Partial
discharges (PD) may occur in electrical insulation systems that operate at 3.3
kV and above. PD only occurs when a gas filled voids are present within the
insulation or a gas (usually air) is present on the insulation surface when
there is a high electric stress [23]. If the stress is high enough, the gas
will experience electrical breakdown, creating a spark consisting of energetic
electrons which will break molecular bonds in any organic polymer. Thus PD will
age the insulation and may eventually cause failure. PD occurs in a wide
variety of high voltage electrical apparatus such as transformers, gas
insulated switchgear, power cables and rotating machines. Since each discharge
causes of a flow of charge, the PD can be detected by measuring the current
pulses on the terminals of high voltage equipment. Off-line PD testing has been
as a factory test for almost 100 years on equipment such as power cables. The
purpose is to detect flaws created during manufacturing that lead to PD, and
thus lead to insulation failure. In the past 30 years or so, owners of high
voltage equipment are also measuring PD over time on installed equipment. Many
aging processes can create voids that can lead to PD, and thus PD is often
a symptom of thermal and thermo-mechanical aging processes. By monitoring the
evolution of PD over time either in off-line tests or by on-line monitoring
while the equipment is operating normally, equipment owners have a powerful
tool for determining when maintenance or equipment replacement is needed. More
commonly, machine owners have been using off-line and on-line PD testing to
assess the condition of the stator winding insulation in order to determine if
maintenance is needed. Problems such as loose coils in the stator slots,
contamination leading to electrical tracking and thermal aging of the
insulation are easily detected
There are many different
types of PD testing equipment that have been used for coils and stator
windings. Most use a capacitor to detect the PD pulse currents in the presence
of the 50/60 Hz high voltage. The instrumentation to measure the PD current
pulses most commonly includes an analog to digital converter that determines
the number, magnitude and phase position (with respect to the 50/60 Hz ac
cycle) of the PD. However almost every brand of PD detector works in a
different part of the frequency spectrum. Since each partial discharge pulse is
the result of a brief flow of electrons lasting only a few nanoseconds, by the
Fourier transform, frequencies from 0 Hz up to several hundred MHz are created
by each discharge. Thus PD can be detected in a very wide range of frequencies,
and this will impact what is actually measured. This paper discusses how the
frequency range affects the detection of PD in stator windings.
2 PD – A COMPARISON TEST
Partial discharges (PD) are small electrical sparks that occur when voids exist
within or on the surface of high voltage insulation of stator windings in
motors and generators. These PD pulses can occur because of the
manufacturing/installation processes, thermal deterioration, winding
contamination or stator bar movement during operation. As the insulation
degrades, the number and magnitude of PD pulses will increase. Although the
magnitude of the PD pulses cannot be directly related to the remaining life of
the winding, the doubling of PD pulse magnitudes approximately every 12 months
has been used as a “rule of thumb” to indicate rapid deterioration is occurring
[If the rate of PD pulse activity increases rapidly, or the PD levels are high
compared to other similar machines, this is an indicator that visual
inspections and/or other testing methods are needed to confirm the insulation
condition Furthermore, if the PD magnitudes by the same test method from
several identical windings are compared, the windings exhibiting higher PD
activity are generally closer to failure .
.
VOLTAGE
It is well known that voltage has a dramatic effect on the PD magnitude, at
least if the insulation is not excessively overstressed. Figure 1 shows the
effect of voltage on the PD magnitude of a 13.8 kV epoxy-mica insulated stator
coil, a 5% reduction in voltage around 8 kV causes 30% reduction in the PD
magnitude, a 10% reduction, 60%. Thus, a small decrease in applied voltage
causes an even larger decrease in the detected PD pulse magnitude. In addition,
at a given test voltage, the number of pulses per second drops exponentially
with pulse magnitude. Hence, there is a significantly lower PD pulse count rate
at the lower voltages.
