reference iec61363
TRANSCRIPT
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IEC_6 363 FAULT Study
This chapter examines the short-circuit current calculation procedures used in the
IEC_61363 Short Circuit Study.
The IEC_61363 Study follows the specifications of theInternational Electrotechncal
Commission (IEC) International Standard 61363: Electrical installations of ships and
mobile and fixed offshore units Procedures for calculating short-circuit currents in
three-phase a.c.
This guide includes:
Engineering Methodology
Terminology and Symbols
Assumptions and Equations
PTW Applied Methodology
Examples
IN
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IEC_61363 FAULT STUDY
1.1 What is the IEC_61363 Study? 2
1.2 Engineering Methodology 2
1.3 PTW Applied Methodology 171.4 Application Example 24
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1.1 What is the IEC_61363 Study?
The IEC_61363 Short Circuit Study (referred to hereafter as IEC363) models the current
that flows in the power system under abnormal conditions and determines the prospective
fault currents in an electrical power system. These currents must be calculated in order toadequately specify electrical apparatus withstand and interrupting ratings. The Study
results are also used to selectively coordinate time current characteristics of electrical
protective devices.
IEC363 represents conditions that may affect typical marine or offshore installations more
significantly than land-based systems, including more emphasis on generator and motor
decay.
1.2 Engineering Methodology
IEC Standard 61363 describes a detailed method for calculating three-phase short circuit
duties for marine or offshore installation. The Standard contains 9 chapters. Individual
paragraphs are referred to as articles or clauses, and sub-paragraphs are referred to as sub-
clauses.
1.2.1 IEC Standard 61363The IEC 61363 standard outlines procedures for calculating short-circuit currents that may
occur on a marine or offshore a.c. electrical installation.
The calculation methods are intended for use on unmeshed three-phase a.c. systems
operating at 50 Hz or 60 Hz; having any system voltage specified in IEC 60092-201 table
2; having one or more different voltage levels; comprising generators, motors,
transformers, reactors, cables and converter units; having their neutral point connected to
the ships hull through an impedance (designed to limit the short-circuit current flowing to
the ships hull; or having their neutral point isolated from the ships hull.
The IEC 61363 standard is intended for three-phase symmetrical short circuit conditions
over the first 100 ms of the fault. The effects of voltage regulators are not considered.
The primary reasons for performing the IEC 61363 short circuit calculations include:
1) obtain the short-circuit current magnitude at each point in the power system;
2) compare the calculated fault current to the ratings of installed equipment to verify
the equipment ratings are adequate to handle the short circuit current;
3) support proper selection of circuit protection equipment.
Note that marine and offshore electrical systems typically have large generating capacities
confined in a small area resulting in high short circuit values with low power factors.
Special attention is required if the calculated power factor during fault conditions is below
the power factor used to test the circuit breakers.
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1.2.2 DefinitionsShort circuit
accidental or intentional connection, by a relatively low resistance or impedance, of two or
more points in a circuit which are normally at different voltages. [61363-1 IEC:1998]
Short circuit current
over-current resulting from a short circuit due to a fault or an incorrect connection in and
electric circuit. [61363-1 IEC:1998]
Prospective current
Short-circuit current that would flow in the circuit if each pole of the device were replaced
by a conductor of negligible impedance. [61363-1 IEC:1998]
Symmetrical short-circuit current
r.m.s. value of the a.c. symmetrical component of a prospective short-circuit current, the
aperiodic component of current, if any, being neglected. [61363-1 IEC:1998]
Initial symmetrical short-circuit current Ik
r.m.s. value of the a.c. symmetrical component of a prospective short-circuit current
applicable at the instant of short circuit if the impedance remains at zero-time value.
