AGILE DIGITAL SUBSTATIONS

Transcription

AGILE DIGITAL
SUBSTATIONS
The complete guide
1
2
Overview
of Digital Substation
Solutions
3
4
Agile Digital Substations
Alstom’s
agile digital
substation offers
unprecedented
performance
using intelligent
primary systems
and tailored
automation
solutions
55
Index
Overview of digital substation
solutions
The complete digital substation solution........ 8
The benefits................................................. 11
IEC 61850................................................... 13
The architecture of digital substations......... 16
Digital instrument transformers................... 20
Primary converters...................................... 23
Control and monitoring................................ 26
Service & technical training......................... 30
Summary.................................................... 32
Digital substation solutions – Q&A............... 33
GIS solutions
GIS overview............................................... 41
Our mission statement................................ 42
GIS fact sheet index..................................... 43
Digital solutions for GIS............................... 44
Digital instrument transformers................... 47
Data sheets:
COSI-RECT............................................. 49
COSI-CEVT............................................. 53
COSI RogoFlex........................................ 57
COSI-PC12............................................. 61
MU Agile XMU800.................................. 65
MU Agile XMU820.................................. 69
BWatch3................................................ 73
Online PDWatch..................................... 79
RPH3..................................................... 83
GIS Service solutions................................... 87
GIS conclusions........................................... 90
AIS solutions
AIS overview............................................... 93
Our mission statement................................ 94
AIS fact sheet index..................................... 95
AIS digital substation overview.................... 96
Data sheets:
COSI-CT.................................................. 99
66
COSI-CT F3........................................... 105
COSI-PC13........................................... 111
MU Agile XMU820................................ 115
CBWatch-2........................................... 119
DWatch................................................ 125
RPH3................................................... 133
AIS Service solutions................................. 137
AIS conclusions......................................... 139
SAS solutions
SAS overview............................................ 142
SAS global footprint................................... 144
Introducing DS Agile.................................. 145
The complete digital substation solution.... 146
DS Agile key benefits................................. 147
DS Agile components................................. 153
Data sheets:
DCS OI................................................. 155
DS Agile Gateway................................. 159
DS Agile WACU.................................... 163
DS Agile bay controllers........................ 165
DS Agile Switchgear Control Unit......... 171
MU Agile AMU...................................... 173
Introducing Protection Relays............... 179
MiCOM Alstom P40.............................. 181
MiCOM Alstom P847............................ 197
P40 Agile.............................................. 203
P60 Agile.............................................. 211
DAPserver™......................................... 219
MiCOM S1 Agile................................... 223
DS Agile H series.................................. 227
SAS conclusions........................................ 229
Online condition monitoring
MS3000.................................................... 233
Reference projects
Jambua, India............................................ 240
Saumade, France...................................... 241
Nadezhda, Russia...................................... 242
Energinet, Denmark.................................. 243
Introduction
After more than 15 years of advanced research and
projects around the world, Alstom Grid’s digital
substations now deliver the great potential of this
technology: interoperability, ease of configuration,
maximised reliability and availability, real-time
performance, Smart Grid communications
capabilities and reduced cost of ownership.
Integration from conventional through to nonconventional substations is ensured, thanks to IEC
61850 compliance.
Alstom Grid’s engineering teams can interface with
any system, whatever its age or generation. We
provide stage-by-stage extensions, whilst keeping
the remaining circuits safely in service.
Alstom Grid has developed simple tools that enable
operators to manage their substations easily
and safely while identifying problems quickly.
We provide a fully documented solution with
clear instructions on interconnecting, testing and
commissioning. Moreover, extension and retrofit
solutions in the future will not require the original
manufacturer to be involved, as everything is
designed for interoperability.
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The complete
digital substation
solution
B
C
IEC 61850 Ethernet
network
DS Agile substation
bay controller
C
Hardwire link
A
M Condition
monitoring
unit
Process bus
IEC 61850
B
A
D
M Condition
monitoring
unit
M Analog
merging
unit
M Numerical
A
L
merging
unit
M Switchgear
controlling
unit
Fibre optic link
A
Condition
monitoring
unit
M
Smart primary equipment
M
8
Merging units
integration
D
E
DS Agile switches
F
DS Agile A300
substation gateway
G
Remote access and
telecommunication
Grid control room
Cyber security
G
F
F
H
I
E
I
F
Central
access
server
K
D
B
Station bus
IEC 61850
J
F
H
I
J
L
Precision time protocol
K
System Configuration
Editor (SCE)
DS Agile Operator Interface (OI)
DS Agile A400 WACU / SACU
MiCOM protection and other
IED integration
9
Alstom Grid agile digital substations –
key advantages
Based on the IEC 61850 unifying communication standard for complete information, future
modernisation and the integration of new systems.
Digital Control Systems may connect with the primary bays via a process bus built
on redundant Ethernet architectures. Merging and control units collect and translate
measurements, indications and commands (I/O) from the primary equipment into sampled
values and GOOSE messages and vice-versa
Digital instrument transformers and HMI (Human Machine Interface)-integrated condition
monitoring systems for the primary equipment can be added, providing superior substation
situational awareness locally and remotely.
Optimise your operational costs
Asset managers now have a critical tool that, with less wiring and fewer commissioning
tests, optimises preventive maintenance and can extend the lifetime of the entire substation,
including third party plant items.
Alstom Grid’s digital solutions:
■■ Maximise the reliability of your substation
■■ Operate assets more efficiently and safely close to the limits of the system
■■ Optimise maintenance, repair and retrofit of equipment with minimal outages
Complete and adaptable solutions
Alstom Grid’s digital solutions solutions are available for:
Retrofit and extension schemes, as they reinforce conventional tools and systems
■■ New substations
■■ The particular solution and architecture can be adjusted to meet your operational needs
according to how critical your asset and substation is to the network.
■■ Extensions and modifications are easier, as the substation functions via software, not
hardware.
■■
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Alstom Grid’s digital
substation – the benefits
Increased reliability and availability
The extensive self-diagnostic capabilities of digital devices ensure the maximum availability
of the substation, as well as its full suite of functionalities: any degradation in the
performance of an asset is pinpointed in real-time.
The inherent redundancy built into the system can be employed to self-heal and permits
troubleshooting without the need for primary system outage.
Optimised operation of assets
The intelligence within digital substation schemes allows close monitoring of the load
capacity of plant equipment, based on their design ratings. This dynamic load analysis
means that lines, cables, transformers and other grid equipment can operate closer to their
limits.
Improved safety
Removal of wired cross-site CT (Current Transformer) circuits reduces the risk of fatal
injury due to inadvertent opening of the circuit by personnel
■■ Absence of oil in transformers reduces explosion risks
■■ Advanced self-monitoring of substation assets ensures that they are operating within safe
limits
■■
Reduced maintenance costs
The digital substation closely monitors all substation assets in terms of operational
conditions, effective load capacity and asset health indicators. Intelligent systems analyse
the data and provide recommendations on maintenance and repair actions. This allows a
shift to predictive maintenance, avoiding unplanned outages and emergency repair costs.
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Investment optimisation
The capital cost of investment projects is reduced on many fronts:
■■ savings on the time needed to engineer and install substations
■■ reduced real-estate needs
■■ copper cabling is cut by up to 80% through the use of optical fibre
■■ asset optimisation tools allow faster targeting of weak areas which need to be reinforced,
allowing for reduced operational costs
Easier renovation and extension of
existing substations
Interoperable solutions and the use of fibre optics instead of copper wires reduce the
duration and costs of unavailability of substations during the refurbishment phase of
secondary equipment. This also applies to extension works.
Standardisation and interoperability
Being IEC 61850 compliant, Alstom Grid digital solutions and substations are designed to
be interoperable with other vendors’ equipment, with a strong degree of standardisation at
the interface level of secondary equipment systems.
Improved communication capabilities
Data exchange between intelligent devices, intra and inter- substation, is optimised
through Ethernet communications. Smart local and wide area control units allow data
exchanges between voltage levels within substations and between substations.
Direct inter-substation communication without the need to transit via a control centre
reduces the response times, enabling fast, real-time applications.
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IEC 61850: the key
technology enabler
Modern sensors and other Intelligent Electronic Devices
(IEDs) must be connected to communicate within the
substation and over the greater grid system. In the past,
there were many different protocols requiring much effort
to make them communicate with each other. Insufficient
standardization, fear of degraded reliability and lack of
return on investment slowed down the emergence of the
fully digital substation. But today, the IEC 61850 standard
makes it possible to facilitate interoperability between
different equipment and suppliers.
Introduced in 2004, the IEC 61850 standard is increasingly
accepted across the world, as its main objective is to ensure
interoperability between equipment coming from various
suppliers. IEC 61850 continues to evolve and encompass
the needs identified by the industry’s user group (UCA UG),
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ensuring that it caters to all substation needs. IEC 61850 is rapidly being enriched as new
application areas are continually added, most notably IEC 61850-8-1 and IEC 61850-9-2.
This permits the full digitising of signals in a substation so that large amounts of data can
be managed and communicated for the real-time management of a modern power grid –
a smarter grid.
IEC 61850
IEC 61850 is the international standard for Ethernet-based communication in substations.
It is more than just a protocol, it is a comprehensive standard designed for utilities, to
deliver functionalities that are not supported in legacy communication protocols.
IEC 61850 defines a domain specific data model (data and services) supporting all
functions required in substations. These unique characteristics can significantly reduce
costs associated with designing, installing, commissioning and operating power systems.
IEC 61850 is designed for interoperability and longevity, removing the dependence on one
supplier and one generation of IEDs.
IEC 61850-8-1
IEC 61850-8-1 is the relevant standard for the station bus. It defines the means to
generate and present reports which may be subscribed to by other devices and HMIs
(Human Machine Interfaces) as well as the way to communicate peer-to-peer. The latter
is achieved by the exchange of GOOSE messages between devices on the LAN (Local Area
Network).
IEC 61850-9-2
IEC 61850-9-2 is the part of the standard that brings non- conventional instrument
transformer technology into play, breaking the constraints of conventional CTs and VTs. It
is particularly important for the process bus, as it describes how analogue signals such as
phase currents and voltages can be exchanged as sampled values.
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15
The digital substation
architecture can be
divided into three levels
Remote access
WAN
The station control area
Advanced
Communication within substation and control
system, coordination with the substation operational
functions and the station-level support functions.
Gateway
Switches
The protection and control level
Protection and control of substation equipment
includes IEDs traditionally called “secondary
equipment” (protections, measurement devices, bay
controllers, recorders...)
Bay controllers
Switches
The primary equipment process level
Capture of voltage and current signals, consolidation,
processing, and transmission of data via optical
fibres: intelligent primary devices (electronic power
and instrument transformers, circuit-breakers,
disconnectors) and optic fibre have replaced
traditional CT/VT systems and conventional cable
wiring.
Figure 1 Generic overview of a digital substation
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Analogue
and digital
merging
units
Protection
relays
The architecture of Alstom
Grid digital substations
Grid control rooms
d substation situation awareness HMI
Alstom Grid’s digital substations incorporate the newest
DS Agile digital control system that provides the complete
architecture, connecting all the components, together and
with the operator interface, through an IEC 61850 Ethernet
network.
DS Agile digital substation solutions are highly scalable in
terms of equipment, functions, architecture and services.
STATION Bus
Phasor data
concentration
Wide area control
Process Bus
Conditioning
monitoring units
Primary equipment
with embedded
digital sensors
17
A typical Alstom Grid digital substation solution incorporates many components, all
designed for optimal inter-operability, data retrieval, protection and control capability and
remote settings. Its architecture is organised on three levels:
1. The process level
A digital substation is based on a communicating
architecture, where real-time operational measurements
and other data are polled from the primary system by
sensors embedded within the primary system. This
data is communicated to devices that must act on those
measurements (pressure or temperatures in GIS switchgear,
current and voltage measurements) via a “process bus”.
Most important is that smart devices and systems within
the substation, (protection relays, recorders, phasor
measurement units, bay controllers, wide area controllers)
can immediately process this data. By subscribing as
clients to this data flow over an Ethernet process bus, the
information from the ‘eyes and ears’ of the power system is
distributed and communicated much more efficiently to the
bay level than in conventional hardwired schemes.
The process bus is also the link by which the primary
equipment information from out in the yard travels back to
the substation control room.
In a fully digital architecture, control commands are also routed to the primary devices via
the process bus. The process bus, therefore, enables time-critical services.
2. The protection and control level
Between the process bus and the station bus are devices identified as ‘secondary equipment’.
In the digital substation, these devices are IEDs (intelligent electronic devices), interacting
with: the field via the process bus; with other peer devices in the bay; with other bays, and
with the digital control system via the station bus. They are designed to provide the Smart
Grid applications demanded by utilities via real-time and secure equipment. They provide
interoperable solutions, stability applications, wide area protection & control plans, and more
globally, substation situation awareness.
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Key components are: the protection relays, bay controllers,
switches and Ethernet network, measurement and
recording devices, substation proxy, the operator user
interface within the substation control room, time
synchronization units, security applications and the panels
where all this equipment is commissioned and energised.
IEC 61850 communications enable complete integration
between devices. It ensures optimal use of the information
for the continuity and reliability of electrical grid operations
in secured access situations.
3. The station control area
The digital substation station bus is much more than a
traditional SCADA bus, as it permits multiple clients to
exchange data, supports peer-to-peer device communication
and links to gateways for inter-substation wide-area
communication.
The IEDs perform their time critical functions such as
protection, point-on-wave switching supervision and other
tasks via direct interaction with the process bus.
Additionally, other clients in the substation may require
information-sharing of some or all of this data. For example,
protection and control schemes may be distributed amongst multiple IEDs.
There is also the need to distribute the information to local or remotely-stationed control
operators so they can visualise the operational status of the substation in real-time. This
requires substation HMIs, proxy server links to remote HMIs and control servers. One or
more workstations can apply the instructions assigned by regional dispatchers, or can be
used as an engineering workstation for IED configuration, or for local concentration and
archiving of power system data. Online condition monitoring may have specific workstations
for alerts and to manage the database history of each primary device.
Using industry norms and enabling technologies to their fullest, Alstom Grid’s global experts
now bring the digital substation to the market. Whether for incremental refurbishment, or
complete green-field installations, Alstom has the equipment, the system delivery capability
and project management expertise to be operational first time and on-time. The component
parts of this offer are detailed in further sections.
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Digital instrument transformers
Decades of extensive research by Alstom Grid has delivered proven non-conventional
instrument transformers, designed to be accurate, intelligent, safe, cost-effective – and very
importantly – core-less.
The root of many of the limitations of conventional instrument transformers is their reliance
on an iron core. The core is a source of inaccuracy, due to the need to magnetise it, but not
to overflux it. In the case of conventional CTs, achieving the lowlevel accuracy and dynamic
range to satisfy both measurement and protection duties is a challenge. Conventional VTs
may experience ferroresonance phenomena resulting in thermal overstressing.
Instead of an iron core, the translation from primary to secondary measurement uses
optical, Rogowski or capacitive technology, with the optimal choice for AIS (air-insulated
substation) and GIS (Gas-Insulated Substation) equipment driven by the size of the
respective digital device, which allows size optimisation for the switchgear.
A wide array of sensors monitor conditions in real-time thanks to multiple applications:
diagnostic analysis, asset management and condition-based maintenance.
Alstom Grid COSI (COmpact Sensor Intelligence) solutions:
Device
Description
Optical
Sensor
Faraday optical technology devices:
COSI-CT: Composite optical CT
COSI-CT F3: Flexible, portable optical current sensor
Rogowski
Sensor CT
COSI-RECT: Rogowski coil for current measurement
COSI-Rogoflex: Flexible Rogowski current sensor
Capacitive
Sensor VT
COSI-VT: AIS voltage transformers
COSI-CT-F3
20
AIS GIS AC
•
•
•
•
•
COSI-CEVT: GIS voltage transformers
COSI-RECT
•
•
•
COSI-CEVT
•
DC
•
The facts
Optical sensors use the Faraday effect. A fibre optic loop
sensor carrying a polarised light beam encircles the
power conductor. This light will experience an angular
deflection due to the magnetic field, generated by the
primary current flow. The sensor’s intelligence is to
accurately determine the primary current based on the
real-time optical measurement.
■■ Rogowski sensors dispense with the conventional CT
core and instead implement windings as tracks on a
multi-layer printed circuit board. Four quadrants of the
board are clamped together to form a toroid around the
primary conductor. The sensor output becomes a lowlevel voltage measurement, which can be accurately
correlated to the primary current.
