994 0.2 (0.33929) 3s

04 4 .69G.4 0.45- (0.2541G) 2.6

0 5 4.6964 0.40 ( .Ue694) 17

0G 1 .964 0,10 (0.16S94) 17

I, 30 4.Gg94 0.05" O.064E2) P;!ESbri1 BR^ACH

24.15S;26 9 487ý - ____

SURGE LINE

301 -01 0.05875' 6 .3465 (0.24593) 4 6 9 SURGELN PIPE.

-0o 0.03875 G .146CS 0.24593) 46'

-01 0.03,75 /4 .07 0. 15771) 403

0.64957 4s8

6=-i

( ) : l in broches arre not eneredcl in input dara ,but are

catcuvacxted by program frorn other (ntered dota.


. r "

I. -
59

FIG4.2 DOrL 1/2 PEACTOP VESSEL NODALISATION

4-
60

FIG.4.3 DO1L 1/2 STE1AM GENEPATOP NODALISATION

134,43
61

FIG4.4 PPESSUPIZEP LEVEL

_ The level programmer Is linear between given limits *

Minimum level For a. no-Ilaod

Tav9 oF 26B.49c ( 556.S5eK) 24.G°50

/ oF level i

Maximum level for a feull laod

T.,c- oF 299.90c (572.75 OK) 58Yo of- level

~Pori.

-Level sport*

(oi) volume (below the pressure rap)

V = 1.5298 + 0.7297 = 2.2565 m 3

(02.) volume \ (berwee-, the pressure taps)

The secrion area. variation atono the 145mm

has beer, neqlceci.

V = 8.243 % 2.5164 = 20.74,34G m.3

(C) volume (above the pressure tap)

V = 1.16192 rn 3

volume Surge fine V= 0.94957 m3

The CONTPOL VARIABLE 900 9gves the collapsed water level

particular values

(-0.109) indicates that only the pressurizer is ei ipty

(- 0.14 ) indicates that both. the pressurizer and the surge

line are empty.

(+ 1.05) water solid conditLons

w Set point study for the DOEL nuclear power station (WENX 73/49,

november 30, 1973)

w Drawing} COCKERILL 4306/9 , 07.03.69 rev. 'K'27.03.72.
RELATIONSHIP BETWEEN REAL COLLAPSED WATER LEVEL AND HIEASURED LEVEL BY :

LEFT : COLD CALIBRATED AP CELL RIGHT i HOT CALIBRATED AP CELL

0'1

COLD CELL READING (X/L)

o', 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0,8 0.9 1.0 M

0

ULhi

rOt

No

CELL READING (X/L) . 0
FIG. 4. G TUPSOPUMP CONTR~OL SY.STrIY- (PW".A)

wp~

(86 $2 1._______ - p/

- sum - sum 05-wERI P0o 2 - SUM .. .

0 0. 10 a. 0 . (We) 0~~iI 0. P.

(eq2 4

) (C417) pp KPC 0

W1.0 calcuy(ates Pumvp heaid

1...3. ___._ -W)+Fe-TT8.--1

note: - I ) Di~c values for Scale factor (S) and njuttiplljer cowtoslatI (Ai) are qivcrn ;n labesIe - 2 2) Valves in parenthesis ( o re symbLols of intripeiesd ate por.arueters for diustration only (are riot rstlvitipheer.S)
64

5. BASE CASE RESULTS

The microfiches joined to this report contain the complete

output file for this case.

The results are discussed on the basis of an exhaustive set of

figures divided in several groups.

The numbering logic for these figures is as follows

group 2 pressuriser pressure

group 3 pressuriser level

group 4 primary coolant pressure

group 5 primary coolant temperatures

group 6 mass addition or depletion from primary system

group 7 primary system energy parameters

group 8 mass flow rates in RCS

group 9 miscellaneous for RCS

group 10 : pressures in SG's

group 11 : water levels in the SG's

group 12 : temperatures in the SG's

group 14 : mass addition or depletion from SG's

group 15 : mass evolution in SG's

To be consistent with the numbering logic of the figures in

this report, the chapter number (5) will preceed the figure

number.

The main results of the base case will be described on the

basis of these figures, whereby apparent anomalies will be

discussion in detail in chapter 6.

fig. 5.2.1. Pressure evolution in the pressuriser

For the initial depressurisation period (up to 900 s), the

calculated pressure drop agrees well with the measured

pressure drop (reconstructed from fig. 4 in annexe 1). When

cooldown starts at 900. the depressurisation rate increases

down to a pressure of 107 bar whereby the HPSI system stops

the depressurisation slightly below the HPSI cut-off head of

108 bar, and compares to a measured plateau pressure of 107

bar (figure 3 in annexe 1).

When the operator actuated full spray at 2106 s elapsed time,

a sharp pressure drop is calculated and observed, followed by
65

a repressurisation when the spray is stopped. The kinks in the

repressurisation are probably caused by anomalous vapour

condensation (or water evaporation) whenever the water level

crosses a volume boundary in the pressuriser.

. Fig 5.3.1. and Fig. 5.3.2. Pressuriser water level.

The curves shown are respectively :

The recorded water level (LRCA - PR1I) in dash-dot line

The collapsed water level L, =[o,,V -VbJ/A (CNTRLVAR 900)

wherein Vi is the volume of component i of pressuriser

Vb is the volume below the lower level tap (fig. 4. 4)

AV is the pressuriser volume between level taps

(fig. 4.4)

The hot AP cell level as calculated from expression b in

paragraph 4.1.5.

The cold AP cell level as calculated from expression a in

par. 4.1.5.

The collapsed water level drops below-the 0 % water level,

meaning that the pressuriser drains below the lower level tap,

down to the level of the hot leg connection.

The hot cell level, which is a &P measured with a 4P cell

calibrated at 100 % nominal condition, follows closely the

recorded water level during initial depressurization, whereby

the 0 level is reached at about 500 s. This close agreement

confirma that the leak flowrate, estimated from a water level

increase in the affected S.G., and the postulated charging

mi'nus letdown flow,are close to the plant values.

The cold calibrated water level measurement cell still records

a finite level since it measures the normalised weight of the

vapour in the pressuriser (see CONTROL VARIABLE 902).
66

During the period of pressuriser spray, the pressuriser fills

up with water which is about 150 0 C colder than the temperature

at which the AP level cells were calibrated.

From the calibration curves, shown in figure 4.5, one observes

that for fluid temperatures in the pressuriser around 2100C, a

hot cell reading of 100 % corresponds to a collapsed water

level of about 68%, which in turn would show a reading of 60 %

on the cold calibrated gange. These were also the values which

were calculated in the very first simulation study (by means

of RELAP-5 MOD-I). As will be seen further, the calculated

cooldown is larger, resulting in a stronger depressurization

during spray, and a faster fill-up of the pressuriser.

At 2500 s, the plant recorded level, the hot cell level and

also the collapsed water level reach about 100 %, while the

cold gauge indicates 80% water level. These calculated data

are consistent for an average fluid density in the pressuriser

of 800 kg/iM3 corresponding to an average fluid temperature of

249 0 C (522 0 K) (the fluid temperature in the pressuriser varies

between 473 0 K and 588 0 K).

The calibration line for 249 0 C has been added in fig. 4.5.

. Fig. 5.3.2. compares the measured and calculated pressuriser

level by means of the hot calibrated AP cell (the only two

quantities that merit exact comparison). The agreement is good

during the initial depressurization. For the remainder of the

transient no conclusion can be drawn since the values are

limited artificially between 0 and 100 %.

Fig. 5.4.1. pressure evolution in hot leg A.

The calculated pressure drop agrees very well with the

recorded pressure evolution except for two periods,

respectively at the initiation of the cooldown (around 1000 s)

and during the pressuriser spray period (between 2106 and 2287

seconds).
67

Since the exact timing and opening rate of the intact SG

atmospheric steam relief valve are unknown (see also chapter

6.1) the discrepancy at the initiation of the cooldown must be

attributed to unprecise boundary condition rather than code

errors.

The excessive depressurization during the pressuriser spray

activation is caused by excessive cooldown of the RCS as will

be further discussed in chapter 6.2.

Figures 5.5.2. till 5.5.9. : Temperature evolution in the

primary loops

figures 5.5.4, 5. 5. 5., 5.5.6 and 5. 5.7., for which

corresponding recordings exist, all manifest too stronJ a

cooldown of the RCS by the intact steam generator, and will be

discussed in chapter 6.2.

The temperature discontinuity at the time of the trip of the

main coolant pump in the affected loop (at 1112 s), visible in

figures 5.5.7 and 5. 5. ) results from a flow reversal in the

loop, whereby cold HPSI water, injected in the cold legs, is

now redirected towards the pump and influences the temperature

sensor (2RC29) located between the HPSI location and the pump.

This sudden temperature drop is not noticeable in the

recordings. This may be caused by injection of all HPSI in

both cold legs, while in the plant at least one! injection line

to the downcomer was open.

Fig. 5.5.9. illustrates clearly the increase in the vapour

temperature at the pressuriser dome between 1200 a and

initiation of pressuriser spray, due to structural heat

release from the pressuriser walls to vapour, leading to a

superheat of about 90C. This structural heat compensates the

vapour condensation at the steam/water interface and maintains

a high pressuriser pressure, during the SI phase.

During the spraying period, the pressuriser temperature is

following the saturation temperature. When the spraying is
68

stopped, a water piston effect is seen whereby the vapour is

compressed adiabatically to about 40 0 C superheat at which

point the heat losses to the structure surrounding the

pressuriser dome (VOL 320), leads to a final reduction in the

vapour temperature from 635 0 K down to 622 0 K.

This figure may illustrate why the simulation of the

structural heat of the pressuriser is important in order to

understand the real pressuriser behaviour, and may explain why

the pressuriser cannot be filled up due to the HPSI injection

when heat is released from the structure to the vapour in an

empty pressuriser, until spray is initiated. A volumetric

balance shows that the HPSI water injected in the RCS

compensates the primary coolant shrinking without increasing

the water level in the pressuriser, as can be seen also from

figs 5.3.1. and 5.8.3.

. The figures of group 5.6. illustrate various RCS inflow and

outflow quantities.

Figures 5.6.1 and 5.6.2. illustrate the evolution of the

break mass flow'rate. While fig. 5.6.2. shows the break flow

rate as calculated, fig. 5.6.1. shows the result of a

integration differentiation operation intended to smooth out

the calculated flowrate when the value oscillates from one

cycle to the next (which was observed in a former calculation

by means of the code RELAP-5 MOD-I).

Since no such oscillation are present, which is a remarkable

improvement in MOD-2, both figures yield essentially identical

results except close to time zero.

The mass flowrate clearly follows the pressure evolution

except for a gradual increase between 1500 s and 1900 s due to

a decrease in the affected SG pressure (see fig. 5.10.1),

since the junction flowrate is not choked during this

transient.

Fig. 5.6.5. shows the charging and the letdown flow rates.

While the letdown closes at 41 s due to low pressuriser level,
69

the charging flow increases in order to maintain the

pressuriser level. Since the breakflow exceeds the charging

flow a'second pump is started at 170 s, and the third charging

pump starts at 900 s.

Fig. 5.6.6 illustrates the HPSI mass flow rate. With a

compensation logic for the HPSI flow (see chapter 4.2.2)

relative strong fluctuations are observed due to minor

variations of the back pressure (fig. 5.4.1). For future runs,

the lag due to the compensation, should be reduced.

Combining all inflow and outflow from the primary system, one

obtains figure 5. 6. 3, illustrating a net coolant loss until

the third charging pump was started around 900 s (when

pressuriser was empty), and a net inventory increase when the

HPSI pumps start injecting at 1200 s.

Fig. 5.6.10. illustrates the variation of the primary

coolant inventory (integral of fig. 5. 6. 3).

Figures of group 5.7 illustrate various energy fluxes in the

primary system.

The core thermal power is shown in fig. 7.1. The increase from

6 HWth to about 7 MWth between 900 and 1500 sec. results from

the cooldown initiated via intact SG. The power spike at

2120 a coincides with the start of the second coolant pump

whereby colder water (AT- 51C), accumulated in the cold leg of

affected loop, reverses direction and is forced through the

core.

The energy removed by the break is shown in figure 5. 7. 2.

Fig. 5. 7. 3. illustrates the energy transferred from the

primary to each steam generator (Heat input in the SG riser

volume).

This figure illustrates many important phenomena (physical and

numerical) which dominate the RCS behaviour.
70

In general, one observes that hardly any heat is transferred

via the SG's until the cooldown is initiated at 900 s.

The intact SG acts as a heat sink during the remainder of the

transient. The cooling power increases during the opening of

the SG relief valve (900 - 1200 s), again at 1428 when the SG

moto pumps, and at 1482 when the turbine driven auxiliary

feedwater pump start injecting cold auxiliary feedwater in the

intact SG.

The affected SG becomes a heat source which explains the

asymmetric behaviour of a plant under SGTR conditions.

Even when the turbine driven auxiliary feedwater pump is

started at 1482 s, the affected SG acts as a heat sink

(contrary to expectation).

The sudden power reversal to the affected SG at the instant

the turbine driven auxiliary feedwater pump is tripped (1900

s) is caused by an anomalous SG behaviour and will be

explained in chapter 6. 3.

The very large heat extraction by the affected SG between

1900 and 2100 s reinforces the excessive cooldown of the

primary systam enhancing the discrepancies observed in the

primary cooldown rate and the ensuing excessive

depressurization during the spray period (e.g. fig. 5.4.1,

5.5.5, 5.5.8).

Fig. 5.7.4. expresses the heat flux extracted from the SG

tubes (primary side) and is basically identical to fig. 5.7.3

except for the sign, the structural heat in the SG tube bundle

and possible heat exchanges between riser and surroundings.

Fig. 5.7.5. illustrates the net energy balance in the

primary system, and shows that the net energy balance is

mostly negative (leading to a sustained depressurization)

except during the spray period which is caused by the very

large injection of HPSI water, with small but non negligible
71

energy content. The large spike around 1900 s is caused by the

sudden energy extraction by the affected SG (see chapter 6.3).

Fig. 5.7.6. illustrates the structural heat input

respectively in the pressuriser and the total primary system.

It is important to note that the core residual heat is about

6MW and at the end of the cooldown period, the structural heat

input (before spray) also reaches a value of 6 MW, hence

illustrating the importance of modelling structural heat

release.

The sudden increase in structural heat release when spray is

actuated results from a strong cooldown of the pressuriser

shell in contact with cold water, combined with the actuation

of the pressuriser heaters at 2230s.

Figures of group 5.8 illustrate flowrates internal in the

reactor coolant systems such as the loop flowrate (fig.

5.8. 1.), the surgeline mass flow rate (Cig. 5.8.3) and the

pressuriser spray flow (fig. 5.8.5.).

The surgeline mass flow rate remains negative, indicating

pressuriser emptying until the HPSI is actuated at 1200 s.

However, the filling of the pressuriser does not start until

the spray is actuated.

The miscellaneous figures of group 5.9. illustrate

the subcooling in the primary system (fig. 5.9.2.)

The initial subcooling is very high corresponding to close to

hot standby condition (about 900C), and decreases due to the

RCS depressurization. When cold SI water is injected, the

pressure is stabilised while the cooldown continues leading to

an increase in the subcooling.

The anomalous strong cooldown at 1900 s is caused by the

excessive heat transfer to the affected SG (fig. 5.7.3.) and
72

causes a sudden increase in the subcooling around 1940 s. The

subcooling reaches a constant value around 1080C, until a

sharp drop occurs during the spray period; and increases again

when the spray is stopped.

status plot of downcomer fluid temperature versus downcomer

pressure ( fig. 5. 9..3. ).

On same plot is shown the limiting vessel integrity curve

(Reference temperature for nil ductility transition) for a 40

year plant condition. This illustrates the PTS (Pressurized

thermal schock) problem potential of such tansient.

- The integral mass balance in the primary system is shown in

fig. 5. 9. 9. ( Relative values)

Figures of group 5.10 illustrate-the pressure evolution in

both steam generators.

For the intact S.G. (fig. 5.10.2), while the calculated

depressurization rate is acceptable, there is a constant lag

between measured and calculated pressure. This discrepency may

be attributed to misjudgment in the cooldown initiation time,

or a time-shift problem in the recorded curves.

For the affected S.G. (fig. 5.10.3), several features show

up :

the calculated pressurization until 1482 s, is too high.

When the auxiliary feedwater is initiated at 1482 sjsteam

taken from this SG to drive the turbine driven auxiliary

feedwater pump creates a depressurization with a rate in

good agreement with the observed rate.

At 1710 sec, the vapour void fraction in volume 627 drops

below 60 % and strong vapour condensation sets in producing

a steeper pressure drop, until the turbine driven auxiliary

feedwater pump is stopped at 1900s.

The pressure anomalies observed after 1900 s are caused by

condensation problems which will be discussed in chapter

6. 3.
73

. Figures of group 5.11 illustrate different water levels in

both steam generators.

Broadband collapsed water levels in the downcorner and the

riser are shown in figure 11.1.

Since no broadband measurements were recorded at the plant,

the plant comparison data in figures 5.11.6 and 5.11.7 are

obtained by adding the distance between tube-plate and lower

level tap of the narrow-band level measurement.

No strict comparison between plant data and calculated data

should be attempted for these figures.

. Comparison of measured and calculated water level in the

intact S.G. is shown in figure 5.11.8. When the cooldown is

started by opening the atmospheric steam relief' valve between

900 and 1200 s, an excessive level swell is observed in the

riser (see also fig. 5.11.1) leading to a hold up of the water

in the downcomer and the region located at the small band

level measurement taps. This leads to an initial offset in the

calculated water level followed by a level drop with a

gradient which agrees well with the measured lcvel gradient

(see also chapter 6.2).

Figure 5.11.9. illustrates the comparison between calculated

and measured water level in the affected S.G. Since the leak

flow rated was tuned to the level rise, good agreement is thus

built-in as input to the code.

Figures of group 5.12 illustrate temperature evolution in

the steam generators

The steam temperatures in the SG domes reflect the pressure

evolution in the steam generators (close to saturation).
74

Figure 5.12.2. illustrates the evolution of the steam

generator inlet and outlet (primary side) and the SGB riser,

temperature.

When the B loop coolant pump in stopped at 1112 sec, flow

reversal in this loop causes a temperature inversion at SG

inlet and outlet (inlet temperature above outlet temperature)

since the affected SG acts as a heat source.

When the auxiliary feedwater motordriverl pump is stopped

(1900 s), cold water hanging up in the SGB downcomer, enters

the riser leading to a temporary very strong cooldown of the

riser region and a strong drop in the primary SG inlet

temperature (see also fig. 5.7.3.).

When the main coolant pump is started at 2105 s, the

temperature inversion (inlet-outlet) is reversed.

Fig. 5.12.3. illustrates the evolution of the temperatures

in the intact SGA (primary inlet, outlet and SG bundle

region). The closeness of the temperatures illustrates the

high heat transfer efficiency during cooldown.

Finally, fig. 5.12.4. gives an illustration of the strong

fluid temperature stratification in the bottled-up affected

S.G. after 2400 s.(see also figure 5.12.1 for dome vapour

temperature).

The large temperature drop in the bottom of the riser around

1900 sec. is another illustration of the sudden cooldown when

cold water, accumulated in the SG downcomer,

suddenly falls down and cools the SG bundle region (see also

chapter 6.2). This figure may give an indication of the

challenges to the code to evaluate the correct flow and heat

transfer regime under such conditions.

Figures of group 5.14 illustrate various mass addition and

release rates from both steam generators.
75

. Figure 5.15.2 illustrates the net mass addition and

depletion rates for both SG's.

. Figure 5.15.1 illustrates the total mass evolution in both

SG' s.

In conclusion one could state that the code calculation does

present the overall macroscopic behaviour in primary and

secondary system, except for three areas where large

discrepancies are observed. These areas will be discussed in

next chapter.

The following main phenomena, observed in the plant, dre also

simulated well by the code :

Non-equilibrium pressuriser behaviour in voided and

partially subcooled conditions.

Couter current flow in the pressuriser during the spray

period result in acceptable coolant distribution and

depressurisation, in contrast to the RELAP-5 MOD-I code

(Ref. 2). Former calculations with RELAP-5 MOD-I required

artifical external steam recirculation to avoid hand-up of

the spray water at top of pressuriser.

Structural heat release to the voided pressuriser during

cooldown leads to a situation whereby the water inventory in

the pressuriser remains low, even when 4 HPSI pumps are

operational.

The cooldown gradient between 1200 s (fully opened relief

valve) and start of the auxiliary feedwater system (1428 s)

in the RCS matches with the plant cooldown gradient, which

illustrates a correct heat transfer between RCS and both

SG's (in direct and reverse direction).
rLOF2W06 i.11.S9 SA- 28 SM.'; 1938' xeaw-/•3 y? , CyJ1. Ires 1.0 oD.srLsr VER 8.2

RELAPS/2/36.O1 REACTOR LOSS OF COOLfANT ANALYSIS PROGRfM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 2. 1 PRESSURE EVOLUTION IN PRESSURIZER

.• ........ . . . . .... .... . 0 o o0................... 0............... .. .. .. . .. .. ......... ° ..., , ............ ... ..... ,........ ... °............. .,.............

C4 ............................... .......................... ................................. ............................... ..........................

0

"'......................

........................ ......... ......................... ..............................

C)

1 . . .. . . . . . . . . . . ........................... . . ." ............................... °....................... . . . . . . . . . . . . . . . . .

0I

0. 0 60A.0 1200u.0 1000.0 2dO0.0 300,0.0 TIME (SEC)
PLOT 3100) 01.11.29 SAlT 28 SEP, INS .3W-ft3Cllfl , Mk5~u. NOS 1.0 OISSttn VtR 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 3.1 HATER LEVEL IN PRESSURIZER

('4

o °°o°° oo-° -o-°-° °° .° .o.°.°.-.°..o.-... ....... •............. ..... °............ ...... ~.°...o... o ...... °...-........ .o ..... ....... o. o.. .. o... . ..........o.

e-LRCfI-PR I1I

. ..................................... o-- COLLAPSED LEVEL ....... ,OT E L L V L ............ .. . ............................... HOT CELL LEVEL ... +---COLD CELL LEVEL

• - ~ ,o oo-...............,,.o...o..o........,.......,...... ~ ~ ~ ~.... .. •.....Io...... .,..,....,,.,........, ........ ,,. .., .. .......... ., . * °, ..-..... ,........

.. ........ . .

0

00M

I I1-- 1

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
rtLD 32DO 01.11.$3 SAT 25 UPr I1aS Joe-flX I * Cyt....T mS 1.0 DISSFtl YV5 3.2

RELAPS/2/36.01 RERCTOR LOSS OF COOLANT ANRLYSIS PROGRAM

DOEL2 SOTR INCIDENT 25 JUNE 1979 85/09/28..

S. FIG 3.2 MEASURED WATER LEVEL IN PRESSURIZER

in ,I .. ......................... .l ........ ...................... ................................ .......................... A .. ......... ....................

........... ........ .......... .......... o........... 

..................... I........... ........................... ....................................

_LRCA-PR I

HOT CELL LEVEL

• . .. .......................... ............................... ............................... ....................... .......I...............................

cm.

. .o....... ........ ..... ... o.. °... oo.. ooo... .. . .. . ...... . .•.o.o o ., ............. o............, ....... •.............. . . . . . . . . . . . . . . . . . . . .

0i e e g o a. i0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
t-l? 1100 DJ.IS.19 SAT 26 S?, 19S .Z8-MI3CIWl , CYKAW! NOS 1.0 DISSML VER 6.2

RELAP5/2/36.01 REFACTOR LOSS OF COOLFANT fANFALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG '11• PRESSURE EVOLUTION IN HOT LEG fl

L .. .. . .. . ........ .. . . . . . . .. . . . . . . . .. . . . .. . . .... °.................

a I I I

P 21102 ........................ ........ f... :................