Figure 1. Pulse magnitude and pulse phase
analysis of the PD on the stator coil energized to 8 kV
This
has a significant implication for on-line PD testing, where the voltage across
each coil decreases linearly between the phase terminal and neutral. In a
typical machine with 100 coils, the coil connected to the phase end will have
the highest PD activity (magnitude and number), A coil connected one coil down,
will have a PD magnitude that is about half of that in the phase end coil, with
the same amount of deterioration. A coil two coils down from the phase
end, will have a PD magnitude one quarter of the magnitude in the phase end
coil, and even fewer pulses. This analysis plus many years of visual
observation of PD effects in actual machines show that only the first few coils
in a winding suffer the most from PD. There is no PD at the neutral end.
From
the data described above, it is clear that the coil voltage has a much higher
impact on the PD magnitude than the winding attenuation effect. The result is
that one can choose whatever bandwidth one desires for PD measurements in
operating stators; if the PD sensor is located at the phase terminals, it is
near the only coils likely to be subject to high PD activity Therefore, one can
detect the PD at either low frequency or high frequency, since pulse
attenuation at higher frequencies is relatively small, because the most active
PD sites are close to the PD sensor.
Therefore,
PD sensors should be located near the first few coils in a stator winding.
6 BANDWIDTH
The frequency domain characteristics of a pulse stream can be calculated using
standard Fourier transforms [39]. Alternatively, several papers [40][41][42]
show how to calculate the spectrum, including the all-important upper frequency
at which the signal level starts decaying to 0. From these calculative methods,
it is clear that pulses, such as those shown in Figure 2 produce frequencies
into ~300 MHz. To a first approximation, this can be seen by making, the
unipolar pulse shown in Figure 2 into the first half cycle of a sinusoid. The
unipolar pulse in Figure 2 has a duration of ~3ns. In constructing the
sinusoid, there is a period of ~6 ns. Since frequency is the inverse of the
period, the pulse in Figure 2 has harmonics at 160 MHz. For shorter duration pulses,
frequencies to 350 MHz are present.
LF VS VHF OFF-LINE PD ON MOTOR STATOR
Off-line PD tests were performed using LF and VHF PD detectors on a 13.2 kV,
6000 HP motor stator winding [37]. The LF test was performed with a PDTech
DeltaMaxx analyzer using a 1000 pF PD detection capacitor. It operated in the
wideband mode in frequency range 40 – 800 kHz. C phase had the highest activity
and is shown in Figure 3. Figure 3 (left) shows the phase resolved PD (PRPD)
pattern obtained after stabilization at 8 kV (just above rated line to ground
voltage). Figure 3 (right) shows the VHF PRPD plot measured on the
same phase of the stator winding at the same voltage using an 80 pF PD
sensor and an Iris Power TGA-B instrument. The PD detection frequency range is
40 -350 MHz.
The
peak PD magnitude (Qm) for the VHF measurement (calculated using the definition
for digital instruments in IEC 60034-27 [24] is +816 mV and -912 mV. The Qm is
the magnitude at a PD pulse repetition rate of 10 pulses per second (pps). The
LF PD instrument calculated Qm to be 2.5 nC, using the same 10 pps definition.
Note however some LF instruments calculate the peak PD magnitude using a method
based on an analog definition of the largest repetitive magnitude in a train of
pulses, as defined in IEC 60270 [23].
C
phase of this stator winding has a ratio of 2.7 pC/mV between the LF and the
VHF detectors. However note the cautions in IEC 60034-27 [24] that different
brands of PD instruments are likely to give much different pC levels even under
the same test conditions. The PRPD patterns and the relationship between
positive and negative PD is essentially the same between LF and VHF.
PD
occurs into frequencies up to ~300 MHz
LF VS. VHF OFF-LINE PD IN A TURBINE GENERATOR
STATOR
The stator winding of an 18 kV, 200 MVA hydrogen-cooled generator was also
given an off-line PD test using both LF and HF instruments described above. The
tests were done at about 9.7 kV, a little below the rated line to ground
voltage, in atmospheric pressure air. Fig 2a shows the PRPD plot from Phase C,
which had the highest activity. The plot shows classic internal groundwall
activity (see IEC 60034-27 for PRPD plots associated with each type of PD
source), with approximately equal positive and negative PD activity. A Qm of
1.1 nC was measured.