■■ Capacitive dividers dispense with the conventional VT
core. Capacitors are built from slimline film stacks for
AIS sensors or printed circuit board electrodes laid on
the interior of the enclosure for GIS sensors.
■■
Customer benefits
Enhanced safety: no
risk of explosion, no
wired CT secondary
circuit running crosssite
■■ Measurement precision
coupled with protection
dynamic range
■■ No saturation,
ferroresonance or
unwanted transients
■■ Long-term accuracy
■■ Outstanding seismic
resilience
■■ Unparalleled reliability
and availability with full
self-diagnostics
■■ Lightweight, compact
and flexible
■■ Minimal inventory,
near-zero maintenance
■■ Harmonic monitoring
■■ Online condition
monitoring
■■
21
22
Primary converters
Converters
Alstom Grid digital substations optimise the amount of electronics residing in potentially
harsh outdoor environments.
The primary converters convert analog signals from the primary equipment into digital
signals. Primary converters can be installed either directly in primary plant hardware or in
cubicles.
Digital controllers (switch control units) are the fast, real-time interface to switchgear,
mounted close to the plant that they command. They replace the hardwiring of inputs
and outputs with an Ethernet interface to the yard.
Merging units
Merging units perform all the digital data processing necessary to produce a precise,
time-aligned output data stream of sampled values according to the IEC 61850-9-2
standard. This processing includes tasks such as sampling, analog to digital conversion,
scaling, precise real-time referencing and message formatting.
The design may vary with the applied technology of the instrument transformers (eg:
optical, Rogowski, voltage dividers, or conventional wound instrument transformers),
the switchgear type, mounting space available and also with the preferred substation
communication architecture.
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Device
Description
DS Agile SCU
Switchgear controller unit:
Processes the I/O signals from/to the primary switchgear as IEC
61850-8-1 GOOSE messages
MU Agile AMU
Standalone compact merging unit:
Digitising of conventional 1A/5A and 100/120V analog secondary circuits
MU Agile
XMU800
Modular digital merging unit:
Interfaces with multiple primary converters in the field
MU Agile
XMU820
Modular merging unit:
Interfaces with digital and conventional instrument transformers
MU Agile NXMU
Modular merging unit:
Interfaces with COSI optical CTs and conventional VTs
Customer benefits
Interfaces with all
types of power system
current and voltage
sensors, whether
digital instrument
transformers (DIT) or
conventional CT/VT
■■ Ensures accuracy of
protection applications
up to highest fault
currents and X/R ratios
■■ Ensures measurement
accuracy
■■
Primary converter
MU Agile
MiCOM IEDs
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Digital protection relays
MiCOM Alstom is a complete range of IEDs designed for digital
substation architectures. The full range of transmission protection
is included, from the simplest back-up device, to subcycle tripping
main protection schemes. In a fully-digital architecture, the relays
receive currents and voltages as IEC 61850-9-2 sampled values
and issue trip or alarm signals using IEC 61850-8-1 GOOSE. The
flexibility of MiCOM allows you to adopt new technology tailored
to match your pace of change – from initial station bus digital
MiCOM P40 Agile
integration, up to full station and process bus schemes. The
following table indicates the typical relays selected, and their main functions:
Device
Principal Application
MiCOM Alstom P446
Subcycle distance protection with integral teleprotection and one
or two breaker reclosing
MiCOM Alstom P546
Line differential for 2 or 3 terminal lines with subcycle distance
and one or two breaker reclosing
MiCOM Alstom P645
Transformer differential for up to 5 ends with advanced loss-of-life
thermal monitoring
MiCOM Alstom P746
& P743
Digital busbar protection for centralised smaller schemes up to
large decentralised bus configurations
MiCOM Alstom P841
Transmission line terminal IED for backup, reclose and breaker fail
management
MiCOM Alstom
C264P
One-box solution feeder protection with control and bay mimic
diagram
Customer benefits
Proven algorithms of conventional applications remain unchanged, no need for reapproval
Time-critical performance is maintained irrespective of the architecture, number of functions
enabled, or extent of logic programmed
■■ Safer test and maintenance operations for technicians – no wired CT secondary circuit exists
■■ Accurate measurement capabilities – as accurate as the incoming -9-2 data itself
■■ Station bus communication redundancy available:
PRP (Parallel Redundancy Protocol) and RSTP (Rapid Spanning Tree Protocol)
■■
■■
25
Also available, the MiCOM P847 phasor measurement unit offers industry-leading accuracy
and dynamic response to frequency excursions.
The MiCOM P594 provides the precision clock source reference for merging units and phasor
measurement units in the substation.
MiCOM Alstom IEDs extend their supervision facilities to address and check the plausibility
of the incoming sampled values from the process bus. This addresses the fact that the
traditional task of current and voltage sampling is now external to the device, and is
connected via Ethernet. The supervision compensates for any latency or mismatch in the
network, provides ride-through intelligent compensation in the event of several missing
samples or jitter, and blocks/alarms if the quality of incoming data compromises the secure
and reliable operation of the IED.
Control and Monitoring
Alstom Grid’s DS Agile range is the latest generation of substation Digital Control Systems
(DCS). It relies on fast Ethernet networks with IEC 61850 communication standards and offers
topology-orientated automation combined with electrical security to minimise outages.
DS Agile can be tailored either to single substations or to a harmonised system across
multiple substations.
Devices
Applications
DS Agile bay
controllers
(C-series)
Alstom’s IEC 61850-compliant bay
controllers, like the C264, provide
embedded or programmable fast
automation (automatic voltage
regulation, synchro-check, autorecloser, busbar transfer, etc.), backup
feeder protection, data concentrator,
events and waveform recorder, hot
standby redundancy etc.
DS Agile OI
Real-time, user-friendly Operator
Interface (OI) for complete
substation automation
26
Redundant architectures
DS Agile architectures can be set up as a self-healing ring (HSR protocol) or dual-homing
star (PRP protocol); both of which are fully redundant, eliminating outages.
Fibre optical networks link all the system’s components together and with the operator interface
(HMI), via a full range of Ethernet switches that provide full reliability and interoperability.
Devices
Applications
DS Agile switches
(H-series)
GOOSE switches
External (rack) or internal
Interoperable standard protocols (PRP/HSR)
Gigabit switches
IEEE 1588 transparent clock
Substation/grid control room
communications
The digital substation benefits from a wide-area network interface, receiving and
responding to the data from its extensive array of sensors and IEDs. It can be integrated
as part of the grid operator’s wide area control systems and defence plans, as the data
from Phasor Measurement Units (PMUs) is concentrated
and relayed from the substation to the control centre
Customer benefits
and analysed by online stability solutions to track current
■■ Reduced unscheduled
oscillations and anticipate incidents.
outages and repair
times
Alstom’s digital substation sensors and control systems
■■ Reduced routine
work seamlessly with its software platforms for grid
maintenance costs
operator control rooms, allowing a real-time data exchange
■
■
Increased equipment
both at the substation operational data level and at the
life expectancy
asset management data level. This substation / control
■■ Frees-up skilled
room communication introduces Smart Grid capabilities
personnel for remote
to the network, bringing complete synergy between field
diagnostics and
equipment operations and network management systems.
operation centres
The networks can be local to the substation or they
27
can interconnect several
dispersed substations,
and all are linked to the
grid control room through
gateway solutions.
Inter-substation or intervoltage level automation
exchanges GOOSE
messages for:
■■ Logic selectivity
■■ Auto-reclose and fault
location
■■ Automatic setting of the
relays
Devices
Applications
DS Agile A300
Gateway
Powerful and ruggedised gateway
solution that offers multiple
communication protocols (including full
IEC 61850 compliance) with hot-standby
redundancy and simple commissioning
DS Agile A400 Substation inter-voltage (SACU) and
SACU & WACU inter-substation (WACU) level exchange
through IEC 61131 automation
IEC 61850-compliant
hot-standby redundancy
Cyber security
The digital substation brings increased cyber security capabilities, as intrusion protection
and protection against virus attacks are integrated in switches and IEDs. Cyber security
provides protection against unauthorised access to equipment and unauthorised transfer,
modification or destruction of data – whether deliberate or accidental.
Particularly when wide area networks extend beyond the traditional substation fence,
cyber-security measures are essential. Security procedures, controls, firewalls and rolebased access are all examples of such measures. A number of standards apply in this area,
typically: NERC CIP, IEEE 1686, IEC 62351, ISO/IEC 27002, ETSI and CEN CENELEC.
C264 bay controller
28
DS Agile switches
and asset management
Online condition monitoring functions are essential for power transformers, circuit-breakers,
disconnectors and gas-insulated switchgear.
Physical parameters are continuously monitored and real- time measurements are combined
and compared to models in order to generate specific recommendations for operations and
maintenance, as well as alarms when necessary.
Expert software providing additional advance warnings, automatic diagnostics and
maintenance suggestions will boost the efficiency of asset management. An interface with
an asset management system yields additional features such as remaining lifetime or
dynamic rating capabilities.
This architecture gives operational and maintenance teams an overview of the condition
of all substations in real-time, so they can make appropriate strategic asset management
decisions.
Device
Principal applications
PTWatch
MS3000
Power transformer condition monitoring: expert system for data management
throughout the life span of the power transformer, with scalable range
of sensors and modules for online continuous monitoring of all major
components of the transformer (active parts, bushings, tap-changer and
cooling system)
BWatch
GIS bay condition monitoring: interactive diagnostics, acquisition of pressure
and temperature, threshold management, leakage, density and liquefaction
calculation, internal arc location, enclosure overheating detection
PDWatch Partial discharge condition monitoring for GIS
GISWatch Integrated bay & partial discharge condition monitoring for GIS
CBWatch
Circuit-breaker condition monitoring: moving part timings and travelling
curves, main contact wear, drive energy and auxiliary parts are continuously
monitored
DWatch
Disconnector condition monitoring
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Services & technical training for
Alstom Grid service is committed to provide the support from retrofit solution engineering
to the full lifecycle of the substation by leveraging the expertise of a worldwide leader in
primary product manufacturing, condition data interpretation and product ageing models.
Expertise and consulting services
In addition to the real-time data information and alerts interpretation consulting services,
reviews can be complemented with on-site condition assessment of the full system –
equipment, sensors, data communication and IED processing units. This assessment
provides the information needed for asset management strategies such as maintenance,
repairs and residual life assessment, while maximising the asset reliability performances
and minimising operational risks.
Services can be provided either on an on-call basis, or a long term contract tailored to
your needs.
Technical training
Dedicated technical training develops the knowledge and skills required to operate and
maintain digital substations for peak performance. Gaining theoretical and hands-on
experience at one of our training centres, Alstom Grid Technical Institute, ensures teams’
efficiency in their daily work.
Our training offer on digital substation applications encompasses several topics such as
cyber security, graphical programmable scheme logic, Ethernet ready solutions and online
condition monitoring for circuit-breakers, CTs & VTs or DC supplies. Furthermore, this
training is complemented by training on power equipment operation and maintenance,
network management solutions and electrical safety.
30
Digital retrofitting of substations
Alstom Grid’s engineering teams can interface with any system, whatever its age or
generation. Simple tools, specifically developed, enable operators to manage their substation
easily and safely while identifying problems quickly. Alstom Grid provides a fully documented
solution with clear instructions on interconnecting, testing and commissioning. Moreover, as
everything is designed for interoperability, a unique service provider will be able to maintain
the equipment and manage the digital retrofitting of the substation in the future.
31
Summary
Alstom’s agile digital substation offers unprecedented performance using intelligent
primary systems and tailored automation solutions.
Digital components can be effectively and easily integrated into existing substations,
networks and grids, allowing users to gradually move from conventional to digital
solutions. This ability to integrate Alstom digital substation components allows for
operator training, system testing and incremental investment while ensuring future
compatibility.
32
Agile Digital Substations | Q&A
Digital substation
solutions – Q&A
33
Let’s share some of the questions we have heard asked about digital
substations so far, and the answers we provided..
“I am not sure
about the reliability
and accuracy
of process bus
solutions”
Regarding reliability and system architecture:
Sometimes users express concern about the architecture of the
digital solutions because it is different. With analogue solutions
the information chain was: sensor then cable then relay. Now the
route is different with sensors, fibre optics, station bus and process
bus. Even though the architecture may seem more complex to
non-specialists, the solution is extremely reliable, because it has
auto-test and health-check capabilities that analogue solutions do
not have.
Regarding accuracy:
The information is digitised from the source, so the information
conveyed is very accurate. Indeed, accuracy is much improved,
especially with digital instrument transformers, as there is no CT/VT
iron core to magnetise or introduce measurement error.
“These systems
transfer too much
unnecessary/
unimportant
information”
“The information
which is delivered
is too complicated
to analyse”
34
Digital solutions are able to capture and transfer a lot of information,
not only simple 0/1 values. Of course, more information means
users have to interpret it and to define for each parameter the alarm
thresholds. Alstom offers many functions to make the best out of
digital systems.
a.Expert support is available at all stages to design and parameter,
analyse etc.
b.Alstom solutions offer user-friendly interfaces with simple colour
coded indicators: green = ok, orange = warning, red = not ok.
c.Alstom solutions enable users to select the information displayed
according to the user’s profile, as operation staff, maintenance
staff or asset managers do not need to monitor the same things.
Alstom makes it possible to
give the right information to
the right person. For example,
the systems can generate data
sets for managers once a day,
while they can display the
information in real time for
operation people.
“Only experts can
use the information
received from these
systems”
d.Alstom solutions can concentrate and filter information before it
is sent to upper levels of the system hierarchy. This avoids placing
unnecessary bandwidth constraints on the communications network.
“What about
the life time
of electronic
components?”
Electronic components obsolescence is a point of interest for
network operators although such technologies are now used in
many industrial applications, and well-proven in Digital Control
Sytems and numerical protection relays.
“What will
happen if we
need to replace
components?”
Solutions are designed incorporating the necessary ‘functional
sustainability’ which implies that all new developments will
replace/be compatible with older generations. Changing a
component in 20 years, while keeping the same functionality, is
made easier with Alstom.
As regards the life time of digital components, the MTBF of many
components is actually several decades.
Temperature is the most impactful parameter when talking about
the life time of digital components and the industry improves
continuously. Alstom choses electronic components that have been
selected to withstand higher temperatures and therefore feature
longer service life.
Furthermore Alstom solutions withstand extensive thermal testing
during their design and development.
Last but not least: with analogue solutions, if a component does not
work, you might not know it unless you perform visual tests. Digital
solutions incorporate automatic health check and if a component is
out of order, it will give a signal, ensuring the reliability of the whole
solution.
And what may happen in 15 or 20 years if a component might need
to be replaced?
Alstom ranges are managed so as to replace the components and
solutions gradually as they become obsolete, maintaining the
same functionality. Service specialists are dedicated to supporting
customers after the warranty period and to supply with the right
component or solution.
35
“Implementing
digital solutions
will be difficult”
“We do not have
the skills in-house
to implement such
systems”
I mplementing a substation with digital control and monitoring will
actually be easier than implementing a substation with analogue
systems. The main reason is that the whole cabling adventure is a
thing of the past! Cabling in a HV substation is reduced by approx.
80%.
For the design and implementation of the digital systems
themselves, Alstom experts provide support and all the solutions
are scalable, meaning that they can be implemented one stage at a
time.
For example, conventional current and voltage sensors can be linked
via fibre optics to digital merging units and protection relays, so as
to reduce the cabling, while keeping the conventional substation
equipment.
Note that much of the digital system engineering is in software,
which means that the maximum can be engineered and proven
before the FAT (factory acceptance test). The site works are
drastically reduced, meaning that the more senior specialists need
not travel to each project site.
Alstom delivers training to all involved staff:
■■
■■
■■
■■
Architecture and design of solution
Maintenance
Operation
Asset management
The younger generation of network engineers are educated and very
familiar with these technologies. As the future is digital, the training
and knowledge gained is career enhancing, so utilities can remain
attractive to talented young engineers!
“The information
given by the
system requires
highly skilled
people to interpret
it”
36
lstom solutions range from the most basic information delivery to
A
expert systems. We are able to discriminate the right information
for the right person according to his/her position and profile. Expert
systems also include some analysis and clever data display, so as
to make the reading and interpretation easier. Training is available
for all positions from operational staff to asset management
executives.
“Is it right that the
safety of my staff
can be enhanced?”
Digital devices run on Safety Extra Low Voltage (SELV), meaning
that staff are at no risk while working with them.
“What are the
references?” or
“which utilities
have already
implemented such
systems?”