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
rLDI 5200 01.1S.46 5111 2a scr. iges .JOB-AIWTI , CT8tNit. NOS 1.0 01ISr~tL VCR 8.2

RELAP5/2/36.01 RERQTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 5.2 TEMPERATURE EVOLUTION IN REACTOR VESSEL

0

.4..

C!

0

0- 0n

(i- c-fOOWNC. TEMP

ooCORE OUTL. TEMIP

O.0 600.0 12O O100.0 le00ziO'u, 3000. U TIME (SEC)
rLDI iW 01 .15.12 SAT 25 SU, IgSI .w-ft3mAT I c*l-- Has. ~1S .0 DnSSMtA VR 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 5.4 TEMPERATURE EVOLUTION IN HOT LEG A

0

0h

_. " ".......... .. ..... ............... ........................ .. .. ........................ ...............................

.................. oo. oo.o..... .. .. .. ° °°. .. . .

co,

O. 002 R0 0

G ---oCLOOP A

0.0 600.0 1200.010. 10030.

0.0 (EC
rw)T SSW 01.16.39 SAlT 2A srr* iuas JOB-ft3otoyl , CxYv Nos 3.0 DISSFRi V1N 8.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 5.5 TEMPERATURE EVOLUTION IN HOT LEG B

0

co

Ua 0~2 RCj25

. .. . . . .. . . . -oLOOP . .. . . . . .. B. . .. .° . 0................. .. . ............................... ........... °0............. ....... •............ .... ° ° 0 , 0 ° ...... ° °, 0 0 , , , 0 ° °

° 1

0.0 60 0 1200.0 1800.0 2100.0 3000,0

TIME (SEC)
tLOl 5600 04.3?.OS SRT 21 Mr~. 190S J05-h3C1IDT , CIKPN. AiS 1.0 OISStrfl VCR 0.2

RELAPS/2/36.01 RERCTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 05/09/28.

0

U)

0

10

0

5. FIG 5.6 TEMPERATURE EVOLUTION IN COLD LEG A

. Im-a2 RO 9 '' ............... o o L O I................................. ............................ 0-00

........ .... ,... - L O OP... A...° ° . .................... ° ..°........ °.... .°.... ............. ................. .......... ........... .. ..... ............

i

O, a 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
tFLO? 5700 04.17.31 SRI 25 SEP, ISAS .O-W-2CAOYT , CYAL. A M 10 .0 DISSPLfl VER 3.2

RELAPS/2/36.0 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.,

5. FIG 5.7 TEMPERRTURE EVOLUTION IN COLD LEG B 0

.. ....... ........ .... .... ................................ .................................

................................................................ .......................... ... . ... ............ ........... ............................... 0 it* " c3-I2IC2

0.0 600.0 1200.0 1000.0 2100.0 3000.0 TIME (SEC)
PLOT S85W 01.17.58 SflT 78 SEP, IN8S J08-IMmyT , Clem NO3S 1.0 DISSrtA VER 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 5.8 AVERRGED PRIMARY TEMPERATURE EVOLUTION

t)

00

CL0

tn

UU

a

9

0.. ... 0 o 120.0.0 1800,0 2.0.. o 3000.0

TIME (SEC)
?L.OT SS~O 01.8.21 SAT 28 SEP. Ins .E8-rt3cauyl , cmo.. ..i Ha~s 1.0 assrt VCRl 8.3

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 5.9 PRESSURIZER STEAM TEMPERATURE EVOLUTION

9

a . ooo.. o.. oo.... o.. .............. .......... °.. °°.°°°°°°....

0

0

.............. ° . ... °° ............. °° ............ °°...................° ...... TIE(SC ........ ° °.°.°.... .. ....... ............... ° .° °.. . . . . . . . . . . . . . . . . . . .

0.0 600.0 1200.0 1800.0 2t00.0 3000.0

TIME (SEC)
Vt-aT 6100 01.19. 17 SnT 28 31?, IN8S im-flt~myl I Cm-.cT "as 1.0 ORSA r~f R .12

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5* PFIG 6. 1 BREAK MASS FLOW RATE (CORRECTED)

Q

QO

. ..... o., .. ,,.o,.* ...o . o.oo........ ........ o.. o... .... ...... o............... H.... ..... ... °.................................................. ..... ....

€ ; . ..... ..... ....... .. . .. . ..... .. ... .... ...... . .... . ..... .. o°......... .. ..................... °.....

co .. ....... ...................o° .o .°, ...... °,.................. °..... °.... ° ° °° ° .°.............................. .. . . .. . . . ... ..... .. ........... ° °........... ... ...

(D I 1

0.0 600o0 1200.0 1000.0 -100.0 3000.0

TIME (SEC)
MLOT 62MDi. 14.9.43 W~ 28 SVt. 190S .No8-?3CROTT , CYg....gC NOS 3.0 DISSFLA '.CR 8.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 6.2 BREAK MASS FLOW RATE 0

C- 00

co

a

0

... , 0 .. 00o ,° o,0 ,0 .. .. ......... ,,0............. 0. ...... .. 0 ~ o o o .... .. •.....• ........... ..... . ... . .. . . 0 . o ....... o...... ...............

0

0.0 600.0 1200.0 1000.0 2100.0O 3000.0

TIME (SEC)
Mal 63M 1 00 O.20.09 $my 21 SEP. ISIS JDO-AWOI3C , CYOA NOS 1.0 ORSSFLA VCRl 1.2

RELRP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

S. FIG 6.3 PRIMARY SYSTEM MASS ADDITION AND DEPLETION RATES

S.................................................. ....... ........ .................................................................

02

Ed(00

C9

ci ... ...... ........... ............................... ........................ . ................. .... Q0

0.0 600.0 1200.0 1800.0 2100 0 3000.0

TIME (SEC)
rul Gsuu Ut.dD..%5 5m 28 so. 13as .,O- DT? , CTOCA I IOS 3.0 DISSLfl VCR 1.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 6.4 INTEGRAL OF HPSI MASS FLOW RATE

ti

Ci!

0

cma

w ..

o0

(ý. .......................................... ......................................................... ..... ...............................

cd

0.0 600.0 1200.0 1000.0 2100.0 3000.0

TIME (SEC)
rLD7 6SSD DI.aI.02 Sill 28 SEP, 196S .8-mcmfl , cmt. c7 mos 3.0 oiss!I vrR s.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5, FIG 6.5 CHARGING AND LETDOWN MASS FLOW RATE

9

MFLOW CV --eMFLOW LETO.

03 E 3E 3GSG1 31 D 3GE o~3D E3 0 El G B0 0 4 . .. .. .oo .,... . . .. .......... o,,ooo ..... °|............... .. . . ...... •................ ° o °..........° °...... °.........°°..... ° ......... ° o. ..... ° ,° ° ....... ° ........ ° ,.

a; . ............................... i. . . ................ .......... ........................... ............................... ........... ;.................... to

(nN

OU O 8•. 130. f30, E3000.0 183. 

CT

-L , ir. . . .. . . . ........................ . ....................... . ........................ ........................

0.0 600.0 1200.0 18000.0 Mo0. 0 3000.0

TIME (SEC)
riLO! 66DO ni.1.29 SftT 28 SEP, 198S .JW-A3CODYT , CYO.if.. NOS 1.0 nISS!Lt VUR 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

B. FIG 6.6 BREAK AND HPSI MASS FLOW RATE

ci .o.........................................................*... ................................. .............. ...... ...........................

o............................................ ..........................................

L c BREAK FLOW

U')

"-U--,HSIFO

co

; .' .. . . ...................... o o- °0 ..* . .*........ ... .. ... ...... ... ° .............. 0° ....... ..... °.°................ ........... . . °.. °.... °°......... .. ............

Q0

C) . .......... ........ , ° ° °.. ° ° .... °°....... .. . ...................... . ................... , ................ °.......... . ............. . .................. •............

O.0 600.0 1200.0 1800.0 2100.0 30

TIME (SEC)
MtOT 67DG00 o.2i.SS SAI 28 SCr* 193S JOO-ft1CW1 ,x~ -T1 "I s 1.0 oiss"u veR 8.1

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 6.7 HPSI MASS FLOW RATE

.° -o ° ...... ° . . .° .° . . . . ° ......... . . . ...... °......,° °° .. ° . °.... . . .o........... . . . .... .... o~°° o .... °........°° .. ...... • ...... °, .. .... °°.... •.......... ........ °o . . . .

1:9

c, .......... .............. ° °.° °. ° o.... .. o...... ... .. .... . . ., ............... ° , ° o ° ° ...... ° °.......... .................. .. . ..... °............. °........ .. .. .. ..

0

S.............................. ............ ......... ..................... ...............

r

0.0 600.0 1200.0 '1BoO. o MO. 0 3000.0

TIME (SEC)
fLol ow( Di.18.50 SflT 28 SEP, 128S .Ea-fk~ciRI , cvtý...CT NOS 1.0 Oissmaf VtR 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28,

5 FIG 6.10 MASS BALANCE IN PRIMARY SYSTEM

"0

co ..... ... ........................ ................................ ............................ o..............................o.... ..............................

.*I . . . . .............................. . . ................ .............. ... . .................

CD4b

U"

to

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
rLOT 71DO 04.22.22 SfnT 28 SErC?. 12S .J -Rt3CY , CYTKIt. JOS 1.0 f.JSSftl VEiR 8.2

RELAFP5/2/36.01 REACTOR LOSS OF COOLANT ANFILYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 7.1 CORE THERMAL POWER

.,U,

zo

00 . ..... •o.... . . . . . .. . .. . .o.o.oo....0 .............. ... .......... i ... ........... , ... ... 0. ...... ... ............ 0. .......... .... .... .......... ,, ....,. ... .. ...... ,,0 .. .....

• ~ ~ ~ ..... . ..... ,.... ,+.... .... 0...0...0,...0.

n."

CD

.. ................

0.0 600.0 1200.0 1600.0 MO0.0 3000.0

TIME (SEC)
runl 7200 01.22.18 SAlT 28 SEP, 193S J28-A3CRDYT , comtJ*, mNJs 1.0 oissrLN VR 8.2

RELAP5/2/36.O1 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5* FIG 7.2 BREAK ENERGY EVOLUTION

cr .. ................. °.o ............. ............... o............. o........... ................... ....... ....................... ... ..........................

•to

0

a-i

• . .. ,. ,°°°... .. °o° ....... ....... °.°o 0 ...... ........ . . . . ...... °o° ... o............. .. .. ...... •........•.... o.. .... oo o° ........ ... ° o .. .......... ...

tq 0o63

TIME (SEC)o

a:

Li

0

0 . . .°. . .° o ° . .° o o . .° . ~ ~ ~ o o ~ o .. . . . . . .o. . . o~ .. . . . . . .. . . . . . .°. . . .. . , . . . .. o ,. . . . . . .

ua

LII Oa:•010o BOo t0030, TIenSC
rtaT 7DoO otn.Z3.SATl 20 SE?* 195S .J8-flCROUT , CYKWIC NOS 1.0 DlSSsrL VER 3.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5, FIG 7.3 HEAT TRANSFER RATE FROM PRIMARY TO SG

So R

o-oSG B

. ............. .... °..°°° ....... ° ..° ° °° °°.............. ...... .... ... . . .. . . . .. . . . .. . . . .. . ...... °. ............ .. . .. .. . . . .. . .. ....

I-!

* -4

Li

03 i 0 .

TIME (SEC)
FLOT 7400 01.23.12 SOT 20 SC?.. 1905 JOB-MC80TOI , CYODK.., NOS 1.0 DISSFLR VCR 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

- DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 7.1 HEAT TRANSFER RATE FROM PRIMARY TO SG'S

"4o

ci ........... . . . ....... ............................... .... ...... .. .. ..........

ILi 0M

TIME (SEC)
MLOT 7S00 01.21.08 SRI 20 SE?, 190S .JI)C-fCRtoy? , C1DL..C? Rog 1.0 DISSrtfi VEr 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5, FIG 7.5 PRIMARY SYSTEM ENERGY BALANCE

.... ~ ~ ~................. : ........ i ................. ' ............. i ....................

i ... ...............

.. '...........

C}

1• . .... . ..... ° ... ..... . . .°o° ..... .... ° °°................... .. . .° .° .. ° ° .° .° ....... ° * ° ° °..... °........ ....... °o................ ...........,.. ,°°............... .

9

0.0 600.0 1200.0 1800.0 MO. 0 3000.0

TIME (SEC)
FIJI 7bUO 0I1.2.35 5111 as sLr. 1985' mo1-Niiou Clg4yr1nylrv~

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 7.6 HEAT ADDITION RATE FROM PRIMARY METAL STRUCTURES

0

o

........................................... ............... c3--3 PRIMARY SYST

G-PRESSU SYST m:

to ......................~ oo...... ... ° .............. o.°.°... . . ....... °. ............ ........ ....... ° ......... ..... . . . ...... .. . . .. . . ............. .

.. .. . .. .............. . - ....

ci l l .. . .. . . .. ............. °..... ............. •..... o..... •.......

0. 0 600.0 1200.0 1000.0 MOM0. 3000.0

TIME (SEC)
MLOT 7700 Di.2S.01 MIT 25 SCF, 198S JOB-113MA0T - CTYOD-.t W~S 1.0 OISSPLA VER 8.2

RELRP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

S. FIG 7.7 THEPMAL CORE AND BPEAK POWER

Ia

9

CL

c-fJCORE POWER]

o-OBREFRK POWER

............................. . ............................... ................ ......

.............................

........................

................ ....

f3

............................... .......................

.......................................

..................... .........

.............................

I-a

0.0 600.0 1200.0 1000.0

TIME (SEC)

2400.0 3000.0
Lun slo0 012~8 sRI 2s s~r t IBBS JJ- A3e~cfItol , cyTDRIs "Os 1.0 DlsstrL vuR 3.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5, FIG 8.1 COLD LEG MASS FLOW RATE (VESSEL INLET)

9

a43-

C)

0-9

C3

C.,

~ci

9-0

~~fLOOP ]

GeLOOPjA

...................... ............... .. V. ..... 0.........0 .......

El M E

............. ..........................

............. ..............................

.............. ...............................

0-

I

0.0 600.0 1200.0

TIME (SEC)

1800.0 2100.0 3000.0
M.01 8?OO 04.2S.SS SAYT 28 SE?, 198S XOU-0SIWT , CTDCE..LT NO~S 1.0 OISSU'UA VCR 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/20.

5. FIG 8.3 SURGELINE MASS FLOW RaTE

C3

. ..... ...........................................................................................

CD

Li-

- . . o........ .............................. ..... ... .... o... .... ... ........ ..... . ............. .o.............................

o 0 0

r a............................................. !........ •............... •...............

I 1 1 000001200.0 1800.0 2100 0 3000.0

TIME (SEC)
PLOT 8S00 01.26AiS SRIT 20 SEP, INOS JOe-A3CR0X1 , CY80t. i NOS 1.0 DISSfUiL VER 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

r, FIG 8.5 SPRflY MASS FLOW RATE

9

0)

LIN

C-9

C.)

a4

................ ................. LOOP B ........

o-LOOP Al

....... ... .... ...... ... ..... ................... .. .. .. .. .. . .. .... A L ... .. . . ... . .

...............................

..............................

...............................

I-

- .1 t--f-f " -

0.0 600.0 1200.0 1800.0

TIME (SEC)

-LA 9'LALALA

2100.0a 3000.0
MOT0 9200 01.27.11 SAT U8 SUP, iIVOS £0-flCIf CY 4CI NOS 1.0 OISS1lA YEN 8.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5* FIG 9.2 SUBCOOLING IN PRIMARY SYSTEM 0

0.

'4.

0

c; . ............... .......... ... ....................... .................... .....-.............. .... ........ ... °............ .........

C) ........ • ... ... •. •.... ... ............. •.. . .. •..... ........... . .•. ..... ° • ..- .•... . . ... ...... . .....° . ....... H° ... , °°.. °......

.. .. .... .... ... .... .... .......... .. . .. . ... ° ,...°..... ....... . . . . . . . . . ... ....... . . . . .,....... . . .

0

IED

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
nT? 9300 0.27.0i SAT 28 SCF, 190S M-03CO-i T , CYBI T NOS 1.0 DISSPLt VrA 6.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

, FIG 9.3 PRESSURE VERSUS TEMPERATURE IN DOWNCOMER

%o/

9/

/

• ....................................... .............. ................................................ ... .........................

C;' ....... ................................. ...................................... ....................................... ....................................... o /

........... ...• ........ ...... ....................................... i...................................... ...........

- -

........... .... a: ................ i i ii i a

i ii i .......................

i................ .. .. ............

......

160. 0 I80, o 506.0 5210.0 510,.0

TEMPF,(K)
MLOT 9900 01.26.07 SAT 29 SC? 1995 JO-R3MCYT , C19! .1 NOS 1.0 OISS1R VrR 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

;. FIG 9.9 MASS BALANCE IN PRIMARY SYSTEM

P.

............................

.......................

....................

................

.. .....

U)'

,r0 .

a)

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
MOT 0 01.20.31 SfA 29 51C, ISIS JOO-AI3;RT? * CS ON I NOS 1.0 DISSPLR VCR 8.2

RELfiPS/2/36.01 REOCTOR LOSS OF COOLRNT nNALYSIS PROGRrlM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 10. 1 PRESSURE EVOLUTION IN STEAM GENERATOR (DOME)

co

;. ............................... i.............................. .... ... ............ " , .- .......................................... ....................

o -

0.. 2-- 2MSO4B

16 P S G R .......... ................. .......'> .......... •................................

9 .... • ... 8 .... ..................... ............... ........... ... .. .. ........................... .K

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
MtCI 0 01.29.o0 •qT 28 SEP, ISSS JCS-6I T1 , CIOS 3 NOS 1.0 DISSl.R WA 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRRA

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5* FIG 10.2 PRESSURE EVOLUTION IN STEAM GENERATOR 1(OOME)

................................ .............. ............. ............................... .......................

.... ........................... :.... ........................... : ............ ........ ......... ............................... ...............................

S ......... i................... ........................ ..... N. .. .................. ............................... 00

0.0 -a 2 MS 04fR

.......................................

• °.. ..... o°.. .. . . ,o ° ..... °°........°o°...... o. °...... .. .. .. .. ...... ... .. . .. ................

O.0O 600.0 1200.0 ] 600.0 21!00.0 J000.0u

TIME (SEC)
MOT0 0 01.29.2? SAT 26 SO,? Ii~i .ioe-Almoll te 'ET POS 1.0 0ISSflAt VCR 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5, FIG 10.3 PRESSURE EVOLUTION IN STEAM GENERATOR B(DOME)

0

cic> CL c . ...... ooo oo ..... , , ....... .... ........ 6 ......., . .... •.....°o.o.......oo.° ....... ... .. .. ... ooo .. oo° . °o .oo .°.....oooo .o .......... o~o o o........

a---a2 MS 04B

o-oP Q

0.0 600.0 1200.0 100. 0 21O.O 3000.0

TIME (SEC)
MlOT 0 01.29.SS 'SAT 20 UP, INIS JO-ogMciwx , .. JWT Nos 1. 0 rlSSrLnj VER 9. a

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28".

5. FIG 11.1 COLLAPSED WATER LEVEL IN STEAM GENERATORS

9

DOOWNC SG A

I-- DOWNC SG B

*RISER ° I E SG ¢ a ... ....................................... . .. .. ... ... ..... ............................... .. RISER SG B

9 ..... ...... ... .. ....... ........ ......... .. ... .. . .... ... .. . ..... ................

.II-.,-i--i-i I 

.J

Lii

0

TIME (SEC)
rLOT 0 01.33.22 SAT 28 SCE, 1985 JW-f3GCRTT , CYb :T NS 1.0 DISSPLfl VCR 8.2

RELRPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRnM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 11.5 MEASURED WATER LEVEL IN STEAM GENERATORS

0

• d ......... .... ......... O N G ...

0.0 060.0 1200.0 1800,0 2100 3000,0o

TIME (SEC)
MOT 0 0..•i@ Sill 28 SM, INS .O-fMWlXITT , C, MONET NOS 1.0 DISSfLA VCR 0.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR -INCIDENT 25 JUNE 1979 85/09/28.

5* FIG 11.6 COLLAPSED WATER LEVEL IN STEAM GENERATOR A

.................. ..... i........................... * ............................... i..............................

............ J .................

.. 2FW 9A ............ o-LEVEL 711

............................... ...... :......................... ............................... ...... .... . ................... i ..... b ........................

._ ................................ ......................... • : :........ •:...... ... •........... ....................... ..............................

(~i•\. 0

-. I I

0.0 600.0 1200.0 1800.0 2100o0 3000.0

TIME (SEC)
MOT 0 01.31.1S ST 20 SU, I96S JW-fT3 T , CYbuLWT WS 1.0 CISSft VER 0.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 11.7 COLLAPSED WATER LEVEL IN STEAM GENERATOR B

........... ... ....... .... i.......................... "............ ............................. .........................

...................

S......... 2.............. .. ........ . ...... ... .. .... .... ..... ....... ................ 3.J -OLEVEL 611 ...... ............

I I

0.0 600.0 1200.0 1800.0 2100.o 3MO0.0

TIME (SEC)
MOT. 0 0t.31.i sai A 2S s•. 5U 8 .x19 30-flfloDT , "V Wfjr MS i1. pjSSnlf VCR A8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT flNfLYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

•. FIG 11.8 MEASURED WAITER LEVEL IN STEnM GENERfWTOR n

0

• ... ~ .°. ° . ~~.. .... o ° o .. .... . ..... .. ,,................ ...... ...,.,.°° °. . .. ... °.... .. ....... ........ ....... ,.......,.......... ... .... ........ ....... •......

o-2 FW 9R .-- LEVEL 713

c; ................................ ............................... ................................ .. . ............... ... ."i ". . .. . . . . .. . r,, ,

Lii

... ...... .... .,.. ......... :.. ............ .................................

i i\ 

-- \

0. I I 0 00.

0.0 600.0 1200.0 1800.0 2100.0 3000.0

TIME (SEC)
fl.D 0 01.32.01 Sf1 2S SEP, iS9S JOB-U3GlYOT , L .T NOS 1.0 DISS!Ft VrA 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

o FIG 11.9 MEASURED WATER LEVEL IN STEAM GENERATOR B

• ... .... ....... • ........ .... ...... .. ... ............................... i............................... ................... ............

ci ..... ........................... •.............................. .. i.................. 2 FW 9 B I ....... •> d- /./.o---LEVEL 613

0

0.0 600.0 1200.0 1000.0 2100.0 0000.0

TIME (SEC)
PLOT a 01323 SRI 2a tff. 19BS .X)-rdCIWYT , MMt: NOS 1.0 D)SSFLA Yvca 8.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 12.1 STEAM TEMPERATURE IN STEAM GENERT'rORS(DOME) 0

U)

Lii '3-i'S

0o • 01200.0 1800.0 2100.0 3000.0B TIME (SEC)
?LOT 0 01.33.02 sRT 26 57, 1985 J0O-A3CRDY7 , My .I NOS 1.0 0ISSP•L VCR 0.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 12.2 LOOP B AND SG B TEMPERnTURES

a

CL 5

S0... i................... i.... iiiiiiiii i ii!!!iii ..i iiiiiiiiiiiiii''iiiiiiiiiiiiil 

o--INLET BOX

-R I SER SG B

OUTLET BOX

0.0 60. 0 1200.0O 1800,.0 2100.0 3000.0

TIME (SEC)
FLOT 0 0i.33.29 SflT 20 SCF, iS9S JOe-ARUCOT , CID. :T tNOS 1.0 DISSPLA VCR 0.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28;

5. FIG 12.3 LOOP A AND SG A TEMPERATURES

9

0-

....... OUTLET...

. ...... ................... ............ .......

D-lINE BOXI

0.0 -600.0 1200.0 1800.0 MO0. 0 3000.0

TIME (SEC)
tLOT 0 01.33.S? SAT 28 SEP. 199S .kie-03CADYT , CYNflh.C NOS 1.0 DI5SLft 'Eft 0.2

RELAP.5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRnM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

N FIG 12.4 TEMPERATURE STRATIFICATION IN SG B

a

UC)

0

a C----BUNDLE BOT.

