IEEE Guide for Synchronization,
Calibration, Testing, and Installation of
Phasor Measurement Units (PMUs) for
Power System Protection and Control
Sponsored by the
Power System Relaying Committee
IEEE
3 Park Avenue
New York, NY 10016-5997
USA
6 March 2013
IEEE Power and Energy Society
IEEE Std C37.242™-2013
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IEEE Std C37.242™-2013
IEEE Guide for Synchronization,
Calibration, Testing, and Installation of
Phasor Measurement Units (PMUs) for
Power System Protection and Control
Sponsor
Power System Relaying Committee
of the
IEEE Power and Energy Society
Approved 6 February 2013
IEEE-SA Standards Board
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Abstract: Guidance for synchronization, calibration, testing, and installation of phasor
measurement units (PMUs) applied in power systems is provided. The following are addressed in
this guide: (a) Considerations for the installation of PMU devices based on application
requirements and typical substation electrical bus configurations; (b) Techniques focusing on the
overall accuracy and availability of the time synchronization system; (c) Test and calibration
procedures for PMUs for laboratory and field applications; (d) Communications testing for
connecting PMUs to other devices including Phasor Data Concentrators (PDCs).
Keywords: calibration, GPS, IEEE C37.242™, PMU, synchrophasor, testing
•
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The following members of the individual balloting committee voted on this guide. Balloters may have
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IEC/TR 61850-90-5, Ed. 1.0, Communication networks and systems for power utility automation—
Part 90-5: Use of IEC 61850 to transmit synchrophasor information according to IEEE C37.118.
IEEE Std 1588™-2008, IEEE Standard for a Precision Clock Synchronization Protocol for Networked
Measurement and Control Systems.
2,
3
IEEE Std C37.118™-2005, IEEE Standard for Synchrophasors for Power Systems.
IEEE Std C37.118.1™-2011, IEEE Standard for Synchrophasor Measurements for Power Systems.
IEEE Std C37.118.2™-2011, IEEE Standard for Synchrophasor Data Transfer for Power Systems.
IEEE Std C37.233™-2009, IEEE Guide for Power System Protection Testing.
IEEE Std C37.238™-2011, IEEE Standard Profile for Use of IEEE 1588™ Precision Time Protocol in
Power System Applications.
IEEE Std C57.13™, IEEE Standard Requirements for Instrument Transformers.
IRIG Standard 200-04 (2004), IRIG Serial Time Code Formats, Telecommunications and Timing Group,
Range Commanders Council, U.S. Army White Sands Missile Range, NM, USA.
4
3. Definitions, special terms, acronyms, and abbreviations
These definitions, acronyms, and abbreviations are especially pertinent to GPS-synchronized devices,
communications protocols, and communications media.
1
IEC publications are available from the International Electrotechnical Commission (http://www.iec.ch/). IEC publications are also
available in the United States from the American National Standards Institute (http://www.ansi.org/).
2
IEEE publications are available from The Institute of Electrical and Electronics Engineers (http://standards.ieee.org/).
3
The IEEE standards or products referred to in this clause are trademarks of The Institute of Electrical and Electronics Engineers, Inc.
4
This document available for download at http://www.irigb.com/pdf/wp-irig-200-04.pdf.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Global Positioning System (GPS): A satellite-based system for providing position and time. The accuracy
of GPS-based clocks can be better than 1 μs.
Intelligent Electronic Device (IED): A general term indicating a multipurpose electronic device typically
associated with substation control and protection.
Phasor Data Concentrator (PDC): A function that collects phasor data and discrete event data from
PMUs and possibly from other PDCs, and transmits data to other applications. PDCs may buffer data for a
short time period but do not store the data.
phasor measurement unit (PMU): A device or a function in a multifuncation device that produces
synchronized phasor, frequency, and rate of change of frequency (ROCOF) estimates from voltage and/or
current signals and a time synchronizing signal.
virtual private network (VPN): VPN is an end-to-end communications method that employs encryption
and key exchange as the security mechanism. VPNs can be established over either public or private
networks.
Wide Area Measurement System (WAMS): One or more networks of measuring devices that may
include phasor measurement unit (PMUs), local recorders, legacy equipment, or advanced technologies that
are Global Positioning System (GPS)-synchronized over a geographically diverse area.
3.2 Special terms
error: In this guide, error is the difference between the result of a measurement and the value of what is
generally called the true value (of the measurand).
uncertainty: A parameter, associated with the result of a measurement, that characterizes the dispersion of
the values that could reasonably be attributed to the measurand. Uncertainty of measurement is
conventionally divided into two components. Type A uncertainty may be evaluated from the statistical
distribution of the results of a series of measurements. Statistical processing can be used to reduce the value
of this kind of uncertainty. Type B uncertainty can be evaluated from assumed probability distributions
based on knowledge from other than that from the measurements, such as the manufacturer’s
specifications, reference data from handbooks or calibration certificates.
3.3 Acronyms and abbreviations
CT current transformer
CVT capacitive voltage transformer
DFR digital fault recorder
DUT device under test
5
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
4. Synchronization techniques, accuracy, and availability
4.1 Introduction
This clause reviews the main technologies available to synchronize geographically distributed PMUs, and
the basic principles of clock synchronization and its impact on the phasor measurement accuracy. This
clause also examines common synchronization sources for time referencing, including both satellite (e.g.,
GPS) and terrestrial [e.g., Precision Time Protocol (PTP)] based technologies. The main advantages (e.g.,
timing accuracy) and potential vulnerabilities (e.g., susceptibility to intentional and unintentional
interference) of these techniques are also reported.
This clause also presents testing procedures (e.g., periodic timing signals measurement, measurement of
two consecutive timing signals) aimed at assessing the main performance characteristics of synchronization
sources (e.g., short-term stability, “bad” data management, hand-off algorithm).
Lastly, the synchronization distribution infrastructure is also discussed within this clause.
4.2 Role of time synchronization in PMUs
The clocks used for time synchronization in PMUs are required to be very accurate. However, their
accuracy may vary over time due to manufacturing defects, changes in temperature, electric and magnetic
interference, oscillator age, and altitude. Additionally, even small errors in timekeeping can add up
significantly over a long period.
Careful work and analysis is required to describe and quantify performance of timing in PMU systems, to
meet the accuracy requirements of IEEE Std C37.118.1-2011. Some clock variations are random, caused by
environmental or electronic variations; others are systematic, caused by a miscalibrated or misconfigured
clock.
Correct operation of a PMU requires a common and accurate timing reference. The timing reference is
described in IEEE Std C37.118.1-2011, which establishes the relationship between the Coordinated
6
Information on references can be found in Clause 2.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
7
The numbers in brackets correspond to those of the bibliography in Annex A.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 1 —Typical voltage/potential and current instrumentation channels
The first link in the instrumentation channel equipment chain consists of voltage and current transformers
(CTs), collectively called instrument transformers. These devices transform power system voltages and
currents to levels appropriate for driving relays, fault recorders and other monitoring equipment, isolated
from the original quantities. Several instrument transformer technologies are presently in use. The most
common devices are potential or voltage transformers (PTs or VTs) and CTs based on magnetic core
transformer technology. Another type of commonly used voltage transducer is the coupling capacitor
voltage transformers (CCVT), based on a combination of a capacitive voltage divider and a magnetic core
transformer. Voltage and current instrument transformers have also been constructed based on the electro-
optical and magneto-optical phenomena. These devices are known as optical voltage transformers (OVT)
and optical current transformers (OCT). There are also other sensor and transducer technologies available
for voltage and current measurement (e.g., Rogowski coils and Hall-effect devices). While reference is
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 2 —Representative (example) PMU system showing major elements
6.3 Pre-installation procedures
6.3.1 Installation design
In most cases, a PMU installation is considered a permanent installation and requires a complete design.
Following are supplementary guidelines to help scope a project and proceed with the design. Typical
design includes selection of power system sources, inputs, outputs, alarms, absolute time source, and
communications interfaces. Some of the key components of a typical PMU are described in the following
subclauses.
6.3.2 Timing input
Timing accuracy is critical. The choice of hardware, antenna location, cabling, and routing of the cable are
therefore critical in the overall design of the PMU system. For a GPS system, an antenna open to GPS
satellites should have a clear sky view (free from obstructions) above about a 10 degree elevation, so that
some satellites are always in view. In cases where this is difficult to achieve, some compromise is possible
because the PMU internal clock should be able to ride through complete or intermittent loss of GPS
synchronization. When available, it is recommended that the GPS clock be configured with its position
LOCKED (a setting in some GPS clocks). With the position LOCKED, the GPS clock can deliver accurate
time with only one satellite visible / receivable.
Figure 3 shows recommended antenna mountings. In the northern hemisphere most of the signals will come
from the south (see Figure 4). It is expected that there may be obstructions that obscure the sky within ten
degrees of the horizon. Above that, good visibility of the sky should be achievable.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 4 —Example of GPS signal visibility pattern reflecting the orbit
for various satellites
Figure 4(a) shows what is called a sky plot or a polar plot of the satellite orbits. It indicates the trajectories
of the GPS satellites for a day, essentially the view from a fish-eye lens gazing upward. This particular plot
is based on a latitude of 45 degrees north (about the latitude of Minneapolis), so the satellites trajectories
across the sky are predominantly to the south. (The satellites would appear to rise in the east and set to the
south, or rise in the south and set to the east. At this assumed latitude, some do go directly overhead. If the
location were further north, the “hole” in the plot would move down the diagram, as no satellites would go
directly overhead.) Figure 4(b) shows the time of day that the various satellites would be visible. At any
latitude, at least six satellites should be in the sky at all times, and at this latitude, the number is often as
many as nine.