[61363-1 IEC:1998]
Current
Theoretical maximum
Peak at 1/2 cycle
(DC decay)
Bottom envelope
Top envelope
Decaying (aperiodic) component i
Time
2
2
I"
i
k
p
2 2 I k
dc Asymmetrical valuesincluding motor contributions
Steady state value(no motor contributions)
dc
i
Subtransient short-circuit current Ikdin the direct axis
r.m.s. value of the short-circuit current flowing through a circuit with rotating machines
having an impedance equal to the transient impedance of the circuit. [61363-1 IEC:1998]
Transient short-circuit current Ikdin the direct axis
r.m.s. value of the short-circuit current flowing through a circuit with rotating machines
having an impedance equal to the transient impedance of the circuit. [61363-1 IEC:1998]
Steady-state short-circuit current Ikdin the direct axis
r.m.s. value of the short-circuit symmetrical current flowing through a circuit with
generators witch remains after the decay of the transient phenomena. [61363-1 IEC:1998]
Aperiodic (d.c.) component of the short-circuit current IdcComponent of current in a circuit immediately after it has been suddenly short-circuited,
all components of fundamental and higher frequencies being excluded. [61363-1
IEC:1998]
Peak short-circuit current Ip
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Maximum possible instantaneous value of the prospective short-circuit current [61363-1
IEC:1998]
Direct-axis subtransient short-circuit time constant Td
Time required for the rapidly changing component, present during the first few cycles in
the direct-axis shrot-circuit current following a sudden change in operating conditions, to
decrease to 1/e, i.e. 0.368 of its initial value, the machine (or equivalent machine) runningat rated speed. [61363-1 IEC:1998]
Direct-axis subtransient open-circuit time constant Tdo
Time required for the rapidly changing component present during the first few cycles of
the open-circuit primary winding voltage which is due to direct-axis flux following a
sudden change in operation, to decrease to 1/e i.e. 0.368 of its initial value, the machine
running at rated speed. [61363-1 IEC:1998]
Direct-axis transient short-circuit time constant Td
Time required for the slowly changing component of the direct-axis short-circuit primary
current following a sudden change in operating conditions, to decrease to 1/e ie.e 0.368 of
its initial value, the machine running at rated speed. [61363-1 IEC:1998]
Direct-axis transient opencircuit time constant Tdo
Time required for a slowly changing component of the open-circuit primary voltage,
whish is due to the direct-axis flux, follwing a sudden change in operating conditions, to
decrease to 1/e i.e. 0.368 of its initial value, the machine running at rated speed. [61363-1
IEC:1998]
DC time constant Tdc
Time required for the d.c. component present in the short-circuit current, following a
sudden change in operating conditions, to decrease to 1/e i.d. 0.368 of its initial value, the
machine running at rated speed. [61363-1 IEC:1998]
Direct-axis subtransient reactance Xd (saturated)
Quotient of the initial value of a sudden change in that fundamental a.c. component ofprimary voltage, which is produced by the total direct-axis primary flux, and the value of
the simultaneous change in fundamental a.c. component of direct-axis primary current, the
machine running at rated speed. [61363-1 IEC:1998]
Direct-axis transient reactance Xd (saturated)
Quotient of the initial value of a sudden change in that fundamental a.c. component of
primary voltage, which is produced by the total direct-axis primary flux, and the value of
the simultaneous change in fundamental a.c. component of direct-axis primary current, the
machine running at rated speed and the high decrement components during the first cycles
being excluded. [61363-1 IEC:1998]
Direct-axis synchronous reactance Xd
Quotient of the steady-state value of that fundamental a.c. component of primary voltagewhich is produced by the total direct-axis primary flux, and direct-axis primary current
after the decay of the transient phenomena. [61363-1 IEC:1998]
Stator resistance of a generator Ra
Resistance of the stator of a synchronous machine, measured at d.c. current. [61363-1
IEC:1998]
Short-circuit impedance Z
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Quotient of the sinusoidal voltage per phase on a balanced a.c. system and the same
frequency component of the short-circuit current in that system. [61363-1 IEC:1998]
Voltage source
Active element which can be represented by an ideal voltage source independent of all
currents and voltages in the circuit, in series with a passive circuit element. [61363-1
IEC:1998]
Nominal system voltage Un
Voltage (line-to-line) by which a system is designated and to which certain operating
characteristics are referred. [61363-1 IEC:1998]
Subtransient voltage of a rotating machine E
r.m.s. value of the symmetrical internal voltage of a machine which is active behind the
subransient impedance Z at the moment of short circuit. [61363-1 IEC:1998]
Transient voltage of a rotating machine E
r.m.s. value of the symmetrical internal voltage of a machine which is active behind the
transient impedance Z at the moment of short circuit. [61363-1 IEC:1998]
Nominal value (n)
Suitable approximate quantity value used to designate or identify a component, device or
equipment. [61363-1 IEC:1998]
Rated value (r)
Quantity value assigned, generally by a manufacturer, for a specified operating condition
of a component, device or equipment. [61363-1 IEC:1998]
Equivalent generator
Fictitious generator having characteristics which will produce the same short-circuit
current at any point on an electrical installation, as would be produced by a combination
of generators having different ratings and different characteristics, which are connected to
the system. [61363-1 IEC:1998]
Equivalent motor
Fictitious motor having characteristics which will produce the same short-circuit current at
any point on an electrical installation, as would be produced by a combination of motors
having different ratings and different characteristics, which are connected to the system.