R, o----BUNDLE TOP

. ... .. SEPARATOR

I I I I

O.3 00. 0 1200, 0 1800, 0 2i00, 0 3000.0O TIME (SEC)
PLOT 0 0.1.34.23 SI 2 S2', INaS JOB-MMI ,1T, CIL . t i.M 10 ISSLA VCR 08.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 14.7 STEAM MASS FLOW RATE NICM SGU TO TURBOPUMP

Ln

cLi

0

0

0)

0

M

0

tn

0-

............................... ..............................................

............................... ............................... ..............

............................... ............................... ..............

............................... ................................ ...............

................

................

................

................

......................... .............. ................

................... ..........................

.......................... ..............................

.......................... ..............................

I-a

t~3 I-h

0.0 i 600.0 1

1200.0

TIME (SEC)

1800.0 2 2100,0 3000.0
RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28..

5. FIG 14.8 FW AND AFW TO STEAM GENERATOR

9)

tn

-9.

Ct)

"IS

...................................................

.............................. ............................... ..............

Q---D SG fl

............................... ............................... ........... ..

............................... ............................... ........... ..

G 9 Q El D E3 G G

.... .......................... ....................... .......

................ .... ..........................................................

................ ......... ...................... ...............................

................ ................................................................

Ps)

v,.m. ]

0.0 600.0 1200.0

TIME (SEC)

0 1800.0 2100.0 3000.0
11.01 0 al3si sal 2* up, Iins .k2-mmyU . cyorAiwi ws i.o cissrLftVR W .2

RELfAPS/2/36.01 REACTOR LOSS OF COOLflNT nNNLYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/20.

5. FIG 14.9 SG A RELIEF VNLVE mnSS FLOW R'TE

C!

9

.1

Cl :

Cd

0

0

0

- Q I0-) C

-I . ... ... .... .. ... . ... ... .. .. .. ... ..... ... ... ... . .. .. .. .. ..... .. ... ... . ....... .

1200.0

TIME (SEC)
MIol 0 0 1. is. 11 SRI 20 SO). ISIS .VSft)CWTY? CYPEAW.1 POS 1.0 0155115 VIA 0.2

RELPS/2/36.O1 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2,SGTR INCIDFNNT 25 JUNE 1979 05/09/28.

m FIG 5.i sTF.InM GENERMtORS MnSS EVOLUTION

r.-r

0G

o-SG A

I-.

u)

0.0 600 0 1200.0 1800. 2 M 0, 3000.

TIME (SEC)
nto? a Di.39.10 SAT1 21Mt. 1915 JO-iAXAWT , fluWCI 105 1.0 PISStIJ V1:R *.2

RELAP5/2/36.01 REACTOR LOSS OF COOLNNT fNNLYSIS PROGRAM

DOEL2 SG'R INCIDENT 25 JUNE 1979 85/09/28.

5. FIG 15.2 5G'S HINSS ADDITION AND DEPLETION RnTES

9

9 .............. 1....................... i .............. ................ .... ........................... i.............................

o-SG A1

................................................................ ............ .. ...... .. .... . ... . ........

ci' " • .- .' ............. "' • • " ..... ' .. ................... ............................... " ...............................

9

. 0 D IIp 006 000 0. 0 600. 0 !200. 0 18000 0 2i00.0 3000.0

TIME (SEC)
126

6. DISCUSSION OF THE BASE CASE RESULTS

From the comparison between available plant data and

calculated dataree can state that the code yields in general

agreeable results as far as the trends are concerned.

A quantitative code assessment however reveals some serious

code deficiencies which will be discussed separately.

6.1. Water level discrepancy in intact S-G at start of

cooldown

Fig. 5.11.8 manifests a level discrepancy at the time the

intact S.G. steam relief valve is actuated to initiate a

cooldown.

There exists indeed a large uncertainty in the time of the

cooldown initation and the opening rate of the relief valve.

A sensitivity study performed earlier, (and discussed in

chapter 7.1) by which the valve was opened instantaneously

showed a very large level swell which clearly deviated from

measured data. Based on this evidence it was decided to

program a linear opening rate of the relief valve between 900

and 1200 seconds for this study.

Fig. 5.11.8. shows that the measured water level manifested a

shortlived level spike which could be indicative of an actual

level swell phenomenon. The irregularities observed could also

be due to unknown operator interventions. Debugging the major

edit at 1000 and 1200 s, manifests following phenomena:

the flowregime in the SGA riser is of the BBY or SLUG type;

the liquid in the riser is entrained by the vapour flow,

such that the liquid velocity varies between 1/3 and 1/2 the

vapour velocity (around 0.5 m/s), indicative of a high

interface friction.

the FIJ increases from bottom (720) of riser to top (722)

from about 3000 to 14000, and is suddenly falling to low

values at the separator outlet junction.

This produces a liquid fall back into the separator volume

where water accumulates, hence leading to a large 4P level
127

as the smallband level taps are located just above and

below the separator.

Even if the precision in the recorded levels is not known, the

calculated trend diverges from the measured trend most

probably due to excessive level swell in the riser region

combined with liquid fallback in the separator region. This

would be indicative of too high an interphase friction in the

S.G. riser section for the prevailing flow regime (SLUG).

Since the water level measurement in a power plant is used for

plant control and also for plant protection, it follows that

numerical discrepancies for predicting SG water level could

have a large impact on the predicted behaviour of a power

plant, and in the timing of the actuation of emergency

safeguard features (e.g. auxiliary feedwater).

6.2. Excessive cooldown between 1500 and 2400 seconds

From the comparison between measured and calculated

temperatures in the primary loops (fig. 5.5.4., 5. 5. 5., 5.5.6.

and 5.5.7.), the calculated cooldown rate starts diverging

from the measured cooldown "rate around 1500 sec, which

corresponds with the start of the turbine

driven auxiliary feedwater pump, whereby steam is derived from

the affected S.G. to drive the turbine driven auxiliary

feedwater pump, and extra feedwater is fed to both steam

generators.

Due to uncertainties in the turbine driven auxiliary feedwater

pump caracteristics (steam flow, auxiliary feedwater flow), it

is not warranted to look for code model deficiencies which may

explain this discrepancy.

During the period wherein the turbine driven auxiliary

feedwater pump is operational, the affected S.G. acts as a

heat source (fig. 5.12.2), whereby about 7.7 MW of heat is

extracted from the S.G. riser volumes, via the SG U tube

bundle into the primary system. Notice that due to the

availability of only I primary coolant pump in the intact
128

loop, a reversed flow exists in the affected loop and cold SI

water injected downstream of the stopped coolant pump enters

directly into the affected SG, leading to an enhanced cooldown

of the riser.

Also the location of the break in the top of the riser

provides a cooldown by injecting colder water from the

primary. Both effects lead to a strong gravity head in the

riser.

On the downcomer side, one observes a strong heat transfer by

conduction between volumes 622 and 612/613 (about 3 MW) and a

large structural heat input in the injection volumes 612/613

which tends to heat up the cold AF water.

The net result is a reversed buoyancy effect which tends to

drive a reversed circulation in the affected SG (KR = 3 X

1000).

When the turbine driven auxiliary feedwater pump is switched

off, the steam flow, taken from the affected SG, is halted and

this stops the strong depressurization in this SG. Also the

temperature drop is stopped whereby the structural heat (the

driving force for the reverse circulation) is strongly

reduced.

Between 1900 and 1992, cold auxiliary feedwater is still

injected in the affected SG by the motordriven pump.

Both effects lead to a reversal in the natural circulation

from initially - 11 kg/s at 1900 s, to over 800 kg/s at 1940 s

and dropping down to 160 kg/s at 2000 s.

At 1900, the fluid temperature in the volumes surrounding the

feedwaterline (vols 611, 612, 613) is about 200 below the

bundle fluid temperature. When the circulation sets in, in the

normal, direction, this large inventory of cooler fluid,

combined with a continuous injection of cold AFW from the motor

driven pump (flowrate z 23 kg/s) produces a strong cooldown
129

in the riser and constitutes an abnormal large heat sink for

the RCS (see fig. 5.7.3) of max. 50 MW.

The strong reversal in the temperature at bottom of the SG is

illustrated in fig. 5.12.4, showing the effect of an

overcooling by more than 20 0 C when the natural circulation

sets in.

From the discussion of a parametric study (chapter 7.2.) it is

believed that this anomaly is caused principally by a wrong

choice of the forward and reverse form losses in the S.G.

downcomer.

In this study, very large reverse form losses and low forward

form losses may act as a leaky diode where during periods of

reversed boyancy colder water leaks slowly in the reverse

direction without mixing with hotter fluid on top of the

downcomer. When the boyancy changes over to the normal

circulation, excessive natural circulation flowrates are

observed leading to the observed phenomena.

Since it is known that RELAP-5 tends to exagerate the natural

circulation flows, it may be recommended to select suitable

form loss factors both for direct and reversed circulation

(e.g. KF = KP = 200 in downcomer junction) in order to allow a

larger reversed flow, and hence better mixing, and a reduction

of the forward flow which should lead to smoother temperature

transitions.

The choice of the form loss factors should however be

consistent with plant values in order to lead to the known

recirculation ratio at various power levels.

The effect of this apparent anomaly propagates back into the

RCS where it aggravates the temperature discrepancy in the

cold legs of the primary loops.

When this colder water is used as spray in the pressuriser at

2100 seconds, the excessive spray subcooling must produce an

excessive depressurization as shown in fig. 5.4.1.

(discrepancy about 9 bar between calculated and measured
130

pressure peak), which in turn increases the cold HPSI flowrate

(fig. 5.6.7.) and yields a positive feedback to the

overcooling.

This example shows how a code anomaly can propagate back from

one S.G. to the primary and lead to a large discrepancy which

maintains itself through the existence of a positive feedback

(e.g. pressure - SI flow).

6.3. Vapour condensation anomaly in affected S.G.

When the affected SG is completely bottled-up after tripping

the AFW turbo and motordriven" pump at 1992 s, a large fluid

temperature stratification exists in this SG (fig. 5.12.4) and

the difference between fluid temperature and vapour

temperature (fig. 5.12.1) in the SG dome levels out at about

70C.

From the pressure history (fig. 7.10.1) one observes a sudden

increase in pressure when the turbine driven auxiliary

feedwater pump steam valve is closed at 1900 s, but levels off

at a pressure of about 36 bar around 2000 s, and has a

tendency to decrease afterwards while the recorded pressure

keeps rising.

In order to explain this anomaly, one should evaluate the

vapour generation/condensation phenomena under such high

temperature disequilibrium, for which fig. 6.1 is a good

illustration of the phenomena occurring the SG dome.

This figure illustrates a vapour generation rate increasing

sharply at 1830 s, when the water level crosses the lower

boundary of the upper dome volume. Since a forced steam flow

of 2.34 kg/s (fig. 5.14.7) is derived to the turbine driven

auxiliary feedwater pump (requiring a vapour generation rate

of 0.089 kg/m3 ,s) the actual .vapour generation rate is much

lower (fig. 6.1) leading to a net vapour mass depletion and a

resulting accelerated pressure drop (see fig 5.10.1).
131

When the steamline to the turbine driven auxiliary feedwater

pump is closed at 1900 s)the vapour generation continues for

a while leading to a sharp pressure increase, until the vapour

generation reverses to a non negligible vapour condensation at

1960 sec. of 0.009 kg/m 3 ,s (or about 0.237 kg/s).

This condensation of vapour combined with a net mass addition

to the affected SG from the break, leads to a stagnation in

the pressure (or even a sl.ght pressure decrease) in contrast

to the recorded pressure increase.

This anomaly is likely due to an excessive vapour condensation

rate in the dome volume of superheated vapour (523 0 K) on

subcooled fluid (507 0 K) for a saturation temperature of 517 0 K

(at 2200 s).

From an energy balance in volume 630 at 2200 s, one obtains a

vapour-water condensation flux of 436 kW resulting in a

vapour-water condensation heat transfer coefficient of about

2 100 W/m2 ,oC. Such excessive heat transfert coefficient is

calculated for a prevailing flow regime "SLUG", while the

volume liquid velocity is negligible (- 6 10-4 m/s) and the

volume vapour velocity also is negligible l= 3 10-4 m/s).

For such velocities a "STRATIFIED" regime should exist which

would probably have resulted in much lower vapour condensation

rates.

Hence, the pressure anomaly can be traced via a condensation

anomaly for a wrong flow regime for this volume.

Finally it should be emphasized that an underestimation of the

pressure in the affected S.G. could have an impact on the

postulated timing of automatic systems and operator

interventions:

a higher S.G. pressure will lead to an earlier isolation of

the break flow from primary to secondary and an earlier

switch-over to post-SGTR cooldown procedures.
132

a higher SG pressure may lead to actuation of the SG safety

valves, with the danger of failing to close when water

should be released.
133

CONCLUSION :

Two important shortcomings of the code.are evident from this

analysis :

a. Exbessive interphase drag in the S.G. riser is observed

under certain conditions.

b. Excessive heat and mass transfer for direct contact

condensation and evaporation for various flow regimes. Such

"TOO EQUILIBRIUM" conditions have also been observed in

RELAP-5/MOD-1 (Ref. 2). Further research on direct contact

condensation at higher pressures may be needed to refine

these physical models.

As for the cooldown discrepancy, an optimisation of the form

loss factors in the recirculation loops in the steam

generators may lead to better code results.
iso tB og.fl.'.-o LA? ua s, tsls *gntpolp I lly t ls t.6 olssittA vr o.

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

FIG,6.1 .. VAPOR .. .. . GENERATION RATE IN S.G,B, (DOME) i m . . . . .

d

I.-

(9

. ,.....,. **..............,...... ...... , ......... ............ ***,•..* ** •• , * °-p. °..i

.,°**,,l.,, ,.,.°...°,o.,..,*,,..,,.. *., ,,... **.,,.,°°,.° ..........,.. • .. ., ., .

............... .... ..................... .... ........

.......................

..................... ..........

.............. ...... .......

.. ...................................................

4w

'-a - I- a

0.0 600.0 1200.0 i 2 1000.0 2160.0 3000.0

T IME (SEC)
135

7. DISCUSSION OF THE RESULTS OF A SENSITIVITY STUDY

Table 7.1. (from Ref. 3) gives a summary of the main inputdata modification between 3 simulation studies of the SGTR

event. While preceding chapters were concentrated only on the

results of case 3, this chapter will discuss those results of

case 2 which may help to explain the observed anomalies

explained in chapter 6.

7.1. Water level discrepancy in intact S -G at start of

For case 2, the cooldown was initiated suddenly at 900 s, by

instantaneous opening of the atmospheric steam dump valve of

the intact S.G. (rather than a gradual opening during POO

seconds for the base case).

Fig. 7.1. illustrates a comparison between calculated and

recorded water level in the intact S.G. for the 3 cases.

The sudden depressurisation produces a much larger level swell

resulting-in a level overshoot of 20 % (compared to about 8 %

for the base case).

Fig. 7.1. also illustrates that the level swell phenomena

occurred only for the cases 2 and 3 (RELAP-5 MOD-2) and not

for case I (RELAP-5 MOD-I). A change in flow regime map

between MOD-I and HOD-2 could explain the basic difference.

Conclusion

Too strong momentum coupling between the vapour and liquid

phase leads to a wrong mass redistribution in the S.G., during

a sudden depressurization.

7.2. Discussion of sensitivity stud' concerning the cooldown

period

Fig. 7.2. illustrates the comparison between the heat transfer

between primary and S. G. *s.
136

The basic differences between the nodalisation for case 3

(base case) and case 2 are related to the form loss

coefficients introduced in the downcomer of the steam

generators, and a slightly simpler nodalisation of the

separator region as shown in fig. 7.3.

In the three downcomer junctions, the forward form loss factor

was set at 200 (case 2) and zero (case 3 - base case), while

the reverse form loss factor was set at 1000 for both cases 2

and 3.

A higher forward form loss factor for case 2 leads to a strong

reduction in the natural circulation flowrate (factor 7) in

the intact S.G. (at t = 1600 s) resulting in a lower cooling

capacity as can be seen in fig. 7.2.

When the AF to the affected S.G. is stopped at t = 1632 s

(tripped prematuraly on high water level in intact S.G.), the

reversed natural circulation in this S.G. is maintained and

has a tendancy to increase, in strong contrast to the base

case when AF trips (at 1900 s).

It follows then that the cooldown rate of the RCS temperature

is closer to the recorded value (fig. 7. 4), and the

depressurisation peak at the end of the spray period is also

closer to the measured value (fig. 7.5.) for case 2.

Conclusion :

The natural circulation in the S.G. depends strongly on a

proper choice of the form loss factors in the junctions along

the natural circulation path, and has a very important impact

on the primary RCS especially for asymmetric plant behaviour.

7.3. Vapour condensation phenomena in highly stratified

conditions

In chapter 6.3., a vapour condensation anomaly was detected in

the dome of the affected S.G. under following conditions

very high temperature stratification

zero steam-and feed flow (bottled-up)

very high water level in the S.G.
137

Fig. 7.6. illustrates the S.G. pressure evolution in both

S.G.'s for case 2 (parametric study). Concerning the affected

S. G. , the premature pressure rise at 1634 s, is caused by a

trip of the turbine driven auxiliary feedwater pump at high

S.G. water level in S.G A (Table 7.1), which also closes the

steam flow to the turbine, and produces a repressurisation of

the affected S.G.

Comparing the measured and the calculated pressure trend

beyond 2400 s, one observes an acceptable pressurization rate,

in contrast to the results of the base case (fig. 5.10.1) and

discussed in chapter 6.3.

Table.7.2 below compares the main S.G. dome parameters for the

base case and the sensitivity study (case 2) from a major edit

at 2200 s.

The interpretation of the results should account for a

different nodalisation between base case (fig. 4.1.) and

parametric study (fig. 7.3.).

From this table several observation can be made.

1. For same the flow regime in the dome volume, (ie SLUG), the

heat transfer regimes are very different.

2. The structural heat flux repartition between vapour phase

and fluid phase is reversed between both cases. While for

case 2, heat is exchanged between gas phase and outer

structures, for case 3 (base case), heat is exchanged only

between water phase and outer structure.

3. For case 2, heat losses from the vapour phase to the

structures produces the vapour condensation on the walls

and run - off in the water phase which corresponds to the

vapour condensation flux calculated.

4. For case 3, the large vapour condensation results only from

a direct contact condensation between the vapour and the
138

water phase, since no heat is extracted from the vapour

phase by the colder structures.

Conclusion :

a/ The absence of the large direct contact condensation in the

sensitivity study results in a heat balance which yields an

acceptable pressure trend.

b/ The selection criteria for the heat transfer regime for

condensation in RELAP should be reviewed in the light of

above observation.
TABLE 7.1

TABLE 1 i SUMMARY OF SGTR - ACCIDENT SIMULATION NODALISATION AND RESULTS

CASES 1 2 3

date of execution 27 June 03 19 april 85 20 september 05

code i RBLAP-5 MOD I CYCLE 014 HOD 2 CYCLE 36 HOD 2 CYCLE 36.01

separator modal MOD I HOD 2 VOVER - 0.1 MOD 2 VOVER - 0.1

VUNDER - 0.1 VUNDER - 0.1

SG plenum + bypass no yes

break area (cm 2) (VCAIS) 1.015 (0000) 1".724 (00003) 1.724 (00003)

Forward loss coefficient in SG downcomer 3 X 200 3 x 200 -

letdown closure, back-up heaters off t - 211 a LPR• 20% LPR A 20%

AFW (turbopxump) off t - 1900 a LSG 451 t = 1900 s

upray nozale location TOP (TD3) (EXTERNIAL) TOP (TDV + TDJ) AS BUILT (TDJ)

SGA cooldown initiated t - 1000 a t. - 1000 a 900 !6 t 4 1200

structural heat losses to containment NO NO YES

fumbar of volumeas 136 144 154

Number of junctions 140 150 150

Number of heat slabs (mesh points) 157 (463) 161 (553) 164 (563)

TIME - STEP LIMITATION (PRINCIPAL) MASS ERROR TRANSIT TIME TRANSIT TIME

(11OT LEG) (U LEG)

ACCUMIULATED MASS ERROR RATIO - 79.10-4 - 1.14 10-4 1..08 to-6

AVERAGE TINE STEP (a) 0.09 0.124 0.124

CPU - TIME / TRANSIENT-TIME 22.6 18.0 19.4

I-a

c-A,

w
140

TABLE 7.2.

COMPARISON TABLE OF S.G. DOME VOLUME DATA AT 2200 S

PARAMETER UNITS SENSITI''ITY BASE

STUDY CASE

Case 2 3

Height of dome compcnent m 3.093 2.093

Volume of dome component m3 36.85 26.29

Dome void fraction 0.652 0.704

Dome flow regime - SLUG SLUG

Dome saturation temperatuze CK 540 517

Dome gas temperature 552 523

Dome fluid temperature OK 515 507

Dome outer heat slab

surface temperature OK 540 517

Heat transfer regime - condensation Subcooled

(11) nucleate boilinc

(3)

Heat fluxes

a. Internal struct to

gas watt 644 29 903

b. External struct. to

gas watt - 76 320 0

c. External struct to

fluid watt 0 163 442

c. Total flux to volume watt - 75 676 193 346

d. Tot. flux to gas watt - 78 502 - 406 216

Vapour generation rate kg/mi3, s - 0.00124 - 0.00824
MOT 0 01.31.11 SAT 26 SF, 19.5 JIO-A YT , CY6. .1 NOS 1.0 OISSL• VCR 8.2

RELAPS/2/36.O1 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

FIG.7.i MEASURED WATER LEVEL IN STEAM GENERATOR A

. PLANT DATA

- - ------- CASE I

CASE 2/

S" CAsE 3(BASE)

co .. . .. . .. . .. ........... . . . . . . . . . . .......................... . . ... ,°°.... ,................ .............. .. ..............o.o ....... ,.°.

aca-c2 FW 9A

-oLEVEL 713/

ci ................................ ..................... .................................. i- ,. ?........... ..............................

-. _. y...... ..................... ..... ...........................

T/

i/

0.0 600.0 1200.0 1800.0 200. 0 3000.0

TIME (SEC)
nOr 73o 01~.23. IS M 28 Srr. 196s .EIC-mftayiO , cyarmw'. tEns 1.n n1ssVLf vfI a.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

FIG 7.2 HEAT TRANSFER RATE FROM PRIMARY TO SC

"b

* CASE 2

* CAsc 3

0

",.. , . . . . . . . . . .

r3-fJ5 A

o---5Q B

N .............................................................. . B.............../. .............

TIME (SEC)


MLOT 5600 01.17.0s SMT 25 SCP. I98S .AB-A3CRDY7 , CERM., NOS 1.0 OlS•SMfl YnR 8.2

RELAP5/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

DOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

Fig.7.4 TEMPERATURE EVOLUTION IN COLD LEG A

M

.i ................................ ............................... i....... ......... ............ i.... .......................... ...............................

0.

U)

CL

Ua--o2 RC 09

S .......... L O P A ....... ........ .............................. ................. . ...............................

0 . .. ............. . .. . . . . . .. A " . . . ... :. ........................... :............................... ........... ..............

•' : CASE. 3

-.t)

00600.0 1200.o 1800.0 2100.0 3000.0

TIME (SEC)
MOT 1100 04.15.19 SRT 20 Sfr, 1985 JOB-f CRY1r ,. CYlrftNttC WS 1.0 O1SSrtn1 VrR 6.2

RELAPS/2/36.01 REACTOR LOSS OF COOLANT ANALYSIS PROGRAM

OOEL2 SGTR INCIDENT 25 JUNE 1979 85/09/28.

FIG 7.5 PRESSURE EVOLUTION IN HOT LEG A

............... .............................................. ....... .....................ooo ............................... o .................... oo...........

.. . . . . ................... .. ... "'". ............................... ................................. ..... o\

c; \\I ...................... .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ... .--- ..... ................. ...