In the northern hemisphere, the antenna should be mounted with a clear view to the south. Small
obstructions more than half a meter away from the antenna will not cause a problem, but a large flat
obstruction within a few hundred meters could act as a reflector and cause multi-path problems. Check
around the mounting location for a structure, such as a flat metal roof, that is oriented so it can reflect a
satellite signal to the antenna (keeping in mind satellites will traverse most points in the sky). Also check
for obstructions that can block the signal, and high power signal sources that can saturate the GPS input.
The most reliable antenna mounting option is an open air sky-view installation.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 5 —Example showing forms of IRIG-B comparing the unmodulated (level shift) B000,
1 kHz modulated B120, and modified Manchester B200
A GPS-fed clock can potentially serve a number of devices using one IRIG-B output port. The number of
clients (users) that a clock can serve depends on both the drive capacity of its IRIG-B port as well as the
amount of load (both capacitive and resistive) that the devices connected to the clock represent. The
cabling, associated routing, and termination methods also affect the clock loading. To design a highly
reliable timing circuit, product specifications should be studied and respective manufacturers may be
consulted. Some of the key factors to consider are the following:
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Ethernet
100BaseFX
FO 2 km
Best for interference rejection and avoiding
grounding problems.
a
Standard CAT5 is unshielded twisted pair (UTP). This should be shielded twisted pair (STP).
6.6.2 Interface medium
PMUs generally will have asynchronous serial (EIA-232, previously known as RS-232) or Ethernet
communications. Both will handle data at the rate and block size used in most measurement systems. An
interface device between the PMU and the communications system is required. The user must identify the
communications medium, interface, and technology required for the particular application (e.g., whether
multi-cast communications is needed). Generally, a modem translates between a digital data system and an
analog communications system, and a service unit or router or bridge translates between a digital data
system and a digital communications system. In either case, the PMU output is a digital data type and needs
one of these devices to interface to the communications system. Most importantly, the appropriate sides of
the interface have to match the PMU and communications system, and must handle the required data rate.
If the PMU output is asynchronous serial, the interface must handle asynchronous serial at the given rate.
See Table 4.
8
PMU communications by Ethernet match directly with digital systems and interface well with digital
communications such as SONET. Ethernet-based digital systems are well developed and supported, so
building these systems is generally very straightforward. Care needs to be exercised when connecting the
local Ethernet system through a digital communications system (e.g., SONET), usually called the Wide
Area Network (WAN) connection. The WAN needs to support the minimum data rate with some room for
overhead, and the interface needs to have sufficient buffering to match WAN and Ethernet speed
differences. Most of these systems currently use Internet Protocol (IP) for data communications. Building
and managing these systems is centered on setting up IP hosts, subnets, and routing. Additional
considerations for communications interface include data exchange with neighboring systems, neighboring
countries, local independent (electricity) system operator (ISO), or at the regional levels. Depending on the
application, data reliability and accuracy may be critical factors.
Cyber security requirements are also important considerations when the application is considered critical.
Each utility will have its own recommendations, but the use of a virtual private network (VPN) form of
communications not connected to the internal Local Area Network (LAN) is one option for providing
isolation and security. Care should be used when applying only VPN technology for security, as whatever
traffic traverses the VPN may be inherently trusted and create a vulnerability to both connected systems.
8
Notes in text, tables, and figures of a standard are given for information only and do not contain requirements needed to implement
this standard.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
A suitable GPS antenna splitter is required
when connecting more than one GPS
receiver to a single antenna. Some
antennas require preamplifier power so the
receiver and splitter must be capable of
routing appropriate power to the antenna.
Does the PMU output match
the communications system
interface?
If system is Ethernet connected and PMU is
EIA-232, make sure the interface conversion
is available with type and speed required (see
Table 5).
What types of communications
are established within the
substation?
If FO, will it match the PMU interface?
If not FO, is the distance short enough for
metallic cabling (see Table 3)?
Other factors include grounding and
shielding when metallic mediums are used.
Design considerations should include
methods of grounding the shield and
whether the cable shield is grounded on
both ends or one end.
What is the impact of including
a PMU into an existing CT and
PT circuits, and the additional
burden impacting PMU
performance?
Most PMU devices have a very low burden.
A good design with engineering
calculations for the overall burden is
necessary to prevent installing a PMU in a
circuit that would impact performance of
the PMU.
When impact of the burden is high,
separate sources (CTs and PTs) may have
to be used or installed to achieve PMU
performance.
Does the application have
particular filtering needs (P
and M classes as defined in
IEEE Std C37.118.1-2011)?
Yes, be sure the PMU has settings that match
or use alterable settings to satisfy the
application requirements.
Filter in this context is in reference to P
and M class. In general, microprocessor
based devices may have filtering beyond
the intent of the reference to the P and M
classes.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
where
P = power flow on the line
X = line reactance
V
1
and V
2
= bus voltages
Power flows from buses with leading angle to those with lagging one. The measured angle will be
reasonably close to the value calculated from the power flow equation, Equation (1).
Even if the stations are not adjacent, or the parameters are not well known, the measurement phasing can be
confirmed using a heuristic approach and applying the following rules:
⎯ Power flows from buses with leading angles to those with lagging angles. By noting the power flow
in the area between the stations being compared, if it is notably flowing from one to the other, the
angle polarity should be consistent with power flow direction.
⎯ If there is little power flow, the distance is short, or the impedance is low, the angle will be small.
Higher voltage systems have lower impedance. Multiple lines or a meshed grid have lower
impedance.
⎯ If the stations are fairly close (within 300 km), expect an angle of 30 degrees or less. If they are
more distant, it could be higher (possibly more than 90 degrees in a meshed grid).
⎯ If the power flow between stations is not clearly one direction or the other, the angle could go
either way but the total will be smaller, perhaps in the area of 15 degrees.
⎯ Large errors of 30 degrees can usually be detected if the PMU is assumed to be connected for line-
to-neutral measurements but is actually line-to-line (or vice versa).
Since the main objective here is to detect phasing errors and phase selection errors resulting in a 120 degree
phase shift, such a large discrepancy will be distinguishable from the angles estimated by power flow using
the rules previously mentioned. However, certain factors such as Y-∆ and phase shifting transformers, as
well as series capacitors, can produce results that make phase checking difficult to determine.
A similar approach is recommended when the PMU data is compared with a neighboring system. The first
step is to confirm the phase naming convention and determine the relative phase angle relation between
comparable power system phases.
With these large errors removed, comparison to SCADA-based EMS load flows can be expected to be
within 2 or 3 degrees.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 6 —Phase calibration of reference PMU with the 1 PPS clock signal
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Notice that the measured phasor can be a voltage phasor or a current phasor. Figure 7 shows how TVE,
magnitude error and angle error are interrelated. The plot in this figure shows the TVE calculated for angle
errors from –0.5 to 0.5 degrees and magnitude errors of 0%, 0.1%, 0.2%, and 0.3%. As expected, the TVE
is greater than the magnitude error except for the case that the phase error is zero. For even a 0.5 degree
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 7 —TVE in percentage for angle errors of –0.5 degrees to 0.5 degrees and
magnitude errors of 0%, 0.1%, 0.2% and 0.3%
7.5.1.2 Frequency error and rate of change of frequency error
FE and RFE measurements are tested for accuracy using the following error definitions:
FE = Frequency error = |f
true
– f
measured
| = |Δf
true
– Δf
measured
|
RFE = ROCOF error = |(df/dt)
true
– (df/dt)
measured
|
where
The measured and true values are taken at the same instant of time
Δf
true
is the deviation of the true frequency from the nominal frequency
Δf
measured
is the deviation of the PMU measured frequency from the nominal frequency
(df/dt)
true
is the true rate of change of the frequency
(df/dt)
measured
is the PMU measured rate of change of frequency
7.5.1.3 Reporting rates and reporting times
The PMU should be configured to operate at each of the required reporting rates as specified by
IEEE Std C37.118.1-2011. With near nominal three-phase input voltage and current signals, the TVE of the
PMU should be measured. The reporting time stamps should be examined to see that the fractional second
values are integer multiples of the reciprocal of the reporting rate 1/F
s
(rounded or truncated to the
appropriate significant figure). Thus, if F
s
is 20 per second, the time stamps should occur at intervals of
exactly 1/20 s, or 50 ms.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Bandwidth
(Hz)
10% Nyquist
of F
s
(Hz)
F
s
/2
(Hz)
F
nom
= 60
(Hz)
10 or less ±2 ±0.5 5 55 to 65
12 ±2.4 ±0.6 6 54 to 66
15 ±3 ±0.75 7.5 52.5 to 67.5
20 ±4 ±1 10 50 to 70
30 ±5 ±1.5 15 45 to 75
60 ±5 ±3 30 30 to 90
50 Hz nominal In band
F
s
Bandwidth
(Hz)
10% Nyquist
of F
s
(Hz)
F
s
/2
(Hz)
F
nom
= 50
(Hz)
10 or less ±2 ±0.5 5 45 to 55
25 ±5 ±1.25 12.5 37.5 to 62.5
50 ±5 ±2.5 25 25 to 75
Interfering signals are not injected at the in-band frequencies above.