[61363-1 IEC:1998]
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1.2.3 IEC 61363 Symbols
PTWs Reports and documentation conform to IEC 61363 notation, including:
f phase Angle
Eq subtransient q-axis voltage of a generator (r.m.s.)
Eq transient q-axis voltage of a generator (r.m.s.)EM subtransient voltage of a motor (r.m.s.)
f frequency
fe lowest frequency of a shaft generator
fr rated frequency of a network
I* subtransient short-circuit current of the equivalent generator (r.m.s.)
I* transient short-circuit current of the equivalent generator (r.m.s.)
I* current of the equivalent generator (r.m.s.)
IM* subtransient short-circuit current of the equivalent motor (r.m.s.)
Ikd subtransient initial short-circuit current of a synchronous machine (r.m.s.)
Ikd transient initial short-circuit current of a synchronous machine (r.m.s.)
I current (r.m.s.)
Iac a.c. component of the short-circuit current of a synchronous machine (r.m.s.)
IacM symmetrical short-circuit current of an asynchronous motor (r.m.s.)ILR asynchronous motor locked rotor current
idc d.c. component of the short-circuit current of a synchronous machine
(instantaneous).
idcM d.c. component of the short-circuit current of an asynchronous motor and an
equivalent motor (instantaneous).
ik upper envelope of the short-circuit current.
I* steady-state short-circuit current of an equivalent generator (r.m.s.)
Ikd steady-state short-circuit current of a synchronous machine (r.m.s.)
iM upper envelope of the short-circuit current of an asynchronous motor.
ip peak value of the short-circuit current of a synchronous machine.
ipM peak value of the short-circuit current of an asynchronous motor.
Ir rated current (r.m.s.)
IrM rated current of an asynchronous motorR resistance
R* resistance of an equivalent generator
Ra stator resistance of a synchronous machine
RC cable resistance
Rdc d.c. resistance
RM motor resistance
RR rotor resistance of an asynchronous motor
RR* rotor resistance of an equivalent asynchronous motor
RS stator resistance of an asynchronous motor
RS* stator resistance of an equivalent asynchronous motor
RT resistance of a transformer
t time duration from the beginning of a short circuit
Td subtransient time constant of a synchronous machineTd transient time constant of a synchronous machine
Td* subtransient time constant of an equivalent generator
Td* transient time constant of an equivalent generator
Te subtransient time constant of a synchronous machine including the non-active
components
Te transient time constant of a synchronous machine including the non-active
components
TM subtransient time constant of a an asynchronous motor
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TMe subtransient time constant of a an equivalent asynchronous motor including
connecting cables.
Tdc d.c. time constant of a synchronous machine
Tdc* d.c. time constant of an equivalent generator
Tdce d.c. time constant of a synchronous machine including the non-active
components.
TdcM d.c. time constant of an asynchronous motorTdcM* d.c. time constant of an equivalent asynchronous motor
TdcMe d.c. time constant of an asynchronous motor including the connecting cables.
U0 prefault voltage (line-to-line)
Un nominal voltage (line-to-line)
Ur rated voltage (line-to-line)
UrM rated voltage of a motor (line-to-line)
X* subtransient reactance of an equivalent generator
X reactance
Xd subtransient reactance of a synchronous machine in the d-axis
Xd transient reactance of a synchronous machine in the d-axis
XM subtransient reactance of an asynchronous motor
Z impedance
Z* equivalent impedance
1.2.4 MethodologyThe Conventional or Comprehensive short circuit analysis procedure involves reducing
the network at the short circuit location to a single Thevenin equivalent impedance,
determining the associated fault point R/X ratio calculated using complex vector algebra,
and defining a driving point voltage (assuming the effect of transformer taps on bus
voltage). The initial symmetrical short circuit current can be calculated and, given the
fault location R/X ratios, the asymmetrical short circuit current at various times during the
onset of the fault can be calculated.
Conventional short circuit analysis techniques do not satisfy IEC Standard 61363
methodology. IEC363 requires a time-dependent calculation divided into active and non-
active components with separate AC and DC calculations. Active components, such as
generators and motors, are combined to form equivalent motors and generators. The
equivalent motors and generators are combined with non-active components, such as
cables and transformers, to further adjust the impedance and time constants of the
equivalent components.