In 2013, Alstom has installed a base of:
The elimination of oil in instrument transformers (removal of explosion
risk), and the removal of cross-site current transformer circuits (risk of
lethal injury if open-circuited whilst live) are the two principal examples
of staff safety being improved.
Protection : over 400 000 digital relays
Control : more than 3000 control systems
■■
Monitoring : more than 1300 GIS bays
There are specific case studies in the ‘Reference Projects’ section of
this handbook.
■■
■■
37
A quick visual guide to answering questions and
overcoming objections
System concerns
Reliability
and
accuracy
Permanent health
check capabilities +
info digitised at its
source
Too much
information
Too
complicated
+ User-friendly HMI
+ tailored datasets
+ expert support
Life time of
components
Functional
sustainability +
robustness of the
design and component
selection
New solution
Numerous references,
pilot projects and
real installations
Implementation concerns
Difficulty to
implement
Easy to implement
+ scalable solutions
38
Need for
experience/skills for
results analysis
How to replace a
component
Alstom provides training
+ such skillsets more
available in the engineering
community today
Functional sustainability
+ dedicated service
specialists
GIS Solutions
39
40
GIS Solutions
Digital solutions
for GIS
With more than 40 years of operational experience
in power substation provision, Alstom Grid is a
leader in the GIS market. Our leadership is largely
thanks to meeting the most demanding operational
criteria through the sustainable process of
improvement of our solutions.
We offer a complete GIS range from 72.5 to 800 kV
to interconnect and protect electrical networks. We
have manufactured and commissioned more than
20,000 GIS bays from 72.5 up to 800 kV and 150
km of GIL circuits worldwide over the last 45 years.
We focus on smarter solutions, integrating devices
for predictive maintenance including online
bay monitoring (BWatch3), Partial Discharge
measurement (PDWatch) and point-on-wave
controlled switching (RPH3)
We are shrinking the technology footprint to
maximise space efficiency and flexibility. For
example, our F35 170 kV has a footprint 30%
smaller than its predecessors.
41
Our mission statement
Alstom Grid’s GIS product line provides power networks
and industrial customers with state-of-the-art
Gas-insulated substations from 72.5 kV to 800 kV.
We offer:
Most compact GIS range
■■ Optimised products at all voltage levels
■■ Fully eco-designed products
■■ First class spring-mechanisms
■■ Connectivity for Smart Grids with integration of automation and
monitoring systems
■■
42
GIS Solutions
GIS Solutions
Fact sheets
Digital Instrument Transformers - DIT
COSI-sensors
COSI-CEVT sensor
■■ COSI-RECT sensor
■■ COSI-Rogoflex sensor
■■
Primary converters
■■ COSI-PC12
Merging units
■■ MU Agile XMU800
Monitoring and control
SF6 and GIS monitoring
■■ BWatch3
Partial discharges monitoring
■■ PDWatch
Point-on-wave switching
■■ RPH3
43
Digital solutions for
gas-insulated substations
The new generation of GIS digital substation
solutions bring unprecedented levels of reliability,
security and performance through real-time
monitoring, automation and interoperability.
They integrate high performance primary
equipment including Alstom’s COSI (COmpact
Sensor Intelligence) and advanced substation
automation solutions. Information acquisition,
processing and output is treated in real-time
through a digital architecture with multiple layers
of automation units.
GIS Bay
44
GIS Solutions
45
Bay introduction
Combined
disconnector /
earthing
switch
Spring drive
Circuitbreaker
Local control
cubicle
Combined
voltage &
current sensors
Busbar
disconnector /
earthing switch
Cable feeder
Full digital
control
cubicle
Reduced
cabling
46
GIS Solutions | DIT
Digital instrument
transformers
Our range of digital instrument transformers
provide measurement using optical, Rogowski or
capacitive technology, which have been optimised
for operation with GIS equipment, integrating into
the relevant switchgear to provide accurate realtime measurement of key operational parameters.
47
47
GIS Solutions | DIT
COSI sensors
Current
sensor
Voltage
sensor
Current & voltage measurement
Current
sensor
Voltage
sensor
Protection
relays
Primary Converter
(Signal-conversion of
analog/digital)
Bay
controller
9.2
508
1
6
IEC
Merging unit
(Conversion to IEC 61850-9-2)
IEEE 1588 synchronisation
48
IEEE 1588
GIS Solutions | COSI-RECT sensor
Fact sheet – Gas insulated substations
COSI-RECT
Rogowski electronic
current transformer
for GIS
High voltage designs now increasingly incorporate
Smart devices - making Smart substations part
of the real world. In the digital chain for current
measurement, the COSI-RECT uses the latest
sensor technologies for DIT applications.
Customer benefits
One single sensor design suitable for protection, metering
and qualimetry
■■ Sensor enclosures are smaller than conventional ones space gains for substations
■■ High degree of electromagnetic immunity
■■
4949
Integrated voltage sensor
Integrated current sensor
Measure
Primary converter
Convert
RECT: High-tech sensor
Less maintenance
Sensors are the basic elements of current
measurement. In order to get the best results
for final measurement or protection applications,
the sensor must be highly accurate and should
be protected against the electromagnetic
perturbations (EMC) found in GIS substations.
Thanks to the coating on the PCBs and the highly
accurate processing, the sensors are designed to
work whether conditions are optimal or not.
Sensors are designed based on an Alstom patent,
using a double-sided PCB (printed circuit board)
as sensor material. This provides an excellent
stability in the measurements, even when
temperature and currents have slight variations.
Compatible with all GIS types
Several sensor designs have been introduced to
cover all types of high voltage equipment. RECT
sensors are available for all GIS equipment. Their
small size allows for smaller enclosures and
consequently smaller GIS substations.
An external memory (EEPROM) is associated to the
sensor allowing all calibration values to be stored as
soon as the sensors are mounted.
Thus, when a sensor is connected to the PC12
primary converter, the electronics automatically
adjust the compensation gains related to
calibration values found in the EEPROM.
Maximum protection
against EMC
Based on an Alstom patent, sensors are on a
double-sided PCB with interlaced copper tracks,
providing high immunity against EMC and external
magnetic fields.
The PCB is shielded to have a perfect immunity
against nearby magnetic fields.
50
important note:
This product may not be
sold on its own. It must
always be integrated in
a global DIT engineering
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
Single-phase GIS design
Three-phase GIS design
COSI-RECT 550 kV
51
Ratings
(sensor associated with PC12)
Module type
Technical features
■■
PC12-3I
3 x RECT*
Rated voltage
kV
-
Rated current
kA
Up to 150
Accuracy 50/60Hz
%
<0.05
Delay time
μs
<500
Sample Values Output rate
(IEC 61869-9)
■■ Protection channel
■■ Metering channel
■■ Qualimetry channel
KSPS
KSPS
KSPS
4.8 /4 /5.76
4.8 /4 /5.76
14.4 /12.8 /15.36
FFT Analysis Harmonics
(qualimetry channel only)
Harmonic
rank
100
Frequency domain
(sensor imput)
Hz
0-10K
A/D converters
Qty
2 + 3 refs
Auxiliary Channels
Type
4/20 mA, RTD150
MTBF (acc. To MIL-HDBK-217F)
khrs
>350
Weight
kg
1.2
*RECT: Rogowski Electronic Current Transformer.
52
■■
■■
■■
■■
■■
Rated supply voltage
48 Vdc (proprietary input)
connected to PC1 power
supply (48 - 350 Vdc / 100 240 Vac)
Power cons. < 10 W @ 20°C
Ambient temperature
-40°C up to 80°C
Protective index
IP64 compliant
Case material
Magnetic Stainless Steel
EMC Protection
IEC 61000-4
1,3,4,5,6,8,12,13,16 Class 3
to 5, 18
55022 Class A
Standard (instrument
transformers)
IEC 61850-9-2
IEC 61869 -1, -6, -7, -8, -9
GIS Solutions | COSI-CEVT sensor
COSI-CEVT
Capacitive Electronic
Voltage Transformers
for GIS
of the real world. In the digital chain for voltage
measurement, the COSI-CEVT uses the latest
sensor technologies in voltage measurement for
DIT applications.
Customer benefits
One single sensor design suitable for protection,
metering and qualimetry
■■ High degree of electromagnetic immunity
■■
53
Primary converter
Measure
Convert
CEVT: High-tech sensor
Less maintenance
Sensors are the basic elements of voltage
measurement. In order to achieve the best accuracy
for final measurement or protection applications,
sensors must be as accurate as possible and
protected against electromagnetic perturbations
(EMC) that exist in GIS substations.
Thanks to the particular coating on the PCBs and
highly accurate processing, the sensors are designed
to work whether conditions are optimal or not.
Sensors are designed following an ALSTOM
patent which uses a doublesided PCB (printed
circuit board) as the sensor material. This provides
excellent stability in the measurements, even
if temperature, pressure and voltages have
variations.
Several sensor designs have been introduced to
cover all types of high voltage equipment. CEVT
sensors are available for ALSTOM GIS substations.
Their small size allows them to fit into smaller
enclosures, which means smaller substations.
54
sensor allowing all calibration values to be stored
while the sensors are mounted. Thus, when a sensor
is connected to a PC12 primary converter, the
electronics automatically adjust the compensation
gains related to calibration values found in the
EEPROM. The components are therefore easily and
quickly replaced
High immunity against EMC
Based on an Alstom patent, the sensors are created
on a double-sided PCB (printed circuit board),
providing high immunity against EMC and fast
transient currents and voltages. The current analog
signal for measurement also provides perfect
immunity against nearby magnetic fields.
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
Single-phase GIS design
Three-phase GIS design (135 kV)
COSI-CEVT 420 kV
55
Ratings
Module type
Technical features
■■
PC12-3U
3 x CEVT*
Rated voltage
kV
Up to 1100
Rated current
A
-
Accuracy 50/60Hz
%
<0.05
Delay time
μs
<500
Sampled Values Output rate:
KSPS
KSPS
KSPS
4.8 /4 /5.76
4.8 /4 /5.76
14.4 /12.8 /15.36
Harmonic
rank
100
Frequency domain
(sensor imput)
Hz
0-10K
A/D converters
Qty
2 + 3 refs
Auxiliary Channels
Type
4/20 mA, RDT100
khrs
>350
Weight
kg
1.2
*CEVT: Capacitive Electronic Voltage Transformer.
56
■■
■■
■■
■■
■■
supply (48 - 350 Vdc / 100 240 Vac)
Power cons. ~ 5 W @ 20°C
Ambient temperature
-40°C up to 80°C
Protective index
IP64 compliant
Case material
EMC Protection
IEC 61000-4
1,3,4,5,6,8,12,13,16 Class 3
to 5, 18
55022 Class A
Standard
IEC 61850-9-2LE
IEC 61869 -1, -6, -7, -8, -9
GIS Solutions | COSI-RogoFlex sensor
COSI-RogoFlex
RogoFlex® electronic
current transformer
for GIS
of the real world. In the digital chain for current
measurement, the COSI-RogoFlex® uses the latest
sensor technologies in current measurement for DIT
applications.
Customer benefits
Very flexible design, allowing installation in a huge variety
of locations in the substation
■■ Higher electromagnetic immunity
■■
57
Measure
RogoFlex® :
Flexible current sensor
Sensors are the basic elements of current
measurement. In order to obtain the highest
accuracy for protection applications, the sensor
should measure the current with the best linearity
and repeatability.
It should also be protected against the
electromagnetic perturbations (EMC) found in
GIS substations.
Sensors are designed based on an Alstom patent,
using flexible polymer pipes as wiring supports with
a shielded double winding.
Thanks to their design, RogoFlex® sensors are
flexible and the length of the ‘ring’ can be calculated
for each application, depending on conductor
diameter.
58
Primary converter
Convert
These sensors are available for the entire GIS range
from 72.5 kV to 1200 kV or higher. Thanks to their
flexibility, RogoFlex® sensors can be installed in
retrofit in existing substations without designing
specific enclosures and with no need to remove
HV parts.
The sensors can be opened if needed (e.g.
inspection). The open/close mechanism is rugged
and locks the external tube.
Less maintenance
sensor, allowing all calibration values to be stored
when the sensors are mounted. Thus, when a
sensor is connected to the PC12 primary
converter, the electronics automatically adjust the
compensation gains related to calibration values
found in the EEPROM.
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
High immunity against EMC
Closed RogoFlex sensor
Based on an Alstom patent, the double wiring inside the sensor
provides immunity to EMC. Moreover, there is a metallic shield around
the windings. The signal cable uses twisted pairs and a specific shield.
COSI-RogoFlex sensor installed on
a bushing
Fixing point for RogoFlex sensors
Fixing point for RogoFlex sensors
59
Ratings
Technical features
■■
Rated current
kA
Up to 200
Accuracy error 50/60Hz
%
<1
Repeatability error
%
<1
Linearity error
IEC Class %
0.2
Resistivity (for D = 336 mm)
Ω
~10
Sensitivity*
mV/kA
48
Harmonic rank
100
Frequency domain
(sensor imput)
Hz
0-10K
khrs
>350
Weight*
kg
1.2
■■
■■
■■
*Standard values; further data is available on request
60
■■
Ambient temperature
-40°C up to 80°C
Protective index
IP64 compliant
Case material
Polymer
EMC Protection
IEC 61000-4
1,3,4,5,6,8,12,13,16 Class 3
to 5, 18
55022 Class A
Standard (instrument
transformers)
IEC 61850-9-2LE
IEC 61869 -1, -6, -7, -8, -9
GIS Solutions | COSI-PC12
COSI-PC12
Primary digital
converter for GIS
applications
Smart devices - making Smart substations part of
the real world. In the digital chain for current and
voltage measurement, the PC12 converter uses the
latest technologies to convert analog signals into
digital data to be transmitted to the merging unit
and ultimately to the protection relays and
control room.
Customer benefits
High performance and rugged design
Easy to maintain & test: off-the-shelf replacement
■■ 3-phase compact design for voltage levels up to 1,100 kV
■■ Reliable substation protection
■■
■■
61
Measure
PC12: A high-tech converter
The digitising of signal outputs from DITs is crucial
and requires state of the art electronics
using high-speed and high-accuracy components.
The PC12 is a smart converter providing high
performance and reliability. It is based on a digital
conversion unit and a digital core (FPGA:
programmable gate array) for signal treatment,
management and communication.
An analog condition circuit, digital filters and
integrator provide low noise, high linearity and
high bandwith to the converter.
Compliant with all GIS layouts and with a rugged
and compact design, the PC12 can be easily
integrated with all HV products in voltage ranges
up to 1,100 kV. The 3-phase design means only
one converter is required for a 3-phase
measurement point.
The design is particularly adapted to harsh
environments where Electromagnetic Compatibility
62
Primary converter
Convert
(EMC) can be a problem, as is the case with
GIS substations in most layouts.
Easy to maintain
Thanks to its modular concept, the replacement
of a PC12 module is as simple as an off-the-shelf
replacement.
Calibration values for sensors are included in the
sensors themselves and pre-stored in an EEPROM
memory unit before leaving the factory.
If a PC12 needs to be replaced, as soon as the new
sensor is plugged in, the calibration values are
automatically swapped to PC12 internal memory.
Several communications rates
High-speed electronics allow the simultaneous
transmission of protection, metering and
qualimetry sample value outputs according to the
IEC 61850-9.2 / 61869-9 standards.
The design meets Smart Grid requirements up to
harmonic 100 on the qualimetry channel.
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
COSI-PC12
COSI-PC12
1. Power connector
2. Led indicators (alarm & power Ok)
3. Optical fibre connector
4. Sensor connectors (from 1 to 3)
5. Auxiliary connector
6. Test connector (for commissioning)
63
Ratings
Technical features
Module type
PC12-3U
3 x CEVT*
PC12-3I
3 x REVT*
Rated voltage
kV
Up to 1100
-
Rated current
kA
-
Up to 200
Accuracy 50/60Hz
%
<0.05
<0.05
Delay time
μs
<500
<500
Sample Values
Output rate:
■■
■■
KSPS
KSPS
KSPS
4.8 /4 /5.76
4.8 /4 /5.76
14.4 /12.8 /15.36
FFT Analysis
Harmonics (qualimetry
channel only)
Harmonic
rank
100
100
Frequency domain
(sensor imput)
Hz
0-10K
0-10K
A/D converters
Qty
2
2
Internal references
Qty
3 (1 at 0.02%)
Auxiliary Channels
Type
4/20 mA,
RTD100
4/20 mA,
RTD100
MTBF (acc. To
MIL-HDBK-217F)
khrs
175
175
Weight
kg
1.2
1.2
■■
■■
*CEVT: Capacitive Electronic Voltage Transformer *RECT: Rogowski Electronic Current
Transformer.