Apply a steady-state, balanced, three-phase signal to both current and voltage inputs, at nominal steady-
state magnitude and nominal system frequency (50 Hz or 60 Hz). Inject into the voltage and current inputs
a positive-sequence interharmonic at frequency f
i
where, as shown in Equation (3):
|f
i
– f
0
| ≥ F
s
/2 (3)
where
F
s
is the reporting rate
f
0
is the nominal frequency
f
i
= f
interharmonic
is the frequency of the interfering signal frequency
a) Add an interharmonic signal at f
i
= f
0
– F
s
/2 at 10% nominal magnitude.
b) Wait for the system to settle.
c) Capture the PMU output for 5 s.
d) Calculate the maximum TVE, FE, and RFE.
e) Run steps b) through d) repeatedly, decreasing the interharmonic frequency logarithmically until it
reaches 10 Hz:
⎯ For each test run, the amount that the interharmonic frequency decreases should increase
logarithmically, thus providing many tests near f
i
= f
0
– F
s
/2 and fewer tests further away from
f
i
= f
0
– F
s
/2. For example, the first decrease should be 0.1 Hz (f
0
– F
s
/2 – 0.1), the next
decrease 0.2 Hz (f
0
– F
s
/2 – 0.2), the third decrease 0.4 Hz (f
0
– F
s
/2 – 0.4), then 0.8 Hz
(f
0
– F
s
/2 – 0.8) until an interharmonic frequency below 10 Hz is reached. For the last
frequency use 10 Hz rather than the frequency below 10 Hz.
f) Add an interharmonic signal at f
i
= f
0
+ F
s
/2 at 10% nominal magnitude.
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
X
b
= X
m
[1 + k
x
cos(ωt)] × cos [ω
0
t – 2π/3 + k
a
cos(ωt – π)] (5)
X
c
= X
m
[1 + k
x
cos(ωt)] × cos [ω
0
t + 2π/3+k
a
cos(ωt – π)] (6)
where
X
m
is the peak amplitude of the input signal
ω
0
is the nominal power system frequency in radians per s (2 × π × f
0
)
ω is the modulation frequency in radians per s
f
m
= ω/2π is the modulation frequency in Hz
k
x
is the amplitude modulation factor
k
a
is the phase angle modulation factor
t is time
k
x
= 0.1 and k
a
= 0.1 for combined phase and amplitude modulation tests.
k
x
= 0 and k
a
= 0.1 for phase modulation tests.
For class P and M, the modulation frequency should range as specified in IEEE Std C37.118.1-2011.
a) Begin with combined phase and amplitude modulated input at ω = 0.1 Hz.
b) Wait for the system to settle (see 7.5.2).
c) Capture the PMU output for at least 2 full cycles of modulation.
d) Calculate the maximum TVE, FE, and RFE.
e) Increase the modulation frequency ω by 0.2 Hz.
f) Repeat steps b) through e) until the upper frequency range limit is reached.
g) Compare the results to the class limits in IEEE Std C37.118.1-2011.
h) Repeat the entire test for phase modulation only.
IEEE Std C37.118.1-2011 only prescribes these combined amplitude-phase and phase only tests. However,
an amplitude only test may be useful to observe if there is an effect on the frequency measurement due to
processing issues in the PMU. Adding this test is an option to consider.
7.5.4.2 Dynamic compliance—performance during ramp of system frequency
PMU performance during system frequency change is tested with a ramp of frequency applied to balanced
three-phase input signals (voltages and currents).
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 8 —Sample of step change at t = 0, illustrating response time,
delay time compensation error, and overshoot measurements
[Note that maximum overshoot may be over or under the final value, and the delay time
compensation error may be positive (response after step) or negative (response before step)]
a) For the first test, let n = 0.
b) Begin with three-phase balanced input at nominal amplitude and frequency.
c) At the beginning of a reporting cycle plus n / (N × F
s
) (i.e., n × reporting period / N)) step the
influence quantity (amplitude or phase) by the amount specified in IEEE Std C37.118.1-2011.
d) Gather the PMU data, return the influence quantity to nominal and wait for the PMU to settle.
e) Increment n by one (n = n + 1), then repeat steps c) through d) until n = N – 1.
f) Index and overlay the PMU data to obtain a smooth response curve.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 9 —Input signal with step change in magnitude
Since IEEE Std C37.118.1-2011 is a performance-driven standard, the actual position of the window with
respect to the time stamp is not explicitly defined. It is contained within the definition of the TVE concept,
5.3, and Annex C of IEEE Std C37.118.1-2011. The intent of IEEE Std C37.118.1-2011 is that the
performance requirements be met and the PMU manufacturer should determine how the data is processed
to achieve that result. In the examples described in IEEE Std C37.118.1-2011, Annex C, the measurement
window is shown centered on the time stamp. That arrangement is also indicated in Figure 9, which shows
two windows centered on the reporting times 28.1 and 28.2.
Of course, the value being calculated from the input samples is not available until some short time after the
last sample within the time window. There is therefore a short delay before the number is transmitted. This
is shown in Figure 10, which illustrates the LRP.
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 10 —Timeline for the event at 28.133
IEEE Std C37.118.1-2011 defines latency measurements in 5.3.4. Two different latencies are defined in the
two paragraphs in this subclause:
Latency in measurement reporting (LMR) defined in the first paragraph is the “time delay from when an
event occurs on the power system to the time that it is reported in data.”
PMU reporting latency (LRP) is the difference between the PMU time stamp and the actual time at which
the record with that time stamp is output (“denoted by the first transition of the first bit of the output
message”).
The two definitions are illustrated in Figure 11. LRP depends only on the time interval from the time tag to
the last sample in the measurement window (generally ½ the length of the window) and the time to process
and emit the measurement. LMR is the measured delay from an event and when it is reported. It is not the
maximum or minimum of such values. It depends upon where within the reporting interval the event occurs
in addition to the time to make the measurement and send it. This will include filtering and windowing
parameters. If we agree to represent an arbitrary event with a step change in value, the time tag is required
to be within ¼ of a reporting period of an event (IEEE Std C37.118.1-2011 5.5.8). Then the minimum
difference between LRP and LMR is ¼ of the reporting period. Detailed analysis reveals that the maximum
value of LMR is one reporting interval greater than LRP, that is, LMR = LRP + 1/Fs. It is called maximum
LMR.
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure 11 —Illustration of PMU Latencies
7.5.4.5 Time quality tests
IEEE Std C37.118-2005 defines a time quality indication field in the FRACSEC portion of all messages.
This time quality is 0 when the PMU is locked to a traceable source of UTC time and indicates a maximum
time error when the PMU is not locked to its time source.
IEEE Std C37.118.2-2011 renames the above time quality indication the message time quality indication
and adds a second PMU time quality indication that is zero only when it is not implemented (as for pre-
IEEE-C37.118.2 devices) and indicates time quality whether the PMU is locked to a traceable time source
or not. This time quality field has also been added to the IRIG-B time code extensions of
IEEE Std C37.118.2-2011 Annex F and to the synchrophasor profile for IEEE Std 1588-2008.
This guide does not provide a test plan for the PMU time quality indication. At the time of writing of this
guide, time sources and PMUs implementing this indication have not been designed and there has been no
field experience with such devices. Test plans have not been discussed nor devised.
7.5.4.5.1 Message time quality test
Testing the message time quality involves measuring the steady-state phase error while the device is locked
to its time source (this will be the “baseline” phase error), removing the time source from the PMU, and
measuring the phase error and comparing it to the message time quality over a period of no less than
1000 s. The phase error minus the baseline phase error is assumed to be caused by the PMU’s timing
inaccuracy. If the phase error “drifts” beyond the phase error that would be caused by the message time
error, the PMU fails the message time quality test.
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for Power System Protection and Control
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for Power System Protection and Control
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
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for Power System Protection and Control
Responses of the reference signal processing model to test signals
B.1 General
This annex provides sample typical responses of the reference signal processing model presented in
Appendix C of IEEE Std C37.118.1-2011. Typical responses are informative only and do not construe
specifications or limits. PMUs being tested may respond in a similar or quite different manner but would
still be in compliance if they meet or exceed the limits of IEEE Std C37.118.1-2011.
The PMU model response examples from this annex do not include time-stamp round-off error as the
model is simulated with a floating-point time resolution with much finer resolution than 1 μs.
B.2 Introduction to the graphs
The following graphs were made using a mathematical model of the PMU reference signal processing
model of IEEE Std C37.118.1-2011 Annex C. The graphs are made at the full system sampling rates of
960 samples/second for M class and 900 samples/second for P class. This is done before the decimation to
the output reporting rate in order to show the actual internal response to the PMU filters that were used to
verify the performance limits of the standard.
B.3 Response of the model to steady-state test signals
B.3.1 Steady-state–signal frequency range
B.3.1.1 M class signal frequency range
The TVE of the M class reference model at nominal frequency is dominated by the attenuation of the filter
following the complex multiplication of the input signal with the nominal frequency carrier. The output of
this multiplication is both the difference of the signals and the sum of the signals. The M class filter passes
the difference signal and attenuates 20 dB of the sum signal.
Following are plots of TVE, magnitude error, and phase error for nominal frequency input at a PMU
reporting rate (F
s
) of 60 FPS. These plots are taken at the internal sampling rate of the PMU model at
960 samples per second and the sum signal can clearly be seen in Figure B.1:
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for Power System Protection and Control
0.4 0.5 0.6 0.7 0.8 0.9
0.0313
0.0313
0.0313
0.0313
0.0313
Time (seconds)
T
V
E
(
%
)
TVE vs Time
0 0.2 0.4 0.6 0.8
-4
-2
0
2
4
x 10
-4
Time (seconds)
M
a
g
n
i
t
u
d
e
e
r
r
o
r
Magnitude Error vs Time
0 0.2 0.4 0.6 0.8 1
-0.02
-0.01
0
0.01
0.02
Time (seconds)
P
h
a
s
e
e
r
r
o
r
(
d
e
g
r
e
e
s
)
Phase Error vs Time
Figure B.1—TVE, magnitude, and phase error for nominal input at 60 FPS reporting rate
B.3.1.1.1 TVE at bandwidth limits
TVE as the input frequency changes is dominated by the magnitude roll off of the PMU filter. This can be
observed by looking at plots of TVE, magnitude, and magnitude error as the frequency ramps from the low
bandwidth limit to the high bandwidth limit shown in Figure B.2 and Table B.1:
55 60 65
0
0.5
1
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
55 60 65
0.7
0.71
0.72
0.73
0.74
Delta Frequency from Nominal
M
a
g
n
i
u
d
e
Magnitude vs Frequency
55 60 65
-5
0
5
10
x 10
-3
Delta Frequency from Nominal
M
a
g
n
i
t
u
d
e
E
r
r
o
r
Magnitude Error vs Frequency
Figure B.2—TVE, magnitude, and magnitude error for F
s
= 60 FPS as frequency ramps
between the bandwidth limits (M class)
More on frequency ramping later.