Short-Circuit Study Procedure
The general study procedure outlined in the IEC 61363 standard includes:
1. prepare a system one-line diagram;
2. define component characteristics;
3. calculate the time-dependent short-circuit currents at the major points in the system
using the equations and methods described in the IEC 61363 standard;
4. prepare a short-circuit summary and document study conclusions.
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1.2.5 IEC 61363 Assumptions
IEC 61363 standard outlines procedures for calculating short-circuit currents that may
occur on a marine or offshore a.c. electrical installation. The calculation methods are for
use on unmeshed three-phase alternating current systems, operating at 50 Hz or 60 Hz.
The following assumptions are applied
- All system capacitance are neglected
- The short-circuit arc impedance is neglected
- The short circuit occurs simultaneously in all three phases (three phase fault)
- Unmeshed systems
When calculating short-circuit currents, it is important to understand the difference
between
- The short-circuit current generated by an individual piece of equipment
- The short-circuit current which results when several pieces of equipment are
connected in a system.
When an isolated machine is being considered, only the electrical parameters of the
machine affect the short-circuit current generated. In a system, however, this current is
limited by the impedance of the non-active components, for example, cables, transformers,
etc., forming the system, changing both the transient and steady-state values of the
resulting short-circuit current.
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1.2.6 IEC 61363 Equations
Generators
Three-phase short-circuit current calculation
The upper envelope of the maximum values of the three-phase short-circuit current of agenerator can be calculated as
)()(2)( titIti dcack +=
The a.c. component
kd
Tt
kdkd
Tt
kdkdac IeIIeIItI dd ++=
'" /'/'" )()()(
2"2
"
0
"
"
0"
da
q
d
q
kd
XR
E
Z
EI
+==
2'2
'0
'
'0'
da
q
d
q
kd
XR
E
Z
EI
+==
="
0qE 000 cos3
IRU
a+ 2 + 0
"
00 sin3
IXU
d+ 2
=' 0qE 000 cos3
IRU
a+ 2
+ 0'00 sin3
IXU
d+ 2
The d.c. component
dcTt
kddc eIIti/
00
" )sin(2)( =
The peak value
)2()2(2)2(
T
i
T
I
T
ii dcackp +==
for 60 Hz system
msT
33.82*60
1000
2==
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Effects of non-active components connected in series with Generators
Impedance changes
[ ] 2/12"2" )()( XXRRZ dae +++=
[ ]2/12'2'
)()( XXRRZ dae +++=
Time-constant changes
[ ] "'"2"'2"2
"
))(()(
)()(
ddda
ddda
eXXXXXRR
TXXXRRT
++++
+++=
[ ] ''2'2'2
'
))(()(
)()(
ddda
ddda
eXXXXXRR
TXXXRRT
++++
+++=
a
adc
dce
RR
fRXT
T +
+
= 1
2
Motors
General motor parameter
)()( statorRrotorRR SRM +=
)()(" statorXrotorXX SRM +=
Rr
SR
MR
XXT
+=
"
Sr
SR
dcMR
XXT
+=
General data for large motors ( > 100 kW)
..16.0" upZM =
..15.0" upXM =
..034.0 upRS=
..021.0 upRR=
msTmsTat dcMM 73.1167.18Hz,60"
==
msTmsTat dcMM 08.144.22Hz,50"
==
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General data for small motors
..2.0" upZM =
..188.0
"
upXM=
..043.0 upRS=
..027.0 upRR =
msTmsTat dcMM 73.1167.18Hz,60"
==
msTmsTat dcMM 08.144.22Hz,50"
==
Three-phase short-circuit current calculation
The upper envelope of the maximum values of the three-phase short-circuit current of anasynchronous motor can be calculated as
)()(2)( titIti dcMacMpM +=
The a.c. component
"/")( M
Tt
MacM eItI =
22
"
"
"
"
MM
M
M
MM
XRE
ZEI
+==
='"
ME rMMMrM IR
U+cos
32
+ rMMMrM IX
U 'sin3
+ 2
The d.c. component