B- a PRA-RO I .. e P 21102

.......o I" -....... - :....... .... . . PL~hT x D~ATA r ............ I ................... ..... ..... ... ...........

CASE 2

_________ CASE 3

I '1 T I

0.0 600.0 1200.0 1000.0 200. 0 3000.0

TIME (SEC)
PLO! 0 rR i q n

0

.

0

.. oar. .V I*'or! 1w* 1.3 MWI'AI. IrR d.4

RELflPS/MOO2/1OG. RErf.'OR L.OSS OF COOLnNT rINnLYS!S PROCRnM

SU'R BENCHMARK 85/04/19.

FIG 7.6 PRESSURE EVOLUTION IN STElrM CF.NFRr'rORS

' I ... .... .. i - . ...... . . ............ , .. .......

COr

C) n

t• • ---ai2 MS 04A •"•: i

-3---•-2 MS O4B

TEMPO SC B.

I*' I II

0l.0 (W)0N. 1200f. 9 Iadoo. Z4nnf. jODO.fl

TIME rSEMc
148

8. RUN STATISTICS

In order to compare run times it should be mentionned that the

CPU time for the CYBER 176 machine of the CDC CYBERNET system

does not correspond with a clock time. For billing purposes,

the CPU time has been manipulated such that for all machines

of the service center, the same equivalent CPU is applicable.

Hence, it turns out that for the CYBER 176 machine the clock

time is about 11 times smaller than the printed CPU time.

In further discussions, clock time will be used (as distinct

from CPU-time) in order to arrive at run statistics comparable

with statistics of other ICAP reports.

Fig. 8.1. illustrates the CPU-time evolution versus transient

time.

The requested time step was constant at 0.25 s.

The average time step varies between 0.122 and 0.125 s.

The time step limitation was "minimum Courant" for most of the

time steps. The limitation occurred systematically in volume

13302 (vertical pump suction segment of intermediate leg) and

25102 (segment in cold leg between pump and SI injection):

volume length max. velocity max. Courant possible

I Cain

(m- ) m) (m/s) s %

13302 1.43 9.861 0. 145 14

25101 1.968 14. 0. 14 12

Table 8.1. illustrates various run statistics at various

transient times.

From this table one observes that the maximum mass error goes

from + 10.5 kg to - 10.0 kg or a max. fraction of ± 3.5 10"6

Fig 8.1 shows that the CPU TIME versus transient time is very

constant and averages out to 19.3 CPU-s/transient-s or 1.76

clock-s/transient-s.
149

The performance rnumrber

52 249 - 122

1 000 x clock-s 1 000 x

11 - --- --------------------- 1.o6

vol x DT 154 x 21 883

Conclusion

In contrast to previous calculations by means of the Code

RELAP-5 MOD-I, the accumulated mass error remains low, and the

running time is very stable, with a performance ratio of about

1.8 (execution/transient time)
150

TABLE 8.1 - PUN STATISTICS TASLE

TRANSIAW7 CPU- CLOCK TOTAL f, MAS $ E1ASSEROR AVERAGE NUMBER REEATEZ

TIME TIME TIME KG JtPRACT7OA1 AT or CYCLES ADV

0

200

400

600

800

1000

1200

1400

1600

1800

2000

2Z00

2400

2600

2700

122

3 855"

-7546

f1250

14930

18 GGG6

22565'

26550

30564

34413

3,8363

42210

54561

50347

11.1

350

686

1023

1357

1697

2051

2414

2779

3128

3488

3837

4233

4577

0

4.4G

6.53

8.37

9.66

6.92

1.63

10.503

3.06

7.11

- 0.025

-10.09

-3.649

1. 663

0.

1.5

2.1 5

2.75

3.17

2.27

0.54

3.45

2.80

2.31

0.008

-3.25"

-1. 17

0

C-61 0,1249

c-6

E-6 E-6

E-6

r- 6

E-6

C'-6

E-6;

E-6

0.f25

0.125

0.125

0.125

0.125

0.124

0.122

0.1 25

0 ,124

0.f244

0.-15

0.1248

1602

3202

4802

6402

8002

9602

11232

12891

14491

16110

17723

19479

210.83

21883

-1

-1

-1

-1

-1

-1

-12

-40

- 40

- 48

- 54-

-72

- 74 0. 53 If-6

52249 4750 .39 39 1. 08 E-6 0. 126 - 74
ttil i 6ji3j.if SAT 70 SFI. WrI J4#DWmct11 . tZsfsI.t VMS 1.0 ',tftfIk tlk $.It

!BELAfPS/2/36.OI REAICTOR LOSS OF COOLFNI ON"ILYSIS PROGRArl

DOEL2 SGIR ]NC]DENT 25 JUNE 1979 85/09/28.

FIG8.1 Cf'UTIfE VERSUS TRNNS]ENT T]E

I I

* i

(F)

*i:

cl . ... .... ............. ............... ....... .. ... . .................... . .. . ...........-...... .-. ................. ...

r-J

0. i~n12010.0 1800.0 2100.0 o00.

TIMEI (SEC)
152

9. CONCLUSIONS

An assessment study for the code RELAP-5 MOD-2 CYCLE 36.01 was

presented in this report based on a real plant transient

(DOEL-2 SGTR event).

Although the quality and quantity of the plant data in terms

of plant diagnostics and recordings may be considered poor

with respect the known thermal-hydraulic facilities, it was

shown that comparison of parameter trends can lead to an

opinion on the strength and weaknesses of the code to simulate

the observed phenomena.

Such as :

1. The code is capable to simulate the observed phenomena

reasonably well and can be used to predict similar

transients. However, lack of precise boundary conditions

does not allow one to quantify the error margin from this

analysis.

2. The code performance is acceptable. The time step is

constant and Courant limited for 99 % of the transient, and

the execution time on a CYBER-176 is about 1.8 times the

transient time. The mass error ratio remains negligible.

3. Impressive improvements over RELAP-5 MOD-I CYCLE 19 have

been observed in the steady break flow rate, and the watervapour flow slip (CCFL) in the pressuriser, when

pressuriser spray is actuated.

4. Excessive water level swell observed in the intact S.G.

during cooldown may be attributed to excessive interphase

momentum transfer in the S.G. riser region when bulk

boiling is initiated.

5. Excessive interphase mass and heat transfer for

condensation and evaporation in quasi stagnant flow

conditions was observed in the vapour space of the isolated

affected steam generator.
153

6. Erratic natural circulation in the affected steam generator

leads to an anomalous cooldown capacity of the steam

generator. This behaviour can be suppressed by inserting

high form loss factors in the natural circulation flow

path.

7. While some anomalies may be reduced by a judicious choice

of the nodalisation and/or code options, this study

suggests that further improvements in the constitutive

equation package, in function of the various flow regimes

is needed, to take full benefit of the potential of a 6

equation code.
154

10. REFERENCES

1. Analysis of Steam Generator Tube Rupture Events at Oconnee

and Ginna. INPO - 82-030 November 1982.

2. Analysis and simulation of the DOEL-2 SGTR event. E.J.

STUBBE et al.

ANS PROCEEDINGS : Anticipated and Abnormal plant transients

in LWR's, Vol 1 pp 183-192, September 1983.

3. Application of RELAP-5 to the analysis of the Doel-2 SGTR

accident, and studies of the Doel 1-2 loss of feedwater and

feedwaterline break accidents.

E.J. STUBBE, L. VANHOENACKER

Presented at the 13th Water Reactor Safety Research

information meeting, GAITHERSPURG Oct. 22-25 1985.

4. RELAP-5/MOD2 CODE MANUAL

V.H. RANSOM et a-1, NUREG/CR-4312, EGG-2396, August 1985
ANNEXE I

155 PD/VEF

Revision A

25/10/79

REPORT ON THE INCIDENT AT DOEL 2 NUCLEAR POWER PLANT

SEVERE LEAKAGE IN STEAM GENERATOR B ON JUNE 25, 1979

1. Status of the power plant at the moment of the incident

The primary system was beThg heated up after repair works

at the actuation system of the main steam valve.

At the moment of the incident, temperature in the primary +

system was - 255 0 C (point A on Fig. 1 & 2) and pressure

had reached its rated value of 157 kg/cm2 (point A on Fig.

3 & 4).

The reactor was subcritical with all rods in.

+ 2

Secondary pressure in the steam generators was - 45 kg/cm 2

the saturaiion pressure corresponding to 255 0 C (point A

on Fig. 6 & 7).

For some time, A-loop steam generator had shown a low

A/ activity value along the secondary side.

2. Sequence of the events (reZer also to various computer

data given in attachment)

2.1. Initiating phase

A/ About 7:20 PM, a quick level decrease (Fig. 5) and a pressure

2 decrease (about 2 kg/cm per minute : see Fig. 4) are

recorded in the pressurizer. The level decrease results in

an acceleration of the operating charging pump. A second
156

-2-

A/ charging pump is started manually. It is confirmed that

' the relief valves are closed, and their isolation valves

are preventively closed. The level in the pressurizer

Z continues to decrease, and as a result the letdown station

of the CV system closes. The electrical heaters are disconnected, which is confirmed manually.

The steam bubble expands into the primary loop.

At the same time, a quickJevel increase is recorded in

B-loop steam generator (point B on Fig. 7).

AZ The importance of the leak has been later evaluated at

40 t/hr. The activity measurement channels of the blowdown

system record a maximum value.

The combination of all those signals indicates a severe leak

in B-loop steam generator. The faulted steam generator is

then immediately completely isolated along the steam side,

A/ but the line to the turbo-pump is omitted.

The discharge valve to the atmosphere is set at maximum

A/ pressure (80 kg/cm )

Meanwhile, the third charging pump is started (was set apart

to be maintained), but three charging pumps are not sufficient

to compensate the loss of fluid in the steam generator.

Indeed, the CV tank is readily empty, and the charging pumps

are automatically supplied from the pool fill tank].

AZ Cooling of the primary system starts through a discharge to

the atmosphere of A-loop steam generator, in which pressure

and temperature quickly -&ecrease (point A on Fig. 6).

Primary pump B is stopped.
157

-3-

2.2. Actuation of the safety injection

About 20' after the incident started, the threshold pressure

(118.5 kg/cm 2) to actuate the safety injection is reached.

The emergency diesels start within the required time lapse

but are not necessary. Phase A isolation and ventilation

isolation of the reactor building are achieved. The vital

components not yet in operation are started.

When reaching the 108 kg/c=2 value, all HP SI-pumps discharge

into the primary system, and the pressure decrease is

stopped (point C on Fig. 3).

A/ As the low level threshold is exceeded in A-loop steam

generator, the auxiliary feed pump starts. The discharge

through this turbo-pump results in a quick pressure decrease

in B-loop steam generator (point C on Fig. 7) for about 8

minutes, time during which ± 1 ton steam could be discharged

(until a level of about 45% in the two steam generators).

To decrease primary pressure and thus also the leak rate,

spray is maximum in the pressurizer. Primary pump B is

started, and both spray lines are used (point D on Fig. 3).

During this phase, the steam bubble in the pressurizer

/ completely disappears, and it fills up with primary water

7 at t 230*C. Spray is stopped at + 75 kg/cm2 -17 - n esr

/ stabilizes at a value corresponding to the head of the four

SI-pumps taking into account-- the leak flow.

The auxiliary feed pump of the faulted steam generator is

stopped locally and isolated (point D on Fig. 7). This

cannot be performed from the control room since the SI signal

still prevails. The auxiliary feedwater supply tank is

filled up from Doel 1.
158

-4-

2.3. Cancelling of SI-signal

Pressure decrease was now mandatory :

(a) to avoid the preset opening of safety valves of the

faulted steim generator

_(b) to start, as soon as possible, the shutdown cooling'

system (low'pressure circuit!l) to stop the letdown

of slightly contaminated steam through the A-loop

steam generator.

First, the safety injection signal had to be cancelled.

This had to' be "performed more than"'once *(each time requiring

A• 5 minutes inte'rVal)` because the relay -did' not start-within

the required time lapse. Finally, the concerned bistables

had to be Zlicked over.

After'definitively cancelling the SI-signal, two HP SI-pumps

are stopped and s6on thereafter a third one. While

considering the subcooling margin, the'last HP SI-pump is

stopped,'-and pressure successively ,decreases to reach "

65 kg/cm2 (point Hon Fig. 3)* ' ' -

A/ At that moment, the'three charging pumps-are running.

It is then tried to initiate° the CV-discharge line, but

valves do not open. Some •egoes by beforethe reason

therefore is ditermined. Duhe'to phAse*A isolation, there

is *no 'longer .acompressed-air supply in thereactor buildinig.

After re-opening thescompresed-air supply line,'the discharge line is opened -(pointI ýZon Fig. 3).

A/ A charging pump is'stopped,'pressIre -decreases, Ifirst

quickly," then-slower. -

The loss of 'compressed-ai9 •supply has also re'sulted in 'the

A Zclosure of the CC-valves to the thermal shield of'the primary

pumps.-.This lasts for about 10 minutes, but no damage was

recorded.
159

-5-

2.4. Initiation of the residual heat removal system

As the CV-system permitted only a slow pressure decrease,

the interlock, which maintains the isolation of the RHRS

2 2

up to a pressure of 28 kg/cm , has been bypassed at 31 kg/cm

There was indeed a sufficient margin compared to the design 2

pressure of the system (42 kg/cm ). Thanks to this operation,

the letdown through A-loop steam generator could be stopped

earlier and the discharge of slightly contaminated steam

could be reduced (point J on Fig. 3).

AZ The signal ordering the automatic isolation of the system

is again operational. However, shortly thereafter isolation

starts again (pressure peak at 37 bar) due to a misregulation

of pressure. Isolation is again bypassed to allow starting

the RHRS.

2.5. Further sequences

Primary pressure decreases to become lower than the secondary

pressure in B-loop steam generator. Secondary level decreases,

which may create a dilution risk-. The boric acid concentration

is controlled every half hour (stabilized at - 1500 ppm).

Thkanks to cooling down, pressure decreases slowly in B-loop

steam generator and reaches a value lower than the primary

pressure. From this moment on, attention is paid to always

maintain primary pressure above that in the steam generator.

Despite the cold water so discharged in the steam generator,

pressure decreases only slowly (due to the presence of a

warm water film at the water surface).

As the level of water in the steam generator approaches the
160

6

upper limit of the broad level measurement, pressure is

sufficiently low (t 12 kg/cm2 ) to allow nitrogen injection.

The secondary drain line is coupled with system B for

liquid waste, and the steam generator discharges into it

through the nitrogen pressure.

As the nitrogen is only slightly contaminated, it is possible

to discharge it to the atmosphere via the annulus between

primary and secondary containments.

A/ 2.6. Comments and conclusion

1) The incident has been mastered as prescribed and has

affected neither the environment nor the installation.

2) The procedure has to be reviewed with regard to the

cancellation of phase A isolat on to restore compressed

air supply to the reactor building.

3) It has to be checked if some changes are not required

in the IA system within the reactor building.

4) The further analysis of the incident has been hard to

perform due to the poor quality of the computer data.
161

ATTACHMENT 1 - COMPUTER DATA

1. Initiating phase

19 21'06" : pressurizer pressure below reference pressure

19 22'51" : demand for accelerating charging pump

19 23'31" : pressuiizer heaters disconnected due to

low level

19 23132" : CV letdown station valves closed

19 25142" : isolation valves of relief and spray valves closed

19 26114" : low pressure in primary system

19 30'30" : very low pressure in pressurizer

19 30O30" : high level in B-loop steam generator

19 38'32" : B primary pump disconnected

2. Safety injection phase

19 40118" : low pressure in pressurizer

19 40119" : safety injection due to pressurizer low pressure

19 40119" : diesels started

19 40'19" : isolation of reactor building ventilation

19 40120" : phase A isolation of reactor building

19 40'24" : actuation signal of HP SI-pumps

19 40133" : HP SI-valves opened

19 43'48" : very large auxiliary feedwater flow to A SG

A/ 19 43154" : low level in A SG

19 44'39' : very large aCxiliary feedwater flow to B SG

A/ 19 44'42" : valve from B SG to turbo-pump opened

A/ 19 44'51" : valve from A SG to turbo-pump opened

19 53'12" : auxiliary feed pump B disconnected

19 56137" : very low level in auxiliary feedwater tank

19 57'11" : pressurizer level back to normal

19 57'29" : pressurizer heaters re-started

19 58148" : high level in pressurizer
162

- 2-

3. SI-sianal cancelling 2hase

20 00'15"

20

20

20

20

20

20

A/ 20

20

20

20

20

20

00 '21"

03 '24"

05 59"

06 '05 "

10,59"

21 15"

22 36"

25 22"

38 '33"

40 '25"

48 '54"

49 '00"

: diesel automatic starting signal cancelled and

SI-pumps actuation signal cancelled

: back to SI

: LP compressed air in the reactor building

: safety injection cancelled

: safety" injection

: reactor building ventilation isolation cancelled

: HP SI-pump B disconnected

: accumulator A valve closed

: HP SI-pump A disconnected

: valve CC-096 closed

: valve CC-099 closed

: compressed air supply to reactor building restored

: primary pumps CC valve-s re-opened

4. Actuation of R9RS

22 35'54" : valves RC-003 opened
163

~JLIbb~~WAT-M- BlEEN F I G'u~ R1

Scbrijvcr : .2 A-1PC 2

B1. RC 05 lus Awa-, eexn7 0 - 350 0C

2. YRO. RC 25 luB ar= bcen~ 0 - 3500C

i
164

.&-;-2ERATLTJR KOU.D BEEN FIGUL-- 2

Schrijver : A - I RC'1

1. B].. RC 09 lus A koud bee;,,- 0 - 350*C

2. Ro. RC 29 lus B koud been~ 0- 3500C

I
165

D.M74 RC F:GM 3

Schrijver : 2. A - I RC 3

I. Ba. RC Il cruk RC 0 - 200 kg/c-.2

fk~0 ;DL~ji 4 2~/cm:' l",i ' i"i ' "..

•'. II

I/,1 ! • 1 f *, : } ! * '

S k 'I :0-2* ) 

i ., .: ,t ' ' .:
166

jR7 R~k-C-~ f=R

Schrijover : 2 A - I TC 3

0 - 20o ýI/c=2

______________ _____________ I ___ II

i zII i UH 75 C

ITI

'TM

IT W.111I.I

iit . ....... Z.... 9. .....
167

DR7K R 2 FILC,7uR 4

Schrijver :. A - I PR

1. Bl. PR 6- 7- 8 - 9 Druk R2

Meting in dienst spoor 1

115 - 175 kg/cz2

ii

I.

I.

I i lik

l'l ,:I

1 17 1110 ;

I I f

lDrb,- R 21-

Ff. t

I, I I I I

71

:J drn .

!

L'_ "i f' __°" '
168

P

PZ.iL R 2 F. ,LT%7-R .5

Schrijvtr : .; A- 1 PR I • . -Z

1. B3. L. PB 11 - 12 - 13 Peil B 2

2. Ro. L. Ref. Ref. Peil R 2

o - 100

o - 100 0

Meting in dienst spoor I :

I j: L iII I L I TE N

IA V .

12.1

I .:L ,. I ; j : P J .I s!. i tL

~~ ji' ;j :. :

1fl. I *VjfIII~f. I.. / 1 I 1___

15 _____ IMI:I. O '*v..1

WY *I L 

verfkeede sc.,-c"

6 evne door

C,10 - 100

0 -100 0

m

I III I * I
169

S3. -F:GUu7-R ?EL 6

Sc~rijiver .2 A - v47 s.1

1. BI. L. 7W 9 A - 10 A Pei. SoA. 0-..3500

2. Ro. P. YS 24 A - 6 A Druk SGA 0 -85 Xg/cmx

Meting in dienst spoor1

spoor 2

.II

I ji

* I r i F: ~ .~r . *~L I. U~.*.3 3 ~~~J: 3

..........

7-*I ?7.___

* :1!' I

3, .3 .. 33

3 3 . . I ~

.3

,, .3: i:u~; fl**~ 3

3p.' * 3*333
170

.5C7 8 -, " , ý .- r

SG. B PEI1L - DRU ':C77vR 7

Schrijver : 2. A - 4 7-

1. B1. L. ?r 9 B - 10 B

2. Ro. P. ys 4 B- 6 B

,V, S &--

Peil SO B

S A C.~4,ju4-rc

flru Sd' B

0 - 3500 =

0 - 85 kg/c-2

Meting in dienst spoor I :

.spoor 2 :

6i Fr. C-ý,
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 001

tN A NttttttttXtEtt*ttt * ANNE XE 2

*t**tt*ttttttttt tt*tt*t

=DOEL2 SGTR INCIDENT 25 JUNE 1979

*

*

100 NEW TRANSNT

101 RUN

201 2700. I.E-S 0.25 3 8 800 2000 M

t MINOR EDIT *

************t t** ***t *******t *,*t*****t**t*t****t**t*t***t*t**tt ***t*****

*

301

302

303

304

305

306

307

308

309

310

311

312

315

318

319

320

322

323

324

325

328

329

;330

331

332

333

334

335

336

337

338

339

P

CNTRLVAR

CNTRLVAR

CNTRLVAR

MFLOWJ

MFLOWJ

P

P

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CNTRLVAR

CNTRLVAR

MWLOWJ

P

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MFLOWJ

CNTRLVAR

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33001CKM0

031

305

901

183000000

181000000

123010000

621010000

045010000

007

600

700

078

969

979

8650000C0

630010000

730010000

617000000

717000000

610

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009

112030000

61800C000

002

612

712

043010000

043020000

043030000

045

*

*

*

*

*

t

*

*

PRESSURISER

CORE POWER

HEATERS POWER

PRESSU LEVEL

LETDOWN

CV

PRESSURE AT BREAK

'-A

'-1

'-A

* UPPER HEAD

2

* HPS I

FW + AFW

STEAM TURBOPUMP

* SO PRESSURE

* HEAT TRANSFER RATE

* ENERGY BALANCE

SURGELINE MASS FLOWRATE

* MASS BALANCE

SO 8 RISER LEVEL

* SO A

PRIMARY MASS FLOW RATES

PRESSURISER MASS
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 002 *

340

341

342

343

344

345

346

347

348

349

351

352

353

354

355

356

357

358

359

360

361

362

363

364

365

366

367

368

369 t

370

371

372

373

374

375

376

377

378

379 *

380

381

382

383

384

385

386

387

388

389

MrLOWJ

CNTRLVAR

VOIDGJ

TEMPF

IEMPF

TEMPF

TEMPG

CNTRLVAR

CNrRLVAR

CNTRLVAR

VOIDO

VOIDG

VOIDO

VOIDG

VOIDO

VOIDG

VOIDO

VOIDG

VOIDG

CNTRLVAR

VOIDG

VOIDG

VOIDG

VOIOG

VOID1

VOIDG

VOIDG

VOTOG

VOIDG

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

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MFLOWJ

CNTRLVAR

CNTRLVAR

VAPGEN

VAPGEN

MFLOWJ

MrFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

MFLOWJ

CNTRLVAR

CNTRLVAR

VAPGEN

VAPGEV

618000000

012

618000000

015030000

041010000

045010000

330010000

991

113

114

620010000

620020000

620030000

620040000

621010000

623010000

611010000

613010000

612010000

600

720010000

720020000

720030000

720040000

721010000

723010000

711010000

713010000

712010000

623030000

623020000

623030000

611010000

611020000

617000000

611

613

613010000

622010000

723030000

723020000

723030000

711010000

711020000

717000000

711

713

713010000

722010000

* BREAK * V

* VESSEL TEMPERATURE *

* PRESSU TEMPERATURE

* PRESSU HEAT LOSSES

* AVG TEMPERATURE

* SUBCOOLING

* SGB VOIDG

* SO B MASS INVENTORY * SG A VOIDG

'-a

* SG B SEPARATOR MASS FLOW RATESY ***

SO 8 BY PASS MASS-FLOW RATES

SO

SG

SG

BBB

DOWNCOMER MASS FLOW RATE

COLLAPSED WATER LEVEL

MEASURED WATER LEVEL

* SG A SEPARATOR MASS FLOW RATES

• SO A BYPASS MASS FLOW RATES

* SO A OOWNCOMtR MASS FLOW RATE

• SO A COLLAPSED WATER LEVEL • SO A MEASURED WATER LEVEL
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 003

391

392

393

394

395

396

397

398

399

2

t

*

VOIDG

VOIDG

VOIDG

CNTRLVAR

TEMPF

1EMPF

TEMPF

TEMPF

CPUTIME

630010000

625010000

627010000

993

251020000

211030000

151020K)00

113010000

0

* * ********************t****************** *2*t*t*t*t* *t*t**t*****tt****t*tt*tt*

tTRIP

t***ttt**tttt*tt*t*****tl ttt*******t***t*ttt**ttttt*tt**ttt*ttt**2t*t**t****t*tt

2

550 TIME

561 TIME *

0 GT NULL 0

0 LT NULL 0

900

1900.