Table B.1—TVE, FE, and RFE at the bandwidth limits (M class)
Reporting rate (F
s
)
upper frequency (Fu)
lower frequency (Fl)
Upper bandwidth frequency
(fu)
Lower bandwidth frequency (Ll)
F
s
= 120
Fu=65 Hz
Fl=55 Hz
Max TVE(%) = 1.0
Max FE = 3.7e-013
Max RFE = 1.2e-010
Max TVE(%) = 0.83
Max FE = 4.5e-013
Max RFE = 1.4e-010
F
s
= 60
Fu=65 Hz
Fl=55 Hz
Max TVE(%) = 0.92
Max FE = 1.7e-013
Max RFE = 9.1e-011
Max TVE(%) = 0.92
Max FE = 2.1e-013
Max RFE = 1.4e-010
F
s
= 30
Fu=65 Hz
Fl=55 Hz
Max TVE(%) = 0.995
Max FE = 1.4e-013
Max RFE = 1.3e-010
Max TVE(%) = 1.0207
Max FE = 1.3e-013
Max RFE = 1.16e-010
F
s
= 20
Fu=64 Hz
Fl=56 Hz
Max TVE(%) = 0.89
Max FE = 1.1e-013
Max RFE = 1.2e-010
Max TVE(%) = 0.88
Max FE = 1.1e-013
Max RFE = 1.4e-010
F
s
= 15
Fu=63 Hz
Fl=57 Hz
Max TVE(%) = 0.88
Max FE = 9.6e-014
Max RFE = 1.4e-010
Max TVE(%) = 0.89
Max FE = 1.2e-013
Max RFE = 1.4e-010
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Table B.1—TVE, FE, and RFE at the bandwidth limits (M class) (continued)
Reporting rate (F
s
)
upper frequency (Fu)
lower frequency (Fl)
Upper bandwidth frequency
(fu)
Lower bandwidth frequency (Ll)
F
s
= 12
Fu = 62.4 Hz
Fl = 57.6 Hz
Max TVE(%) = 0.89
Max FE = 1.2e-013
Max RFE = 1.7e-010
Max TVE(%) = 0.88
Max FE = 1.0e-013
Max RFE = 1.6e-010
F
s
= 10
Fu = 62 Hz
Fl = 58 Hz
Max TVE(%) = 0.85
Max FE = 1.1e-013
Max RFE = 1.4e-010
Max TVE(%) = 0.86
Max FE = 1.0e-013
Max RFE = 1.7e-010
B.3.1.2 P class signal frequency range
For steady-state input at the nominal frequency, the P class reference model filter has extremely good
attenuation of all harmonics. This means that the effect of the sum output of the complex multiplication is
insignificant and TVE for nominal signals is effectively 0.
The P class PMU model also uses magnitude compensation for off-nominal signals, which improves
performance; however the attenuation for off-nominal sum signal can be as little as 25 dB.
Figure B.3 shows plots of TVE, magnitude, and magnitude error for a frequency ramp from 5 Hz below to
5 Hz above the nominal frequency:
55 60 65
0
0.1
0.2
0.3
0.4
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
55 60 65
0.7
0.705
0.71
0.715
0.72
Delta Frequency from Nominal
M
a
g
n
i
u
d
e
Magnitude vs Frequency
55 60 65
-2
-1
0
1
2
x 10
-3
Delta Frequency from Nominal
M
a
g
n
i
t
u
d
e
E
r
r
o
r
Magnitude Error vs Frequency
Figure B.3—TVE, magnitude and magnitude error for P class
In the preceding figures, the effect of the sum signal at off-nominal frequencies is apparent. The effect of
the frequency compensation for magnitude is also apparent when compared to the M class magnitude plot.
See Table B.2.
Table B.2—TVE, FE, and RFE at the bandwidth limits (P class)
Reporting rate (F
s
)
upper frequency (Fu)
lower frequency (Fl)
Upper bandwidth
frequency (Fu)
Lower bandwidth frequency (Ll)
F
s
= 60
Fu = 62 Hz
Fl = 58 Hz
%TVE =0.03
FE =2.0e-013
RFE = 1.3e-010
%TVE = 0.032
FE = 3.5e-013
RFE = 7.5e-011
Note that the P class reference model filter is the same at all reporting rates so the performance will be the
same for all reporting rates.
B.3.2 Steady-state signal magnitude range
The PMU reference model performs the same under any steady-state signal magnitude. The results of this
test for the limits of the magnitude range are trivial and are not shown here. The results will not be trivial
for real-world PMUs.
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IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
a
7th
F
s
=
Any
%TVE =
1.8e-012
FE = 1.1e-013
RFE| =
3.1e-011
%TVE =
1.8e-012
FE = 1.0e-013
RFE =
2.6e-011
%TVE =
1.5e-012
FE = 8e-014
RFE =
2.1e-011
%TVE =
2.2e-012
FE = 1.5e-013
RFE =
3.9e-011
%TVE =
2.7e-012
FE = 2.4e-013
RFE =
4.2e-011
%TVE =
2.1e-012
FE = 1.2e-013
RFE = 4.0e-011
a
Harmonic numbers with multiples of 3 are zero sequence and have no effect on the Frequency and ROCOF measurements.
B.3.5 Steady-state worst-case out-of-band interfering signal
For each PMU reporting Rate F
s
, the passband is defined as |f – f
0
|≤ F
s
/2
where f is the frequency of an interfering signal and f
0
is the nominal frequency (50 Hz or 60 Hz).
IEEE Std C37.118.1-2011 5.5.5 Table 3 and Table 4 specify limits for TVE, FE, and RFE in the presence
of out-of-band interfering signals where |f – f
0
|≥ F
s
/2. There are no specified limits for P class, only for M
class.
For the test, the input test frequency is varied between f
0
and 10% of the Nyquist frequency of the reporting
rate. The worst-case performance happens when the input frequency is furthest away from nominal
(f
0
± 10% of Nyquist)
IEEE Std C37.118.1-2011 Annex C PMU reference model has a passband of ± F
s
/5 on either side of
nominal frequency. The worst-case interference is when the interfering signal is near the band limit
frequency. Performance improves rapidly as the frequency of interfering signal gets further from the
nominal frequency.
For the model, the off-nominal input test frequency contributes to TVE due to the magnitude error of the
filter response. The worst case is when the input frequency is at f
0
± 10% of Nyquist.
Example
For IEEE Std C37.118.1-2011 Annex C model with nominal frequency f
0
= 60 Hz and F
s
reporting rate
30 FPS, Table B.5 shows TVE, FE, and RFE for input and interfering frequencies on either side of nominal
under worst-case conditions.
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for Power System Protection and Control
Table B.5—Worst-case effect of out-of-band interfering signals for F
s
= 60 and 10 FPS
F
s
F
in
29 Hz 29.5 Hz 30 Hz 90 Hz 90.5 Hz 91 Hz
TVE (%) 0.99727 1.1041 1.1497 1.1515 1.1024 0.98901
FE (Hz) 1.99E-13 2.27E-13 2.34E-13 2.20E-13 2.34E-13 2.20E-13 63.0 Hz
RFE (Hz/s) 1.24E-10 8.48E-11 7.16E-11 8.44E-11 9.12E-11 1.04E-10
TVE (%) 0.95245 1.0698 1.1907 1.1925 1.0688 0.95627
FE (Hz) 2.20E-13 2.27E-13 2.27E-13 2.42E-13 2.27E-13 2.27E-13
60 FPS
57.0 Hz
RFE (Hz/s) 5.88E-11 9.76E-11 9.08E-11 8.48E-11 1.04E-10 9.81E-11
54 Hz 54.5 Hz 55 Hz 65 Hz 65.5 Hz 66 Hz
TVE (%) 0.13599 0.29562 0.99495 0.99515 0.3094 0.13072
FE (Hz) 4.97E-14 7.82E-14 4.974E-14 6.39E-14 8.53E-14 6.39E-14 60.5
RFE (Hz/s) 9.12E-11 7.17E-11 8.473E-11 1.24E-10 7.17E-11 9.44E-11
TVE (%) 0.13516 0.30457 1.0008 1.001 0.29098 0.13338
FE (Hz) 4.97E-14 7.11E-14 5.68E-01 3.55E-14 5.68E-14 5.68E-14
10 FPS
59.5
RFE (Hz/s) 7.81E-11 1.11E-10 1.43E-10 5.21E-11 1.24E-10 7.33E-11
Note that the effect of out-of-band interfering signals on FE and RFE are negligible. The errors shown here
are primarily due to floating point errors in the simulation.
B.4 Response to dynamic input signal tests
B.4.1 Dynamic measurement bandwidth tests response
To understand how the PMU reference model responds to modulated input, it is helpful to look at the
response to phase modulation (PM) and amplitude modulation (AM) separately.