dcMTtMrMMdcM eIIti
/" )sin(2)( =
The peak value
)2
()2
(2)2
( T
iT
IT
ii dcMacMkp +==
for 60 Hz system at cycle
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msT
33.82*60
1000
2==
Effects of non-active components connected in series Motors
Impedance Changes
RRRR SRMe ++=
XXXX SRMe ++="
Time-constant changes
Rr
Me
MeR
XT
""
=
)(
"
RR
XT
Sr
Me
dcMe+
=
Equivalent generator
*
/
*
'
*
/'
*
"
**
'*
"* )()()( k
TtTt
ac IeIIeIItI dd ++=
*
/
*
/
**
'*
"*)( k
TtTt
ac IeNeMtI dd ++=
*/"
** 2)( dcTt
dcM eItI =
where we defined the following variables,nn
"
*I = +"
kdiI"
MjIii
n
'
*I ='
kdiI
i
n
*kI = kdiI
i
)( '*"
** IIM =
)( *'
** kIIN =
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Equivalent generator time constant
For generator:
'/'"""
)()( kdTt
kdkd IeIItK d +=
For motor:
"/"" )( MTt
MeItK
=
Thus,n n
= +*" )(tK )(" tKi
MTt
jMeI"/"
i i
*
'
**
""*
)(ln
)(
M
ItKttT
x
xxd
=
*
*
/
**
'
*)()(
ln
)( "*
N
IeMtI
ttT
k
Tt
xac
xxd
dx +
=
"
*
**
2
)(ln
)(
I
ti
ttT
xdc
xxdc
=
Equivalent generator impedance
"
*
0"
*3I
UZ = ,
'
*
0'
*3I
UZ = ,
*
0*
3I
UZ =
)()()( "** 3 tXtctR = , )(2
1)(
*3 tfT
tcdc
=
2
3
"
*"
*1)( c
Z
tX +=
2
*
2'
*
'
* )( RZtX =
2
*
2
** )( RZtX =
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Effects of non-active components connected in series with Equivalent Generators
Impedance changes
[ ] 2/12"2" )()( XXRRZ dae +++=
[ ]2/12'2'
)()( XXRRZ dae +++=
[ ] 2/122' )()( XXRRZ dae +++=
Time-constant changes
[ ] "'"2"'2"2
"
))(()(
)()(
ddda
ddda
eXXXXXRR
TXXXRRT
++++
+++=
[ ] ''2
'2'2
'
))(()(
)()(
ddda
ddda
e XXXXXRR
TXXXRRT
++++
+++=
a
adc
dce
RR
fRXT
T+
+
=1
2
Three-phase short-circuit current calculation
The upper envelope of the maximum values of the three-phase short-circuit current of an
equivalent generator can be calculated as
)()(2)( titIti dcack +=
The a.c. component
e
kd
e
kd
e
kdZ
UI
Z
UI
Z
UI 0
'
0'
"
0" ,, ====
kd
Tt
kdkd
Tt
kdkdac IeIIeIItI dd ++=
'" /'/'" )()()(
The d.c. component
dcTt
kddc eIti/" )(2)( =
Equivalent motor
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"*/"
**)( MTt
MacM eItI =
*/"
** 2)( dcMTt
MdcM eItI
=
where we defined the following variables,
=n
j
MjM II""
*
Equivalent motor time constant
="/"" )( MTtMM eItK
= dcMTt
MdcM eItK/"2)(
"
*
"
"
*)(
ln
)(
M
xM
xxM
I
tKttT =
"
*
*
2
)(ln
)(
M
xdcM
xxdc
I
tK
ttT
=
Equivalent motor impedance
)()( " *1* tXctR MR = , )()()("
*2* tXtctR MS =
)(2
1)(
"
*
1tfT
tcM
= ,)(2
1)(
*
2tfT
tcdcM
=
"
*
0"
*3 M
MI
UZ = or
2"
*
2
**
"
* )( MSRM XRRZ ++=
2
21
"
*"
*
))()((1)(
tctc
Z
tX M
M
++=
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Effects of non-active components connected in series Equivalent Motors
Impedance Changes
RRRR SRMe ++=
XXXX SRMe ++="
Time-constant changes
Rr
Me
MeR
XT
"
"=
)(
"
RR
XT
Sr
Me
dcMe+
=
Three-phase short-circuit current calculationThe upper envelope of the maximum values of the three-phase short-circuit current of an
equivalent asynchronous motor can be calculated as
)()(2)( titIti dcMacMM +=
The a.c. component
"
0"
e
kdZ
UI =
"/")( dTt
kdac eItI =
The d.c. component
dcTt
kddc eIti/" )(2)(
=
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1.3 PTW Applied Methodology
PTW applies the methodology described in Section 1.2. Section 1.3 describes how to run
the IEC_363 Study, including explanations of the various options associated with the
Study.
1.3.1 Before Running the IEC 61363 Fault StudyBefore running the IEC 61363 Fault Study, you must:
Define the system topology and connections.
Define feeder and transformer sizes.
Define fault contribution data.