N

N

* OPEN RELIEF VALVE

* TURBOPUMP ON

*

503

504

529

530

542

560

571

580

574

575

576

591

601

602

630

641

642

661

676

t

TIME 0

TIME 0

TIME 0

TIME 0

TIME 0

TIME 0

P 330010000

CNTRLVAR 901

TIME 0

TIME 0

TIME 0

TIME 0

503 AND 504

-503 OR -504

529 AND 530

-591 AND -580

641 OR 542

560 ANU 561

575 AND 576

GT

LT

GT

LT

GT

GT

LT

LT

GTGT

LT

GT

N

N

N

N

N

N

N

NULL

NULL

NULL

NULL

NULL

NULL

NULL

NULL

NULL

NULL

NULL

NULL

0

0

0

0

0

0

0

0

0

0

0

0

1112.

2105.

2106.

2287e

2248.

1482.

117.E5

0.2

1428.

1479.

1992.

1000.

N

N

N

N

N

N

L

L

N

N

N

N

• PUMP B STOP * PUMP B STOP

* SPRAY

* SPRAY

* HEATER ON

* TURBOPUMP

* SI

* LPR 20%,

* MOTOPUMP "A" ON

* MOTOPUMP "B"

*13

* SGA DISCHARGE

'-I

--J

2 SPRAY ON *

* HEATER ON

TURBOPUMP ON 2 MOTOPUMP B ON

598 TIME

599 TIME

0 LE NULL 0

0 GE NULL 0

10000.

10000.

L BIDON

L 2 BIDON

*VESSEL2

222*22t*22222t22* 2*22222*222*222*2t*2*22t*t2222t22222222222*ttt22t2t2t22*22*22t2
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 004

*DOWNCOME-R

0110000 VDCOMER BRANCH

0110001 2 1

0110101 2.169 1.584 0. 0. 90. 1.584 4.E-5 0.467 00

0111101 013000000 011000000 0. 0. 0. 0000

0112101 011010000 045000000 0.00256 2.7 2.7 0000 f

0130000 INOZZLE BRANCH

0130001 3 1

0130101 2.0874 0.872 0. 0. -90. -0.872 4.E-5 0.467 00

0131101 013010000 015000000 0. 0. 0. 0000

0132101 153010000 013000000 0.383 0.6075 0.6075 0000

0133101 253010000 013000000 0.383 0.6075 0.6075 0000 a

*

$

* DOW14COMER ANNULUS

0150000 DOWNCOM ANNULUS

0150001 3

0150101 1.41 3

0150301 1.361 2

0150302 1.362 3

0150601 -90. 3

0150801 4.E-5 0.11 3

0150901 0.10835 0.10835

0151001 00 3

0151101 0000 2

0151300 1 *

* VESSEL BOTTOM *

0210000 VESBOT SNGLVOL

0210101 0. 0.638 2.679 0. *

* LOWER MIXING PLENUM *

0230000 LMIXPL BRANCH

0230001 3 1

0230101 0. 0.638 5.359 0.

0231101 015010000 023010000

0232101 023010000 025000000

0233101 023000000 021010000 S

* CORE INLET PLENUM *

0250000 CORINPL BRANCH

0250001 2 1

0250101 0. 1.013 3.574 0.

0251101 025010000 031000000

0252101 025010000 035000000 C * CORE

*

2 I-a

90. 0.638 4.E-5 O 00

90. 0.638 4.E-5 0. 00

0. 1. 1. 0000

1a 1. 1. 0000

0. 0. 0. 0000

90. 1.013 4.E-5 0. 00

2.5 3.93 3.93 0000

0.1 6.32 6.32 0000
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 005

0310000 CORE PIPE

0310001 4

0310101 2.5 4

0310301 0.6095 4

0310601 90. 4

0310801 4.E-5 0.0155 4

0310901 2.5 2.5 3

0311001 00 4

0311101 0000 3

0311300 1 *

* CORE EXIT *

* CORE BYPASS *

0350000 CORBYPS SNGLVOL

0350101 0. 2.438 1.9706 0. 90. 2.%38 4.E-5 0.0 00

0390000 COREX BRANCH

0390001 3 1

0390101 0. 0.6085 2.3252 0. 90. 0.6085 4.E-5 0. 00

0391101 031010000 039000000 2.5 1.8 1.8 0000

0392101 035010000 039000000 0.1 6.32 6.32 0000

0393101 039010000 041000000 1. 0.202 0.262 0000

t CORE PLENUM

0410000 CORPLEN SNGLVOL Lr

0410101 0. 0.8965 5.103 O0 90. 0.8965 4.E-5 0.2 00

UPPER PLENUM

0430000 UPPLEN BRANCH

0430001 3 1

0430101 0 1.584 9.349 0. 90. 1.584 4.E-5 0.2 00

0431101 041010000 043000000 0. 0. 0. 0000

0432101 043000000 111000000 0;383 0.1737 0.1737 0000

0433101 043000000 211000000 0.383 0.1737 0.1737 0000 2

* VESSL DOME I

0450000 DOME BRANCH

0450001 1 1

0450101 0. 1.496 8.833 0. 90. 1.496 4.E-5 0. 00

0451101 043010000 045000000 0.00256 2.7 2.7 0000 H

C HEAT STRUCTURES

* CORE HEAT STRUCTURES

10311000 4 5 2 1 O0

10311100 0 1

10311101 2 04004647 1 0.0047425 1 0.005395

10311201 1 1 1 2 -4 3 -2 4

10311301 1, 1 1. 2 O, 3 0. 4
FILE: SGTR4 CU)(WCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 006

10311400

10311401

10311402

10311403

10311404

10311501

10311601

10311701

10311702

10311703

10311704

10311901

*

-1

1158.3 1061.4 812.12 606. 583.

1158.3 1061.4 812.12 606. 583.

1158.3 1061.4 812.12 606. 583.

1158.3 1061.4 812.12 606. 583.

0 0 0 0 0. 4

031010000 10000 1 0 441.0 4

100 0.16667 0. 0. 1

100 0.33333 0. 0. 2

100 0.33333 0. 0. 3

100 0.16667 0. 0. 4

0 0. 0.0136 0.0136 4

S

* FIRST PRIMARY LOOP

* HOT LEG *

1110000 HTLGll SNOLVOL

1110101 0.383 2.476 0. 0. 0. 0. 4.E-5 0.698 00

1120000

1120001

1120101

1121101

1122101

1123101 *

*

1130000

1130101

t

*

'STEAM

S

S

HTLG12 BRANCH

3 1

0.383 2.476 0. 0. 0. 0. 4.E-5 0.698 00

111010000 112000000 O 0. 0. 0000

112010000 113000000 0. 0. 0. 0000

301000000 112000000 0. 10. 10. 0000 *1 KF TO BE CHECKED

HTLG13 SNGLVOL

0.383 2.476 0. 0. 30.8 0.95 4.E-5 0.698 00

01

GENERATOR B

* INLET BOX

1110000

1210001

1210101

1212101

1211101

1220000

1220001

1220101

1220301

1220601

1220801

1221001

1221101

INBOX BRANCH

2 1

0. 1.685 4.392 0. go. 1.685 4.E-5 1.822

121010000 122000000 0.99 0.5 1.0 0000

113010000 121000000 0.435 0.4145 0.5 0000

00

UUTUBE PIPE

8

0.99 8

0.908 8

90. 8

1.6E-6 0.01966

o 8

0000 7

8
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 007

1221300 1 *

1230000 UJUN BRANCH

1230001 2 1

1230101 0.99 1.816 0. 0. 45.0 1.284 1.6E-6 0.01966 00

1231101 122010000 12300(0000 00.00 0. 0. 0000

1232101 123010000 124000000 00.00 0. 0. 0000 *

*

*

1240000 DUTUB1 PIPE

1240001 5

1240101 0.99 5

1240301 1.816 5

1240601 -45. 1

1240602 -90. 5

1240801 I.E-7 0.01966 6

1241001 00 5

1241101 0000 4

1241300 1

* OUBOX BRANCH *

1250000 OUBOX BRANCH

1250001 2 1

1250101 0. 1.685 4.392 0. -90. -1.685 4.E-5 1.822 00 4

1251101 124010000 125000000 0.99 1. 0.5 0000

1252101 125010000 131000000 0.487 0.040 1.000 0000

*

* STEAM GENERATOR SECONDARY SIDE *

6110000 BYPASSB BRANCH

6110001 2 0

6110101 8.048 2.424 0. 0. 90. 2.424 5.E-5 0; 00

6112101 611010000 627000000 0.00 00.0 00.0 00000

6111101 611000000 612000000 0. 200ý 1000. 00000

t

6120000 8612 BRANCH

6120001 1 0

6120101 8.048 .735 0. 0. -90. -. 735 5.E`5 O 00

6121101 612010000 613000000 00.00 0. 200. 0000

4

6130000 FEEDMIX SNGLVOL

6130101 O, 0.697 54596 0. -90. -0.697 5.E-5 0. 00 I

6140000 FEEDOWC SNGLJUN

6140101 613010000 615000000 8.0398 0. 1000.' 0000 *

6150000 SGLDCOME1 ANNULUS

6150001 4
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 008

6150101

6150102

6150301

6150302

6150601

6150801

6150802

6150901

6151001

6151101

61513)00

6170000

6170101

6200000

6200001

6200101

6200301

6200601

6200801

6201001

6201101

6201300

2

6210000

6210001

6210101

6211101

6212101

6220000

6220001

6220101

2

6230000 6230001

6230101

6231101

6232101

6233101

2.589 1

0.4845 4

1.938 1

2.55 4

-90. 4

5.E-5 0. 1

5.E-5 0. 1015 4

0. 1000. 3

00 4

0000 3

0

SGDCPJ1 SNOLJUN

615010000 620000000

SOPIPE PIPE

4

4.432 4

1.816 4

90. 4

1.E-4 0.03543 4

00 4

0000 3

0

.000 3.3 1000. 0000

cO

BREAK BRANCH

2 0

4.432 2.324

620010000 621000000

621010000 622000000

TOPRIi BRANCH

0 0

4. 1.432 0.

TOPRI2 SEPARATk

3 0

4. 2.424 O.

0. 0.

00.00

00.00

90.0 2.324

0. 0. 0000

0. 0. 0000

1.E-4 0.03543 00

0. 90.0 1.432 0.00009; 0. 00

0 . o

623010000 625000000 2.75

623000000 612000000 0.00

622010000 623000000 0.00

90.0 2.424 0.00005

20.4 20.4 01000 01

1.0 1000. 01000 0.1

1.81 1.81 01000

0. 00

2--------------------------------------------------------2

* RREAK JUNCTION 1 *--------------------------------------------------------*

6180000 BREAK SNGLJUN

6180101 122010000 621000000 1.724E-4 2.6 2.6 00003 0. 0.

6180201 1 14.987 0. 0. a
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAUE (009

6300000 SGOOMEI BRANCH

6300001 1 1

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6270000 PLENUMB BRANCH

,6270001 1 1

6270101 8.5600 1. 0. 0. 90. 1. 5.E-5 0. 00

6271101 627010000 625000000 .00 .0000 .0000 00003 *

*

6400000 SGL1 PIPE

6400001 3

6400101 0.288 3

6400301 22.7171 3

6400601 00.0 3

6400801 4.E-5 00.000 3

6401001 00 3

6401101 0000 2

6401300 1 *

*

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8600000 TV860 TMDPVOL

8600101 10. 1. 0. v 0. 0. 0. 0. 00

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8650101 640010000 860000000 0.

8650200 1 661 CNTRLVAR 883

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* AUXILIARY FEED WATER

6050000 POOL1 TMOPVOL

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(1MTPUMP)

0. 00

0. 00
FILE: SG(R4 CDCJCL Al

ý-6060201 0. 1.E5 308.15

S,

VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 010

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FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 011

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FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 012

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FILE: SGTR4 COCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE Olý

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FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 014

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$ SSTEAM GENERATOR SECONDARY SIDE

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FILE: SGTR4 COCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PACE 015

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FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 016

7230000 TOPRI2 SEPARATR

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FILE: SGTR4 CDCJCL Al

7050200 3

7050201 0. 1.E5 308.15

VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 017

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1-i

* STEAM GENERATOR HEAT STRUCTURE 9

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FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYS.TEM PAGE 018

6

* PUMP SUCTION LEG

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FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 01g

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FILE: SGFR4 CDU:CL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 020

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3170001 2 1

3170101 2.5164 0.6 0. 0. go. 0.6 0. 0. 01

3170200 2 155.E5 1.

3171101 3160100(X) 317000000 0. 0. 0. 0000

3172101 31701fX000 320000000 0. 0. 0. 000n

0. 0. 01

0. 0. 01

01

01

F-i

0D

01

01
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 021

3171201 0. 0. 0.

3172201 0. 0. 0. *

3200000 PRES320 PIPE

3200001 6

:3200101 2.5164 1 1.6964 6

3200301 0.4 1 0.3 2 0.2 3 0.15 4 0.1 6

3200601 90. 6

3200801 0. 0. 6

3201001 01 6

3201101 0000 5

3201201 2 155.E5 1. 0. 0. 0. 6

3201300 1

3201301 0. 0. 0. 5 *

3300000 PRESDOM BRANCH

3300001 1 1

3300101 1.6964 0.05 0. 0. 90. 0.05 0. 0. 01

3300200 2 155.E5 1.

3301101 320010000 330000000 0. 0. 0. 0000

3301201 0. 0. 0.

*

t

* HEATERS

13113000 2 3 2 1 0. I-h

13113100 0 2

13113101 0.005 1 0.00338 2

13113201 5 2

13113301 1. 1 0. 2

13113401 618. 3

13113501 0 0 0 1 62.532 1

13113502 0 0 0 1 93.798 2

13113601 312010000 0 1 1 62.532 1

13113602 312010000 0 1 1 93.798 2

13113701 311 0.4 0. 0. 1

13113702 311 0.6 0. 0. 2

13113901 0 0. 0. 0.772 1

13113902 0 0. 0. 1.158 2

* SPRAY SYSTEM * ******t S** *****************,*****************2,************,*****

*

3410000 SPRJUN SNGLJUN

3410101 152010000 343000000 8.171E-3 0. 0. 0000

3410201 0 0. 0. 0. *

3430000 SPRLINE PIPE

3430001 4

3430101 8.171E-3 4
FILE: S(3tR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 02ý

3430301 3. 3

3430302 3.956 4

3430601 90. 4

3430801 4.E-5 0. 4

3431001 00 4

3431101 0000 3

3431201 3 154.88E5 528. 0. 0. 0. 1

3431202 3 154.64E5 528. 0. 0. 0. 2

3431203 3 154.41E5 528. 0. 0. 0. 3

3431204 3 154.13E5 528. 0. 0. 0. 4

3431300 1

3431301 0. 0. 0. 3 *

3450000 RESPR TMDPJUN

3450101 343010000 317010000 0.00456

3450200 0 630

3450201 -1. 0.0 0. 0.

3450202 0. 2.741 0. 0. *

S

3420000 SPRJUN SNGLJUN

3420101 252010000 344000000 8.171E-3 0. 0. 0000

3420201 0 0. 0. 0. *

3440000 SPRLINE PIPE

3440001 4

3440101 8.171E-3 4

3440301 3. 3

3440302 3.958 4

3440601 90. 4

3440801 4.E-5 0. 4,

3441001 00 4

3441101 0000 3

3441201 3 154.88E5 528. 0. 0. 0. 1

3441202 3 154.64E5 528. 0. 0. 0. 2

3441203 3 154.41E5 528. 0. 0. 0. 3

3441204 3 154.13E5 528. 0. 0. 0. 4

3441300 1

3441301 0. 0. 0. 3

S

3460000 RESPR TMDPJUN

3460101 344010000 317010000 0.00456

3460200 0 630

3460201 -1. 0.0 0. 0.

3460202 0. 2.741 0. 0. S

* CONTAINEMENT

9500000 V950 SI4GLVOL

9500101 10000. 10.33 0. 0. -90.0 -10.33 4.E-5 0. 00

9500200 1 318. .01
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 023

*

9600000 V960 SNGLVOL

9600101 10000. 16.53 0. 0. -90.0 -16.53 4.E-5 0. 00

9600200 1 318. .01 *

9700000 V970 SNGLVOL

9700101 10000. 16.53 0. 0. -90.0 -16.53 4.E-5 0. 00

9700200 1 318. .01 *

*

$ HEAT STRUCTURES

* PRESSURIZER

* SURGE LINE *

13000000 3 3 2 1 0.10795

13000100 0 2

13000101 0.01 1 0.01858 2

13000201 3 2

13000301 0. 2

13000501 301010000 10000 1 1 6.3465 2

13000502 301030000 0 1 1 4.07 3

13000601 0 0 0 1 6.3465 2

13000602 0 0 0 1 4.07 3

13000701 0 0. 0. 0. 3

13000801 0 0. 0. 0. 2

13000802 0 0. 0. 4.07 3

* BOTTOM

13001000 2 4 3 1 0.9

13001100 0 2

13001101 0.01 1 0.02 2 0.044 3

13001201 5 3

13001301 0. 3

13001401 617.91 4

13001501 310010000 0 1 1 0.16666 1

13001502 311010000 0 1 1 0.33333 2

13001601 950010000 0 3950 1 0.16666 1

13001602 950010000 0 3950 1 0.33333 2

13001701 0 0. 0. 0. 2

13001801 0 0. 0. 0.3 1

13001802 0 0. 0. 0.6 2 i

* CYLINDRICAL SHELL

13002000 7 4 2 1 0.g95

13002100 0 2

13002101 0.01 1 0.02 2 6.069 3

13002201 5 3

13002301 0. 3

13002401 617.91 4
FILE: SGIR4 C[JCJCL Al

13002501 312010000 1000000

13002502 314010000 

0

13002503 3150 10000 

0

13002504 316010000 

0

13002505 317010000 

0

13002506 320010000 

0

13002601 956010000 

0

13002602 950010000 

0

13002603 950010000 

0

13002604 950010000 

0

130026('5 950010000 

0

13002606 9500100("0 

0

13002701 0 0. 0. 0. 

7

13002801 0 0. 0. 1.766 

2

13002802 0 0. 0. 1.539 

3

13002803 0 0. 0. 1.515 

4

13002804 0 0. 0. 0.8 

5

130028035 0 0. 0. 0.6 

6

13002806 0 0. 0. 0.4 

7

*

VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 024

I

3950

3950

3950

3950

3950

3950

1.765

1.539

1.515

0.8

0.6

0.4

1.766

1.539

1.515

0.8

0.6

0.4

23456723456

UPPER SHELL

*

13003000 6 4 3 1 0.9

13003100 0 

2

13003101 0.01 1 0.02 

2

13003201 5 

3

1300)3301 0. 

3

13003401 617.91 

4

13003501 320020000 0 

1

130035012 320030000 0 

1

130035(03 320040000 0 

1

1300)3504 320050(000 0 

1

13003505 3200)60(00 0 

1

13003506 330010000 0 

1

13003601 950010000 

(

13003602 95W0 10000' 

(

13003603 950010000

13003604 950010000

13003605 950010000

13003606 95001 0f0X)00

13003701 0 0. 0. 0. 

6

13003801 0 0. 0. 0.3

13003802 0 0. 0. 0.2

13003803 0 0. 0. 0.15

13003804 0 0. 0. 0.1

13003005 0 0. 0. 0.1

13003806 0 0. 0. 0.05 *t

* STEAM GENERATOR

* COOLANT CIIANNEL

0.034 

3

f-a

13456

0.16666 ..

1

0.11111 

2

0.08333 

3

0.05555 

4

0.05555 

5

0.02777 

6

3950 

1

3950 

1

3950 1

3950 

1

3950 

1

3950 

1

0. 16668 1

0.11111 

2

0.08333 

3

0.05555 

4

0.05555. 

5

0.02777 

6
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 025

11211000 1 7 1 1 0.

12211000 1 7 1 1 0.

11211100 0 

2

12211100 1211

11211101 0.01 1 0.05 2 0.083 4 0.05 5 0.01 

6 11211201 5 6

11211301 0. 

6

11211501 121010000 0 1 0 7.1 

1

11211601 125010000 0 1 0 7.1 

1

11211701 0 0. 0. 0. 

1

11211801 0 0. 0. 1.503 

1

11211901 0 0. 0. 1.503 

1

12211501 221010000 0 1 0 7.1 

1

12211601 225010000 0 1 0 7.1 

1

12211701 0 0. 0. 0. 

1

12211801 0 0. 0. 1.503 

1

12211901 0 0. 0. 1.503 

1

* TUBE PLATE

11212000 2 2 1 1 0.

12212000 2 2 1 1 0.

12212100 1212

11212100 0 

2

11212101 0.03056 

1

11212201 5 

1

11212301 0. 

1

11212501 121010000 400CO. 1 0 61. 

2

11212601 620010000 0 1 0 61. 

2

11212701 0 0. 0. 0. 

2

11212801 0 0.01966 0.01966 .575 

2

11212901 0 0. 0. 0. 

2

*

12212501 221010000 4000000 1 0 61. 

2

12212601 720010000 0 1 0 61. 

2

12212701 0 0. 0. 0. 

2

12212801 0 0.01966 0.01966 0.575 

2

12212901 0 0. 0. 0. 

2

* LOWER SHELL

16151000 3 4 2 1 1.5465

17151000 3 4 2 1 1.5465

16151100 0 

2

17151100 6151

16151101 0.01 1 0.02 2 0.04526 

3

16151201 5 

3

16151301 0. 

3

16151501 615040000 -10000 1 1 2.55 

3

16151601 960010000 0 3960 1 2.55 

3

16151701 0 0. 0. 0. 

3

16151801 0 0. 0. 2.55 

3

17151501 715040000 -10000 1 1 2.55 

3

17151601 970010000 0 3960 1 2.55 

3

17151701 0 0. 0. 0. 

3
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 026

17151801 0 0. 0. 2.55 

3

*

: TRANSITION CONE

16152000 1 4 2 1 1.7822

17152000 1 4 2 1 1.7822

16152100 0 

2

17152100 6152

16152101 0.01 1 0.03 2 0.055 

3

16152201 5 

3

16152301 0. 

3

16152501 615010000 0 1 1 1.937 

1

16152601 960010000 0 3960 1 1.937 

1

16152701 0 0. 0. 0. 

1

16152801 0 0. 0. 1.937 

1

17152501 715010000 0 1 1 1.937 

1

17152601 970010000 0 3960 1 1.937 

1

17152701 0 0. 0. 0. 

1

17152801 0 0. 0. 1.937 

1

*UPPER SLL

* UPPER SIELL

16153000 5 4 2 1 2.2446

17153000 5 4 2 1 2.2446

16153100 0 

2

17153100 6153

16153101 0.01 1 0.03 2 0.051 

3

16153201 5 3 On

16153301 0. 