64
■■
■■
supply (48 - 350 Vdc / 100 240 Vac)
Ambient temperature
-40°C up to 80°C
Protective index
IP64 compliant
Case material
Stainless Steel
EMC Protection
IEC 61000-4
1,3,4,5,6,8,12,13,16 Class 3
to 5, 18
55022 Class A
Standard
(instrument transformers)
IEC 61850-9-2LE
IEC 61869 -1, -6, -7, -8, -9
GIS Solutions | MU-Agile XMU800
MU Agile
XMU800
Merging unit
smart devices – making smart substations part of the
real world. In the digital chain for current and voltage
measurement, the MU-Agile 800 merges data and
signals to make them IEC 61850 compliant.
Customer benefits
Self monitored and easy to set up via webserver
■■ Many input/output ports provide compatibility with most
known GIS layouts
■■ Remote supervision of primary sensors and converters
■■
■■
65
Measure
Primary converter
Convert
XMU800: Smart, powerful
device
Compliant with GIS
architectures
As soon as the analog signals have been digitised
via the COSI-PC12, the data is sent digitally to the
MU-Agile XMU800. Several COSI-PC12s can send
their measurements to one merging unit.
The MU-Agile XMU800 design is compact, with all
the communications ports at the back of the box.
A mechanical form factor was chosen for simple
integration into a 19-inch bay.
The large number of I/O ports allows the MU-Agile
XMU800 to fulfill most GIS substation architectures
(one busbar, two busbars, one and half circuitbreakers) thanks to the 13 Ethernet ports: 10 as LC
optical connectors, 3 as RJ45.
The MU-Agile XMU800 merges all signals and
synchronises them using 1 PPS (Pulse Per Second)
input or the PTP IEEE 1588 protocol. Then, the
data is packed into one or several 61850.9-2
frames and sent to protection relays, data loggers,
smart terminals, etc. The device has a powerful
FPGA core (parallel microprocessor), creating a
real time matrix for interconnections between
HV sensors and secondary Intelligence Electronic
Devices (IEDs).
Highly communicative device
Thanks to its powerful core, the device is able to
communicate via 61850.9-2 (& 9-2 LE) and the
future IEC 61869-9, sending Sample Values (SV) to
a 9-2 network simultaneously over several ports.
It is also possible to connect another digital network
(such as a 61850.8-1 network) to check the health
of the unit or, for example, the RMS value on each
PC12 channel.
66
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
MU-Agile XMU800
User-friendly interface
A webserver integrated into the device allows users, depending
on access rights, to check the health of the unit, to change some
parameters and to display measured values on a webpage. This can be
done via any computer equipped with an internet browser.
MU-Agile XMU 800
Available ports:
Optional ports (e.g. 600044-8)
■■ 1 PPS input (a PPS output is also available for
daisy chaining for IEEE 1588 synchronisation)
■■ Ethernet input ports
■■ Power supply and alarm contact
■■ HMI Ethernet connection
■■
67
Ratings
Technical features
Unit Type
MU-Agile XMU800
Ethernet ports:
- Input (PCBUS type)
- Output (61850.9-2 type)
- HMI/8.1 connections
Qty
Qty
Qty
6
7: 4LC, 3RJ45
1 front (HMI) + 1 rear
(8.1 compliant)
PPS synchro. ports
Qty
1 In + 1 Out
Optional ports
(Compliant 44-8)
Qty
8 (4 In + 4 Out)
Auxiliary contacts
Type
Alarm NO & NC Type
MTBF
(acc. To MIL-HDBK-217F)
KHrs
150
Weight
Kg
2.7
Dimensions (mm):
- Height:
- Width:
- Depth:
mm
mm
mm
90
480
240 / 340 with optical fibre
68
■■
■■
■■
■■
■■
Option 1: 100 to 350 Vdc
+ 100 to 240 Vac
Option 2: 20 to 72 Vdc
Power cons. max. 18 W @ 25°C
Ambient temperature
-40°C up to 70°C
Protective index
IP20 compliant
Case material
Aluminium anodised (EMC)
EMC Protection
IEC 61000-4
1,3,4,5,6,8,12,13,16 Class 3
to 5, 18
55022 Class A
MU-Agile
XMU820
Analog & Digital
Merging Unit
Smart devices and Smart substations are now part
of the real world. DIT sensors, for both current and
voltage, are one of the most important components
of this new generation of GIS. The XMU820 (Analog
& Digital Merging Unit) is the ‘switchboard’ of DIT
systems, facillitating communications using the
61869 and 61850 protocols.
Customer benefits
■■ Both digital & analog CT & VT use is possible on the same unit
■■ Remote supervision of digital primary sensors and
converters
■■
■■
69
Measure
Primary converter
Convert
device
Compliant with GIS
architectures
As soon as the analogue signals have been
digitised via the PC12, the data is sent digitally to
the XMU820 merging unit. (Several PC12s can send
their measurements to one or more merging units).
The XMU820 design is compact, with all the
communications ports at the back of the XMU box.
The XMU820 merges all those digital signals and
is also able to include analog signals coming from
conventional VT & CTs and synchronises them using
the 1 PPS (Pulse Per Second) input or IEEE1588
protocol. Then, the data is packed into one or
several 61850.9-2 frames and sent to protection
relays, data loggers, Smart terminals, etc. The
device is powered by a powerful FPGA, creating a
real time matrix for interconnections between HV
Sensors (conventional and/or DIT) to secondary
IEDs.
70
integration into a 19-inch wide bay.
The large number of I/O ports allows the XMU820
to fulfill most GIS substation architectures (one
busbar, two busbars, one and half circuit-breakers)
thanks to the 13 Ethernet ports and 14 analog input
terminals which can be used as PC12 and/or CT,VT
inputs. All communication ports are designed with
standard LC- type optical connectors or RJ45 plugs.
Thanks to its powerful core, the device is able
to communicate via 61850.9-2 (& 9-2 LE)
sending Sample Values (SV) to a 9-2 network
simultaneously over several ports.
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
MU-Agile XMU820
It is also possible to connect another digital network (such as a
61850.8-1 network) to check the health of the unit or, for example,
the RMS value on each PC12 channel.
User-friendly interface
A webserver integrated into the device allows users (depending
on access rights) to check the health of the unit, to change some
done by connecting any computer equipped with an internet browser.
MU-Agile XMU 820
1. Ethernet input ports
2. Optional ports (e.g. 600044-8)
3. 1 PPS input (a 1 PPS output is
also available for daisy chaining)
4. Power supply
5. HMI ethernet connections
6. Ethernet output ports
7. Conventional VT input Terminals
(1A and/or 5A type)
8. Conventional CT input Terminals
71
Ratings
Technical features
Unit Type
Ethernet ports:
- Input (PCBUS Type)
Qty
- Output (61850.9-2 Type) Qty
or input or mirror
Qty
MU Agile XMU820
■■
6
7
■■
1 HMI/Station Bus 61850.81 compliant RJ45 or LC
■■
■■
Conventional TC inputs
Qty/
type
4 x 1A + 4 x 5A
Conventional CT inputs
Qty/
type
6 x 100/√3 V AC up to
600V AC
PPS synchro. Ports
Qty
1 In + 1 Out
Optional ports (Compliant
44-8)
Qty
8 (4 In + 4 Out)
Auxiliary Contacts
Type
Alarm NO & NC Type
MTBF (acc. To MILHDBK-217GF)
KHrs
150
Weight
Kg
7
Dimensions (mm):
- Length:
- Width:
mm
mm
- Depth:
mm
480
240 (340 with rear
connectors)
135 (3U)
72
■■
48 to 300V DC - 90 to 220V AC
Power cons. - 14 to 22 W @ 20°C
Ambient temperature
-40°C up to 60°C
Protective index
IP40 compliant
Case material
Stainless Steel
EMC Protection
610004-1,3,4,5,6,8,12,13,16
Class A
55022 Class A
GIS Solutions | BWatch3
BWatch3 system
Expert GIS and SF6
monitoring
The BWatch3 system is our expert solution for GIS
monitoring.Thanks to modern condition monitoring
systems, transmission substations can now be
monitored remotely and in real time, providing
better reliability and availability in the Smart Grid era.
Customer benefits
Asset management: schedule maintenance
Greater safety for personnel and switchgear
■■ Environmentally-friendly
■■ Quality assurance: life span extension
■■ Ergonomic and simple HMI
■■ Permanent monitoring and auto-test
■■
■■
73
Local control
cubicle
Sensors
Control monitoring unit
Customer challenge
Transmission systems and related equipment must
be designed for reliability. Energy managers require
cost effective applications and solutions to avoid
unscheduled downtimes, major failures and the
subsequent penalties.
Alstom Grid’s solution
The most effective solution to avoid potential
GIS failure is through condition based asset
management with advanced detection. The
BWatch3 system is therefore designed for accurate
and anticipated SF6 monitoring.
The BWatch3 monitoring system is a digital, open
and modular system, easy to adapt to all switchgear
types, cost effective and reliable. Optional functions
are also available, such as internal fault localisation
and circuit-breaker condition monitoring.
74
Main features
- Gas density monitoring
Gas density monitoring with immediate and
anticipated density threshold alarms, fast leakage
alarms, centralised displays of compartment status,
alarm management, protected circuit-breaker security
tripping and interlocking.
- Data management
Archival recording and displays of measurements
and events in the central monitoring unit for
switchgear condition evaluation and assistance for
diagnosis before maintenance and repairs.
Evolutive system capacities for additional functions
requiring monitoring.
- Gas temperature monitoring
Liquefaction and overheat alarms management
thanks to the temperature sensor embedded in
each transducer. The friendly mobile HMI displays
all current measurements and alarms and allows
maintenance and commissioning.
References
Internet links
Electrical wire
Ethernet fibre optic
More than 150 gas-insulated
substations around the world
are equipped with Bwatch3
representing more than 1,200
bays and 20,000 gas sensors.
Ergonomic HMI
Expert remote support
Options
-Advanced communications features
and remote access
Digital gas sensors
GIS current and stored monitoring data are available to any
authorised external PC user using high-speed ethernet links via
internet, intranet or telephone links.
- CB monitoring
Electrical wear calculation and recording
Operations counter by current ranges
■■ Travel curves recording with comparison to reference curves.
■■
■■
Mobile HMI
- Internal fault location
■■
■■
Allows quick faulty compartment location
Helps secure substation automatic reconfiguration through
interlock, even in the CB compartment (faulty and normal
operation discrepancy).
Bwatch3 sensor
75
Ratings
Units
Values
Warranted measurement scale (Full Scale)
abs Bars
0-11
1 minute overpressure withstand
abs Bars
20
Measurement resolution
FS%
<= 0.01
Long term stability
FS%
0.1
Accuracy
FS%
<=0.1
Repeativity at 25 °C
FS%
< 0.05
Endurance (0…100 % FS at 25°C)
No. of cycles
1,000,000
°C
0.1
°
90
1. Gas sensors
Pressure
Temperature
ToB Bridge temperature resolution
2. Travel sensors
Range
Independant linearity (at 20°C)
<±0.25%
3. Acquisition and process unit
Gas compartments
Gas sensors bus length
Up to 30 (3x10)
m
Up to 800
Digital ouputs
Up to 128
Digital inputs
Up to 64
Analog inputs
Up to 16
Density sets
Up to 8
Pressure acquisition cycle time
ms
300
Temperature acquisition cycle time
min
1
Density calculation cycle time
s
2
Leakage advanced alarm forecast time
days
90
Gas sensors communication speed
bytes/s
115,000
LVCC touch panel communication speed
bytes/s
19,200
Distributed Control System communication speed
bytes/s
9,600
4. Central Monitoring Unit
Gateway
Up to 4
Bays by gateway
Up to 12
Event records
Infinite
Density records
Infinite
76
System composition
1. Digital gas sensors with separated pressure and temperature measurements, daisy chained in field bus
on each bay. Sensors for HV current and and CB operation curve available as options.
2. Programmable logic controller implemented in the low voltage control cubicle of each bay, with I/O and
communications modules.
3. Central unit, which is dedicated to display measurements and alarms, to record events and trends and to
communicate the data to users. CB operation curve available as options.
4. A LVCC touch panel HMI, which is an independent unit, manages the display of current monitored values
and alarms that it is able to read directly from the APU’s* memory.
(*Aquisition and Process Unit)
Technical Features
EMC Protection
IEC 61004-2,3,4,5,6,8,10,12 Class 3 to 5
55022 Class A
Standard
Gateway
APU
Gas sensors
Travel sensors
Low temperature
IEC 60068-2-1
-40°C
-40°C
-40°C
-20°C
Dry heat
IEC 60068-2-2
55°C
55°C
110°C
80°C
Protection index
IEC 60068-2-30
IP20
IP20
IP68
IP65
Climatic withstand
Mechanical withstand
Shocks
IEC 60068-2-27
15 g
25 g
25 g
40 g
Vibration
IEC 60068-2-6
1 g / 10 - 150 Hz
1 g / 10 - 150 Hz
1 g / 10 - 150 Hz
10 g / 10 - 150 Hz
77
78
GIS Solutions | PDWatch
Online PDWatch
Online partial
discharge monitoring
for GIS
The UHF PDWatch online monitoring system
records and displays the UHF signals generated
by partial discharges in a GIS. Thanks to modern
condition monitoring systems, transmission
substations can now be monitored remotely and in
real time, providing better reliability and availability
in the Smart Grid era.
Customer benefits
Predict potential faults
■■ External noise discrimination
■■ Superior reliability and auto-test
■■ Ergonomic and simple HMI
■■ Expert support available
■■
79
Sensors
PD Panel
System composition
External noise discrimination
1.A set of UHF modules, which are dedicated to
signals acquisition and pre-treatment.
In order to avoid spurious alarms, signals generated
by real partial discharges must be distinguishable
from external noises: the detection of UHF signals
is based on calculations of spectrum key features,
such as average and variance.
2.A central unit dedicated to recording the signals,
generating alarms and displaying data to users.
Predict potential faults
The system is permanently fitted into the substation
and can be queried remotely. Thanks to this system,
developing dielectric faults can be detected and
eliminated before complete breakdown occurs.
Used with suitable couplers, this system can detect
all critical defects such as particles, coronas, free
potentials and insulator voids at the sensitivity
specified by CIGRE TF 15/33.05.03.
The link between the UHF modules is ensured by
a 100 Mbit/s ethernet network with self-healing
features, providing greater reliability.
80
The key features are calculated by placing specific
masks on the spectrum to exclude the known
externally disturbed frequency bands. This
possibility is not currently offered by broadband
systems using thresholds on analog signals.
A clever algorithm validates an event generated
by a threshold on the mean and variance of the
spectrum by making an analysis of signals on
internal and external noise sensors.
Internet links
Electrical wire
Ergonomic HMI
UHF coupler for external noise
discrimination
Short and long term analysis
A trend curve shows the evolution of the UHF signals level inside the
GIS over the short and long term. It is very useful for risk
assessment because the UHF signals level is not fully linked to the
partial discharge level (due to factors such as the kind of defect or
the distance to coupler,). This evolution of UHF activity is crucial to
the determination of the defect’s severity.
PDWatch sensor
A single HMI with monitoring
The HMI shows the Single Line Diagram with gas compartments
and PD couplers. It is thus common to both PD monitoring and SF6
density monitoring, avoiding the need for multiple HMIs. This tool also brings
important time savings thanks to automatic test report generation.
PD-Box
Auto-test function
The status of the complete system is continuously checked, including
the couplers: the HMI displays an indication if a UHF module is out of
order, if a UHF coupler is disconnected or if a synchronisation signal is absent.