Figure
4 shows the PDPD plot measured in the VHF range on C phase under the same test
conditions as for the LF test.
It
shows the same PRPD pattern as for the LF test. The Qm (calculated at 10 pps)
is +106 mV and -121 mV. Thus the ratio between the LF test in pC and the VHF
test in mV is 9.1 pC/mV, which is substantially different than the ratio
measured on the motor. This variability exemplifies the difficulty in
calibration as described below.
SIGNAL TO NOISE RATIO
During on-line testing, the noise (i.e. electromagnetic pulses from sources
different to PD from stator winding) becomes relevant, because the stator
winding subjected to testing is connected to the rest of the system with many
sources of noise (sparks from busbars, corona from bolts, tracking from
insulators, PD from current transformers, sparks from tools, radio broadcasting
signals, etc). This electrical interference is a factor which can have an
influence on the measurement bandwidth. The electrical noise can be as much as
l000x (60 dB) larger than the PD signals from an operating motor or generator,
especially if the stator winding is cooled by high pressure hydrogen gas. [Figure
5]
The
question to be asked when trying to detect PD in an operating motor-or
generator is not-how large is the PD signal, but how large is the PD signal in
comparison to the ‘noise’, i.e. the signal-to-noise ratio (SNR). Boggs [34]
shows that if the noise has a broadband (white noise) characteristic,
contamination theory indicates that the optimum (i.e. highest SNR) frequency
band for PD detection, assuming there is little attenuation, occurs at ~250
MHz. This is because the power in broadband (white or electronic) noise
increases with the square root of the bandwidth of the measuring system;
whereas, the power in the PD signal increases proportionately, with bandwidth,
up to the upper limit set by the PD pulse risetime. The result is that the SNR
increases with the square root of the bandwidth. A higher SNR reduces the risk
of false indications of stator winding problems caused by noise. This is why
VHF or UHF with UWB (i.e. ~100 MHz) PD detectors have become dominant for
on-line PD defection in rotating machines [33], [35], [36].
On-line
tests, high SNR (VHF or UHF with UWB) reduces risk of false indications
ADVANTAGES OF LF AND VHF PD DETECTION
Off-tine PD testing is best performed with PD detectors operating in the 1 MHz
range, to ensure that PD can be detected in all the coils in a stator winding
with the minimal amount of attenuation. On-line PD tests are best performed at
higher frequencies since this optimizes the signal to noise ratio, as well as
enabling the separation of disturbances from PD based on time-of pulse
arrivals. The result is a PD signal free of interference, and thus a reduced
risk of false alarms. Although more pulse attenuation will occur at the higher
measurement bandwidth needed to separate out the noise, this attenuation is
relatively minor, since in an operating stator the sensor can be placed very
close to the few coils experiencing the HV.
Off-line
tests on both coils/bars and complete stator windings should be performed in
the LF range, even though Figure 3 and Figure 4 show the PRPD patterns are
essentially the same. For coil/bar tests this will allow the PD to be
scientifically quantified in terms of apparent charge (pC). For windings, the
LF range maximizes sensitivity to PD in more of the coils/bars in the winding.
The
basic advantages of the LF test for off-line testing, as described in IEC
standards [24][28], include
The
LF advantage of greater sensitivity is less important than for off-line tests,
since the coil/bar voltage decreases linearly through the circuit from the
phase terminal to the neutral end of the winding. As the voltage deceases so
does the PD magnitude and the number of defects that produce PD.
There
is greater immunity to noise and disturbances from the power system with VHF
and UHF methods, which lowers the risk of false indications of stator winding
problems. Also this implies that less expertise is needed to perform and
interpret PD results, since there is a lower risk the stator PD is obscured by
the noise. This implies a lower marginal test cost. As a consequence,
continuous PD monitoring is less likely to give false indications.