Plots of PMU response with respect to input signal frequency can be quite informative, especially when
troubleshooting. Figure B.4 shows plots for measured phase at reporting rate of 60 FPS versus both time
and frequency for a ω
a
= ω
x
= 1 Hz phase modulation at K
a
= K
x
= 0.1 Hz modulation index:
0 0.5 1 1.5 2
-10
-5
0
5
10
Time (seconds)
M
e
a
s
u
r
e
d
P
h
a
s
e
(
d
e
g
r
e
e
s
)
Phase vs Time
-0.1 -0.05 0 0.05 0.1
-10
-5
0
5
10
Delta Frequency from Nominal
M
e
a
s
u
r
e
d
P
h
a
s
e
(
d
e
g
r
e
e
s
)
Phase vs Frequency
Figure B.4—Phase versus time and frequency for 1 Hz modulation at 0.1 index
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for Power System Protection and Control
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for Power System Protection and Control
(
%
)
TVE vs Time
-0.4 -0.2 0 0.2 0.4
0
0.01
0.02
0.03
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
Figure B.5—TVE versus time and frequency for F
s
= 60, 3 Hz phase modulation
at 0.1 index
The plots in Figure B.6 were made at 6Hz modulation frequency, 0.1; the maximum TVE is about 0.15%
and the minimum TVE is about 0.05. Notice that the TVE samples are symmetrical on either side of 0 delta
frequency. This is an effect of the relation between the modulation frequency and the sample rate.
0 0.2 0.4 0.6 0.8 1
0.05
0.1
0.15
0.2
0.25
Time (seconds)
T
V
E
(
%
)
TVE vs Time
-1 -0.5 0 0.5 1
0.05
0.1
0.15
0.2
0.25
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
Figure B.6—TVE versus time and frequency for F
s
=60, 6Hz phase modulation at 0.1 index
An interesting and important effect occurs then the TVE samples are not symmetrical about 0 delta
frequency, as shown in the plots of 8 Hz modulation frequency in Figure B.7:
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for Power System Protection and Control
-1 -0.5 0 0.5 1
0
0.1
0.2
0.3
0.4
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
Figure B.7—TVE versus time and frequency for F
s
= 60, 8 Hz phase modulation
at 0.1 index
Notice on the plot of TVE versus time the lines between the TVE sample points. This effect could be a
problem an insufficient number of samples is taken. The maximum TVE may not be found, as illustrated by
the following set of plots taken at 9.8 Hz modulation frequency.
In the plots in Figure B.8, it is clear that an insufficient number of samples were taken to determine the
maximum TVE. The pair of plots took a sufficient number of samples.
0 0.1 0.2 0.3 0.4 0.5
0
0.2
0.4
0.6
0.8
Time (seconds)
T
V
E
(
%
)
TVE vs Time
-1 -0.5 0 0.5 1
0
0.2
0.4
0.6
0.8
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
0 0.5 1 1.5 2
0
0.2
0.4
0.6
0.8
Time (seconds)
T
V
E
(
%
)
TVE vs Time
-1 -0.5 0 0.5 1
0
0.2
0.4
0.6
0.8
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
Figure B.8—TVE versus time and frequency for F
s
= 60, 9.8 Hz phase modulation at
0.1 index
Finally, the plots in Figure B.9 show what happens at the upper limit of the measurement bandwidth test.
The upper set of plots was taken at modulation frequency of 12 Hz (still at 60 FPS reporting rate) and the
lower set taken at modulation frequency of 11.9 Hz. Both show the maximum TVE at about 1.15%.
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for Power System Protection and Control
-2 -1 0 1 2
0
0.5
1
1.5
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
0 0.5 1 1.5 2
0
0.5
1
1.5
Time (seconds)
T
V
E
(
%
)
TVE vs Time
-2 -1 0 1 2
0
0.5
1
1.5
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
Figure B.9—TVE versus time and frequency for 12 Hz and 11.8 Hz modulation at 0.1 index
B.4.1.1.1 Combined amplitude and phase modulation
An interesting thing happens to TVE when phase and amplitude modulation is combined (see Figure B.10).
0 0.2 0.4 0.6 0.8 1
0
0.1
0.2
0.3
0.4
Time (seconds)
T
V
E
(
%
)
TVE vs Time
59 59.5 60 60.5 61
0
0.1
0.2
0.3
0.4
Delta Frequency from Nominal
T
V
E
(
%
)
TVE vs Frequency
Figure B.10—TVE versus time and frequency for AM and PM at 6 Hz, 0.1 index
TVE as frequency is increasing is lower than TVE as frequency is decreasing. The maximum TVE is where
the frequency crosses zero, which is also the maximum ROCOF because this is where the phase error is at
its maximum. The main contributor to TVE at the frequency endpoints (where the ROCOF is 0) is
magnitude error due to the filter roll-off described in B.3.1.
The reason that the TVE versus frequency is different for increasing and decreasing frequency is because
the amplitude modulation is 180 degrees out of phase with the frequency modulation. When the frequency
is increasing, the amplitude is decreasing, and its contribution to TVE is reduced compared to when the
frequency is decreasing and the amplitude is increasing.
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for Power System Protection and Control
59.8 59.9 60 60.1 60.2
-2
-1
0
1
2
x 10
-3
Frequency
F
r
e
q
u
e
n
c
y
E
r
r
o
r
Frequency Error vs Frequency
Figure B.11—Frequency error versus time and frequency for 1 Hz phase modulation at
0.1 index
The frequency error is greatest when the delta frequency is crossing zero. This is because the rate of change
of frequency is at its greatest at this point, and the effect of the very small difference between the phasor
time stamp and the actual time of the frequency measurement has its greatest effect. The sign of the
frequency error changes and is positive while the frequency is increasing and negative when it is
decreasing. See Figure B.12.
0 0.5 1 1.5 2
-2
-1
0
1
2
x 10
-3
Time (seconds)
R
O
C
O
F
e
r
r
o
r
ROCOF Error vs Time
59.8 59.9 60 60.1 60.2
-2
-1
0
1
2
x 10
-3
Frequency
R
O
C
O
F
E
r
r
o
r
ROCOF Error vs Frequency
Figure B.12—FE versus time and frequency for 1 Hz phase modulation at 0.1 index
RFE is greatest where the delta frequencies are greatest and least where the delta frequency crosses zero.
The reason for this is that ROCOF itself is zero when the modulation signal is at its positive and negative
peaks and maximum where the modulation signal is crossing zero.
As the phase modulation frequency increases, so does the error due to the effect of the small time offset
from the phasor estimate (see Figure B.13):
An improvement can be made to the frequency and ROCOF estimation by centering the estimate over the
time stamp. This is made at the cost of one or two internal PMU sample periods of additional latency.
Figure B.14 shows plots at the same modulation as above using a three sample estimate of frequency
centered on the phasor being reported at the time of the time stamp. Maximum FE is improved from 0.069
Hz to 0.024 Hz and RFE is improved from 3.08 Hz/s to 1.37 Hz/s.
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for Power System Protection and Control
59 59.5 60 60.5 61
-0.1
-0.05
0
0.05
0.1
Frequency
F
r
e
q
u
e
n
c
y
E
r
r
o
r
Frequency Error vs Frequency
0 0.5 1 1.5 2
-4
-2
0
2
4
Time (seconds)
R
O
C
O
F
e
r
r
o
r
ROCOF Error vs Time
59 59.5 60 60.5 61
-4
-2
0
2
4
Frequency
R
O
C
O
F
E
r
r
o
r
ROCOF Error vs Frequency
Figure B.13—FE and RFE versus time and frequency for 6 Hz phase modulation
at 0.1 index
0 0.5 1 1.5 2
-0.01
-0.005
0
0.005
0.01
Time (seconds)
F
r
e
q
u
e
n
c
y
e
r
r
o
r
Frequency Error vs Time
59 59.5 60 60.5 61
-0.01
-0.005
0
0.005
0.01
Frequency
F
r
e
q
u
e
n
c
y
E
r
r
o
r
Frequency Error vs Frequency
0 0.5 1 1.5 2
-1
-0.5
0
0.5
1
Time (seconds)
R
O
C
O
F
e
r
r
o
r
ROCOF Error vs Time
59 59.5 60 60.5 61
-1
-0.5
0
0.5
1
Frequency
R
O
C
O
F
E
r
r
o
r
ROCOF Error vs Frequency
Figure B.14—Similar plots using a three sample estimate of frequency centered on the
phasor being reported at the time of the time stamp
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for Power System Protection and Control
Table B.7—Response to combined amplitude and phase modulated input, 10% index
M class P class
F
s
= 120 Hz
Fmod = 24 Hz
%TVE = 0.83
FE = 0.28
RFE = 26.5
Fmod = 12 Hz
%TVE = 1.79
FE = 0.33
RFE = 29.4
F
s
= 60 Hz
Fmod = 12 Hz
%TVE = 1.60
FE = 0.29
RFE = 26.3
Fmod = 6 Hz
%TVE = 0.47
FE = 0.078
RFE = 3.6
F
s
= 30 Hz
Fmod = 6 Hz
%TVE = 0.56
FE = 0.077
RFE = 3.9
Fmod = 3 Hz
%TVE = 0.12
FE = 0.019
RFE = 0.43
F
s
= 20 Hz
Fmod = 4 Hz
%TVE = 0.35
FE = 0.047
RFE = 2.04
Fmod = 2 Hz
%TVE = 0.06
FE = 0.008
RFE = 0.13
F
s
= 15 Hz
Fmod = 3 Hz
%TVE = 0.34
FE = 0.030
RFE = 0.75
Fmod = 1.5 Hz
%TVE = 0.03
FE = 0.005
RFE = 0.05
F
s
= 12 Hz
Fmod = 2.4 Hz
%TVE = 0.34
FE = 0.021
RFE = 0.44
Fmod = 1.2 Hz
%TVE = 0.02
FE = 0.003
RFE = 0.03
F
s
= 10 Hz
Fmod = 2
%TVE = 0.34
FE = 0.017
RFE = 0.29
Fmod = 1 Hz
%TVE = 0.01
FE = 0.002
RFE = 0.02
B.4.1.3 Response to amplitude modulation only
Though IEEE Std C37.118.1-2011 does not specify AM only testing, the graphs of the PMU response
should be useful to the practitioner.