Acquisition Box
81
Ratings
Technical features
UHF modules
■■
6 inputs for PD couplers (N type sockets)
■■
■■
Amplitude resolution: 256 amplitude levels
Overall signal range: - 100 dBm to - 10 dBm
Spectrum analysis
■■
■■
UHF spectrum bandwidth: 300 to 1200 MHz
UHF spectrum resolution: 2.5 MHz
Time analysis
■■
■■
Time resolution: 20 μs at 50 Hz / 16.7 μs at 60Hz
Band-pass filtering on central frequency during acquisitions
Coupler test through UHF cable
3 possibilities of synchronisation signal: main supply, voltage
transformer, capacitive coupler
Versatile layout: Integration in GIS control cubicles or in
stand-alone boxes
Network
■■
■■
Ethernet 100 Mbits/s between PC and measuring units
IEC 61850-8-A compliant
Operational limits
Temperature: -250C to 550C
Protection: IP54 or IP66
■■ EMC compliant (electronics completely protected)
■■
■■
82
Mains supply
■■ 48 Vdc – 15% to 250 Vdc
■■ 110/240 Vac +/- 20%
■■ Power consumption: 20 W
per UHF module
■■ Central unit: PD-Panel:
■■ Industrial PC:
■■ Fanless, without moving
parts
■■ Touch screen 17”
■■ Processor: Core II duo,
1.5 GHz
■■ Memory: 2 GB, DDR
■■ Hard disk capacity:
80 GB Flash (SDD)
■■ Long duration storage
with external HDD
■■ OS: XP Embedded
■■ MODEM
■■ For digital lines
■■ For G3 links (on request)
■■ Possible integration with SF6
monitoring BWatch3
GIS Solutions | RPH3
RPH3
Point on Wave
switching
Optimising the closing and opening of a circuitbreaker is of the utmost importance because
random switching can result in high transient
overvoltages and/or high inrush currents. These
transients generate stresses on all substation and
network equipment, leading to accelerated aging
- or the worst case scenario - flashover of the HV
apparatus.
Customer benefits
Eliminate switching transients
Reduce stress, overvoltages and inrush currents on
electrical networks
■■ Increase lifetime of HV equipment
■■ Enhance power system security
■■ Support operations and maintenance
■■ IEC 61850-9-2 compliant
■■
■■
83
Sensors CB drive
(Spring or Hydraulic)
Controlled switching of
high voltage circuit-breakers
The RPH3 is an advanced microprocessor-based
synchronising relay suitable for Independent pole
operated circuit-breakers. More commonly referred
to as a Point-on-Wave controller, it protects high
voltage network components from transients
generated during switching operations.
Thanks to the RPH3’s sophisticated algorithms,
the operation of the circuit-breaker is configured
to reduce stress in all conditions and network
configurations.
Random switching operations on high voltage
networks cause electrical transients that stress
equipment and degrade power quality.
The way to deal with switching transient
phenomena is to act efficiently on their root-causes.
Eliminate random switching and replace these
practices with a controlled switching strategy - or
“point-on-wave” switching.
Point-on-wave controlled switching consists of
84
Synchronous
switching relay
issuing switching commands to the circuit-breaker
at the optimal point on the reference voltage
waveform. Thanks to its electronics and software,
the RPH3 point-on-wave controller effectively sends
a switching command to the circuit-breaker to
operate at the correct instant, thus eliminating or
substantially reducing transients.
Perfect matching with the
circuit-breaker under control
Success of controlled switching operations depends
on the ability of the RPH3 controller relay to assess
beforehand the reference synchronising voltage, as
well as the characteristics and the consistency of
circuit-breaker operations under all operating and
ambient conditions.
To optimise the performance of the RPH3 in its
controlled switching operations, the relay can be
programmed according to network and circuitbreaker operational characteristics.
Thanks to the permanent monitoring of the circuitbreaker’s parameters and the sophisticated adaptive
Internet links
Electrical wire
Ergonomic HMI
RPH3
control routines, the RPH3 enables a reliable and accurate control
over the behaviour of the device, thus permitting optimal switching
sequences.
Advanced communications features and
user friendly interfaces
With its integrated memory and communications ports, the RPH3
records switching parameters and communicates the results of
controlled switching operations.
An embedded web server for the machine interface allows:
Real-time information on the RPH3 device & application status
■■ Configuration of parameters needed for controlled switching
applications
■■ Retrieval of switching archives and data from RPH3 devices
■■
DIT for current measurement
The web server program operates by accepting HTTP requests from
the client via a standard web browser.
The ‘RPH3 Manager’ dedicated software allows the analysis of
archive records stored in the RPH3 relay in service and can perform
data evaluations of controlled switching operations.
GIS 550 kV circuit-breaker
85
Functionalities
Technical features
Switching applications
■■
Capacitor banks
■■
Reduce overvoltages and eliminate
inrush current
■■ Switch in at zero voltage
Shunt reactors
■■
Power transformers
■■
Reduce overvoltages and prevent current
chopping and re-ignition
■■ Switch out with medium arcing time
■■
Transmission lines
(uncompensated
and shunt reactor
compensated)
Eliminate inrush current
Switch in under conditions where
residual flux is minimal
Limit overvoltages while energising
or re-closing
■■ Switch in at zero voltage across circuitbreaker poles
■■
Advanced features
■■
■■
86
Digital interface via ethernet 100 Mbit/s
Open for 61850-9.2 protocol
Temperature : -25°C to +55°C
EMC compliant (electronics
completely protected)
■■ Mains supply
■■ 48 Vdc – 15% to 250 Vdc
■■ 110/240 Vac +/- 20%/5060 Hz
■■ Power consumption: < 20 W
■■ Solid state control of breaker
coils
■■ 48 V= / 250 V=
■■ 10 A – 300 ms / 15 A –
200 ms
■■ Alarm relays operating range:
230 V= / 5 A
■■ Reference synchronising
voltage:
15 – 330 V~ (20-60 Hz)
■■ Switching time resolution:
0.1 ms
■■ Control voltage (auxiliary)
■■
GIS Solutions | Service
GIS Service
solutions
87
Improve equipment availability
through SF6 monitoring
SF6 leakages are the first root causes of the minor failures in GIS, due to sealing technologies of the interfaces and
ageing of the material. Maintenance and monitoring functions are the key solutions for keeping the substations in
good operating conditions.
In addition, looking forward to protecting the environment from the global warming, many regulations are
increasing the level of requirements pertaining to SF6 leakages in high-voltage equipment.
Digital GIS substation
From a standardised technical solution to a
tailored application on existing assets, our Service
engineering departments can propose retrofit
solutions to install the BWatch system to all existing
substations, either Alstom or third-party branded.
The sensor installation, cabling and low-voltage
cubicle upgrades can be performed during
scheduled maintenance or overhaul.
Expertise and consulting
Our experts are available for customer data
interpretation and analysis. Several options for
data collection and transmission are available, from
remote online access to manual file exchange. This
consultancy can be provided on an on-call basis and
on a contractual frequency basis.
All the BWatch data are applicable to the Asset
Health Index (AHI) of our asset management solution,
supporting customer asset management policies.
88
GIS Solutions | Service
Monitoring dielectric condition
Partial discharges are the key indicators of highvoltage equipment dielectric condition.
The assessment of the GIS dielectric condition is
one of the major conditions to reach the level of
Reliability Centred Maintenance (RCM), combining
the advantages of time based maintenance and
those of condition monitoring.
Retrofitting GIS Substations
with new sensors
The use of several types of sensors allows our
experts to define the optimum comprehensive
retrofit solution for most installed GIS substations.
The sensor installation, cabling and low-voltage
cubicles upgrades and signal calibration can be
performed during scheduled maintenance or
overhaul.
The UHF method used along with all PDWatch
features and options, allow maximum leveraging
the GIS condition and improve lifetime expectancy
of the existing assets.
89
GIS Solutions
GIS conclusions
Alstom Grid’s digital substation solutions offer a range of market leading benefits for
GIS operations. These include:
■■ GIS product range from 72.5 to 800 kV
■■ Integration with our complete range of state-of-the-art digital hardware, software
and communications products
■■ Increased reliability and availability delivered through extensive
self-diagnostic abilities
■■ Improved safety, through innovations and self monitoring
■■ Investment optimisation delivered through reduce space requirements, service and
maintenance scheduling, and asset optimisation
■■ Global footprint, local service.
90
AIS Solutions
91
92
AIS Solutions
Digital solutions
for AIS
With more than 100 years of experiences in High
voltages switchgear, Alstom is the leader on the
Air Insulated substation market. Our leadership is
largely thanks to our complete product portfolio
from 72.5 kV up to 1200 kV.
A leader in the field of High Voltage equipment,
Alstom has delivered and commissioned more
than 10,000 of each key element of a substation
(Circuit-breaker, Disconnectors and Instrument
Transformers) worldwide.
Thanks to recent progress in electronics, in
information technology and in new communication
protocol standards, Alstom has developed and
put into service a new generation of Air Insulated
equipment such as Instrument Transformers, which
allow real time information input from modern
sensors and complete interoperability. Digital
substations are able to meet a whole new set of
expectations.
93
Our mission statement
Alstom Grid provides essential equipment from 72.5 kV
up to 1200 kV, to secure and optimise transmission of the
electricity from generation to consumption with a full range
of Circuit-breakers, Disconnect Switches and Instrument
Transformers.
We offer:
Full product portfolio up to 1200 kV
■■ High performance range
■■ First class spring mechanism
■■ Solution to ensure the operational reliability of self-monitoring equipment
■■
94
AIS Solutions
AIS Solutions
Fact sheets
Digital Instrument Transformers - DIT
COSI-sensors
■■ COSI-CT
■■ COSI-CT F3
Primary converter
■■ COSI-PC13
Merging unit
Monitoring and control
SF6 and AIS monitoring
■■ CBWatch-2
Partial discharges monitoring
■■ DWatch
Point-on-wave switching
■■ RPH3
95
AIS digital substation overview
Alstom, the worldwide market leader in Air
Insulated Switchgear, offers all the advantages
of the new generation of AIS digital substation
solutions.
Alstom offers you a state-of-the-art Air Insulated
product portfolio, combined with advanced
substation automation solutions.
96
AIS Solutions
97
AIS Solutions
Digital instrument
transformers
The new generation of AIS digital substation solutions bring
unprecedented levels of reliability, security and performance through
real-time monitoring, automation and interoperability. Integrating
high performance primary equipment including Alstom’s COSI
(COmpact Sensor Intelligence) and advanced substation automation
solutions. Information acquisition, processing and output is treated
in real-time through a digital architecture with multiple layers of
automation units.
Monitoring and controls
Our range of digital instrument transformers provide measurement
using optical, Rogowski or capacitive technology, which have been
optimised for operation with AIS equipment, integrating into the
relevant switchgear to provide accurate real-time measurement of key
operational parameters.
98
AIS Solutions | COSI-CT
Fact sheet – DIGITAL INSTRUMENT TRANSFORMERS
COSI-CT
Optical Current
Transformer
Our comprehensive COSI range (COmpact Sensor
Intelligence) includes innovative digital instrument
transformers for AC and DC applications. The
COSI-CT optical current sensor brings a new level of
accuracy to sensing over the range between 1 A rms
and 63 kA rms.
Customer benefits
Improved measurement performance
Significant system cost reduction
■■ Environmentally friendly
■■ World-wide standard for Interconnection
■■ Reliability, availability, safety
■■ Light weight
■■ One device only – not multiple CTs
■■
■■
99
Performance
features
Accuracy exceeds ANSI/IEEE
Class 0.15S/IEC Class 0.2S for
metering and IEC Class 5P/
IEEE 10% for protection
■■ Wide dynamic range
■■ Bandwidth from DC to 100th
harmonic
■■ No magnetic core saturation
■■ Excellent phase accuracy
■■ Digital Interface and analog
output
■■ DC / AC without calibration
■■
The reduced size and weight are attractive benefits compared to
conventional oil-filled equipment, allowing placement in compact
substations or in retrofit applications where space may be limited.
A lightweight dry-type insulator and window head design allow
pedestal mounting or suspension from a rigid bus.
Its broad dynamic range makes this CT particularly suited for both
high-precision metering and protection applications at the same time.
The accurate measurement of DC and AC to the 100th harmonic
and the measurment of phase angle is a must for new Smart Grid
applications.
The standard digital interface will ensure smooth integration of COSICT in the digital substation application.
100
Intrinsically safe,
environmental
friendly
No oil, gas or SF6
No hazardous open secondaries
■■ No violent failure
■■
■■
Smart Solutions for Smart Grid
Fast fault response
Extreme fast and accurate
response
■■ COSI-CT actually measures the
dynamic current
■■ No distortion due to core
saturation, no need for TPY TPZ specs, yet no danger for
secondary equipment
■■
40 000
20 000
0
Basic Faraday effect
In Faraday Effect current sensors; the current flowing through a
conductor induces a magnetic field that affects the propagation of
light traveling through an optical fibre encircling the conductor.
A linear state of polarization rotates in the presence of a magnetic
field because the field produces a circular birefringence in the glass.
Birefringence refers to an optical material with two indices of refraction.
Current (A)
-20 000
-40 000
-60 000
-80 000
-100 000
-200 000
1200
1600
Time (arb.)
CT
Ref
2000
2400
Metering and protection accuracy
The COSI-CT design permits measurements to be made with the
highest possible accuracy and stability. To address stringent revenue
metering applications, its performance exceeds IEC Class 0.02S and
IEEE Class 0.3 accuracy (optional 0.15%) with a dynamic range that
extends from 1 A to 5000 A.
The COSI-CT has ultra-accurate and stable phase measurement, which
is critical for intertie metering. For protection applications, the COSI-CT
exceeds IEC Class 5P accuracy ratings and IEEE 10% accuracy ratings.
101
Wide dynamic range
Choice of connection option
Accuracy specification is
maintained over a broad dynamic
range - from 0.2% to 150% of rated
current (extended metering range
sensor) and up to 171 kA (protection
range sensor). Broad dynamic range
allows elimination of separate
high and low range CTs.
New window head design allows a variety of
connection options including standard NEMA pads,
up to 300 mm rigid bus, or flexible cable pass
through, allowing optimal selection for ease of
installation and reliability.
Wide bandwidth
Accurate waveform reproduction up to 6 kHz
allows full power quality analysis of harmonics and
transients with no sensor-imposed limitations.
Dry type insulator
seismic stable
Field-proven lightweight composite
insulator reduces transportation
costs, substation support structure
requirements, and installation
equipment demands.
The lightweight design also allows location
in seismically active areas.
Green design
The COSI-CT insulator contains no oil, SF6 or
other gas. There is no internal mechanism for
violent failure to endanger personnel or adjacent
equipment. There are no environmental concerns or
gas to recycle. With an optical design there are also
no open secondary concerns.
Low maintenance
The COSI-CT has no active components at line
potential, eliminating the need for costly outages to
maintain the electronics. Since there is no insulating
oil or paper there are no complex maintenance
procedures. The polymeric insulating column
employs silicone rubber sheds that do not require
liveline washing.
Smart Grid ready with digital
interface
The standard digital interface will ensure smooth
integration of COSI-CT into digital substation
applications the accurate measurement of harmonics
and phase angle is a must for new Smart Grid
applications.
102
Specifications
COLUMN MECHANICAL & ELECTRICAL Ratings
CT Type
72.5
123
145
245
362
420
550
800
72.5
121
145
245
362
420
550
800
350
550
650
1050
1300
1550
1800
2100
57
1400
115
2900
115
2900
193
4900
285
7240
562
14280
562
14280
562
14280
54.7
1389.4
54.7
1389.4
77.91
1978.9
107.44
2729
127.13
3229.1
204.71
5199.6
204.71
5199.6
204.71
5199.6
kg
75
34
88
40
88
40
111
50
124
56
177
80
177
80
177
80
lbs
N
675
3000
675
3000
675
3000
900
4000
Suspension application only
Maximum system
Voltage (Um)
kV
Impulse test voltage
(BIL))
kV
Minimum creepage
distance
in
mm
Height
in
mm
Weight
Static Withstand
lbs
Suspension application only
Ratings and dimensions for IEC pollution Class 2. Other ratings are available.
Environmental
Operating Temperature Range
- 40° C to 55° C (- 40° F to 131° F) Outdoor Service Conditions
Opto-Electronic Module
- 5° C to 40° C (23° F to 104° F) Indoor Service Conditions
Seismic Capability
0.5 g
Mechanical
Standard Pollution Withstand
IEC Level II, other ratings available
Insulation
Solid composite insulator
Electronics Dimensions
19’’ x 18’’ x 8.75’’ (482 mm x 457 mm x 222 mm)
(includes high energy metering interface)
103
Specifications continued...