3

16153501 613010000 0 1 1 0.696 

1

16153502 612010000 0 1 1 0.735 

2

16153503 611010000 0 1 1 2.424 

3

16153504 627010000 0 1 1 1.000 

4

16153505 630010000 0 1 1 2.093 

5

16153601 960010000 0 3960 1 0.696 

1

16153602 960010000 0 3960 1 0.735 

2

16153603 960010000 0 3960 1 2.424 

3

16153604 960010000 0 3960 1 1.000 

4

161'53605 960010000 0 3960 1 2.093 

5

16153701 0 0. 0. 0. 

5

16153801 0 0. 0. 0.696 

1

16153802 0 0. 0. 0.735 

2

16153803 0 0. 0. 2.424 

3

16153804 0 0. 0. 1.000 

4

16153805 0 0. 0. 2.093. 

5

17153501 713010000 0 1 1 0.696

17153502 712010000 0 1 1 0.735 

2

17153503 711010000 0 1 1 2.424 

3

17153504 727010000 0 1 1 1,000 

4

17153505 730010000 0 1 1 2.093 

5

17153601 970010000 0 3960 1 0.696 

1

17153602 970010000 0 3960 1 0.735 

2

17153603 970010000 0 3960 1 2.424 

3

17153604 970010000 0 3960 1 1.000 

4

17153605 970010000 0 3960 1 2.093 

5
FILE: SGrR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 027

17153701 0 0. 0.

17153801 0 0. 0.

17153802 0 0. 0.

17153803 0 0. 0.

17153804 0 0. 0.

17153805 0 0. 0. *

0. 5

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1

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2

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3

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4

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5

1.524

1.524

* WRAPPER

16154000

17154000

16154100

17154100

16154101

16154201

16154301

16154501

16154502

16154503

16154504

16154505

16154606

16154601

16154602

16154604

16154605

16154606

16154607

16154701

16154801

16154802

16154803

16154804

16154805

16154806

16154901

16154902

16154903

16154904

16154905

16154906

17154501

17154502

17154503

17154504

17154505

17154506

17154601

17154602

17154604

17154605

17154606

17154607

17154701

17154801

17154802

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1 8 2 2 1

0 

2

6154

0.01 

1

5 

1

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1

620010000

620020000

621010000

622010000

622010000

623010000

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613010000

612010000

611010000

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0 0. 0.

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0 0. 0.

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0 0. 0.

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720010000

720020000

721010000

722010000

722010000

723010000

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713010000

712010000

711010000

0 0. 0.

0 0. 0.

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5

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6

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7

0 1 1 2.424 8

-10000 1 1 1.461

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5

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6

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7

0 1. 1 2.424 8

0. 8

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7

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0 1 1 2.324 

5

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6

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7

0 1 1 2.424 

8

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6

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7

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0, 

8

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1414
FILE: SGTR4 CDCJCL Al

17154803 0 0. 0. 2.324

17154804 0 0. 0. 0.696

17154805 0 0. 0. 0.735

17154806 0 0. 0. 2.424

17154901 0 0. 0. 1.461

17154902 0 0. 0. 1.816

17154903 0 0. 0. 2.324

17154904 0 0. 0. 0.696

17154905 0 0. 0. 0.735

17154906 0 0. 0. 2.424 I * INTERNAL STRUCTURES *

VM/SP CONVERSATTONAL MONITOR SYSTEM PAGE 028

567845678

16203000

17203000

16203100

17203100

16203101

16203201

16203301

16203501

16203503

16203504

16203506

16203507

16203508

16203601

16203603

16203604

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FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PACE 029

17203606 725010000

17203607 730010000

17203701 0 0. 0.

17203801 0 0. 0.

17203802 0 0. 0.

17203803 0 0. 0.

17203805 0 0, 0.

17203806 0 0. 0.

17203807 0 0. 0.

17203901 0 0. 0.

17203902 0 0. 0.

17203903 0 0. 0.

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17203906 0 0. 0.

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* STEAM LINES t

0.

1.816

2.324

1..L32

2.424

1.000

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1.432

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1 1 1.000 

8

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16400000

17400000

16400100

17400100

16400101

17400101

16400201

17400201

16400301

17400301

16400501

17400501

16400601

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16400701

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VESSEL

*

* COVER

10451000

10451100

10451101

10451201

10451202

10451301

10451501

10451601

10451701

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3 3 21 3 3 21

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I 0.02346

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1

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1

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FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 030

10452000 1 5 1 0 0.

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2

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4

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4

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4

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1

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$

* BOTTOM

10210000 2 5 3 1 1.695

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2

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4

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1

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4

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4

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2

10210601 0 0 0 1 0.25 

2

10210701 0 0. 0. 0. 

2

10210801 0 0. 0. 0.638 

2

*

* DOWNCOMER WALL

10150000 3 20 2 1 1.6635 CD

10150100 0 

2

10150101 1.25E-3 5 2.OOE-3 6 3.OOE-3 7 4.OoE-3 8 5.OE-3 0 6.00E-1 10

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10150103 23.916E-3 19

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4

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10150301 0. 19

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2

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3

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2

10150602 0 0 0 1 1.362 

3

10150701 0 0. 0. 0. 

3

10150801 0 0. 0. 1.361 

2

10150802 0 0. 0. 1.362 

3

a

* UPPER PLENUM a

10110000 2 7 2 1 1.6635

10110100 0 

2

10110101 0.005 2 0.03 3 0.06 4 0.10 5 0.137 

6

10110201 3 

1

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6

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6

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2
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAUE 031

10110701 0 0, 0, O 

2

10110801 0 0. 0. 1.584 

1

10110802 0 O 0, 0.872 

2

* THERMAL SHIELD

10151000 3 3 2 1 1.4635

10151100 0 

2

10151101 0.04525 

2

10151201 3 

2

10151301 0. 

2

10151501 015010000 10000 1 1 1.136 

3

10151601 015010000 10000 1 1 1.136 

3

10151701 0 0. 0. 0. 

3

10151801 0 0. 0. 1.136 

3

10151901 0 0. 0. 1.136 

3

*

INTERNAL STRUCTURES

10300000 10 3 2 1 6.255

10300100 0 

2

10300101 0.01 

2

10300201 3 

2

10300301 0. 

2

10300501 021010000 2000000 1 1 0;638 

2

10300502 025010000 0 1 1 1.013 

3

10300503 031010000 10000 1 1. 0;6095 

7

10300504 039010000 0 1 1 0.6095 

8

10300505 041010000 0 1 1 0;8965 

9

10300506 043010000 0 i 1 1.584 10

10300601 021010000 2000000 1 1 0.638 

2

10300602 025010000 0 1 1 1.013 

3

10300603 031010000 10000 1 1 0;6095 

7

10300604 039010000 0 1 1 0.6095 

8

10300605 041010000 0 1 1 0;8965 

9

10300606 043010000 0 1 1 1.584 10

10300701 0 0. 0. 0. 10

10300801 0 0. 0. 0.638 

2

10300802 0 O 0. 1.013 

3

10300803 0 0. 0. 0.6095 

8

10300804 0 0. 0. 1. 

9

10300805 0 0. 0. 1.584 10

10300901 0 O 0. 0,638 

2

10300902 0 0. 0. 1.013 

3

10300903 0 0. 0. 0.6095 

8

10300904 0 0. 0. 0.8965 

9

10300905 0 0. 0. 1%584 10 i

* PRIMARY LEGS *

*- HOT-COLD LEGS

l1110000 3 3 2 1 0.34925

11510000 4 3 2 1 0,34925 12110000 3 3 2 1 0.34925

.12510000 4 3 2 1 0.34925
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 032

11110100 0 2

11510100 1110

12110100 1110

12510100 1110

11110101 0.031375

11110201 3 2

11110301 0. 

2

11110501 111010000

11110502 113010000

12110503 211010'(X)0

11510504 151010000

11510505 1520100(X)

12510506 251010000

12510507 252010000

11110601 

0

11510602 

0

11110701 0 0. 0.

11510701 0 0. 0.

11110801 0 0. 0.

11510801 0 0. 0.

12110601 0 0 0 1

12510601 0 0 0 1

12110701 0 0. 0.

12510701 0 0. 0.

12110801 0 0. 0.

12510801 0 0. 0.

PUMP SUCTION LEG

2

10O0O0(

10000( 1OOOOO 1000(

1O00O00( 1 (K)

0. 3

0. 4

0.6985

0.6985

2.476

1.968

0. 3

0. 4

0.6985

0. 6985

0J)

0100

0100

1 1

I I

1 1

¶ I

1 1

1 1

1 1

0 1

0 1

2.476

2.476

2.476

1.968

1.968

1.968

1.968

2.476

1.968

233242434

34

34

34 0•

1310000 4 3 2 1 0.3937

11310100 0 

2

12310000 4 3 2 1 0.3937

12310100 1310

11310101 0.035125 2

11310201 3 2

11310301 0. 

2

11310501 131010000 10000 1 1 1.806 

1

11310502 132010000 10000 1 1 1.806 

2

12310502 231010000 10000 *1 1 1.806 

2

1131050:3 13301000W 0 1 1 1.633 

3

11310504 133020000 0 1 1 1.43 

4

11310601 0 0 0 1 1.806 

2

11310602 0 0 0 1 1.633 

3

11310603 0 0 0 1 1.43 

4

11310701 0 0. 0. 0. 

4

11310801 0 0. 0. 1.806 

2

11310802 0 0. 0. 0.7874 3

11310803 0. 0. 0. 1.43 

4

12310503 231030000 0 1 1 1.633 

3

12310504 23104Y)0(X 0 1 1 1.430 

4

12310601 0 0 0 1 1.806 2

12310602 0 0 0 1 1.633 

3

12310603 0 0 0 1 1.430 

4

12310701 0 0. 0. 0. 

4

12310801 0 0. 0. 1.806 2
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 033

12310802 0 0. 0. 0.7874 

3

1ý310803 0 0. 0. 1.43 

4

t

PUMP

*

11400000 1 5 3 1 1.228

11400100 0 

2

12400000 1 5 3 1 1.228

12400100 1400

11400101 0.01 1 0.03 2 0.08 3 0.162 

4

11400201 5 

4

11400301 0. 

4

11400501 140010000 0 1 1 1. 

1

11400601 0 0 0 1 1. 

1

11400701 0 0. 0. 0. 

1

11400801 0 0. 0. 1.232 

1

12400501 240010000 0 1 1 1. 

1

12400601 0 0 0 1 1. 

1

12400701 0 0. 0. 0. 

1

12400801 0 0. 0. 1.232 

1

***t~tttt*tt**tt*t**tt~t~~•ttt~tt~t~t~tt**************t*t*t******tt $** t**t*t*

* INITIAL CONDITIONS t*t*t***tttttttttttttttttt*tttttttttttttttttttttttt~i*tttt*jt**tt*ttttttttttt*t

*

* MASS FLOW RATE

0111201 16.900 0. 0. 

0 0112201 16.900 0. 0.

0131201 7239.1 0. 0.

0132201 3628. 0. 0.

0133201 3628. 0. 0.

0151301 7239.1 0. 0. 

2

0231201 7239.1 0. 0.

0232201 7239.1 0. 0.

0233201 0. 0. 0.

0251201 6911.8 0. 0.

0252201 327.33 0. 0.

0311301 6912. 0. 0. 

3

0391201 6912. 0. 0.

0392201 327.35 0. 0;

0393201 7239.1 0. 0.

0431201 7239.1 0. 0.

0432201 3628. 0. 0.

0433201 3628. 0. 0.

0451201 -16.894 0. 0.

1121201 3628. 0. 0.

1122201 3628. 0. 0.

1123201 0. 0. 0.

1211201 3628. 0. 0.

1212201 3628. 0. 0.

1221301 3628. 0. 0. 

9

1231201 3628. 0. 0.

1232201 3628. 0. 0.

1241301 3628. 0. 0. 

4
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 034

1251201 3628. 0. 0.

1252201 3628. 0. 0.

1311201 3628. 0. 0.

1321201 3628. 0. 0.

1331301 3628. 0. 0. 

1

1400201 1 3628. 0. 0.

1400202 1 3628. 0. 0.

1511301 3628. 0. 0. 

1

1521201 3628. 0. 0.

1522201 3628. 0. 0.

2111301 3628. 0. 0. 

2

2211201 3628. 0. 0.

2212201 3628. 0. 0.

2221301 3628. 0. 0. 

9

2230201 1 3628. 0. 0.

2241301 3628. 0. 0. 

4

2251201 3628. 0. 0.

2252201 3628. 0. 0.

2311301 3628. 0. 0. 

3

2400201 1 3628. 0. 0.

2400202 1 3628. 0. O0

2511301 3628. 0. 0. 

1

2521201 3628. 0. 0.

2522201 3628. 0. 0.

3011301 0. 0. 0. 

2

3050201 1 0. 0. 0.

6111201 0.0. 0. 

6112201 0. 0. 0.

6121201 0. 0. 0.

6301201 0.00 0. 0.

6140201 0 .0 .0 .0

6151301 0. 0. .0

6151302 0. 0. .0 

2

6151303 0. 0. .0 

3

6170201 0 0. 0. .0

6201301 .0 0. 0. 

3

6211201 0. 0. 0.

6231201 0. 0. 0.

6232201 0. 0. 0.

6233201 0. 0. 0.

6212201 0. 0. 0.

6401301 0. 0. 0. 

2

7111201 0. 0. 0.

7112201 0. 0. 0.

7121201 0. 0. 0.

7301201 0.00 0. 0.

7140201 0 .0 .0 .0

7151301 0. 0. .0 

1

7151302 0. 0. .0 

2

7151303 0. 0. .0 

3

7170201 0 0. 0. .0

7201301 .0 0. 0.

7201302 .0 04 0. 

2
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PACE 035

7201303 .0

7211201 .0

7212201 .0

7231201 0.

7232201 0.

7233201 0.

7401301 0. 0. 0. 

2

3011301 0. 0. 0. 

2

3050201 1 0. 0. 0. *

0.

0.

0.

0.

0.

0.

0. 3

0.

0.

0.

0.

0.

* HEAT STRUCTURES TEMPERATURES 1

10110401 528. 

7

10150401 528. 20 10151401 528. 3

10210401 528. 

5

10300400 

0

10300401 528. 

3

10451401 528. 

6

10452401 528. 

5

11110401 528. 

3

11510401 528. 

3

11211401 528. 7

11212401 528. 

2

12212401 528. 

2

11310401 528. 

3

11400401 528. 

5

13000401 528. 

3

16151401 528. 

4

16152401 528. 

4

16153401 528. 

4

16154401 528. 

2

16203401 528. 

3

16202401 528. 

2

16400401 528. 

3

17400401 528. 

3

17202401 528. 

2

12110401 528. 

3

12510401 528. 

3

12211401 528. 

7

12310401 528. 

3

12400401 528. 

5

17151401 528. 

4

17152401 528. 

4

17153401 528. 

4

17154401 528. 

2

17203401 528. 

3

I

* PRESSURE,INTERNAL ENERGY,OUALITY

0110200 3 15S.E5 528.

0130200 3 155.E5 528.

0151201 3 155.E5 528.

0210200 3 155.E5 .528.

0230200 3 155.E5 528.

0250200 3 155.E5 528.

01

0. 0. 3
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM OA GE03l6

0311201

0350200

0390200

0410200

0430200

0450200

1110200

1120200

1131202

1210200

1221201

1230200

1241201

1250200

1311201

1400200

1511201

1520200

1530200

2111201

2210200

2221201

2241201

2250200

2311201

2400200

2511201

2520200

2530200

3011201

6110200

6120200

6130200

6151201

6201201

6210200

6220200

6300200

6230200

6401201

7110200

7120200

7130200

7151201

7201201

7210200

7220200

7230200

7300200

7401201

*I

155. r5

155.E5

155.E5

155.E5

155.E5

155.E5

155 .E5

155.E5

155.E5

155.E5

155.E5

155.E5

155 .E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.E5

155.ES

155.E5

155.E5

155.E5

155.E5

155.E5

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528. C

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

528.

0.

0.2277

0.

0.

0.

0.

0.

0.

I.

.2277

1.0. 2277

O.

0.

0.0.

0.0.

).2277

1.0000

1.

0. 0. o. 4

0. 0. O. 

2

0. 0. o. 

8

0. 0. 0. 

5

0. 0. U. 4

0. 0. 0. 

2

0. 0. 0.

0. 0. 0. 10

0. 0. 0. 

5

0. 0. 0. 

4

0. 0. O 

2

0. 0. 0. 

3

0. 0. 0. 

4

0. 0. 0. 

4

0. 0. 0. 

3

m

C)

0,

0.

0.

0. 0. 

4

0. 0. 

4

0. O. 

3

THERMAL PROPERTIES
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGF 037 *

N 12

* 

3

* 

4

* 

6

20100100

20100100

20100101

20100102

20100103

20100104

20100105

20100106

20100107

20100108

20100109

20100110

20100111

20100112

20100 151

20100152

20100153

20100154

20100155

20100156

20100157 *

21

20100200

20100201

20100202

20100203

20100204

20100205

20100206

20100207

20100208

20100209

20100210

20100211

20100212

20100251

20100252

20100253 20100254

20100255

20100300

20100301

20100302

U02 

* ZR

S-STEEL 

* GAP

C-STEEL 

* INCONEL-600 *

TBL/FCTN 

1

293. 8.37

366. 6.577

533. 5.78

616. 4.623

700. 4.633

783. 4.221

866. 3.88

950. 3.596

1033. 3.357

1200. 2.984

1977; 2.29

3088. 2.99

I fU02

273.

323.

373.

473.

673.

1373.

4700.

2.31E6

2;57E6

2.75E6

2;92E6

3. 13E6

3.44E6

6.80E6

0

",4

TBL/FCTN

273.15

473.15

673.15

873.15

1073.15

1273.15

1473.15

1673.15

1873.15

2073.15

2273.15

2473.15

255.3722

1077.594

1185.928

1248.428

2199.817

TBL/FCTN

273.

1190.

I 1 t ZR

7.

1.200438E1

1.400510E1

1'.700793E1

1.900866E!

2.200975E!

2.501085E1

3.001267E1

3.601486E1

4.401777E1

5.502352E1

6,802826E1

1.904141E6

2.312171E6

5.712422E6

2.311769E6

2.312171E6

1 *S-STEEL

13.

25.
FILE: SGTR4 COCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 038

t

20100351

20100352

20100353

225.

580.

1300.

3.5E6

4.34E6

5.29E6

I I *GAP

'REF.:STABILIZATION VESSEL.

*RHO-CD EOO-LOFT-5480

20100400 TBL/FCTN

20100401 0.56

20100451 5.4 *

*

20100500 TOL/FCTN 1 1 *C-STEEL

20100501 46.05

20100551 3.8775E6

20100600

20100601

20100602

20100603

20100604

20100605

20100651

20100652

20100653

20100654

20100655

S

TBL/FCTN

294.15

366.15

477.15

589.15

700.15

294.15

366.15

477.15

589.15

700..15

1 1 "INCONN*L-600

14.86

15.76

17.45

19.18

20.91

3.88E6

3.88E6

4.227E6

4.227E6

4.580E6

C) 00

*CONTROL SYSTEM

t SATURATION TEMPERATURE ' t

9990000 TV999 TMOPVOL

9990101 10. 1. 0. 0 0. 0. 0. 0. 00

9990200 2 0 P 113010000

9990201 -1. 155.E5 0.

9990202 1.E5 1.E5 0.

9990203 200.E5 200.E5 0.

20500100 BREAK INTEGRAL 1. 0. 0

20500101 MFLOWJ 618000000

20500200 MASSBIL SUM 1. 0, 0

20500201 0. -1. CNTRLVAR 001 BREAK

20500202 1. CNTRLVAR 079 *SI

20500203 1. CNTRLVAR 180 tCV

20500206 -1. CNTRLVAR 004 *LETDOWN 2

20500400 LETDO INTEGRAL 1. 0, 0

1*11*1 I*SS***I*****II*III*

* MASS BALANCE '
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 039

20500401 CNTRLVAR 188

20500500 LETENERG. MULT 1. 0. 1

20500501 CNTRLVAR 188 CNTRLVAR 093 t

* ENERGY *

20500600

20500601

2

20500700

20500701

20500902

20500903

20500904

2050O905 20500906

20500907

20500909

20500911

20500912

CVENERGY MULT 1. 0. 1

MFLOWJ 181000000 CNTRLVAR 083

BREAKENER MULT 1. 0. 1

CNTRLVAR 012 CNTRLVAR 081

ENERGY SUM 1. 0. 1

0. 1. CNTRLVAR 031

-1. CNTRLVAR 610

-1. CNTRLVAR 710

73190. CNTRLVAR 078

1. CNTRLVAR':006

-1. CNTRLVAR 007

1. CNTRLVAR 993

-1. CNTRLVAR 005

1. CNTRLVAR 140

1. CNTRLVAR 240

* CORE POWER

* SGB TRANSFER

* SGA TRANSFER

* SI

* CV

* BREAK

* METAL

* LETD * PUMP a

t PUMP A

* ENERGY BALANCE*

20501000 SUMW - ADDITION RATE *

20501001 0.

20501002

20501003

20501006

20501200 BRKDO

20501201 CNTF *

SUM 1. 0. 1

1. CNTRLVAR 078

1. MFLOWJ 181000000

"1. MFLOWJ 618000000

-1. CNTRLVAR 188

IFF DIFFREND 1. 0.0

RLVAR 001

t

ST

CV

BREAK

LETDOWN

'0

0

20501300

20501301

20501302

205031ou

20503101

20503102

20503103

20503104

S

20503300

20503301

20503302

20503303

20503304

20503305

CVLET SUM i.0 0. 0

0. 1. CNTRLVAR 006

-1. CNTRLVAR 005

COREPUW SUM i.

0. 1. 0 031010000

1. 0 031020000

1. 0 031030000

1 Q 031040000

6.E6 0

i*COtttt*PWttttR t*CORE POWER

LEvELCORE SUM 1. 0. 1

0 0,638 VOIDF 021010000

0.638 VOIDF 023010000

1.013. VOIDF 025010000

0.6095 VOIDF 031010000

O6095 VOIDF 031020000

CORE IICOLL4PSE0:LEVEL. !
FILE: SGrR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PACE 040

20503306

20503307

20503308

20503309 2

20503400

20503401

20503402 a2

20503500

20503501

20503502

20503503

20503504

20503505

20503506 **

20504004

20504000

20504001

20504002

20504003

20504004

20504005

20504016

20504007

20504008

20504010

20504010

20504011

20504012

20504013

20504014

20504015

20504016

20504106

20504017

20504108

20504109

205041104

20504113

20504100

20504101

20504102

20504111 a

0.6095 VOIDF 031030000

0.6095 VOIDF 031040000

0.6095 VOIDF 039010000

0.8965 VOIDF 041010000

HEADLEV SUM 1. 0. 1

0. 1.584 VOIDF 043010000

1.496 VOIOF 045010000

DOWNLEV SUM 1. 0. 1

0. 0.638 VOIDF 021010000

0.638 VOIDF 023010000

1.362 VOIDF 015030000

1.361 VOIDF 015020000

1.361 VOIDF 015010000

0.872 VOIDF 013010000

*, UPPER HEAD COLLAPSED LEVEL

*' DOWNCOMER COLLAPSED LEVEL at

atttasta•aVSStE a tt M SSt INVEsttO t

atttttastat *tttasat*ttttt tta

at VESSEL MASS INVENTOR1Y a VESSMASS SUM

0. 3.4357

1.8202

1.9190

1.9190

1.9190

2.6790

5.3590

3.5740

1.5238

1.5238

1.5238

1.5238

1.9706

2.3252

5.1030

9.3490

8.8330

LOOPS SUM

0. .9483

.9483

.9483

.87952

.87952

.79527

.69641

.75374

.75374

.75374

.75374

7.7570

1. 0. 1

RHO 011010000

RHO 013010000

RHO 015010000

RHO 015020000

RHO 015030000

RHO 021010000

RHO 023010000

RHO 025010000

RHO 031010000

RHO 031020000

RHO 031030000

RHO 031040000

RHO 035010000

RHO 039010000

RHO 041010000

RHO 043010000

RHO 045010000

0

1. 0.