Note that there are no plots versus frequency. That is because there is no frequency shift to AM only.
It is interesting to note that the maximum modulation frequency may expose the worst-case TVE.
Figure B.15 shows a plot of TVE at F
s
= 60 FPS with a 12 Hz modulation frequency:
0 0.2 0.4 0.6 0.8 1
0
0.5
1
1.5
Time (seconds)
T
V
E
(
%
)
TVE vs Time
Figure B.15—TVE for AM at 12 Hz, index 0.1 at F
s
= 60 FPS
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for Power System Protection and Control
Figure B.16—TVE for AM at 11.9 Hz, 0.1 index at F
s
= 60 FPS
The second plot shows once again why it is important to make sure enough samples are gathered to help
ensure that maximum TVE is reached.
B.4.2 Dynamic response to linear frequency ramp test signals
B.4.2.1 M class TVE response to frequency ramps
In B.3, a plot from a frequency ramp was used to illustrate the impact of magnitude roll off of the M class
reference model’s filter on TVE. For reporting rates of F
s
below 30 FPS, the TVE is above 1% until the
input frequency reaches reporting rate divided by 5 (F
s
/5). This is the basis for the M class limits of
IEEE Std C37.118.1-2011. See Figure B.17.
55 60 65
0
0.5
1
Frequency
T
V
E
(
%
)
TVE vs Frequency
Figure B.17—TVE versus time and frequency for 1Hz frequency ramp from
–5hz to +5hz at F
s
= 30 FPS
The primary contributor to the M class TVE is the magnitude roll off of the M class reference model’s
filter, which is not required to be frequency compensated. Figure B.18 shows graphs of magnitude and
Figure B.19 shows phase error over the ramp:
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55 60 65
-5
0
5
10
x 10
-3
Frequency
M
a
g
n
i
t
u
d
e
E
r
r
o
r
Magnitude Error vs Frequency
Figure B.18—Magnitude error versus time and frequency for 1 Hz frequency ramp from
–5Hz to +5Hz at F
s
= 30 FPS
0 2 4 6 8 10
-0.1
-0.05
0
0.05
0.1
Time (seconds)
P
h
a
s
e
e
r
r
o
r
(
d
e
g
r
e
e
s
)
Phase Error vs Time
55 60 65
-0.1
-0.05
0
0.05
0.1
Frequency
P
h
a
s
e
E
r
r
o
r
(
d
e
g
r
e
e
s
)
Phase Error vs Frequency
Figure B.19—Phase error versus time and frequency for 1 Hz frequency ramp from
–5Hz to +5Hz at F
s
= 30 FPS
B.4.2.2 M class frequency and RFE response to frequency ramps
The primary contributor to PMU reference model frequency and ROCOF error under ramp test is the small
offset of the frequency measurement from the time stamp. See Figure B.20 and Figure B.21.
Figure B.20—Frequency error versus time and frequency
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Figure B.21—ROCOF error versus time and frequency
The ROCOF error for frequency ramp tests is very low.
B.4.2.3 P class TVE response to frequency ramps
The P class reference PMU model requires magnitude compensation for the frequency roll off of the filter.
Since magnitude roll off is the main contributor to TVE in the M class model, the P class model responds to
frequency ramps with lower TVE (see Figure B.22):
0 2 4 6 8 10
0
0.05
0.1
0.15
0.2
Time (seconds)
T
V
E
(
%
)
TVE vs Time
55 60 65
0
0.05
0.1
0.15
0.2
Frequency
T
V
E
(
%
)
TVE vs Frequency
Figure B.22—TVE versus time and frequency for P class frequency ramp
Despite the improved TVE performance of the P class PMU, the bandwidth (BW) is limited to ±2Hz for the
ramp test. This gives even better TVE. See Table B.8.
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Table B.8—Response to frequency ramp rate = 1 Hz/s, ramp range = ±BW
M class
P class same for all F
s
BW = ±2 Hz
F
s
= 120 Hz
BW = 5 Hz
%TVE = 1.02
FE = 0.003
RFE = 3e-008
%TVE = 0.04
FE = 0.003
RFE = 6e-008
F
s
= 60 Hz
BW = 5 Hz
%TVE = 0.92
FE = 0.003
RFE = 1.6e-006
—
F
s
= 30 Hz
BW = 5 Hz
%TVE = 0.97
FE = 0.003
RFE = 3.4e-005
—
F
s
= 20 Hz
BW = 4 Hz
%TVE = 0.93
FE = 0.004
RFE = 0.0003
—
F
s
= 15 Hz
BW = 3 Hz
%TVE = 1.05
FE = 0.004
RFE = 0.0008
—
F
s
= 12 Hz
BW = 2.4 Hz
%TVE = 0.96
FE = 0.005
RFE = 0.0021
—
F
s
= 10 Hz
BW = 2 Hz
%TVE = 1.13
FE = 0.007
RFE = 0.0042
—
B.4.3 Dynamic response to step changes in amplitude
When a step change in input occurs, the Annex C PMU model output amplitude is a finite impulse step
response centered around the 50% point of the step because the Annex C model uses a symmetrical FIR
filter centered around the time of each report.
IEEE Std C37.118.1-2011 limits the response time, which is the difference in time that the TVE leaves the
specified accuracy limit until it returns to and remains within the specified limit. In Figure B.23, the
response time is shown. Recall that the response time is the time that the TVE exceeds 1%. Figure B.24
shows the TVE during the step change in amplitude.
A minor difference may exist between the time reported for the instant a step change is applied and the
actual time, shown in Figure B.23 and Figure B.24 as a delay-time compensation error. The measurement
delay time compensation error can be very small.
IEEE Std C37.118.1-2011 also limits the maximum overshoot, which is a maximum percentage of the step
magnitude that the signal can reach before it settles to the final value. Figure B.23 shows this overshoot and
undershoot.
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Figure B.23—Measurement response to a 10% step change in magnitude
Figure B.24—TVE for a 10% step change in amplitude
B.4.4 Dynamic response to step changes in phase
When a step change in the input occurs, the Annex C PMU model output phase is a finite impulse step
response centered around the 50% point of the step. It makes no difference if the step change was
amplitude or phase because the Annex C model uses a symmetrical FIR filter centered around the time of
each report. Figure B.25 shows the response to a 90º step change in phase at time t = 0.
IEEE Std C37.118.1-2011 limits the response time, which is the difference in time that the TVE leaves the
specified accuracy limit until it returns to and remains within the specified limit. In Figure B.26, the
response time is the time elapsed between the vertical lines shown about one eighth of a second before and
one eighth of a second after the step change in phase. These are the times that the TVE exceeds the
specified limit of error in response to the step change in phase.
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Figure B.25—Measurement response to a 90° step change in phase—example
Figure B.26—TVE for a 90° step change in phase
It is worth pointing out that the error is not calculated in quite the conventional way, by taking the
difference between the measurement and the “true value” and finding a ratio. Because of the way TVE is
defined, the errors are Vee-shaped functions, such as shown in Figure 7 in 7.5.1.1 of this guide.
It is observed in 7.5.1.1 that the TVE is dominated by phase errors for phase errors greater than 0.5 degrees.
In fact, if the amplitude error is zero, the TVE due to phase error can be expressed as shown in
Equation (B.1):
TVE = 1.75 ε (B.1)
where ε is the phase error in degrees and the TVE is in percent.
In the case of a 90º phase shift, the error will be 45º at the center of the response, so the TVE will be nearly
79%, as shown in Figure B.26.
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Effects of signal channels
C.1 Introduction
Even though a PMU is required by IEEE Std C37.118.1-2011 to have errors less than 1% (TVE), the
overall error in a synchrophasor measurement system may be larger due to other sources. In particular, the
errors in instrument transformers and the associated cabling may be significant. This annex examines such
sources of error.
From the measurement point of view, two observations must be made. First, such sources of error are what
is termed Type B uncertainty by metrologists. That means that no amount of repeated measurement and
data processing will reduce their effect. A value that is wrong because (for example) of a scaling error is
always wrong, no matter how many times the measurement is made.
Second, the source of error is external to the PMU hardware. A PMU that meets all the requirements of the
PMU standard (IEEE Std C37.118.1-2011) in terms of its accuracy can still furnish synchrophasor readings
that (for example) do not agree with readings from another PMU in a nearby part of the power system, even
if both are compliant with the same standard. The differences are not the result of PMU problems. They are
system differences, caused by the differences of the instrument transformers, the cabling, and the
transformer burdens.
Established standards set classes for instrument transformers based on application-dependent limits in the
phase and magnitude errors. These standards were developed when there were, for all practical purposes,
two applications for the instrumentation transformer: metering and protection. For metering, with the
implication of energy billing, it was crucial to establish performance specifications that gave very accurate
results provided the quantities being measured were close to “nominal.” The frequency could be expected
to be very close to the nominal value of power frequency, for example, and no significant attention had to
be paid to the frequency response of the device. Typically, accurate performance within 1% or 2% of the
rated power frequency was required. For a protection application, on the other hand, conditions were
expected to be at times far from nominal. A CT was expected to furnish good current values even if there
was a very large overcurrent, for example, 20 times greater than the rated current. In this situation, the
stringent accuracy requirements of metering were relaxed.
It may be worthwhile to note that the 2011 revision to IEEE Std C37.118.1-2011 (as compared to its
predecessor IEEE Std C37.118-2005) effectively acknowledges different requirements for protection and
metering applications and sets different dynamic performance requirements for the “P class” and “M class”
synchrophasor data.