With
some of the VHF methods and all of the UHF methods, it is possible to locate
with more certainty where the PD is occurring within the winding.
Most
capacitive PD sensors in VHF methods can meet the sensor reliability
requirements stipulated in IEC 60034-27-2, thus reducing the risk that a PD
sensor may fail the machine
Peer-reviewed
databases containing hundreds of thousands of test results have been summarized
in tables of “high” and “low” PD. These severity levels have been
confirmed by visual inspections on many hundreds of machines [22]
It is
clear from the IEC standards that both the LF and VHF ranges can detect severe
PD in a winding. The LF method tends to be preferred by OEMs and test service
providers who have the expertise to separate the PD from the noise, and judge
the severity based on experience with similar machines. Owners of machines tend
to use the VHF and UHF methods since utility staff can perform the test and do
a basic interpretation with relatively little training and experience.
On-line
tests, high SNR (VHF or UHF with UWB) reduces risk of false indications
6.5
MATCHING BANDWIDTH FREQUENCIES
An instrument provider researched doing on-line PD data collection service
using a LF instrument connected to existing 80 pF capacitive PD sensors [38].
80pF sensors terminated in 50ohms provide a high-pass filter of ~ 40MHz.
According to the data available for the LF PD monitoring instrument, the input
frequency range is up to 20 MHz and bandwidth up to 3 MHz, and it has only one
PD sensor input per phase (single ended installation). Note that VHF
instruments have a bandwidth from 50 kHz to 350 MHz and when combined with the
80 pF capacitive PD sensor, the system bandwidth is 40 MHz to 350 MHz. The LF
instrument configuration used a matching unit (basically an amplifier plus a
low pass filter) intended to get from 80 pF PD sensors (EMCs), to a
measuring range between 100 kHz to 500 kHz [38].
The
measured background noise, the signal to noise ratio (SNR) of the LF instrument
connected to the 80pF sensors is only 12% of the SNR from the typical 2nF PD
sensors. The research shows that when the matching unit described above is
used, the measurement is less reliable since the SNR from the connected 80 pF
sensors gets worse and decreases to 11% of the SNR from the 2nF PD sensors.
Thus it is clear from these tests that if a low frequency measurement system is
used, it is best to connect it to a large capacitance, rather than try to force
fit the instrument to a PD sensor made for high frequency applications.
Bandwidth
frequency of the sensors should match that of the instrument
7 DISTURBANCES
Much of the noise or disturbances encountered in operating machines is not of
the white sort, but is pulse-like, for example: corona on HV buses, switching
noise, etc. Traditional filtering cannot completely remove such pulse-like noise,
since, as described above, such signals will contain frequency components at
all frequencies, especially if the noise pulse risetime is fast. Hence, any
filtering of the noise pulses will also filter the PD, resulting in no net gain
in SNR. It is apparent that alternative methods to filtering are needed to
eliminate pulse-like noise [25]. Several methods have been developed based on
time-of-pulse arrival from a pair of sensors, or on more complex
differentiation of pulse shapes in the time domain [33], [35]. Such pulse
discriminations are now widely used, and the required specialized sensors are
installed in ~3500 machines. The discrimination techniques require the
measurement of PD at high frequencies (≥40 MHz), since the fast risetime pulse
characteristic of PD needs to be preserved so that it can be used as a precise
riming signal, Of course, human experts observing data displayed on
oscilloscope screens and spectrum analyzers, are also capable of separating the
stator PD from the noise.