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

111010000

112010000

113010000

131010000

132010000

133010000

133020000

151010000

152010000

)53010000

151020000

140010000

*5 LOOP 8 MASS INVENTORY a statatalt asstttatteattttsa
FILE: SGTR4 CDCJCL Al *

20504200

20504201

20504202

20504203

20504204

20504205

20504205

20504207

20504207

20504213

20504209

20504210

20504211

20504300

20504301

20504302

20504303

20504304

20504305

20504306

20504307

20504308

20504310

20504311

20504312

20504313

20504314

20504315

20504316

20504317 t

20504400

20504401

20504402

20504403

20504404

20504405

20504406

20504407

20504408

20504409

20504410

20504411

20504412

20504413

20504414

20504415

20504416 20504417 *

LOOPA SUM

0. .9483

.9483

.9483

.87952

.87952

.79527

.69641

.75374

.75374

.75374

.75374

747570

1, O 

1

RHO 211010000

RHO 211020000

RHO 211030000

RHO 231010000

RHO 231020000

RHO 231030000

RHO 231040000

RHO 251010000

RHO 251020000

RHO 252010000

RHO 253010000

RHO 240010000

VM/SP CONVERSATIONAL MONITOR SYSTEM

**t** *tt'**tt*tt***tt*t***

** LOOP A MASS INVENTORY 

*

** UTUBE SGA MASS INVENTORY 

*

PAGE 041

SGB

0.

SGA

0.

SUM 1. 0. 

1

.89892 RHO 122010000

.89892 RHO 122020000

.89892 RHO 122030000

.89892 RHO 122040000

;89892 RHO 122050000

.89892 RHO 122060000

.89892 RHO 122070000

.89892 RHO 122080000

1.7978 RHO 123010000

1.7978 RHO 124010000

1.7978 RHO 124020000

1.7978 RHO 124030000

1.7978 RHO 124040000

1.7978 RHO 124050000

4.3920 RHO 121010000

4.3920 RHO 125010000

SUM 1. 0. 

1

mI--

uttU3E SGA MASS INVENTORY 

* t~ttttttttltttlttt 2*ttt .89892

.89892

.89892

.89892

.89892

.89892

.89892

.89892

.89892

.89892

1.7978

1.7978

1.7978

1.7978

1.7978

4.3920

4,3920

RHO

RHO

RHO

RHO

RHO

RHO

RHO.

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

222010000

222020000

222030000

222040000

222050000

222060000

222070000

222080000

222090000

222100000

224010000

224020000

224030000

224040000

224050000

221010000

225010000
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 042

20504500

20504501

20504502

20504503

20504504

20504505

20504506

20504507

20504508

20504509

20504510

20504511

20504512

20504513

20504514

20504515

20504516

20504517

20504518

*

2

20505000

20505001

20505002

20505003

20505004

20505005 20505OO6

*

*

PRES SUM 1.

0. .24593

.24593

.15771

.50892

1.0178

4.4440

4.4440

3.8727

3.8123

2.0131

1.5098

1.0066

.50892

.33928

.25446

.16964

.16964

8.482E-2

0.

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

RHO

1

301010000

301020000

301030000

310010000

311010000

312010000

313010000

314010000

315010000

316010000

317010000

320010000

320020000

320030000

320040000

320050000

320060000

330010000

** PRESU MASS INVENTORY * *****t*,********t***** .*t

PRIMASS SUM 8.5982E-6 0.

0. 1. CNTRLVAR 045

1. CNTRLVAR 044

1. CNTRLVAR 043

1. CNTRLVAR 042

1. CNTRLVAR 041

1. CNTRLVAR 040

I * PRIMARY MASS *

tt SI SYSTEM * 20507000 P011 SUM 1. 107.010E5

20507001 0. 0.1 P 043010000

20507002 0.9 CNTRLVAR 070 *

20507100 SISUM SUM 1. 0. 0

20507101 0. 1. MFLOWJ 171000000

20507102 "1. MFLOWJ 271000000

20507800 SISUM SUM 1. 0. 1

20507802 0. 1. CNTRLVAR 071 *

0

20507900 SIBILAN INTEGRAL 1. 0. 0

20507901 CNTRLVAR 078

20508000 P/RH0122 DIV 1. 0. 1

20508001 RHOF 122080000 P 122080000

20508100

20508101

20508102

20508200

20508201

0

ENTHA122 SUM 1# 0.

0. 1. UF 122080000

1. CNTRLVAR 080

1

P/RHO180 DIV 1. 0 1

RHOF 180010000 P 180010000
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 043

20508300 ENTHA180 SUM 1 0. 1

20508301 0. 1. UF 180010000

20508302 1. CNTRLVAR 082 *

*2050B400 P/RHOG DIV 1. 0. 1

*20508401 RHOG 777010000 P 77?010000 *

'20508500 P/RHOF DIV 1. 0. 1

*20508501 RHOF 777010000 P 777010000

'20508600 ENTHAF?? SUM 1. 0. 1

*20508601 0. 1. UF ??7010000

*20508602 1. CNTRLVAR 085

*

*20508700 ENTHAG?? SUM 1. 0. 1

'20508701 0. 1. UG 771010000

*20508702 1. CNTRLVAR 084

'20508800 XENTHAG?? MULT 1. 0. 1

'20508801 CNTRLVAR 087 QUALE 777010000 i

*20508900 XENTHAL?? MULT 1. 0. 1

'20508901 CNTRLVAR 086 QUALE 777010000

i20509000 ENTHA??? SUM 1. 0. 1

'20509001 0. 1. CNTRLVAR 086

'20509002 1. CNTRLVAR 088

'20509003 ýJ. CNTRLVAR 089

20509200 P/RH0131 DIV 1 C. 1

20509201 HHOF 1310100C0 P 131010000

20509300 ENTHA131 SUM 1. 0. 1

20509301 0. 1. UF 131010000

20509302 1. CNTRLVAR 092

20511300 TAVG SUM 0.25 575.33 1 **AVERAGED TEMPERATURE*

20511301 0. 1. TEMPF 113010000

20511302 1. TEMPF 151010000

20511303 1. TEMPF 251020000

20511304 1. TEMPF 211030000

20511400 SU8COOLING SUM 1. 0. 1

20511401 0. 1. TEMPF 999010000

20511402 -1. TEMPF 113010000

*"SGB U TUBE:LEVEL.'

20512200 LEVCSGB SUM 0.908 0. 1

20512201 0. 1. VOIDF 122010000

20512202 1. VOIDF 122020000
FILE: SGIR4 Cu;JCL. AT VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 044

20512203

20512204

20512205

20512206

20512207

20512208

20512209

2

20512400

20512401

20512402

20512403

20512404

t

*

*

20513100

20513101

20513102

205132(w)

20513201

20514000

20514001

*

*

S

*

1.1.

1.

1.

1.

1.

1.414

LEVHSOB SUM

0. 0.707

1. 1.

1.

1.

VOIDF

VOIDF

VOIDF

VOI OF

VOIDF

VOIDF

VOIDF

1.816

VOIDF

VOIDF

VOIDF

VOIOF

VOI OF

122030000

122040000

122050000

122060000

122070000

122080000

123010000

0. 1

124010000

124020006

124030000

124040000

124050000

** LOOP SEAL B COLLAPSED LEVEL .*ttt*ttttttttttt ttttt*tttt55*ttt

SEALB SUM 1.

0. 1.806 VOTOF

1.806 VOIDF

0. 1

131010000

1320 1•X)00

SEALB SUM

0. 1.43

1. 0. 1

VOTOF 133020000

I..

PUMPR TRIPUNIT 2.44E6 2.44EB 0

602

20518000 INTCV INTEGRAL 1. 0. 0

205180X)1 MFLOWJ 181(X)0000

20518800 LETDOWN SUM 1. 0. 0

20518801 0. 1. MPLOWJ 183000000 S

*

*

*t CHARGING SYSTEM.* 5*t*5*ttt*t*tt*t*t*5t

SGA U TUBE LEVEL * *sstee *ssstttsss****

20522200

20522201

20522202

20522203

20522204

20522205

20522206

20522207

20522208

20522209

20522210

LEVCSGA SUM

1.

0.707

0.707

0.908

VOIDF

VOIDF

VOIDF

VOIDF

VOIOF

VOIDF

VOIDF

VOIDF

VOIOF

VOIDF

0. 1

222010000

222020000

222030000

222040000

222050000

222060000

22207C000

222080000

222090000

222100000
FILE: SGTR4 COCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 045

2

20522400

20522401

20522402

20522403

20522404 20522405

S

20523100

20523101

20523102

*

20523200

20523201

*

*

LEVHSGA SUM

0. 0.707 1.

1.

1.

1.

1.816

VOIOF

VOIDF

VOIOF

VOIDF

VOIDF

0. 1

224010000

224020000

224030000

224040000

224050000

5* LOOP SEAL A COLLAPSED LEVEL * ttttttt5 ttt5tttttt5$555*5*t*t*5tt

SEALA SUM 1. 0. 1

0. 1.806 VOIOF 231010000

1.806 VOIDF 231020000

SEALA SUM

0. 1.43

1. 0. 1

VOIDF 231040000

20524000 PUMPA TRIPUNIT 2A44E6 2.44E6 0

20524001 598

20542000

20542001

20542002

20542003

20542004

20542005

20542006

20542007

20542008

20542009

20542011

20542012

20542013

20542014

20542100

20542101

20542102

20542103

20542104

20542105

20542106

20542107

20542108

20542200

20542201

20542202

FRBL SUM LJl

0. 0.908

0.908

0.908

0.908

0.908

0.908

0.908

0.908

1.284

1.685

0.950

1.430

1.232

FMBL SUM

0. 1.284

1.816

1.816

1.816

1.816

1.685

1.806

1.806

9.81 0. 1

RHO 122010000

RHO 122020000

RHO 122030000

RHO 122040000

RHO 122050000

RHO 122060000

RHO 122070000

RHO 122080000

RHO 123010000

RHO 121010000

RHO 113010000

RHO 133020000

RHO 140010000

9.81 0. 1

RHO 124010000

RHO 124020000

RHO 124030000

RHO 124040000

RHO 124050000

RHO 125010000

RHO 131010000

RHO 132010000

DRI*V* N F*OR** C*5** ****** ** DRIVING FORCE IN LOOP 8

55 ******5*555******* *SSSSS S

FMFRBL SUM 1.0 0. 1

0. 1. CNTRLVAR 421

-1. CNTRLVAR 420
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 046

20542300

20542301

20542302 S

20541000

20541001

20541002

20541003

20541004

20541005

20541006

20541007

20541008

20541009

20541010

20541011

20541012

20541013

20541014

20541100

20541100

20541101

20541102

20541103

20541104

20541105

20541106

20541107

20541108 2

20541200

20541201

20541202 *

20541300

20541301

20541302

20540006

20540007

20540001

20540003

20540004

20540006

20540008

20540009

20540010

20540011 20540012 S

FMFRTOBL

0. 1.

1.

SUM 1.0 0. 

1

CNTRLVAR 422

CNTRLVAR 400

FRAL SUM

0. 0.908

0.908

0.908

0.908

0.908

0.908

0.908

0.908

0.642

0.642

1.685

0.950

1.430

1.232

FMAL SUM

0. 1.284

1.816

1.816

1.816

1.816

1.665

1.806

1.806

9.81 0. 

1

RHO 222010000

RHO 222020000

RHO 222030000

RHO 222040000

RHO 222050000

RHO 222060000

RHO 222070000

RHO 222080000

RHO 222090000

RHO 222100000

RHO 221010000

RHO 211030000

RHO 231040000

RHO 240010000

9;81 0. 

1

RHO 224010000

RHO 224020000

RHO 224030000

nHO 224040000

RHO 224050000

RHO 225010000

RHO 231010000

RHO 231020000

DRIVING FORCE IN LooP A 

*

'-a

FMFRAL SUM 1.0 0, 

1

0. 1. CNTRLVAR 411

-1. CNTRLVAR 410

FMFRTOAL

0. 1.

1.

SUM 1.0 0. 

1

CNTRLVAR 412

CNTRLVAR 400

FMFRCORE SUM 9.81 0. 

i

0. 0.872 RHO 013010000 "DRIVING FORCE IN VESSEL 

* **t*ttttttt 5**ttt***tt e * t*t*

1.361

1.361

1.362

-1.013

-0.6095

-0.6095

-0.6095

-0.6095

-0.6095

-0.8965

RHO'015010000

RHO 015020000

RHO 015030000

RHO 025010000

RHO 031010000

RHO 031020000

RHO 031030000

RHO 031040000

RHO 039010000

RHO 041010000
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 047 *

20560000

20560001

20560002

20560003

20560004

20560005

20560006

20560007

20560008

20560009

20560010

20560011

20560014

20560015

20560016

20560017

20560018

20560012 t

20560300

20560301

20560302

20560303

20560309 t

20560400

20560401 *

20560900

20560901

20560902

20560903

20560904

20560905

20560906

20560907

20560908

20560909

20560910

20560911

20560912

20560913

20560914 20560915

20560916 t

20561000

20561001

SGBMASS SUM

0. 19.508

5.596

5.015

1.2355

1.2355

1.2355

8.049

8.049

8.049

8.049

10.3

5.728

9.696

26.288

4.000

8.560

5.90940

1. 0. 

1

RHO 611010000

RHO 613010000

RHO 615010000

RHO 615020000

RHO 615030000

RHO 615040000

RHO 620010000

RHO 620020000

RHO 620030000

RHO 620040000

RHO 621010000

RHO 622010000

RHO 623010000

RHO 630010000

RHO 625010000

RHO 627010000

RHO 612010000

ttSttGt*MttSIttVEttttORY

** SO 8 MASS INVENTORY 

*

* SGB ADDITION RATES 

* **ttnt* *ttnt tttttttttt G600 SUM 1.

0. 1. MFLOWJ

1. MFLOWJ

1. MFLOWJ

-1. MFLOWJ

0. 

1

618000000

607000000

608000000

865000000

N)

I-A

GILSGB INTEGRAL 1. 0. 

1

CNJRLVAR 603

SGBPOWPR

0. 1. 

0 1. 0

1. 

0

1. 

0 1. 0

1. 

0

1. 

0

1. 

0 16 0

1. 

0

1. 

0

1. 

0

1. 

0

1. 

0 1. 0

1 

0

SUM 1. 5;96E8

121010000

122010000

122020000

122030000

122040000

122050000

122060000

122070000

122080000

123010000

124010000

124020000

124030000

124040000

124050000

125010000

0 * SGB HEAT TRANSFER RATE 

t

SGOPOW SUM 1. 5.96E8

0. 1. 0 620010000

0
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 048

20561002

20561003

20561004

20561005

*

20561100

20561101

20561102

20561103

20561104

20561105

20561106

20561107

20561108

20561109

20561200

20561201

20561202

20561203

20561204

20561205

20561206

20561207

*

*

20561300

20561301

20561302

20561303

20570000

20570001

20570002

20570003

20570004

20570005

20570006

20570007

20570008 20570009

20570010

20570011

20570014

20570015

1. 0

1. Q

1. Q

1. 0

620020000

620030000

620040000

621010000

LSG8 SUM 1.

0. 2.424 VOIDF

0.696 VOIDF

1.937 VOIDF

2.55 VOIDF

2.55 VOIDF

2.55 VOIDF

0.735 VOIDF

2.093 VOIDF

1.000 VOIDF

LSGBRT SUM 1.

0. 1.816 VOIDF

1.816 VOTOF

1.816 VOIDF

1.816 VOIDF

2.324 VOIDF

1.432 VOIDF

2.424 VOIOF

11.662 1

611010000

613010000

615010000

615020000

615030000

615040000

612010000

630010000

627010000

5.71 1

620010000

620020000

620030000

620040000

621010000

622010000

623010000

LEVEL S68 DOWNCOMER * **t**tttttttt~tt*ttt**tttttl*

#*'LEVEL SOB RISER * 9*t** ***tt**t**ttttt* * CHECK? *

*

OPLSGB SUM 3.794E-5 6. 1 3 0 1

-1068.9 4.6303 RHO 613010000

23.779 RHO 611010000

7.2104 RHO 612010000

SGBMASS SUM 1. 0. 1

0. 19.508 RHO 711010000

5.596 RHO 713010000

5.015 RHO 715010000

1.2355 RHO 715020000

1.2355 RHO 715030000

1.2355 RHO 715040000

8.049 RHO 720010000

8.049 RHO 720020000

8.049 RHO 720030000

8.049 RHO 720040000

10.3 RHO 721010000

5.728 RHO 722010000

9.69G RHO 723010000

it SGB LEVEL OP *

9' 50 A MASS INVENTORY ' 9*99*9t9* 9*99999*9999**t
FILE: SUJTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 049

20570016

20570017

20570018

20570012

*

2

20570300

20570301

20570303

20570310

t

20570400

20570401 *

*

20570900

20570901

20570902

20570903

20570904

20570905

20570906

20570907

20570908

20570909

20570910

20570911

20570912

20570913

20570914

20570915

20570916

20570917

*

*

20571000

20571001

20571002

20571003

20571004

20571005

*

*

20571102

20571100

20571101

20571103

20571104

26.288 RHO 730010000

4.000 RHO 725010000

8.560 RHO 727010000

5.90940 RHO 712010000

G700 SUM 1. 0. 1

0. 1. MFLOWJ 707000000

1. MFLOWJ 708000000

-1. MFLOWJ 791000000

INTG7 INTEGRAL 1. 0. 1

CNTRLVAR 703

SGAPOWPR SUM 1. 5.96E8 0

0. 1. Q 221010000

1. 0 222010000

1. 0 222020000

1. Q 222030000

1, Q 222040000

I. Q 222050000

1; 0 222060000

1. 0 222070000

1; 0 222080000

1. Q 222090000

1. Q 222100000

1. Q 224010000

1; 0 224020000

1. Q 224030000

1. 0 224040000

1. 0 224050000

1. 0 225010000

* ADDITION RATES * tttt5t tt t tt t

*5 SGA HEAT TRANSFER RATE *

N)

I-a

(0

SGAPOW

0. 1i1.

1.

1.

1.

SUM 1. 5.96E8

o 720010000

o 720020000

o 720030000

o 720040000

o 721010000

0

LSGA. SUM 1 '1.662 1

0. 2.424 VOIbF 711010000

0.696 VOIDF 713010000

1.937 VOIDF 715010000

2.55 VOIDF 715020000

**.LEVEL *SGA DOWNCOMER' ssstttsss~tttasssslslst**
FILE: SG7R4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 050

20571105

20571106

20571107

20571108

20571109 t22

20571200

20571201

20571202

20571203

20571204

20571205

20571206 20571207 *

20511300

20571301

20571302

20571303

20570000

20590001

20590002

20590003

20590004

20590005

20590006

20590007 20590008

20590009

20590010

20590011

20590012

20590013

20590014

20590015

20590016

20590017

20590018

2.55

2.55

0.735

2.093

1.000

VOIDF

VOIDF

VOIDF

VOIDF

VOIDF

715030000

715040000

712010000

730010000

727010000

76. 

10 

720010000

7.20020000

720030000

720040000

721010000

722010000 723010000

LSGARI SUM 1.

0. 1.816 VOIDF

1.816 VOIDF

1.816 VOIDF

1.816 VOTOF

2.324 VOIDF

1.432 VOIOF

2.424 VOIDF

22 LEVIL.RISER SGA

i*2*2*222t22* *2*2**

OPLSaA SUM 3.794E"S 0. 1 3 0. 1.

-1068.9 4.6303 RHO 713010000

23.779 RHO 711010000

7.2104 RHO 712010000

LEIPRESS SUM 0.048209 0. 

1

-2.906086 4.44396 VOIDF 312010000

4.44396 VOIOF 313010000

3.873 VOIDF 314010000

3.81208 VOIDF 315010000

2.01312 VOIDF 316010000

1.50984 VOIDF 317010000

1.00656 VOIDF 320010000

5.0892E-1 VOIDF 320020000

3.3928E-1 VOIDF 320030000

2.5446E-1 VOIDF 320040000

1.6964E-1 VOIDF 320050000

1.6964E-1 VOIOF 320060000

8.4620E-2 VOIOF 330010000

1.0178 VOIOF 311010000

0.24593 VOIDF 301010000

0.24593 VOIDF 301020000

0.15771 VOIDF 301030000

0.50892 VOIDF 310010000

22 SGA LEVEL OP 

*

t2 PRESSURTZER.LEVEL 

2 222* 2* *2t 2*2 *22*222 t* CD

N)

0O

20590100 LE2PRES

20590101 -8248.

20590102

20590103

20590104

20590105

20590106

20590107

20590108

SUM 2.515E-5

14.4796

17.324

15.0976

14.862

7.848

5.886

3.924

1.4224

0. 1 -3 

0

RHO 312010000

RHO 313010000

RHO 314010000

RHO 315010000

RHO 316010000

RHO 317010000

RflO 320010000

RHO 320020000
FILE: SGTR4 -DCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 051

f

20590200

20590201

20590202

20590203

20590204

20590205

20590206

20590207

20590208

*

20596900

20596902

20596903

i

v

t

20597900

20597902

20597903

20598900

20598901

20599000 20599001

20599100

20599101 *

20599200

20599201

20599202

20599203

20599204

20599205

20599206

20599207

20599208 20599209

20599210

20599211

20599212

LE3PRES SUM 1.2459E-5

O 14,4796

17.324

15,0976

14.862

7.848

5.886

3.924

1.4224

(AFW+FW) SUM 1. 0. 1

0. 1. MFLOWJ 607000000

1. MFLOWJ 608000000

(AFW+FW) SUM 1. 0. 1

0. 1. MFLOWJ 707000000

MFLOWJ 708000000

0. 1 3 0.

RHO 312010000

RHO 313010000

RHO 314010000

RHO 315010000

RHO 316010000

RHO 317010000

RHO 320010000

RHO 320020000

1.

SO 80 FW +AFW~

*SG A FW +AFW~

*HEAT .LOSSES * r,

I-h

HEATLOSGA SUM 1.

0. 1.

HEATLOSGB SUM 1.

0. 1.

HEATLOSPR SUM 1.

0. 1.

0. 1

0. 1

0

0. 1

0

970010000

960010000

950010000

*.WALLS HEAT TRANSFER *

OPRIM1 0. .1.

1.

1.

i.

1.

1.

1,

1.

1.

1.

1.

Q

Q

Q

Q

0

0

0

Q

Q

0

0

SUM !..0; 1

011010000

013010000

015010000

015020000

015030000

021010000

02301000

025010000

035010000

039010000

041010000

043010000

2* VESSEL x *
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 052

20599213 1. 0 045010000

2059930') QLOOP8 SUM 1. 0. 

1

20599301 0. 1. 0 132010000

20599302 1. Q 133010000

20599303 1. Q 133020000

20599304 1. Q 140010000

20599305 1. 0 151010000

20599306 1. Q 151020000

20599307 1. Q 152010000

20599308 1. Q 153010000

20599309 1. Q 111010000

20599310 1. 0 112010000

20599311 1. Q 113010000

20599312 1. Q 131010000 **

20599400 QPRESS SUM 1. Cf. 

1

20599401 0. 1. 0 330010000

20599402 1. 0 310010000

20599404 1. 0 301010000

20599405 1. 0 301020000

20599406 1. 0 301030000

20599407 1. 0 311010000

20599408 1. 0 312010000

20599409 1. Q 313010000

20599410 1. 0 314010000

20599411 1. Q 315010000

20599412 1. 0 316010000

20599413 1. Q 317010000

20599414 1. 0 320010000

20599415 1. Q 320020000

20599416 1. 0 320030000

20599417 1. Q 320040000

20599418 1. 0 320050000

20599419 1. 0 320060000 *

20599500 OLOOPA SUM 1. 0.

20599501 0. 1. Q 251020000

20599502 1. 0 252010000

20599503 1. Q 253010000

20599504 1. Q 211010000

20599505 1. Q 211020000

20599506 1. 0 211030000

20599507 1. 0 231010000

20599508 1. 0 231020000

20599509 1. 0 231030000

20599510 1. 0 231040000

20599511 1. 0 240010000

20599512 1. 0 251010000 I

** LOOP B *8

PRESSURISER**

t%3

** LOOP A **
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 053

20599600 QPRIMT SUM 1. 0. 1 t* TOTAL **

20599601 0. 1. CNTRLVAR 993

20599602 1. CNTRLVAR 995

20599603 1. CNTRLVAR 994

20599604 1. CNTRLVAR 992

t

*TURBO PUMP MODEL t ,***tt **tt*****tt**tt*ttt***t******tt*ttttttttttt*t***tt**t*t***ttt

6080000 J608 TMDPJUN

6080101 606000000 61300CX)00 1.