PMUs are expected to furnish good results in a wide variety of circumstances, and yet at the time this is
written (2012) no particular PMU-application standards have been written to specify the performance of the
instrument transformers that they are connected to. It is common when a PMU is installed to use existing
voltage and CTs. Often little consideration is given to the suitability of the transformer characteristics or to
the cabling system that connects it to the PMU because there are few cost-effective options.
Testing performed on instrument transformers prior to installation determines accurately the phase and
magnitude errors of an individual device or of a type under certain conditions. In principle, such errors, if
known, and if constant as a function of time and environmental conditions, could be stored in the PMU and
used to correct the readings if necessary. It is important to keep in mind that some of these corrections may
be suitable in only a limited or narrow range of conditions.
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Table C.2—Maximum magnitude and phase error for ANSI class VTs (IEEE Std C57.13)
ANSI VT type Max. magnitude error
(%)
Max. phase error
(degrees)
Relaying 10 Not specified
Metering 1.2 1.2 2.08
Metering 0.6 0.6 1.04
Metering 0.3 0.3 0.52
Table C.3—Maximum magnitude and phase errors of IEC class CTs (IEC 60044-x series)
IEC CT type Load
Max. magnitude error
(%)
Max. phase error
(degrees)
100% 3 Not specified
Relay type 10P
Max. limit 10 (composite error) Not specified
100% 1 1
Relay type 5P
Max. limit 5 (composite error) Not specified
5% 3.0 3.0
20% 1.5 1.5
100% 1.0 1.0
Metering type
1.0 accuracy
120% 1.0 1.0
5% 1.5 1.5
20% 0.75 0.75
100% 0.5 0.5
Metering type
0.5 accuracy
120% 0.5 0.5
5% 0.75 0.5
20% 0.35 0.25
100% 0.2 0.167
Metering type
0.2 accuracy
120% 0.2 0.167
5% 0.4 0.250
20% 0.2 0.133
100% 0.1 0.083
Metering type
0.1 accuracy
120% 0.1 0.083
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Figure C.1—Simplified equivalent circuit of VT and CT feeding PMU
The instrument transformers shown in Figure C.1 will typically have significant inter-winding capacitances
and capacitances to ground; these are not shown in the figure. Such features complicate the response
further.
Figure C.2 shows the frequency response (amplitude and phase) of a commercial wound-type VT as
measured and reported in Meliopoulos et al. [B50].
21
See for example Meliopoulos et al. [B50].
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Figure C.2—Magnitude and phase error of a VT
(adapted from Meliopoulos et al. [B50])
The resonance exhibited by the particular device whose response is shown here is thought to be broadly
representative. At and near power frequency, the transformer is within the limits established by standards.
The magnitude error and phase error are both negligible (i.e., within the allowed errors specified on the VT
nameplate) at power frequency (as expected for VTs that are built and installed properly). Nor, according to
these authors, are the errors significantly affected by the transformer burden, provided that the burden is
within a reasonable range (as specified on the VT nameplate).
The pronounced resonance peak in the response above 1 kHz should be noted. Nevertheless, for most PMU
applications, the filtering in the PMU should reduce the effect of this resonance to insignificance.
The other common kind of VTs, coupling capacitor voltage transformers (CCVTs), are dismissed in
Meliopoulos et al. [B50] as not being useful over the frequency range of interest (for harmonics
measurement). Some interesting field measurements have been made on CCVTs, nevertheless, see for
example Fernandez et al. [B15]. An example is shown in Figure C.3.
Readers who are familiar with the behavior of the sort of tuned coupled inductors used in the IF
transformers of radios may recognize a familiar shape. It certainly seems that the circuit parameters have
been adjusted so that the amplitude and phase response are flat across the region of power frequency
(60 Hz in this example). However, the rest of the response is likely to give significant difference, even at
just the second harmonic.
It may be pointed out that CTs do not, in general, have such pronounced peaks in their response. A device
tested in Meliopoulos et al. [B50], for example, had only 0.17 degree error across the frequency range
tested.
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Figure C.3—Magnitude and phase error of CCVT versus frequency
(adapted from Fernandez et al. [B15])
C.4 Conclusions
While PMUs are required to meet the requirements on TVE as per IEEE Std C37.118.1-2011, there is no
such requirement on a complete synchrophasor measurement system as installed. Significant errors can
arise, particularly in systems with capacitive voltage transformers (CVTs), that can be very difficult to
determine without field calibration or verification. It is important to keep in mind that if differences are
observed between the results of measurements from PMUs that are expected to give similar results, the
cause might be in the instrumentation channels, including instrument transformers, the cabling or the
burden.
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Examples of instrumentation channel impact on accuracy using
approximate models
D.1 General
This annex provides a few examples of instrumentation channels. In selecting the instrumentation channels,
the following voltage measurement technologies have been considered:
⎯ Wound-type potential transformers (PTs)
⎯ Capacitive coupled voltage transformers (CCVTs)
⎯ Capacitive voltage dividers (CVDs)
⎯ Resistive voltage dividers (RVDs)
Generally voltage dividers provide accurate wide bandwidth measurements with flat frequency response;
however, these technologies are usually limited to laboratory grade instrumentation. In high-voltage power
system applications (outdoor relaying and metering units), PTs and CCVTs are commonly used,
accordingly examples below include PTs and CCVTs only.
Current transformers (CTs) are typically wire-wound ferromagnetic core type transformers with current
output. The ratings depend on the maximum permissible current that can be developed on the secondary
before saturation occurs. For PMU type applications, saturation is generally not a concern as the current
through the CT is typically much lower than the capability of the CT.
In the following examples, some basic models for instrumentation channels have been defined. The
parameters of these instrumentation channel models have been selected to represent near practical systems.
They have been constructed by considering combinations of the following important instrumentation
channel parameters: CT types, VT types, CCVT types, instrumentation cables (type, shielded/unshielded,
length). Instrumentation channels based on optical CTs and VTs have not been considered in this annex.
The instrumentation channel examples listed in Table D.1 are based on data provided from measurements
in the field and laboratory settings. Using these sample instrumentation channels, the variability and
amount of errors potentially introduced are evaluated and tabulated here. Please note that the examples
modeled here are a very small subset of what may actually be installed in the field. Also, the models may
not be detailed or accurate enough to represent actual instrumentation channels in some cases.
Nevertheless, the results provided in the tables in this annex are simply meant to provide an appreciation
for the approximate impact of various parameters on measurement variability.
It is also important to note that the resolution of the numbers provided in the tables in this annex may be
significantly finer than the accuracy of the models and the resultant numbers. Nevertheless, this higher
resolution shows the level of variability and dependency (albeit sometimes very small) as certain system
parameters change.
D.2 Description of typical instrumentation channels
In this annex, samples of instrumentation channel models are provided, taking into account the possible
effects of the following parameters:
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In addition, the phase error is defined as the phase angle difference between the reading at the
primary side of the PT and voltage reading seen by the PMU.
⎯ CT instrumentation channels: The current magnitude error is defined as the percentage difference
between the primary current of the CT and current seen by the relay or PMU scaled by a nominal
factor k, as shown in Equation (D.2):
% 100 %
,
×
⋅ −
=
primary
relay primary
magnitude I
I
I k I
Error
(D.2)
In addition, the phase error is defined as the phase angle difference between the current reading at
the primary side of the CT and current reading seen by the PMU.
D.3 Potential transformer instrumentation channel error
A PT instrumentation channel example has been analyzed using a model, and the estimated errors have
been tabulated. These results provide an approximate quantitative measure of the impact of various
elements of the PT instrumentation channel on the quality and accuracy of the synchrophasor data reported
by the PMU.
The PT instrumentation channel model is shown in Figure D.1. The model includes the effect of parasitic
capacitances and instrumentation cable. The PMU burden is also accounted for in the model by a large
resistance (typically on the order of few thousand ohms).
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Figure D.1—Sample PT instrumentation channel model parameters
The simulation is performed for different values of the model parameters. The errors are quantified in terms
of magnitude and phase errors.
D.3.1 Example, a 199kV/69V PT
The base case model parameters for this example are shown in Table D.1. The calculated error results are
presented in Table D.2, Table D.3, Table D.4, and Table D.5. The parameters not shown in the results
tables can be assumed to be the same as the base case values.
Table D.1—Base-case parameters for 199 kV/69 V PT instrumentation
channel model simulation
Parameter description Value
Nominal ratio 199 kV/69V
PT VA rating 30 kVA
PT resistance 0.01 pu
PT leakage reactance X
ℓ
0.025 pu
PT nominal core loss 0.005 pu
PT nominal magnetization current 0.005 pu
PT parasitic capacitance C
p
50 nF
Instrumentation cable type #10 copper pair
Instrumentation cable length ℓ 60 m (200 ft)
PMU burden resistance R
B
10 kΩ
Table D.2—199 kV/69 V PT instrumentation channel voltage magnitude error
in % for different burden resistances and cable lengths
Instrumentation cable length ℓ
Burden resistance R
B
(Ω)
30 m (100 ft) 60 m (200 ft) 150 m (500 ft) 240 m (800 ft)
5 k 0.009 0.016 0.22 0.52
10 k 0.009 0.015 0.19 0.48
20 k 0.009 0.014 0.18 0.41
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For this high-voltage PT, Table D.2 and Table D.3 show that the impact of burden resistance combined
with cable length can be significant, especially for longer cable lengths. We can see estimated voltage
magnitude errors close to 0.5% TVE for longer cable runs (240 m or longer is a typical cable run in many
230 kV and higher voltage substations). Phase angle errors are also significant and can exceed 0.57° (1%
TVE) for longer cable runs.