1.3.2 Running the IEC61363 Fault StudyYou can run the Study from any screen in PTW, and it always runs on the active project.
To run the IEC 61363 Study
1. From the Run menu, choose Analysis.
2. Select the check box next to Short Circuit and choose the IEC 61363 option button.
3. To change the Study options, choose the Setup button.
4. Choose the OK button to return to the Study dialog box, and choose the Run button.
The Short Circuit Study runs, writes the results to the database, and creates a report.
1.3.3 IEC 61363 Study OptionsThe IEC_FAULT Study dialog box lets you select options for running the Study.
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Following is a list of the available Study options.
Report and Study Options
These boxes allow you to customize the breadth of the Study and its Report. You can
choose between a summary report, standard report or a detailed report
Faulted Buses: All or SelectedYou can report a fault at a single bus, a group of buses or all buses. If a fault is to be
reported at a single bus or selected group of buses, then the faulted bus(es) must be
specified using the Select button. The default is to report the fault current at all buses.
System Modeling
These options further customize the Study.
System Frequency
The system frequency must be defined for the time-dependent calculations. The
system frequency is set in the Project>Options>Application menu.
Model Transformer Tap
You may model the transformer taps by selecting this check box.
Time Varying Setup
The time varying setup allows you to specify times to report Iac and Idc time-dependent
short circuit currents.
1.3.4 Component Modeling
Fault Contribution Data
Contribution data must be defined for synchronous generators, synchronous motors, and
asynchronous motors.
Synchronous Generators and Motors
Synchronous generator and motor short circuit current contributions are defined in the
Component Editor as shown in the following figures:
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ANSI Contribution Format
IEC Contribution Format
The IEC 61363 calculations requires entry of the following values: Xd, Xd, Xd, Ra,
Td, Td and Tdc. For definitions of these values refer to section 1.2.2. Since the IEC
61363 calculations are for 3-phase faults only, the negative sequence, zero sequence and
neutral impedance values are not used. However values for these fields are still required
since the IEC60909, ANSI and Comprehensive fault calculations use them.
PTW calculates the machine kVA and voltage base using the data you enter in the first
subview of the Component Editor. The motor rated size is in mechanical units of work(output) when entered as horsepower, but in equivalent electrical units of work (input)
when entered as electrical quantities of kVA, MVA or kW. Motor efficiency is used to
convert horsepower to electrical units of work, and power factor is used to convert kW to
kVA. If the rated kVA base in the IEC Contribution subview is zero, then PTW calculates
the equivalent kVA base from the machine rated size shown in the first subview of the
Component Editor. If the rated kVA base is not zero, PTW will not change it, even if you
enter a revised rated size in the motors first subview. Also, if the rated voltage is not zero,
PTW will not change it. Therefore, you may need to modify the rated machine kVA and
kVA base together; if you do not modify them together, the kVA base will remain
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unchanged, even if you change the rated size on the first subview of the Component
Editor.
In order to fully model a synchronous machine, the rated size of the machine must be
defined, along with the power factor. Motors can be defined in the Component Editor as
either a single motor (the default) or as multiple motors. PTW will calculate the power for
multiple motors modeled at the bus.
Asynchronous Induction Motors
Asynchronous motor short circuit currents should be modeled in IEC 61363 calculations.
The Component Editor ANSI and IEC contribution data boxes are shown in the following
figures:
ANSI Format
IEC Format
The fields added specifically for the IEC 61363 calculations are the ratio of Stator
Resistance to Rotor Resistance, Td, and Tdc. Either entry format can be used.
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The motor rated size is in mechanical units of work (output) when entered as horsepower,
but is in equivalent electrical units of work (input) when entered as electrical quantities of
kVA, MVA or kW. Motor efficiency is used to convert horsepower to electrical units of
work, and power factor is used to convert kW to kVA. If the rated kVA base is zero, then
PTW calculates the equivalent kVA base using the machine rated size as defined in the
first subview of the Component Editor. The number of pole pairs, combined with the rated
kW of asynchronous machines, is used to calculate the breaking current duty. If multiplemotors are modeled in a single motor object, PTW will model the MW/pp of each of the
individual motors that comprise the group. Asynchronous motors are modeled as delta-
connected. If specific motor data is not available, the following typical data can be used
for the IEC 61363 calculations:
Large motors ( > 100 kW)
..16.0" upZM =
..15.0"
upXM =
..034.0 upRS=
..021.0 upRR =
msTmsTat dcMM 73.1167.18Hz,60"
==
msTmsTat dcMM 08.144.22Hz,50"
==
Small motors (
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Transformers also are modeled with a positive sequence impedance value. Zero sequence
impedance values are not used in the IEC 61363 calculations and therefore transformer
earthing impedance is also not used.