Electronics
Packaged in 2 modules:
Low Energy Analog Interfaces1
< 0.2% error at rated current for 4V output,
< 0.5% error at rated current for 200 mV output
Dynamic Range
< 2% error at 108 kApeak (using protection
sensor)
Sensor Electronics
Bandwidth
0.5 Hz to 6 kHz DC available
High Energy Analog Interfaces
1 Arms [2 ohm burden] or 5 Arms [B0.1 (2.5 VA)
burden] nominal at power 0.9 for metering
Dynamic Range
< 0.2% error from 1 A to 4000 A (using extended
metering range sensor)
Bandwidth
10 Hz to 6 kHz for 1 A metering output
Input Power Requirements
70 Vdc to 150 Vdc
1
Current Amplifier/Power Supply
4 Vrms metering
200 mVrms protection
Typical power 60 W
Electronic Turns Ratio
Electronic Turns Ratio
Alarms Contacts
Data invalid / Maintenance required
ElectrICAL PERFORMANCE
Type I3:
Type II3:
Metering Accuracy
IEC Class 0.2S, IEEE Class 0.3, 0.15S
Protection Accuracy
IEC Class 5P, IEEE 10%
Extended Range Std Metering Accuracy
0.2% (0.2% to 150% of rated current)2
Extended Range High Metering Accuracy
0.15% (0.2% to 150% of rated current)2
Continuous Current
4800 A Max (4800 A, RF = 1; or 3000 A, RF = 1.33;
or 2500 RF = 1.5)
Rated Current
User specified for up to 4000 A
Short-time Thermal Current
63 kArms for 1 s
Type II3:
1 Scales linearly with primary voltage and current. / 2 Accuracy window moves with selected ratio. / 3 Other ratings available, consult Alstom Grid.
104
AIS Solutions | COSI-CT F3
Fact sheet – DIGITAL INSTRUMENT TRANSFORMERS
COSI-CT F3
Flexible Optical
Current Transformer
Our comprehensive COSI range (COmpact Sensor
Intelligence) includes innovative digital instrument
transformers for AC and DC applications. The COSICT F3 optical current sensor is the most flexible,
portable optical current transformer sensor available
and the easiest to install.
Customer benefits
Flexible Form Factor
Easy installation and configuration
■■ Improved measurement performances
■■ On-site calibration tool
■■ World-wide standard for interconnection
■■
■■
105
Three product types are available, Type A, Type B, and Closed Loop,
each optimised for different applications and specifications.
Each F3 has a wrap-around sensing head around high-voltage
bushings, generator buses, and other conductors in ways not possible
with conventional Current Transformers.
The sensing loop is an all-dielectric cable, which connects to the
standard electronics, giving the user the same high
performance capability and output options as the high-voltage optical
CT. It is an ideal solution for retrofit applications and installations in
difficult spaces, on a temporary or permanent basis.
Type A F3 Current Transformer
The type A F3 CT is a fibre optic current sensor consisting of an
electronics module, a fibreglass sensor box, and a flexible PVC conduit
wrap-around sensing cable.
The sensing fibre resides in the PVC conduit, which attaches directly to
the sensor box.
Standard telecommunications optical fibre cabling and wire cabling
connect the electronics module to the sensor box. Because the sensor
box has a wire connection to the electronics, it should not be installed
in a high-voltage environment.
However, it may be installed in a low-voltage environment, allowing
the sensing cable to be wrapped around a high-voltage bushing.
106
Flexible Form Factor
The type A F3 CT has metering
grade accuracy to 0.15%, and it
can measure both AC and DC
currents with this accuracy from
1 A to 160 kA, depending on the
number of sensing cable wraps
used to measure the current.
COSI-CT F3 installed on AIS bushing
Undersea cable metering
& protection
Type B F3 Current Transformer
DC valve hall wall bushing
The cable length between the
electronics module and the
sensor box can be up to one
kilometer. The sensing cable has
a standard length of 20 m, but
other lengths may be specified at
the time of order.
The output of type A F3 CT can
be analog with 1 A or 5 A for
metering application or digital
for metering and protection
applications.
■■
The type B F3 CT is a fibre optic current sensor consisting of an
electronics module, a fibreglass sensor box, and a flexible PVC conduit
wrap-around sensing cable.
The sensing fibre resides in the PVC conduit, which attaches directly
to the sensor box. Standard telecommunications optical fibre cabling
connects the electronics module to the sensor box.
In the type B sensor, no wire connection is required at the sensor box,
allowing it to be installed in a high-voltage environment.
The type B F3 CT is a protection grade sensor with accuracy to 1%. It
measures AC currents over a bandwidth of 10 Hz to 3 kHz and can
cover a range from 1 A to 160 kA, depending on the number of
sensing cablewraps used to measure the current.
Applications include metering
and protection, wrap-around
bushing for metering or
protection, DC valve hall
measurements for metering
and protection, and very large
aperture applications.
Sensor box
107
Measuring current at an
overhead to underground
line transition
Closed Loop F3 CT
The Closed Loop F3 CT is a fibre optic current sensor
consisting of an electronics module, a fibreglass
sensor box, and a flexible PVC conduit wrap-around
sensing cable.
The sensing fibre resides in the PVC conduit which
attaches directly to the sensor box. Standard
telecommunications optical fibre cabling and wire
cabling connect the electronics module to the
sensor box. However, it may be installed in a lowvoltage environment allowing the sensing cable to
be wrapped around a high-voltage bushing.
Underground Power Line Protection
The cable length between the electronics module
and the sensor box can be up to 10 km. The sensing
cable has a standard length of 20 m, but other
lengths may be specified at the time of order.
The output of the type B F3 CT can be an analog
voltage (11.3 V full scale), a current (1 A or 5 A
formats), or digital (IEC61850).
■■
Applications include protection, wrap-around
bushing for protection, temporary field service
measurements, and underground cable
monitoring.
The underground cable monitoring application
uses sensors at both ends of the underground
line to measure the differential current. When
the underground cable is in good condition,
there is little to no difference between the two
measured currents. But, when the cable between
the two sensors has faulted, there is a substantial
differential current.
Because the type B F3 CT sensor box can be placed
up to 10 km away from its associated electronics,
this line differential currentprotection scheme can
be implemented at remote sites where there is
no substation or power available (such as an
overhead to underground line transition).
108
0.1% class Closed Loop F3 metering CT for DC valve hall
The Closed Loop F3 CT uses a current feedback to
null the impact of the sensed current on the sensing
cable. As a result, the Closed Loop F3 CT achieves
accuracies Cl 0.1. Both AC and DC currents are
measured from 1 A up to >500 kA.
The distance between the electronics module and
the sensor box is limited to 100 m. The sensing
cable has a standard length of 20 m, but other
lengths may be specified at the time of order. The
output of the Closed Loop F3 CT can be an analog
voltage (11.3 V full scale), a 1 A current, or digital
(IEC 61850-9.2).
■■
Applications include protection, wrap-around
bushing for protection, temporary field service
measurements, and underground cable
monitoring.
Current Transformer specifications
■■
■■
Single phase, three phase, and six phase system
configurations available
■■
Sensor enclosure; fibreglass box;
-Type A and Type B:Dimensions: 355 x 304 x 145 mm
Weight: 9 Kg
IP66
-Closed Loop F3: Dimensions: 406 x 355 x 145 mm
Weight: 20 Kg
IP66
F3 CT
■■
■■
20-meter length wrap-around sensing fibre
standard, other lengths available on request
Programmable output scaling
Output format options: analog voltage (IEC
60044-8 200 mV and 4 V formats), current (1 A
or 5 A metering format), digital (IEC 61850-9.2)
Type A
Type B
Closed Loop
Class 1
x
Class 15s
x
x
Class 2s
x
x
Class 3
x
x
Class 1
x
Class 5
x
AC
x
(up to 20 kHz)
DC
x
AC/DC
x
Sensor box HV isolated
Max distance between electronics and sensor
x
(10 Hz to 3 kHz)
x
(up to 20 kHz)
x
x
x
1 km
10 km
(no repeater)
Fibre cable required
x
x
Copper cables required
x
100 km
x
x
109
APPLICATIONS
Bushing
Type A
Type B
Closed Loop
x
x
x
Currents > 160 kA
x
AIS
x
x
Calibration
x
Field service
x
x
Metering
x
Protection
x
x
Cable monitoring
x
x
x
x
x
Rated current range vs. number of fibre wraps
# of fibre wraps
Minimum rated current*
Max rated current*
1
2000 A
80 kA
2
1000 A
40 kA
5
400 A
16 kA
10
200 A
8 kA
20
100 A
4 kA
*F3 maintains accuracy class from 1% to 200% of rated current.
110
AIS Solutions | COSI-PC13
Fact sheet – AIR insulated substations
COSI-PC13
Primary digital
converter for AIS
applications
Smart devices - making Smart substations part of
the real world. In the digital chain for current and
voltage measurement, the PC13 converter uses the
latest technologies to convert analog signals into
digital data to be transmitted to the merging unit
and ultimately to the protection relays and
control room.
Customer benefits
Easy to maintain & test: off-the-shelf replacement
■■ 3-phase compact design for voltage levels up to 1,200 kV
■■ Reliable substation protection
■■
■■
111
Primary converter
Measure
PC13: A high-tech converter
The digitising of signal outputs from DITs is crucial
and requires state of the art electronics
using high-speed and high-accuracy components.
The PC13 is a smart converter providing high
performance and reliability. It is based on a digital
conversion unit and a digital core (FPGA:
programmable gate array) for signal treatment,
management and communication.
An analog condition circuit, digital filters and
integrator provide low noise, high linearity and
high bandwith to the converter.
Compliant with all AIS layouts and with a rugged
and compact design, the PC13 can be easily
integrated with all HV products in voltage ranges
up to 1,100 kV. The 3-phase design means only
one converter is required for a 3-phase
measurement point.
The design is particularly adapted to harsh
environments where Electromagnetic Compatibility
112
Convert
(EMC) can be a problem, as is the case with
AIS substations in most layouts.
Easy to maintain
Thanks to its modular concept, the replacement
of a PC13 module is as simple as an off-the-shelf
replacement.
Calibration values for sensors are included in the
sensors themselves and pre-stored in an EEPROM
memory unit before leaving the factory.
If a PC13 needs to be replaced, as soon as the new
sensor is plugged in, the calibration values are
automatically swapped to PC13 internal memory.
Several communications rates
High-speed electronics allow the simultaneous
transmission of protection, metering and
qualimetry sample value outputs according to the
IEC 61850-9.2 / 61869-9 standards.
The design meets Smart Grid requirements up to
harmonic 100 on the qualimetry channel.
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
COSI-PC13
113
Ratings
Technical features
Module type
PC13-3U
3 x CEVT*
PC13-3I
3 x RECT*
Rated voltage
kV
Up to 1100
-
Rated current
kV
-
Up to 200
Accuracy 50/60Hz
%
<0.05
<0.05
Delay time
μs
<500
<500
Sample Values
Output rate:
■■
■■
kHz
kHz
kHz
4.8 /4 /5.76
4.8 /4 /5.76
14.4 /12.8 /15.36
■■
■■
FFT Analysis
Harmonics (qualimetry
channel only)
Harmonic
rank
100
100
Frequency domain
(sensor imput)
Hz
0-10,000
0-10,000
A/D converters
Qty
2
2
Internal references
Qty
3 (1 at 0.02%)
Auxiliary Channels
Type
4/20 mA,
PT100
4/20 mA,
PT100
MTBF (acc. To
MIL-HDBK-217F)
khrs
175
175
Weight
kg
1.2
1.2
*CEVT: Capacitive Electronic Voltage Transformer *RECT: Rogowski Electronic Current
Transformer.
114
■■
■■
supply (48 - 350 Vdc / 100 240 Vac)
Ambient temperature
-40°C up to 80°C
Protective index
IP64 compliant
Case material
Stainless Steel
EMC Protection
IEC 610041,3,4,5,6,8,12,13,16 Class 3
to 5
55022 Class A
Standard
IEC 61850-9-2LE
IEC 61869 -1, -6, -7, -8, -9
AIS Solutions | MU-Agile XMU820
MU-Agile
XMU820
Analog & Digital
Merging Unit
Smart devices and Smart substations are now part
of the real world. DIT sensors, for both current and
voltage, are one of the most important components
of this new generation of AIS. The XMU820 (Analog
& Digital Merging Unit) is the ‘switchboard’ of DIT
systems, facillitating communications using the
61869 and 61850 protocols.
Customer benefits
■■ Both digital & analog CT & VT use is possible on the same unit
■■ Remote supervision of digital primary sensors and
converters
■■
■■
115
Primary converter
Measure
Convert
device
Compliant with AIS
architectures
As soon as the analogue signals have been
digitalised via the PC13, the data is sent digitally to
the XMU820 merging unit. (Several PC13s can send
their measurements to one or more merging units).
The XMU820 design is compact, with all the
communications ports at the back of the XMU box.
The XMU820 merges all those digital signals and
is also able to include analog signals coming from
conventional VT & CTs and synchronises them using
the 1 PPS (Pulse Per Second) input or IEEE1588
protocol. Then, the data is packed into one or
several 61850.9-2 frames and sent to protection
relays, data loggers, Smart terminals, etc. The
device is powered by a powerful FPGA, creating a
real time matrix for interconnections between HV
Sensors (conventional and/or DIT) to secondary
IEDs.
116
integration into a 19-inch bay.
The large number of I/O ports allows the XMU820
to fulfill most AIS substation architectures (one
busbar, two busbars, one and half circuit-breakers)
thanks to the 13 Ethernet ports and 14 analog input
terminals which can be used as PC13 and/or CT,VT
inputs. All communication ports are designed with
standard LC- type optical connectors or RJ45 plugs.
Thanks to its powerful core, the device is able
to communicate via 61850.9-2 (& 9-2 LE)
sending Sample Values (SV) to a 9-2 network
simultaneously over several ports.
important note:
solution.
Merging unit
Merge
IEC 61850
Protection relay
Protect
MU-Agile XMU820
It is also possible to connect another digital network (such as a
61850.8-1 network) to check the health of the unit or, for example,
the RMS value on each PC13 channel.
User-friendly GUI (Graphic User Interface)
A webserver integrated into the device allows you (depending on
rights and privileges) to check the health of the unit, to change some
done by connecting any computer equipped with an internet browser.
MU-Agile XMU 820
1. Ethernet input ports
2. Optional ports (e.g. 600044-8)
3. 1 PPS input (a 1 PPS output is
also available for daisy chaining)
4. Power supply
5. HMI ethernet connections
6. Ethernet output ports
7. Conventional CT input Terminals
(1A and/or 5A type)
8. Conventional VT input Terminals
117
Ratings
Technical features
Unit Type
Ethernet ports:
- Input (PCBUS Type)
Qty
- Output (61850.9-2 Type) Qty
or input or mirror
Qty
Conventional TC inputs
MU-Agile XMU820
■■
6
7
■■
1 HMI/Station Bus
61850.8-1 compliant RJ45
or LC
Qty/
type
4 x 1A + 4 x 5A
Conventional VT inputs
Qty/
type
6 x 100/√3 V AC up to
600V AC
PPS synchro. Ports
Qty
1 In + 1 Out
Optional ports (Compliant
44-8)
Qty
8 (4 In + 4 Out)
Auxiliary Contacts
Type
Alarm NO & NC Type
MTBF (acc. To MILHDBK-217GF)
KHrs
150
Weight
Kg
7
Dimensions (mm):
- Length:
- Width:
mm
mm
- Depth:
mm
480
240 (340 with rear
connectors)
135 (3U)
118
■■
■■
■■
48 to 300V DC - 90 to 220V AC
Power cons. - 14 to 22 W @ 20°C
Ambient temperature
-40°C up to 60°C
Protective index
IP40 compliant
Case material
Stainless Steel
EMC Protection
610004-1,3,4,5,6,8,12,13,16
Class 3 to 5
55022 Class A
AIS Solutions | CBWatch-2
Fact sheet – AIS SOLUTIONS
CBWatch-2
Modular circuitbreaker monitoring
system
Substation equipment life management is of
key importance - and one of the best ways to
accurately supervise your network is through an
efficient monitoring system. Alstom has developed
the CBWatch-2 monitoring system which can be
your proactive link to cost-effective circuit-breaker
management.
Customer benefits
Optimised, proactive circuit-breaker maintenance through
constant surveillance
■■ Increased circuit-breaker availability
■■ Diagnostic assistance in case of failure
■■ Optional web interface display
■■
119
The CBWatch-2 monitoring system offers you the
possibilities to manage a proactive, more cost
effective maintenance programme by constantly
monitoring your circuit-breakers’ condition
and the trends in your operational parameters.
These advance warning notifications are the
best insurance to avoiding network failure and
guarantee a longer life to your equipment.
The CBWatch-2 installs directly on the circuitbreaker and maintains a constant, monitored
link with your local or remote database via the
CBWatchTool software package. The monitoring
system records information coming from the
sensors installed on the breaker and analyses this
information, comparing it with standard operational
parameters programmed into the system.