6080200 1 0 CNTRLVAR 870

6080201 -1. 0. 0. 0.

6080202 0. 0. 0. 0.

6080203 50. 50. 0. 0. t

7080000 J708 TMOPJUN

7080101 706000000 713000000 1.

7080200 1 0 CNTRLVAR 871

7080201 -1. 0. 0. 0.

7080202 0. 0. 0. 0.

7080203 50. 50. 0. 0. r)

20586200 TRIPB TRIPUNIT 1. 1. 0

20586201 661

20586300 TRIPA TRIPUNIT 1. 1. 0

20586301 661 *

20586400 P-PB SUM 1. 0. 0

20586401 0. 1. CNTRLVAR 882

20586402 -1. P 613010000 t

20586500 P-PA SUM 1. 0. 0

20586501 0. 1. CNTPLVAR 882

20586502 -1. P 713010000 *

20586600 WPB2 SUM 7.22E-5 0. 0

20586601 0. 1. CNTRLVAR 864

20586602 -181. CNTRLVAR 873

20586700 WPA2 SUM 7.22E-5 0. 0

20586701 0. 1. CNTRLVAR 865

20586702 -181. CNTRLVAR 873

20586800 WPS POWERR 1. 0. 0

20586801 CNTRLVAR 866 0.5

20586900 WPA POWERR 1. 0. 0

20586901 CNTRLVAR 867 0.5
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 054 ;

20587000

20587001

I

20587100

20587101

4

20587200

2058720?

20587202

20587203

0

20587300 20587301

20587400

20587401

If

20587500

20587501

20587502

20587503

2

20587600 20587601

I

20587700

20587701

20587800

20587801

2058801

20588001

20588002

20588100

20588100

20588200

20588201

20588202

20588203

20588300

20588301

S

t

*

WPB MULT 1. 0. 1

CNTRLVAR 868 CNTRLVAR 862

WPA MULT 1. 0. 1

CNTRLVAR 869 CNTRLVAR 863

WPAtWPB SUM 0.5 0. o,

0. 1. CNTRLVAR 870

1. CNTRLVAR 871

1. CNTRLVAR 872

WP2 POWERI 1. 0. 0

CNTRLVAR 872 2

E018 MULT 4.734 0. 0

CNTRLVAR 872 CNTRLVAR 878

VP SUM 0.5 368. 0

0. 244. CNTRLVAR 876

1. CNTRLVAR 874

1. CNTRLVAR 875

VT/VP DIV 368. 1. 0 2

CNTRLVAR 875

N/NO POWERR 1. 1. 0 3

CNTRLVAR 876 0.33333

(N/NO)2 POWER! 1. 1. 0 2

CNTRLVAR 877 2

E017 SUM 1. 0. 0

0. 1. CNTRLVAR 872

-8.89 CNTRLVAR 877

E017 POWER! 1. 1. 0

CNTRLVAR 880 2

PPUMP SUM . 0.5 92.4E5

0. 1. CNTRLVAR 882

-1918. CNTRLVAR 881

92.4E5 CNTRLVAR 878

WT SUM 1. 0.

0.75 0.00433 CNTRLVAR 875

1.

0.5 1.

1.

0 2 92.4E5

2 2.344

*GENERAL sa*ttt,. swv*ss*sgtt*S**t~e*g**ttttetlt*t*t**tS*S*t~t*****tStt*t******t TABLES

S

:POWER TABLE t
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 055

20210000 POWER

20210001 0. 6.E6

*

* PRESSURIZER HEATERS

20231100 POWER 642

20231101 -1. 0.

20231102 0. 850.E3

*HEAT TRANSFER COEFF. PPESSU-CONTAINEMENT

t

20295000 HTC-T

20295001 0. 1.91

*HEAT TRANSFER COEFF. SG-CONTAINEMENT *

20296000 HTC-T

20296001 0. o.g5 *

** PLOT REQUEST

20300010 DOTGRID

20302100 P 330010000 29

20303100 CNTRLVAR 900 901 902 20303200 CNTRL VAR 901

20M04100 P 211020000

20305200 TEMPF 015030000 041010000

20305400 TEMPF 211030000

20305500 TEMPF 113010000

20305600 TEMPF 251020000

20305700 TEMPF 151020000

20305800 CNTRLVAR 113

20305900 TEMPG 330010000

20306000 CNTALVAR 002

20306100 CNTRLVAR 012

20306200 MFLOWJ 618000000

20306300 CNTRLVAR 010

20306400 CNTRLVAR 079

20306500 MFLOWJ 181000000 183000000

20306600 CNTRLVAR 012 078

0

20307100 CNTRLVAR 031 20307200 007

20307300 CNTRLVAR 710 610

20307500 CNTRLVAR 009
FILE: SGITR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 056

20307600 CNTRt.VAR 996 994

20307700 CNIRLVAR 031 007

20308100 MFLOWJ 013020000 013030000

20308300 MPLOWJ 301010000

20308400 PMPVEL. 140 240

20308500 MFtLOWJ 345000000 3400000000

20309200 CNTRLVAR 114

20309300 P 015030000

20309310 TEMPF

20309900 CNTRLVAR 050 2

20310100 P 730010000 630010000

20310200 P 730010000 203 10300 P 630010000 *

20311100 CNTRLVAR 711 611 712 612

20311500 CNTRLVAR 713 613

20311600 CNTRLVAR 711

20311700 CNTRLVAR 611

20311800 CNTRLVAR 713

2031190{Y CNTRLVAR 813 *

20312100 TEMPG 630010000 730010000

20312200 TEMPF 121010000 620040000 125010000

20312300 TEMPF 121010000 720040000 225010000I.

20312400 TEMPF 620010000 621010000 623010000 630010000 *

20314700 MFLOWJ 865000000

20314800 CNTRLVAR 979 969

203149(Y) MFLOWJ 791000000 2

20315100 CNTRLVAR 600 700 20315200 603 703

20318300 CNTRLVAR 001

20318400) EMPF 043010000 999010000 S

20320000 CPUTIME 0 *

*

* TITLES

20302130 "FIG 2.1 PRESSURE EVOLUTION IN PRESSURIZER 2

20303130 FIG 3.1 WATER LEVEL IN PRESSURIZER 20303230 ."FIG 3.2 MEASURED WATER LEVEL IN PRESSURIZER '

20304130 " FIG 4.1 PRESSURE EVOLUTION IN HOT LEG A"

20305230 "FIG 5.2 TEMPERATURE EVOLUTION IN REACTOR VESSEL "

20305430 " FIG 5.4 TEMPERATURE EVOL.UTION IN HOT LEG A"
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM .PAGE 057

20305530 " FIG 5.5 TEMPERATURE EVOLUTION IN HOT LEG B1"

20305630 " FIG 5.6 TEMPERATURE EVOLUTION IN COLD LEG A"

20305730 FIG 5.7 TEMPERATURE EVOLUTION IN COLD LEG Ba, 20305830 " FIG 5.8 AVERAGED PRIMARY TEMPERATURE EVOLUTION

20305930 " FIG 5.9 PRESSURIZER STEAM TEMPERATURE EVOLUTION 

"

20306030 " FIG 6.10 MASS BALANCE IN PRIMARY SYSTEM

20306130 " FIG 6.1 BREAK MASS FLOW RATE (CORRECTED)"

20306230 FIG 6;2 BREAK MASS FLOW RATE," 20306330 ' FIG 6.3 PRIMARY SYSTEM MASS ADDITION AND DEPLETION RATES 20306430 " FIG 6;4 INTEGRAL OF HPSI MASS FLOW RATE"

20306530 " FIG 6.5 CHARGING AND LETDOWN MASS FLOW RATE

20306630 " FIG 6.6 BREAK AND HPSI MASS FLOW RATE *

20307130 " FIG 7;1 CORE THERMAL POWER

20307230 " FIG 7.2 BREAK ENERGY EVOLUTION

20307330 " FIG 7.3 HEAT IRANSFER RATE FROM PRIMARY TO S 

' 20307530 " FIG 7.5 PRIMARY SYSTEM ENERGY BALANCE " 20307630 " FIG 7A6 HEAT ADDITION RATE FROM PRIMARY METAL STRUCTURES 

" 20307730 " FIG 7.7 CORE AND BREAK POWER

20308130 ' FIG 8.1 COLD LEG MASS FLOW RATE (VESSEL INLET)" 20308330 " FIG 8.3 SURGELINE. MASS FLOW RATE

20308430 ' FIG 8.4 PUMP VELOCITY"

20308530 " FIG 8.5 SPRAY MASS FLOW RATE

20309230 " FIG 9.2 SUBCOOLING"IN PRIMARY SYSTEM

20309330 ' FIG 9.3 PRESSURE VERSUS TEMPERATURE IN DOWNCOMER" -4 20309930 " FIG 9.9 MASS BALANCE IN PRIMARY SYSTEM" 2

20310130 " FIG 10.2 PRESSURE EVOLUTION IN STEAM GENERATOR (DOME) 

" 20310230 20310330 " FIG 10.2 PRESSURE EVOLUTION IN STEAM GENERATOR A(DOME) " FIG 10.3 PRESSURE EVOLUTION IN STEAM GENERATOR B(OOME)" 2

20311130 "FIG 11.1 COLLAPSED WATER LEVEL IN STEAM GENERATORS"

20311530 " FIG 11.5 MEASURED WATER LEVEL IN STEAM GENERATORS 

" 20311630 "FIG 11.6 COLLAPSED WATER LEVEL IN STEAM GENERATOR A"

20311730 'FIG 11.7 COLLAPSED WATER LEVEL IN STEAM GENERATOR B" 20311830 20311930 " FIG 11.8 MEASURED WATER LEVEL IN STEAM GENERATOR A" '• FIG 11.9 MEASURED WATER LEVEL IN STEAM GENERATOR B" I

20312130 1-IG 12.1 STEAM TEMPERATURE IN STEAM GENERATORS(DOME)" 20312230 " FIG 12.2 LOOP B AND SG B TEMPERATURES"

20312330 " FIG 12.3 LOOP A AND SG A TEMPERATURES"

20312430 " FIG 12.4 TEMPERATURE.STRATIFICATION IN SG B" *

20314730 " FIG 14.7 STEAM MASS FLOW RATE FROM SGB TO TURBOPUMP"

20314830 " FIG 14.8 FW AND AFW TO STEAM GENERATOR 

" 20314930 " FIG 14.9 SG A RELIEF VALVE MASS FLOW RATE

20315130 " FIG 15.1 STEAM GENERATORS MASS EVOLUTION"

20315230 " FIG 15.2 SG'S MASS ADDITION AND DEPLETION RATES"

20318330 " FIG 9.12 INTEGRAL OF BREAK MASS FLOW RATE

20318430 " FIG 18.4 SUBCOOLING"
FILE: SGIR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PACE 058

*

*

20320030 " FIO 20 CPUTIME VERSUS TRANSIENT TIME , st*t*tttt**stt***t****s*tst*******stsst*tt*ttt***ttttttta****ittlusesttstt*t

* LINE AND CURVE SPECIFICATIONS *

20303150 "COLLAPSED" "LEVEL" LINE 1 40

20303151 "HOT CELL" "LEVEL" LINE 2 40

20303152 "COLD CELL" "LEVEL" LINE 3 40

I

20303250 "r1OT CELL" "LEVEL" LINE 1 40 *

20304150 " P . "21102" LINE 1 40 *

20305250 "DOWNC." "TEMP" LINE 1 40

20305251 "CORE OUTL." "TEMP" LINE 2 40 *

20305450 "LOOP " "A" LINE 1 40

2

20305550 "LOOP " "8" LINE 1 40 *

20305650 "LOOP " "A" LINE 1 40

20305750 "LOOP " "0" LINE 1 40

*

20306550 "MFLOW " "CV" LINE 1 40

20306551 "MFLOW . "LETD." LINE 2 40

20306650 "BREAK . ..FLOW" LINE 1 40

20306651 "HPSI " "FLOW" LINE 2 40

*

20307350 "SG ."A" LINE 1 40

20307351 "SG " "B" LINE 2 40

20307650 "PRIMARY" "SYST" LINE 1 40

20307651 "PRESSU of "SYST" LINE 2 40 *

20307750 "CORE" "POWER" LINE 1 40

20307751 "BREAK "POWER" LINE 2 40

2

20308150 "LOOP " "A" LINE 2 40

20308151 "LOOP " "A" LINE 2 40

I

20308450 "LOOP " "3" LINE 1 40

20308451 "LOOP .. "A" LINE 2 40

S

20308550 "LOOP " "B" LINE 1 40

20308551 "LOOP " "A" LINE 2 40

20310150 " P " "SG A" LINE 1 35

20310151 " P "I "SO 8" LINE 1 40 I
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 059

20310250 " P 11"SG A" LINE 1 35

20310350 " P "SG " li LINE 1 40

20311150 "DOWNC " "So A'" LINE 1 40

20311151 "DOWNC 13"SO B" LINE 2 40

20311152 "RISER " "SO A" LINE 3 40

20311153 "RISER ' "SG B" LINE 4 40

20311550 "DOWNC . "SGA" LINE 1 40

20311551 "DOWNC " "iSGB"i LINE 2 40

20311650 "LEVEL " I I1I LINE 1 40

20311750 "LEVEL " "611' LINE 1 40

20311850 "LEVEL " "713" LINE 1 40

20311950 "LEVEL . "613" LINE 1 40

20312150 " SG ". .B" LINE t 40

20312151 " SO " "A" LINE 2 40 *

20312250 "INLET" 1BOX" LINE 1 40

20312251 "RISER ' `'SG B' LINE 2 40

20312252 "OUTLET" "BOX" LINE 3 40 *

20312350 "INLET" "BOX" LINE 1 40

20312351 "RISER " "SG A" LINE 2 40

20312352 "OUTLET" "BOX" LINE 3 40

20312450 "TUBE BUNDLE" "BOT." LINE 1 40

20312451 "TUBE BUNDLE" "TOP" LINE 2 40

20312452 "SEPARATOR" " ' LINE 3 40

20312453 "DOME" ". ".LINE 4 40

20314850 "SG " "A" LINE 1 40

20314851 "SG " "A" LINE 2 40

20315150 "SG "..B LINE 1 40 20315151 "SG " "A" LINE 2 40

20315250 "SG "..B" LINE 1 40

20315251 "SG ""A' LINE 2 40

20318450 "CORE" "TEMP" LINE 1 40

20318451 "SAT." "TEMP" LINE 2 40 *

* AXES TITLES *

20303132 "LEVEL " 20303232 "LEVEL "

20305832 "TEMP " "(K)" I
FILE: SGTR4 CUCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 060

20306032

*

20306132

*

20306332

20306632

2

20307132

20307232

20307332

*

20307532 *

20307632

20307732

*

20309232

t

20311132

20311532

20314832

20315132

20318332

2

"MASS "

"MFLOW

"MF LOW

"MFLOW

"POWER "

"BREAK POWER"

"POWER "

"POWER

"POWER R

"POWER

"DELTA TEMP"

"LEVEL "

"LEVEL "

"MFLOW "

"MASS

"MASS"

"(KG)"

"(KG/SEC)"

"(Kr/SEC)"

" (K{]/SEC)"

"(WATT)"

"(WATT)"

"(WATT)"

"(WATT)"

"(WATT)"

"(WATT )"

"(K)"

"(KG/SEC)"

"(KG) "

"(KG) "

r13 I0wJ

ttttttttttttttttttttttttttttttttttttttt*2**tttttttt*t*t2tttt*ttt2tt2tt2tttt**

* Y-AXE LIMITS * *2tt*tt*2t*2t*ttttttttttt2*tttttttttt$2*t*t2*t2tttttt*ttttt22tt2ttt2tttttttt

* PLOTS COMPARISON

20304120 04100 'FIG. 14 PRESSURE EVOLUTION HOT LEG (LOOP-A)(PRA-RC 11)

20404100 P 2 211020000

20404119 "PRA-RC" 11" CDOTS

20404120 0. 155.E05 152. 148.E05 422. 138.E05 8286 128.E05 980. 126.E05

20404121 1132. 108.EO5 1470. 107.EO5 2100. 107.E05 2281. 74.E05 2417. Q9.E05

20404122 2636. 105.E05

2

20303120 03100 'FIG.15 WATER LEVEL IN PRESSURIZER (LRCA/PRII) 20303220 03100 'FIG. 15 WATER LEVEL IN PRESSURIZER (LRCA/PRI1)

20403100 CNTRLVAR

20403119 "LRCA-PR" "11" CDOTS

20403120 0.0 0.25
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 061

20403121 47.4 .197 284,2 .065 362i ,032 442. 0. 2196. 0.

20403122 2368. 1. 2700. 1. *

20312620 11200 *FIG.17 WATER LEVEL IN INTACT S.G. A (2 FW 9A)

20412600 CNTRLVAR

20412619 "2 FW " 9A" CDOTS

20412620 0. 11,217 871. 11.21 888. 11.187 890, 11,402. 1006. 11.115

20412621 1008. 11.053 1142. 11.112 1260. 10.834 1429. 10.583 1716. 11.184

20412622 1817. 11.379 2021, 11.608 2190, 11.608 2527. 11.953

20311720 11300 tFIG.18 WATER LEVEL IN BROKEN S.G. 8 (2 FW 98)

20411700 CNTRLVAR

20411719 "2 FW " "98" COOTS

20411720 0. 11.229 1484. 13.231 1535. 13.443 2700. 13.443 *

20311820 11500 *FIG.17 WATER LEVEL IN INTACT S.G. A (2 FW 9A) 20411800 CNTRL.VAR

20411819 "2 FW " "9A" COOTS

20411820 0. 0.39 871. 0.385 888. 0.379 890. 0.438 1006. 0.359

20411821 1008. 0.342 1142. 0.358 1260. 0.282 1429. 0.213 1716. 0.378

20411822 1817. 0.432 2021. 0;495 2190. 0.495 2527i 0;590 *

20311920 11600 *FIG.18 WATER LEVEL IN BROKEN S.G. B (2 FW 98)

20411900 CNTRLVAR

20411919 "2 FW " "98" COOTS

20411920 0. 0.39 1484. 0.94 1535. 1.

NA) 20305620 05600 *FIG.19 TEMPERATURE IN COLD LEG A (2 RC 09)

20405600 TEMPF *251020000

20405619 "2 RC " "09" CDOTS *1 ilt! Ilt I lCHECK

20405620 0. 529ý 763. 528; 1255. 524. 1565. 514. 1843. 502.

20405621 2155. 493. 2395. 482. 2816. 472.

20305420 05400 *FIG.20 TEMPERATURE IN COLD LEG A (2 RC 05)

20405400 TEMPF *211040000

20405419 "2 RC " "05" COOTS tiltl!lI tIlCHECK

20405420 0. 529. 763. 528. 1255. 524. 1565. 514. 1843. 502,

20405421 2155. 493. 2395. 482. 2816. 472.

20305720 05700 *FIG.21 TEMPERATURE IN COLD LEG 0 (2 RC 29)

20405700 TEMPF *151020000

20405719 "2 RC " "29" CDOTS it! It III ICHECK

20405720 Op 529i 763i 5281 1255. 524. 1565. 514. 1843 502.

20405721 2155. 493. 2395. 482. 2816. 472.

20305520 05500 *FIG.22 TEMPERATURE IN HOT LEG 8 (2 RC 25)

20405500 TEMPF.*211040000

20405519 "2 RC " "25" CDOTS iitll ilt! IICHECK

20405520 O 529. 763. 528. 1255. 524 1565. 514. 1843. 502.

20405521 2155. 493. 2395. 482. 2816. 472.

20310120 10100 10200 *FIG.23 PRESSURE IN S.G. A (2 MS 04 A)

20410100 P * 734010000

20410119 "2 MS " .04A" COOTS

20410120 0. 43,1E05 412i 44,4E05 1000. 45,2E05 1084. 43,4E05 1237 43.lEO5
FILE: SGTR4 CDCJCL Al VM/SP CONVERSATIONAL MONITOR SYSTEM PAGE 062

20410121 1338. 40.6EO5 1591. 35.BE05 1744. 30.7EO5 1845. 29.EO5 1946.. M58EO5

20410122 2183 23.5EO5 2183. 22.2E05 2301. 20.8FO5 2453. 18.4EO5 3112. 14.6EO5 2

20310220 10100 203 10320 10200

20410200 P SC S

20410219 "2 MS " 4B" DASHES

20410220 0. 42.BBE05 149. 43.1ED5 369. 44.1EOS. 673, 14.7EOS 816, 45.EOS

20410221 1197. 44.9EO5 1484. 45.EO5 1687. 40.4EO5 1890. 35.63EO5 2177. 37.95E05

20400222 2397 38.71E05 2598. 39.06EO5 *

*

* END OF DATA *

/IEOR

/*EOI

cJJ

r~3
NRC FORM 335 U.S. NUCLEAR REGULATORY COMMISSION 1. REPORT NUMBER (Assignedbv TIDC. add Vol No., ifenyj

42-841

NRCM 1102.

3201.3202 BIBLIOGRAPHIC DATA SHEET NUREG/IA-0008

SEE INSTRUCTIONS ON THE REVERSE.

2. TITLE AND SUBTITLE 3. LEAVE BLANK

Assessment Study of RELAP-5 MOD-2 Cycle 36.01: Based on

the Doel-2 Steam Generator Tube Rupture Incident of

June 1979 4, DATE REPORT COMPLETED

MONTH YEAR

5. AUTHORISY

E.J. Stubbe 6. DATE REPORT ISSUED EJStbeMONTH 1986A

October 1986 7. PERFORMING ORGANIZATION NAME AND MAILING ADDRESS lI'cf.dOZIp Code) B. PROJECTITASK/WORK UNIT NUMBER

Tractionel 9. FIN OR GRANT NUMBER

Rue de la Science 31

B-1040 Brussels, Belgium

10. SPONSORING ORGANIZATION NAME AND MAILING ADDRESS fInclude Z~p Code) Ila TYPE OF REPORT

Office of Nuclear Regulatory Research

U.S. Nuclear Regulatory Commission

Washington, DC 20555 b. PERIOD COVERED Ic,.o,,o dam)

12. SUPPLEMENTARY NOTES

13. ABSTRACT (200 words or less)

The code assessment results in this report were based on all the available data (from

plant computer and plant recordings) from the Doel-2 steam generator tube rupture

incident of June 1979. The study revealed that the code is capable to simulate the

observed phenomena reasonably well and can be U'sed to predict similar transients.

However, lack of precise boundary conditions does not allow one to quantify the error

margin from this analysis.

14. DOCUMENT ANALYSIS - a. KEYWORDSIDESCRIPTORS I5. AVAILABILITY

RELAP5/MOD2 STATEMENT

steam generator tube rupture

Doel-2 plant Unlimited

ICAP code assessment 16. SECURITYCLASSIFICATION

1This poe)

s. IDENTIF IERS/OPEN-ENDED TERMS Unclassified

ITh's raopo)

Unclassified

17. NUMBER OF PAGES

18. PRICE




UNITED STATES

NUCLEAR REGULATORY COMMISSION

WASHINGTON, D.C. 20555

OFFICIAL BUSINESS

PENALTY FOR PRIVATE USE, $300

SPECIAL FOURTH-CLASS RATE

POSTAGE & FEES PAID

IUSNRC

WASH. D.C.

PERMIT No. G-67