Transformer taps may be modeled. A negative primary tap raises the secondary voltage.
Taps will only be considered if the IEC 61363 Study Setup dialog box is set to model
them. The driving point voltages are defined by the generators and are not modified by thetransformer tap settings.
Transformer off-nominal voltage ratios, as compared to the primary and secondary bus
system nominal voltages, are modeled when the Model Transformer Taps check box is
selected in the Study setup dialog box. Essentially, PTW will create a fictitious primary
and/or secondary tap to ensure that the voltage ratios are properly matched.
1.3.5 Error MessagesPTW examines the entered data for the IEC 61363 Study. If PTW finds missing or
incomplete information, it sends an error message to the Study Message dialog box. The
Study Messages dialog box will report both fatal and warning messages. The Study will
attempt to run to completion even if fatal errors are detected, in order to identify any other
errors. The error messages are shared between all fault studies even though each has
slightly different data requirements.
A somewhat common error is:
The calculated zero sequence impedance is negative.
It involves the entry of single-line-to-easrth short circuit contribution data. PTW uses the
three-phase fault data and the single-line-to-earth fault data to calculate the positive-,
negative- and zero-sequence impedances from the following per-unit equations:
Z Z
Z1.0
I
I3 1.0
Z Z Z
Z3
IZ Z
1 2
1f
f1 2 0
0f
1 2
3
sle
sle
=
=
=
+ +
=
b g
b g
Utilities often report available single-line-to-earth fault duties on an equivalent three-
phase rating apparent power basis, using the equation:
kVA 3 I kV3 fsle= LL
However, the actual apparent power of a single-line-to-ground fault is:
kVA = IkV
31 fsle
where
kV line-to-line voltage.
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You cannot use the three-phase equivalent rating of a single-line-to-ground short circuit
contribution. If you do, PTW may attempt to calculate the zero-sequence impedance as a
negative value. The actual apparent power to be entered into PTW is the utility equivalent
single-line-to-earth duty divided by three. Enter the single-line-to-ground fault current
X/R ratio, not the zero sequence impedance X/R ratio.
1.3.6 ReportsFor each fault location, IEC_363 reports:
Iac at 1/2 Cycle, 3 Cycles, 5 Cycles, and one user-defined time, T4
Idc at 1/2 Cycle, 3 Cycles, 5 Cycles, and one user-defined time, T4
Iac for each branch and source feeding the fault at 1/2 Cycle, 3 Cycles, 5 Cycles, and
one user-defined time, T4
Idc for each branch and source feeding the fault at 1/2 Cycle, 3 Cycles, 5 Cycles, and
one user-defined time, T4
Ipeak for each bus and branch
*FAULT BUS: B1Voltage: 4.200 kV Ipeak: 38583.56 A x(peak factor): 1.615
TIME (Cycles) 0.0 0.5 3.0 5.0 12.5================================================================================Iac(A) 16893.27 14520.23 9684.34 8743.52 7935.77Idc(A) 22907.14 18048.85 9065.28 6133.30 1573.11
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1.4 Application Example
1. 4. 1 Sample Project in IEC 61363 Standard
The following example was included in the IEC 61363 1996 Standard:
B1
4200 V
T2
S 2000.0 kVAR 1.150 %X 6.400 %
T4
S 2500.0 kVAR 1.050 %X 6.410 %
B5
600 V
B2
600 V