SF6 or gas mixture
The installation of the CBWatch-2 monitoring system makes it possible to constantly watch the gas
pressure and temperature, calculating the SF6 or gas mixture density using the Beattie-Bridgeman
algorithm. It detects and inhibits false alarms in the event of liquefaction. The system measures SF6 leakage
rates giving you advance warning before sending alarms or reaching lockout threshold levels. The system
also maintains historical records.
Mechanical operation
CBWatch-2 monitors close and open operating times, allows the use of conventional auxilary switches
or primary contact travel sensors, monitors primary contacts separation speed, buffering and over travel,
detects mechanical performance deterioration (friction, corrosion, breakage, spring fatigue and buffer
defects) and it monitors auxilary switch timing.
120
Spring or hydraulic operating mechanism
Swiching
CBWatch-2 can also monitor the hydraulic or spring-operated
mechanisms. For spring-operated mechanisms, the system monitors
recharging motor operating times and can detect motor limit switch
defects. For hydraulic operating systems, it monitors pump motor
operating times, detects internal and external leakage, nitrogen loss
from the accumulator and threshold pressure.
During switching, the
CBWatch-2 monitors the current
during breaking, arc duration,
and estimates primary contact
wear.
Auxiliary and control
circuits
The CBWatch-2 system monitors
operating coil continuity, your
auxiliary supply voltage and
heater integrity.
Available versions
CBWatch-2 exists for circuitbreakers with one operating
mechanism for all three pole or
for one operating mechanism for
each of the three poles.
CBWatch-2 also exists for
generator circuit-breakers
(please consult us for the
available functions).
CBWatch-2 installed in the central control cubicle.
121
Installation
Power supply
Dimensions:
310mm x 280mm x 95mm
121/4”x11”x3 3/4”
■■ Installation in operating
mechanism, local control
cubicle or separate enclosure
> 48-125 Vdc; 48 - 120 Vac
> 150-250 Vdc; 150 - 240 Vac
> Tolerance: -30 % to +15 %
> Power consumption: 30 VA
maximum
■■
Environment
Ambient temperature: -40oC to
+55oC (Option: -50oC with heater)
■■ Electromagnetic compatibility
according to the following
standards:
-IEC 255-5
-IEC 1000-4-4
-ANSI C37-90-1
-IEC 1000-4-12
-IEC 255-22-3
■■
122
Dependability
■■
High reliability and high
availability due to continuous
self monitoring of electronic
module and sensors: auto
diagnostic
Local interface
LCD display and keypad
(optional)
■■ 1 self monitoring status relay
■■ 4 configurable output relays
■■ 1 self monitoring status LED
■■ 4 local LED indicators
■■ RS232 local communication port
■■
Network interface
■■
Isolated RS485 communication
port with MODBUS protocol
Sensors required for
different functions
SF6 or gas mixtures:
Pressure and temperature
sensors
■■ Operations:
Coil signal sensors
Auxiliary contacts
Primary contact travel sensors
■■ Primary current:
Auxiliary current transformers
■■ Spring mechanism:
Spring motor limit switch
contacts
■■ Hydraulic mechanism:
Pump start contacts
Hydraulic pressure sensor
■■ Auxiliary and control circuits:
Temperature sensors
Coil supervision relays
■■
CBW2TOOL software
CBWatch-2 has communication interfaces that connect to a personal
computer loaded with the CBW2Tool Human-Machine Interface
Software.
This software gives access to CBWatch-2 settings, event recordings,
measurements and alarms.
Connection and configuration
Connection to a CBWatch-2 can be made via a RS232 or a RS485
serial link, via MODEM or an Ethernet gateway. The software
configures and edits the data via a user-friendly interface.
Access to the measurements and to the alarms
The software provides a visual display of the state of the on-going
alarms and measurements on the connected CBWatch-2.
Access to the recordings of events
The data archived in the CBWatch-2 connected to the PC can be
downloaded and saved in the EXCEL format, then recalled, visualised,
and printed out. The archived events can be studied and/or recalled on
your PC on demand.
Example of a CBWatch-2 installation
on a circuit-breaker with one
operating mechanism per pole.
CBWatch-2 interface software
Examples of some of the industrial
sensors used.
123
124
AIS Solutions | DWatch
Fact sheet – AIR INSULATED SWITCHGEAR
DWatch
The Smart operating
mechanism
DWatch integrates a hardware and software solution
to enable the smart automation and monitoring of
disconnector operations, through continuous control
of a variety of modes across the entire range of
disconnectors
Customer benefits
Continuous monitoring of the circuit to maximise
efficiency
■■ Early detection of excessive torque
■■ Flexible configuration based on disconnector types
■■ Improved reliability, better lifetime management and
optimised maintenance.
■■
125
The D-Watch Application
The D-Watch device is designed to drive the Disconnector operation through the automation of the
operating mechanism with an electronic board
■■ The D-Watch permits users to monitor and control mechanism and most of the disconnector’s
mechanical parts
■■ D-Watch is a reliable electronic module that manages the control unit for very flexible operation
■■
Operating
mechanism
overview
0.22 to 0.5 kW
AC or DC supply voltage
■■ Stainless steel box
■■ Irreversible reduction gear
■■ Lubricated for life
■■ Maintenance free
■■ Easy wiring
■■ Emergency crank
■■ IP55
■■ Padlockable front door
■■
■■
126
D-Watch Features
The new operating mechanism equipped with the D-Watch device
features:
■■ Stainless steel box
■■ Irreversible gearbox
■■ Robust design to cope with adverse environmental conditions
■■ Can be adjusted for any motor-driven motor supply voltage
■■ Less cabling and wiring
■■ Reduced maintenance cost by predictive maintenance (“when
necessary”)
■■ Variable speed during the operations
■■ Disconnector operation time is independent for voltage supply
■■ Time operation not function of voltage supply
■■ Modularity on the configuration to suit any type of installation
■■ Digital communication plug
D-Watch Installation
The electronic device is installed inside Alstom Grid’s motor operating
mechanism.
D-Watch Smart Product
Speed control
Data logger of several parameters
■■ All integrated in the standard operating mechanism
■■ Standard drive for all disconnectors
■■ Plug & play (ready to use)
■■
■■
127
D-Watch benefits
This solution allows the system to manage a multitude
of information.
Digital Mechanism
Two way communication
Adaptive
Several sensors available
Less copper wires with fibre optics
Self-monitoring
Self-diagnostic
Generalised and deeper control
Vast range of options available for customers
Standardised device fully adaptable
Software Interface
128
Monitoring benefits
The D-Watch device offers the following benefits to the user:
■■ Archive curve to have historical data for maintenance purposes
■■ Evaluate the state of kinematic chain and live part position during the operation
■■ Control circuit monitored
■■ Quickly identify location of failure thanks to digital internal control
■■ Control the real end open-close position of disconnector
■■ Operation times recorded for each operation
■■ Record load curves during commissioning activities and for maintenance purposes
■■ Detect an excessive torque to operate the disconnector
■■ Offer a flexible configuration based on the different disconnector type
D-Watch device
Alstom Grid has designed a very flexible electronic module that allows its entire range of disconnectors to
be controlled. Through continuous monitoring with variable speed, the D-Watch device allows various
operation modes to be set considering different disconnector kinematics, architecture, live part design and
special environmental conditions: e.g. operations under ice, etc.
D-Watch can be used with any disconnector in service
Monitoring specification
D-Watch device monitors/controls following parameters as a function of position and time:
1. Voltage
2. Current
3. Operating time
4. Synchronisation of operation
5. Disconnector in motion/not in motion
6. N° of operation cycles
7. Max current reached
8. Minimum voltage reached
9. Motor torque
Data is recorded in non-volatile memory and transferred via PC communication.
Ethernet connection for remote diagnostic and integration to the Digital substation using the
IEC 61850 protocol.
129
I/O functions and integration in substation networks –
Features of Communication
■■
RS-232-USB connection for commissioning measurement/set-up
− Maintenance DMC
• Firmware update
• Debug warning alarm
• Download operation data
− On-site diagnostic
− On site adjustment
− PC operation
Integration examples
With PC
With C264 BCU
■■
Webserver for Remote diagnostic
− Viewing status of disconnector
− Debug warning alarm
− Download operation data
− Notification via e-mail
130
■■
■■
IEC 60870-5-104 integration through fibre optics
−Integration with substation network with possibility to integrate
data in control network
IEC 61850-8-1 integration through fibre optics
− Integration with a SMART –GRID protocol
− Exchange data with other devices in the substation
Schematic block with communication
features in Modbus RS-485 Fibre optics
Technical features
■■
■■
■■
■■
■■
I/O: communication with substation through serial or Ethernet
1,2,..n: speed/torque profile memorized in the electronic board
■■ E: PWM driver
■■ M: DC motor
■■ R: reduction gear
■■ DS: disconnector
■■ Temp: temperature
■■
■■
■■
(power or/and auxiliary)
70 V to 250 V DC - 50 to
400 V AC
Motor 0.22 kW to 0.5 kW
Ambient temperature
-60°C up to 50°C
Protective index
IP55 compliant
Case material
Stainless Steel
MC Protection according to
E
IEC62271-1
(6.9.1, 6.9.2, 6.9.3,..) Class A
Dimensions
Length: 545mm
Height: 600mm
Depth: 460mm
Weight: 65Kg
131
132
AIS Solutions | RPH3
RPH3
Point on Wave
switching
Optimising the closing and opening of a circuitbreaker is of the utmost importance because
random switching can result in high transient
overvoltages and/or high inrush currents. These
transients generate stresses on all substation and
network equipment, leading to accelerated aging
- or the worst case scenario - flashover of the HV
apparatus.
Customer benefits
Eliminate switching transients
Reduce stress, overvoltages and inrush currents on
electrical networks
■■ Increase lifetime of HV equipment
■■ Enhance power system security
■■ Support operations and maintenance
■■ IEC 61850-9-2 compliant
■■
■■
133
Sensors CB drive
(Spring or Hydraulic)
Controlled switching of
high voltage circuit-breakers
The RPH3 is an advanced microprocessor-based
synchronising relay suitable for Independent pole
operated circuit-breakers. More commonly referred
to as a Point-on-Wave controller, it protects high
voltage network components from transients
generated during switching operations.
Thanks to the RPH3’s sophisticated algorithms,
the operation of the circuit-breaker is configured
to reduce stress in all conditions and network
configurations.
Random switching operations on high voltage
networks cause electrical transients that stress
equipment and degrade power quality.
The way to deal with switching transient
phenomena is to act efficiently on their root-causes.
Eliminate random switching and replace these
practices with a controlled switching strategy - or
“point-on-wave” switching.
Point-on-wave controlled switching consists of
134
Synchronous
switching relay
issuing switching commands to the circuit-breaker
at the optimal point on the reference voltage
waveform. Thanks to its electronics and software,
the RPH3 point-on-wave controller effectively sends
a switching command to the circuit-breaker to
operate at the correct instant, thus eliminating or
substantially reducing transients.
Perfect matching with the
circuit-breaker under control
Success of controlled switching operations depends
on the ability of the RPH3 controller relay to assess
beforehand the reference synchronising voltage, as
well as the characteristics and the consistency of
circuit-breaker operations under all operating and
ambient conditions.
To optimise the performance of the RPH3 in its
controlled switching operations, the relay can be
programmed according to network and circuitbreaker operational characteristics.
Thanks to the permanent monitoring of the circuitbreaker’s parameters and the sophisticated adaptive
Internet links
Electrical wire
Ergonomic HMI
control routines, the RPH3 enables a reliable and accurate control
over the behaviour of the device, thus permitting optimal switching
sequences.
Advanced communications features and
user friendly interfaces
With its integrated memory and communications ports, the RPH3
records switching parameters and communicates the results of
controlled switching operations.
An embedded web server for the machine interface allows:
Real-time information on the RPH3 device & application status
■■ Configuration of parameters needed for controlled switching
applications
■■ Retrieval of switching archives and data from RPH3 devices
■■
RPH3
The web server program operates by accepting HTTP requests from
the client via a standard web browser.
The ‘RPH3 Manager’ dedicated software allows the analysis of
archive records stored in the RPH3 relay in service and can perform
data evaluations of controlled switching operations.
AIS 420 kV circuit-breaker
135
Functionalities
Technical features
Switching applications
■■
Capacitor banks
■■
Reduce overvoltages and eliminate
inrush current
■■ Switch in at zero voltage
Shunt reactors
■■
Power transformers
■■
Reduce overvoltages and prevent current
chopping and re-ignition
■■ Switch out with medium arcing time
■■
Transmission lines
(uncompensated
and shunt reactor
compensated)
Eliminate inrush current
Switch in under conditions where
residual flux is minimal
Limit overvoltages while energising
or re-closing
■■ Switch in at zero voltage across circuitbreaker poles
■■
Advanced features
■■
■■
136
Digital interface via ethernet 100 Mbit/s
Open for 61850-9.2 protocol
Temperature : -25°C to +55°C
EMC compliant (electronics
completely protected)
■■ Mains supply
■■ 48 Vdc – 15% to 250 Vdc
■■ 110/240 Vac +/- 20%/5060 Hz
■■ Power consumption: < 20 W
■■ Solid state control of breaker
coils
■■ 48 V= / 250 V=
■■ 10 A – 300 ms / 15 A –
200 ms
■■ Alarm relays operating range:
230 V= / 5 A
■■ Reference syncronising
voltage:
15 – 330 V~ (20-60 Hz)
■■ Switching time resolution:
0.1 ms
■■ Control voltage (auxiliary)
■■
AIS Solutions | Service
AIS Service
solutions
137
AIS Solutions | Service
Condition based maintenance
Time based maintenance is still the most frequently maintenance strategy
in use, although it has been shown not to be the most efficient when
looking at cost and equipment failure prevention compromise.
With a clear objective of shifting to condition base maintenance and
reliability centred maintenance (RCM) strategy, the need for monitoring
ageing physical parameters in real-time has increased. Maintenance
and monitoring solutions are key for keeping the substation’s primary
equipment in optimal operating condition.
Digital AIS substation
From a standardised technical solution to a tailored application on existing assets, our Service engineering
departments can propose retrofit solutions to apply DWatch and CBWatch to most existing disconnectors
and circuit-breakers in substations regardless of OEM.
The sensor installation, cabling and IED upgrades can be performed during scheduled maintenance or
overhaul.
Expertise and consulting
Our experts are available for customer data interpretation and
analysis. Several possibilities for data collection and transmission are
available, from remote online access to manual file exchange, this
consultancy can be provided on an on-call basis and on a contractual
frequency basis.
BWatch and CBWatch data are applicable to Asset Health Index
(AHI) of our asset management solutions, supporting customer asset
management policies.
138
AIS Solutions
AIS conclusions
Alstom’s digital substation solutions offer a range of market leading benefits
for AIS operations. These include:
■■
■■
■■
■■
■■
■■
■■
Entire Air Insulated Switchgear product portfolio
A range from 72.5 up to 1200 kV
Worldwide footprint, with local services
High level of reliability and availability, with real time performance and extensive selfdiagnostics
Standardisation and solutions designed to be interoperable
Investment optimisation through reduced real estate needs, with copper cabling cut
by up to 80%
Move to predictive maintenance thanks to intelligent asset management systems
139
AIS Solutions
140
SAS Solutions
141
142
Substation Automation Solutions
Substation
Automation
Solutions
Alstom Grid is the technology leader in substation
automation solutions.
Alstom Grid benefits from a leading position in the
substation automation market: The number one in
the Near and Middle East, India, Western Europe
and Africa, its worldwide market-share amounts
to more than 10%. With a complete substation
automation range, offering full IEC 61850
compliance, the products are ready for Smart Grid
applications. Alstom Grid Substation Automation
Solutions (SAS) is amongst the leading suppliers
to provide high-performance, mission-critical
solutions that protect, control and monitor electrical
substations. Our leadership is based on a strength
of over 1600 experts, with fully-local project,
delivery and application support capabilities, to
offer integrated solutions for utilities and industrial
customers worldwide.
143
SAS global footprint
The new era of intelligent Smart Grids requires more
sophisticated substation automation systems which allow
energy operators to provide a secure, dependable and cost
effective power supply to meet increasing customer
demands for higher standards of power automation.
Alstom Grid SAS provides intelligent systems and smart services to protect
and control all equipment and assets, for secure and optimum transmission
and distribution of electricity.