DIFFERENTIAL CONFIGURATION (HYDROS)
In a differential configuration, the installation is calibrated in such a way
that a noise pulse will be detected at a pair of Iris Power 80 pF PD sensors
(EMCs) at the same time. The Iris Power PDA-IV can resolve the pulse arrival
time from a pair of sensors to <6 ns. PD originating near one sensor (C1 or
C2) will arrive a significant time later at the other sensor. The differential
configuration is employed in large hydro generators that have enough room to
install PD sensors along the circuit ring bus. An instrument with only one
input per phase, will be not able to discriminate the pulses from a pair of PD
sensors as either coming from the parallel C1, coming from parallel C2, or
noise. Thus such an arrangement will mean the results will be corrupted by
electrical noise, greatly increasing the probability of a false indication (and
unnecessary testing and stator repairs being planned). Alternatively a human
expert (presumably from the vendor) will be needed to interpret all results,
rather than the utility performing and interpreting their own tests – greatly
increasing test costs.
DIRECTIONAL CONFIGURATION (MOTORS AND
TURBOGENERATORS)
For machines with a small bore diameter (< 2 m) such as motors and
turbogenerators, a pair of Iris Power 80 pF PD sensors (EMCs) is located
outside of the machine along the output bus, in a directional configuration. It
is called a directional configuration because pulses coming from beyond the bus
segment between the PD sensor pair, arrive first to one sensor and a delayed
time after, arrive to the second sensor. The PD sensor closest to the machine
is named M and the PD sensor further down the system is named S. PD pulses
coming from the stator winding arrive at the M sensor first and are classified
by an instrument called the Iris Power TGA-B as stator PD. Otherwise, pulses
are classified as noise (pulses from beyond S, and pulses between the pair of
PD sensors). This differentiation between stator PD and power system noise
occurs because it takes time for electrical pulses to travel, and the TGA-B can
resolve the arrival time differences as short as 6 ns. An instrument with only
one input per phase, will be not able to discriminate the pulses from a pair of
PD sensors as either PD or power system noise. Thus it will be prone to false
indications, and unnecessary testing and repairs on the stator.
STATOR SLOT COUPLER (LARGE TURBOGENERATORS)
The SSC is a two port directional electromagnetic coupler that is installed in
slots of large turbo generators, either under the wedges, or between the two
bars in the slot. An instrument with only one input per phase, will be not able
to discriminate the pulses from the two port coupler as either PD from the
slot, PD from the endwinding, or noise.
Sensor
configuration is necessary to reduce influence of disturbances
8 COLLECTION OF DATA
PD TEST METHOD
During normal machine operation, the VHF instrument called the PDA-IV or TGA is
temporarily connected to the previously installed sensors in each phase. The
sensor blocks the power frequency voltage, and passes the high frequency
voltage pulse accompanying partial discharge. To avoid any confusion with
electrical noise from power tool operation, corona from the switchgear, RF
sources, etc., the PDA-IV or TGA separates PD from system noise and
disturbances on the basis of time-of-arrival and pulse characteristics, and
measures the number, magnitude and ac phase position of the PD pulses.
DATA
PRESENTATION
Two types of plots are generated for each partial discharge test. The first
type of plot is two-dimensional (2-D), where the number of partial discharges
per second versus PD magnitude is displayed. The greater the number of pulses
per second, the more widespread is the deterioration in the winding. The higher
the PD magnitude, the more severe is the deterioration. The second type of plot
is three-dimensional (3-D), where the quantity (vertical scale) and magnitude
(scale coming out of the page) of the PD versus the ac phase angle (horizontal
scale) are displayed. Experience has indicated that such pulse phase analysis
can be used to identify if multiple deterioration mechanisms are occurring, and
what the mechanisms are.
The
2-D and 3-D plots are unwieldy for making comparisons amongst the machines. The
PDA-IV or TGA summarizes each plot with two quantities: the peak PD magnitude
(Qm) and the total PD activity (NQN). The Qm is defined to be the magnitude
corresponding to a PD repetition rate of 10 pulses per second. Qm relates to
how severe the deterioration is in the worst spot of the winding, while the NQN
is proportional to the total amount of deterioration and is similar to the
power factor tip-up. Since the Qm scalar quantity is more indicative of how
close the winding is to failure, the peak magnitude (Qm) will be used
throughout this paper for comparisons.
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