MB4/5
2000.0 kW (Output)X"d 0.1880 puTd" 18.67 msTdc 11.73 msRs/Rr 1.5926
M2
2000.0 kW (Output)X"d 0.1500 puTd" 18.67 msTdc 11.73 ms
Rs/Rr 1.6190
T7
S 250.0 kVAR 1.780 %X 6.770 %
B7120 V
B2BEC
46.0 MetersR 0.164 Ohms/kmX 0.096 Ohms/km
B2B3C
30.0 MetersR 0.069 Ohms/kmX 0.092 Ohms/km
BE
600 V
B3
600 V
E1
500 kWX"d 0.12 puX'd 0.18 puXd 2.60 puRa 0.01 puTd" 20.00 msTd' 320.00 msTdc 64.00 ms
G4
2000 kWX"d 0.17 puX'd 0.29 puXd 2.75 puRa 0.01 puTd" 26.00 msTd' 420.00 msTdc 93.00 ms
G1 3500 kWX"d 0.17 puX'd 0.29 puXd 2.75 puRa 0.01 puTd" 26.00 msTd' 420.00 msTdc 93.00 ms
G2 3500 kWX"d 0.17 puX'd 0.29 puXd 2.75 puRa 0.01 puTd" 26.00 msTd' 420.00 msTdc 93.00 ms
G3 3500 kWX"d 0.17 puX'd 0.29 puXd 2.75 puRa 0.01 puTd" 26.00 msTd' 420.00 msTdc 93.00 ms
T2C
10.0 MetersR 0.125 Ohms/kmX 0.098 Ohms/km
T2B5C
18.0 MetersR 0.069 Ohms/kmX 0.092 Ohms/km
T4C
10.0 MetersR 0.095 Ohms/kmX 0.095 Ohms/km
T4B2C
10.0 MetersR 0.069 Ohms/kmX 0.092 Ohms/km
G4C
11.0 MetersR 0.069 Ohms/km
X 0.092 Ohms/k
E1C 10.0 MetersR 0.110 Ohms/km
X 0.095 Ohms/km
MB2/3
1700.0 kW (Output)X"d 0.1880 puTd" 18.67 msTdc 11.73 msRs/Rr 1.5926
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A portion of the output report is shown:
*FAULT BUS: B1Voltage: 4.200 kV Ipeak: 38406.35 A x(peak factor): 1.616
TIME (Cycles) 0.0 0.5 3.0 5.0 12.5================================================================================Iac(A) 16806.57 14453.94 9663.52 8732.21 7930.09
Idc(A) 22784.53 17965.39 9036.90 6119.38 1571.28
TIME-DEPENDENT SHORT-CIRCUIT CURRENTS AT THE MAJOR POINTS:
Bus Name:B1 Voltage: 4.200 kVTIME(Cycles) 0.0 0.5 3.0 5.0 12.5================================================================================- M2 Ipeak: 3127.69 A.Iac(A) 1884.71 1206.14 129.47 21.72 0.03Idc(A) 2893.48 1421.95 40.76 2.38 0.00
- G1 Ipeak: 9382.70 A.Iac(A) 3838.60 3454.88 2608.89 2419.96 2221.24Idc(A) 4918.30 4496.76 2872.92 2007.53 523.52
- G2 Ipeak: 9382.70 A.Iac(A) 3838.60 3454.88 2608.89 2419.96 2221.24Idc(A) 4918.30 4496.76 2872.92 2007.53 523.52
- G3 Ipeak: 9382.70 A.Iac(A) 3838.60 3454.88 2608.89 2419.96 2221.24Idc(A) 4918.30 4496.76 2872.92 2007.53 523.52
- MB4/5 (Eq. Motor) Ipeak: 2004.50 A.Iac(A) 1047.51 775.94 173.05 52.10 0.58Idc(A) 1800.69 907.16 29.44 1.90 0.00
- B2 (Eq. Gen.) Ipeak: 5126.06 A.Iac(A) 2358.54 2107.21 1534.33 1398.52 1265.76Idc(A) 3335.47 2146.01 347.95 92.52 0.72
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Datablock results for the same faulted bus are displayed on the following one-line:
B1
AC (0.5cy) 14520 AAC (3cy) 9684 ADC (0.5cy) 18049 ADC (3cy) 9065 AIp 38584 AT2
S
T4
S
B5
B2
MB4/5
M2
AC (0.5cy) 1206 AAC (3cy) 129 ADC (0.5cy) 1422 ADC (3cy) 41 AIp 3128 A
T7
S
B7
B2BEC B2B3C
BE B3
E1 G4
G1
AC (T0) 3842 ADC (T0) 4924 AIp 9392 A
G2
AC (T0) 3842 ADC (T0) 4924 AIp 9392 A
G3
AC (T0) 3842 ADC (T0) 4924 AIp 9392 A
T2C
AC (0.5cy) 831 AAC (3cy) 185 AIp 2136 A
T2B5C
T4C
AC (0.5cy) 2108 AAC (3cy) 1535 AIp 5143 A
T4B2C
G4CE1C
MB2/3
Note that the contributions from MB4/5 Equivalent and Equivalent Generator EG are
slightly different in PTW than the hand calculation example shown in the IEC 61363
standard. These slight differences are due to neglecting motor pre-load condition in PTW
and inconsistent rounding in the hand calculation. The contributions from G1, G2, G3
and M2 match as expected.