Table D.4—199 kV/69 V PT instrumentation channel voltage magnitude error
in % for different parasitic capacitances and cable lengths
Instrumentation cable length ℓ (ft)
Parasitic capacitance C
p
(nF)
30 m (100 ft) 60 m (200 ft) 150 m (500 ft) 240 m (800 ft)
25 0.008 0.012 0.17 0.41
50 0.009 0.015 0.19 0.48
75 0.015 0.026 0.22 0.61
Table D.5—199 kV/69 V PT instrumentation channel voltage phase error in degrees for
different parasitic capacitances and cable lengths
Instrumentation cable length ℓ (ft)
Parasitic capacitance C
p
(nF)
30 m (100 ft) 60 m (200 ft) 150 m (500 ft) 240 m (800 ft)
25 0.090 0.185 0.382 0.538
50 0.115 0.198 0.411 0.614
75 0.196 0.235 0.479 0.779
Similarly, Table D.4 and Table D.5 show that the impact of parasitic capacitances combined with cable
length can be significant, especially for longer cable lengths. We can see estimated voltage magnitude
errors close to 0.6% TVE for longer cable runs. The estimated phase angle errors at longer cable length are
on the order of 1% TVE (0.6°), noticeably higher than voltage magnitude errors.
D.4 Current transformer instrumentation channel error
In this subclause, a CT instrumentation channel example has been analyzed using a model, and the
estimated errors have been tabulated below. These results provide an approximate quantitative measure of
the impact of various elements of the CT instrumentation channel on the quality and accuracy of the
synchrophasor data reported by the PMU.
The CT instrumentation channel model is shown in Figure D.2. The model includes the parasitic
capacitances and instrumentation cable. The PMU burden is also accounted for in the model (usually
0.1 Ω or 0.14 Ω).
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure D.2—Sample CT instrumentation channel model parameters
The simulation is performed for different values of the model parameters. The error is quantified in terms
of magnitude and phase error.
D.4.1 Example, a 3000/5 A/A CT
The base case model parameters shown in Table D.6 represent the model used here for a 3000/5A/A (600:1
ratio) CT. The value of the current magnitude error is calculated using this model to be less than 0.07%,
effectively independent of the cable length, the burden resistance, and the parasitic capacitance values. The
calculated phase error results are shown in Table D.7 and Table D.8; burden resistance and parasitic
capacitance (in a reasonable range) have negligible impact on phase errors. Longer cable lengths appear to
be the only significant factor affecting the estimated synchrophasor phase errors, amounting to 0.2° to 0.3°
(close to 0.5% TVE) for a 240 m cable length.
Table D.6—Base-case parameters for 3000/5 A/A CT instrumentation channel
model simulation
Parameter description Value
Nominal ratio 3000/5 A
CT VA rating 500 VA
CT resistance 0.001 pu
CT leakage reactance X
ℓ
0.003 pu
CT nominal core loss 0.004 pu
CT nominal magnetization current 0.005 pu
CT parasitic capacitance C
p
5 nF
Instrumentation cable type #10 pair
Instrumentation cable length ℓ
60 m (200 ft)
PMU burden resistance R
B
0.1 Ω
Table D.7—3000/5 A/A CT instrumentation channel current phase error in degrees for
different burden resistances and cable lengths
Instrumentation cable length ℓ (ft)
Burden resistance R
B
(Ω) 30 m
(100 ft)
60 m
(200 ft)
150 m
(500 ft)
240 m
(800 ft)
0.1 0.03
o
0.04
o
0.09
o
0.23
o
0.14 0.03
o
0.04
o
0.09
o
0.23
o
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
D.5 CCVT instrumentation channel error
A sample CCVT instrumentation channel has been analyzed using a model and the estimated errors have
been tabulated. The results provide an approximate quantitative measure of the impact of various elements
of the CCVT instrumentation channel on the quality and accuracy of the synchrophasor data reported by
the PMU.
The basic CCVT configuration is illustrated in Figure D.3. The capacitive divider is formed by capacitors
C1 and C2. In typical high-voltage CCVTs (115 kV to 500 kV), the capacitor values are selected so that the
voltage at the tap point A is in the order of 4 kV to 10 kV. The transformer scales this voltage to standard
instrumentation voltage level (e.g., 69 V or 120 V). The output of the transformer is connected to a burden
via instrumentation cable (usually a multi-conductor cable, sometimes with an overall shield). The burden
represents the PMU or relay input impedance, which is typically resistive. Since the interaction of the
capacitive divider and the resistive burden introduces considerable phase shift, a series inductor L is added
to compensate for the divider output capacitance. A CCVT equivalent model is shown in Figure D.4. The
CCVT model parameters are summarized in Table D.9.
Figure D.3—CCVT physical circuit
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
In designing a CCVT, the inductor L is selected by setting the sum of the equivalent capacitive reactance
and the inductive reactance to zero at the power frequency. Note that the Thevenin equivalent capacitive
reactance at point A is the sum of the upper and lower leg capacitances, C
1
+ C
2
, thus, as shown in
Equation (D.3):
( )
0
1
2 1
=
+
+
C C j
L j
ω
ω
(D.3)
Or equivalently:
( )
2 1
2
1
C C
L
+
=
ω
The reactor L
D
, known as the drain reactor, is for the purpose of power line carrier filtering and may be
optionally shorted by a manual switch. For the purpose of low frequency analysis (0 to 1 kHz) this reactor
has negligible effect and is ignored.
In standard CCVT designs, typical values of capacitor dividers are selected so that the sum of the
capacitances C
1
+ C
2
is in the order of 100 nF. The corresponding compensating reactor inductance for
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
are tuned to the power frequency. Thus during
normal steady-state operation, the impedance of the L
F
//C
F
branch is very large and the suppression circuit
draws negligible current. During transients, the impedance of L
F
//C
F
branch is lower and thus the resonating
energy is dissipated through the filer resistor R
F
.
The passive suppression circuit (see Figure D.6) consists of a saturable core reactor L
F
and a damping
resistor R
F1
connected at the center tap of the transformer secondary, plus a spark gap in series with a
second damping resistor R
F2
.
Figure D.5—Equivalent circuit of a CCVT with active ferroresonance suppression circuit
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure D.6—Equivalent circuit of a CCVT with passive ferroresonance suppression circuit
During steady-state 60 Hz operation, both of these filter circuits have negligible effect on the CCVT
response. However during transients they generally prolong the CCVT transient response. It has been
shown that CCVTs with passive ferroresonance suppression circuits have better transient response
characteristics (error decays to negligible levels faster).
The CCVT simulation model used here is that shown in Figure D.4. The model explicitly represents the
upper and lower capacitors, the drain inductor, the compensating reactor inductance and resistance,
ferroresonace suppression damping, the parasitic capacitance, and the burden resistance.
D.5.1 Example, a 288 kV:120 V CCVT
The base case parameter values for this example are given in Table D.10. The simulation is repeated for
various instrumentation cable lengths. In addition, different values of burden resistance, and different
inductance and capacitance values are used to calculate CCVT phase errors under different conditions. The
calculated phase errors are presented in Table D.11 and Table D.12. Table D.11 shows the results of a
parametric analysis with respect to burden resistance and instrumentation cable length. Table D.12 shows
the results of a parametric analysis with respect to CCVT component parameter inaccuracies. Specifically
the varied parameters are the compensating reactor inductance and the capacitive divider capacitance.
Table D.10—Base-case CCVT instrumentation channel simulation parameters
Parameter description Schematic reference Value
CCVT capacitance class — Normal
Input voltage — 288 kV
Output voltage — 120 V
Upper capacitor size C
1
1.407 nF
Lower capacitor size C
2
99.9 nF
Drain inductor L
D
2.65 mH
Compensating reactor inductance L
C
68.74 H
Compensating reactor resistance R
C
3000 Ω
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Table D.11—CCVT phase error (in degrees) versus burden resistance and cable length
Cable length
Burden resistance (Ω)
3 m (10 ft) 300 m (1000 ft) 600 m (2000 ft)
50 1.33 1.44 1.55
100 0.7 0.77 0.85
200 0.37 0.41 0.45
400 0.2 0.22 0.25
1000 0.1 0.11 0.12
Table D.12—CCVT phase error (in degrees) versus capacitive divider capacitance
and compensating reactor inductance
Inductance error (%)
Capacitance error (%)
0% 1% 5%
0 0.10 0.12 0.18
–1 0.11 0.13 0.19
–5 0.17 0.19 0.24
The results in Table D.11 show that low burden resistances (higher burdens) can have a very significant
impact on synchrophasor measurement accuracy. Nevertheless, since most modern PMUs have a fairly
high input impedance (more than several kilohms), the impact of burden on voltage phasor accuracy is
expected to be minimal.
The results also show that changes in the capacitive divider’s capacitance (e.g., due to aging or temperature
changes) or inaccuracies in selecting the compensating reactor’s inductance can have noticeable impacts on
phase accuracy. The impact of capacitive divider’s capacitance change on voltage magnitude accuracy is
not shown here since they have a commonly well-understood near-linear relationship; e.g., a 2% change in
C
1
’s capacitance will result in nearly 2% error in CCVT voltage magnitude error (ratio error).
Additional examples and references can be found in Meliopoulos et al. [B49].
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IEEE Std C37.242-2013
IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs)
for Power System Protection and Control
Figure E.1—PMU performance test setup example
Various kinds of tests can be performed, including steady-state accuracy tests, dynamic performance tests
(if the signal generator supports the step and ramp functions), and various protocol tests and delay
measurements.
A connection testing software (an off-the-shelf tool) can act like a local PDC and be used to confirm
correct expected magnitudes and angles. Final results may be taken from a PDC located at a control center
at a distance in order to include various types of delays such as the delays within the communications
network.
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