We offer a complete control, protection and monitoring range in all
segments, from medium voltage to over 1000kV, including:
■■ Fully-engineered digital control systems (DCS)
■■ Numerical protection relays
■■ Merging units, switchgear controllers, Ethernet switches and gateways
for use in digital substations
■■ Automation turnkey projects
■■ Recording, measurement and phasor measurement solutions
■■ Conventional control/relay panels
■■ Refurbishment, training and post-delivery support services
144
Introducing
DS Agile
DS Agile is the latest in turnkey automation
solutions for digital substations. It combines
cutting-edge hardware, software, communications
and the highest technology engineering to IEC 61850
standards. DS Agile is a fully scalable solution, in
terms of functionality, architecture and services,
that can be tailored either to single substations or to
a harmonised system across multiple substations.
145
The complete
digital substation
solution
D
C
B
IEC 61850 Ethernet network
●● International standard protocol
●● Allows interoperability between
IEDs from different vendors
DS Agile substation bay controller
Substation control, communication, monitoring,
protection and automation functions
●● Modular, IEC 61850-compliant solution
●● Open platform for real-time automation schemes
●● Both legacy and cutting-edge communication protocols
●● LCD graphical display for local control, monitoring and
maintenance
●● Suitable for retrofitting and modernising
existing installations
DS Agile switch
For various Ethe
ring, multi-ring,
●● Interoperable
●● Gigabit switch
●● Full complian
constraints (I
●● Internal PC an
●● External racka
C
Hardwire link
A
M Condition
monitoring
unit
Process bus
IEC 61850
B
A
D
M Condition
monitoring
unit
A
M Analog
merging
unit
M Numerical
L
merging
unit
L
M Switchgear
controlling
unit
Fibre optic link
A
Smart primary equipment
●● Non-conventional voltage and current transformers
Condition M
●● for gas-insulated switchgear (GIS)
monitoring
unit
●● for air-insulated switchgear (AIS)
●● Primary devices with embedded sensors for condition
monitoring
●● Power electronics-based equipment: HVDC systems, FACTS
146
M
Merging units inte
●● AMU (Analogue)
●● NMU (Numerica
●● SCU (Switchgear
transformer tap●● CMU (Condition
G
hes
ernet redundant architectures:
, star, double-star
e protocols (PRP/HSR)
hes
nce with electrical installation
IEC 61850-3)
and bay controller switches
kable switches
E
F
DS Agile A300
substation gateway
●● Protocols: IEC 61850,
IEC 60870-5-104,
IEC 60870-5-101, DNP 3.0,
ModBus
●● Hot standby redundancy
●● Integrated Ethernet switch
Remote access and
telecommunication
●● Remote desktop
●● Cyber-secure web access to
substation
●● e-terragridcom telecommunication
solutions for MV & HV networks
F
Grid control room
●● Network management systems
(EMS/DMS)
●● Market management systems (MMS)
●● Asset management solutions
●● Wide area solutions (WAMPAC)
G
F
H
I
E
I
F
Central
access
server
K
D
I
B
Station bus
IEC 61850
J
F
Precision time protocol
●● Synchronisation of IEDs
and merging units
●● GPS clock server 1 PPS,
IEEE 1588
K
egration
) - for conventional instrument transformers
al) - for digital instrument transformers (DIT)
r controller) - for circuit-breakers, disconnectors and
-changers switching and control
monitoring) - for monitoring of primary devices
Cyber security
●● Intrusion protection
●● Integrated in switches
and IEDs
MiCOM protection and other
IED integration
●● MiCOM protection relays for
application from MV through to EHV
●● Measuring and recording devices
●● Phasor measurement units
●● Interoperable third-party relays integration
through IEC 61850, IEC 60870-5-103, IEC
60870-5-101, DNP 3.0 and ModBus protocols
J
DS Agile A400 WACU / SACU
Wide Area Control Units (WACU) for
inter-substation and inter-voltage
exchange
●● IEC 61131 PLC automation
●● IEC 61850 -compliant
●● Hot stand-by redundancy
DS Agile Operator Interface (OI)
●● Single-line dynamic diagram viewer and bay viewer
●● Alarm viewer
●● Select-before-operate configurable function
●● Data monitoring, logging, archiving and curve trends
●● Phasor data concentrator
●● Condition monitoring HMIs
●● Secure access control by user profile
●● Protection and automation engineering toolsuite MiCOM
S1 Agile
H
System Configuration Editor (SCE)
●● Allows integral data creation for system coherency
●● ISaGRAPH editor IEC 61131 standard
●● PSL editor for fast automation
●● Graphical editor
●● Reference templates library
147
DS Agile key benefits
DS Agile is a complete substation automation solution whose typical architecture consists of
a local IEC 61850 Ethernet network (LAN) that links all components, together and with the
operator interface (HMI). The network can be local to the substation or can interconnect several
dispersed substations. Redundant architectures can be set up as self-healing ring or dualhoming star; eliminating outages. All LAN configurations are linked to the grid control room.
Industry standardisation
Alstom DS Agile offers topology-orientated automation protecting, controlling and
monitoring installations to ensure continuity and reliability of electrical networks.
Based on IEC 61850 communication standards, DS Agile enables complete integration
between devices and therefore ensures optimum use of information.
Reliability and security
DS Agile provides ultimate reliability through the application of fully redundant
architectures. This is reinforced by unmatched cyber security, at all levels throughout the
digital substation.
Wide-area automation
DS Agile is much more than a control and protection system for substations. Rapid data exchange
and communications between all control and protection IEDs is enabled, not only across the
substation and substation gateway, but also through Wide-Area Control Units (WACU) that can
process real-time automation, taking into account the topology of multiple substations.
The new WACU solution developed by Alstom makes inter-substation automation and
protection possible, helping protect assets and optimise power flows.
Project delivery and support
Alstom has experienced teams located worldwide, with a proven track record in project
management, engineering, application support, maintenance and training. Our experts can
provide assistance in any or all of these areas, allowing users to make the best use of DS Agile.
148
Substation Automation Solutions | DS Agile
DS Agile
Interface
(HMI)
A-series
Gateway
SCADA
IEC 61850 ethernet network
C26x
Bay
Controllers
Serial
communication
with IEDs
MiCOM
P40
IED
Digital I/Os, instrument transformers, etc.
DS Agile functions
Data concentration and processing
One of the main functions of the DS Agile is to concentrate and process data: the
information can come from a variety of sources, both analog and digital. For example, when
re-using legacy equipment, analog data can be acquired directly from current and voltage
transformers and digital data can be acquired over serial communications links or via
hardwired links.
DS Agile manages many types of data from the substation’s primary and secondary
equipment such as: tapchanger and switchgear positions, control signals, measurement
values, disturbance records, settings, etc. Each item of qualified data is uniquely referenced
in the system configuration tool in order to ensure full consistency of the information, as
well as allowing it to be re-used in other parts of the system.
149
Automation
Monitoring and analysis
Among DS Agile standard features are functions for locally
or remotely monitoring and analysing collected data.
Extremely compact monitoring can be achieved via the
embedded LCD in the C26x bay controller, displaying single
line diagrams, alarms, measurement values and sequence of
event lists.
Alternatively, more sophisticated monitoring is possible via
one or more flat screens, providing additional benefits such
as busbar colouring for easier maintenance, advanced alarm
screens and accurate fault localisation within the system.
Other features include advanced reporting, dual language
display and disturbance record analysis.
Control
Controls can be initiated by the operator (locally or
remotely) and multiple checks are performed before the
issue of a control signal in order to make it fully secure.
For instance, interlocking is achieved by logical equations
or as the result of a dynamic topological analysis coupled
with expert rules. Interlocks are managed as close to the
process as possible in order to provide the best security of
operation. Interlocking conditions are graphically displayed
on the operator’s screen in order to immediately identify the
locking conditions (if any), allowing the operator to make
the appropriate changes before issuing the order.
150
An operator can configure
specific control sequences
or automation schemes,
across one or more
sites (e.g. automatic
reclosing, System Integrity
Protection Schemes (SIPS),
load shredding). Such
applications can be based
on local or remote data.
Similarly, the outputs can
perform local or remote
actions. Programmable
logic can be implemented
using either ProgrammableScheme Logic (PSL) or
the Programmable-Logic
Controller (PLC). PSL is for
fast automation applications
and it is available in the
C26x bay controller. It is
event-driven, so there is
no cycle time. The optional
PLC tool is fully compliant
with IEC 61131-3 and it
can be used for complex
or sequential automation
applications, not only at bay
level (in the C26x) but also
at inter-substation (or intersystem) level, by means of
the programmable WideArea Control Units (WACU).
DS Agile architecture
Homogenous
DS Agile offers a unified architectural framework for building multiple solutions tailored to
the real needs of almost any application. It allows for progressive upgrading of the system
design according to the evolving requirements in terms of functions, size, performance etc.
Extendable
A DS Agile solution can be contained within a standard panel or be geographically
distributed, depending on the application. The DS Agile architecture is structured in a series
of hierarchical levels. Each level maintains a given performance in terms of transmission
time, dependability and automation independently of the other levels. It therefore ensures
that the system can be extended consistently and securely.
Standardised
The combination of modern, multi-functional and highly programmable IEDs together with
fast communications greatly improves the capabilities for producing a “standard bay”. A
standard bay is a product made of standard hardware, software and engineering libraries
(automation, graphical representations, wiring interface and IED composition). It can then
be customised to the exact requirements of the project through changes to the database.
Reliable
System availability is a function of the reliability of each individual component and the
architecture in which they are combined. DS Agile accommodates a variety of redundancy
options, ranging from the switch redundant power supply to the complete redundancy of
each component, including configuration database redundancy.
A DS Agile solution can be engineered from a few integrated components or have its
functions split into several components, thus offering a balance between functional
availability, cost and compactness.
In addition to the self-checks carried out by each component, DS Agile offers a variety of
system test modes such as ‘device maintenance management’ and ‘data forcing’ to further
increase the overall availability.
151
Communications protocols
Physical communications between components are based on both Ethernet and serial RS
links in order to cope with different applications such as the re-use of existing devices and
the integration of third-party equipment. State-of-the-art communications technology based
on client-server and peer-to-peer links such as IEC 61850 is DS Agile’s standard. It relies
on fast Ethernet networks and offers new perspectives in terms of distributed functions,
performance and flexibility, enabling innovative automation schemes and the flexible
addition of new application clients.
In addition to Ethernet’s IEC 61850, DS Agile supports the most typical serial protocols
(T103, DNP3 and MODBUS), in order to interface with existing devices, and it can be fully
integrated within a remote control scheme. When using MiCOM Alstom devices, the same
link can be used to retrieve settings or disturbance records.
Communications with remote control centres is achieved using IEC 60870-5-101,
IEC 60870-5-104 or DNP3 protocols. DS Agile also supports a series of older protocol
generations.
State-of-the-art communications technology based on client-server and peer-to-peer links
such as IEC 61850 is DS Agile’s standard. It relies on fast ethernet networks and offers
new perspectives in terms of distributed functions, performance and flexibility, enabling
innovative automation schemes and the flexible addition of new application clients.
Simple architecture
The DS Agile base architecture interconnects a Remote Terminal Unit (RTU) or a PC with a
series of Intelligent Electronic Devices (IEDs) such as protection relays or measurement IEDs.
This architecture is typically used within a simple distribution substation, a wind farm or a
transmission substation bay (a feeder, for example).
Complete architectures
A DS Agile complete architecture is made up of an ethernet network linking components
from the base architecture with an operator interface (HMI), gateway and IEDs.
The ethernet network might be local to a substation, typically for a transmission application,
or it may interconnect dispersal sites commonly found in industrial or infrastructure
applications through wide-area control units.
The client-server communications exchange avoids any central point between local and
remote control (as found in the simple architecture) and allows for tailored redundancy of
the client and/or server.
152
The full architecture is also typically implemented as a way to make an existing installation
evolve progressively via new technologies. The older system thus becomes a slave to an
IEC 61850 converter and new devices can successively be plugged into this network.
DS Agile components
A typical DS Agile Digital Control System (DCS) will incorporate different Intelligent
Electronic Devices (IED, such as protection relays, measurement devices and monitoring
equipment), bay controllers, Ethernet switches and gateways. All key components are
designed for optimal interoperability, data retrieval, control capability and remote settings.
DS Agile substation server with DCS OI operator interface (HMI)
The DS Agile system database is hosted in at least one Human-Machine Interface (HMI)
server, but it may support two servers with hot-standby redundancy. The HMI itself can be
hosted either in the main server workstation or in a dedicated one and supports up to 10
HMI Clients.
The DCS OI software platform provides real-time access to all substation automation data
and enables secure and intuitive control operation functions.
DS Agile bay controllers
IEC 61850-compliant substation bay controllers that provide fast automation, embedded or
programmable (automatic voltage regulation, synchrocheck, autorecloser, busbar transfer),
IED interface for legacy protocol conversion, data concentrator, events and waveform
recorder, hot standby redundancy and are adaptable for individual requirements. Alstom’s
bay controllers, like the MiCOM C264, are proven solutions with more than 30,000
units installed worldwide.
MU Agile merging units and DS Agile switchgear control units
Alstom provides a full range of flexible merging units, allowing measurement conversion and
switchgear control. Both AMU and SCU are based on proven architectures, such as those of
MiCOM P40 Agile relays and MiCOM C264 bay controllers, respectively.
153
DS Agile switches
The DS Agile H-series Ethernet switches combine interoperable redundancy protocols (such
as PRP) and fibre-optic connections for ultimate reliability of the substation communication
networks. They maintain the flexibility to connect to standard Ethernet networks for
substation upgrades or refurbishments.
DS Agile communication devices
Alstom’s A-series provide powerful and ruggedised gateway and wide-area automation
solutions for interfacing bay level devices, station level devices or upper level systems.
They combine full IEC 61850 compliance with hot standby redundancy and simple
commissioning.
MiCOM Protection range
The MiCOM Alstom and agile protection ranges provide a complete family of technologically
advanced protection relays for the modern digital substation. Typical protection applications
include busbar, transformer and line differential, distance, feeder, generator, motor and
phasor measurement.
Condition monitoring IEDs
A complete range of state-of-the-art systems for online condition monitoring of the primary
substation equipment can be fully integrated within the DS Agile system, through
IEC 61850, to provide valuable online condition data, plus expert tools for safer operation,
preventive maintenance and lifetime management of your assets.
Measuring and recording IEDs
Alstom supplies advanced IEDs for highly accurate, real-time fault recording and analysis,
power quality measurements and trend recording. They are the ideal IED for analysing
network faults, protection IED reactions, dynamic network stability and long term trends.
154
Substation Automation Solutions | DCS OI
Fact sheet – SUBSTATION AUTOMATION SOLUTIONS
DCS OI
Operator interface
(HMI) platform for
substation automation
While substations are usually unmanned during normal
conditions, efficient information access is a key requirement
in emergency situations. Design, installation, life extension
and maintenance instances of an electrical substation’s
digital control system (DCS) demand a straightforward,
user-friendly interface. Intuitive access to the most relevant
information and fully secure operations are necessary to
ease operator tasks. To help you meet these challenges,
we offer the Alstom DCS OI operator interface platform
dedicated to our substation automation systems, DS Agile
v5.0 and upwards, and PACiS (up to v4.6).
Customer benefits
Native integration of substation requirements
Intuitive, secure and efficient interface
■■ Scalable platform tailored to each project
■■ HMI server hot redundancy
■■ Consistent suite of operator tools
■■ Compatible with all versions of Alstom Grid’s DCS
■■
■■
155
Native integration of substation
requirements
Alstom DCS OI relies on a standard graphical user interface, enabling
local or web visualisation of single line displays. The HMI’s true added
value consists of a series of fully tested modules that match electrical
application needs such as: real-time communication protocol interface,
select before operate sequences, automation capabilities and no data
loss guarantee.
Intuitive and fully secure interface
Alstom’s DCS OI scans of two dimensional substation representations
or remote visualisations of real time video significantly improve the
operator’s understanding of the situation. Embedded buttons enable
functions such as synchro-check or interlocking condition displays to
greatly increase the safety of operation and maintenance actions. Multiple
language management allows dynamic switching between task-oriented
dialects (operation vs. maintenance), or between national languages.
Scalable platform tailored to your project
The configuration of Alstom’s DCS OI is tailored according to the needs of each project. This includes the
number and type of screens and engineering facilities. From a performance perspective, the HMI can be
expanded seamlessly from a single box to a series of interconnected PCs - with partial or complete redundancy.
The interface is open to the integration of any additional software and may display any type of HMI, including
real-time images issued from video cameras, providing a remote and secure view of the application.
Open and efficient interfaces
The DCS OI provides an open interface to multiple intelligent electrical devices (IEDs) and Master SCADA through
the latest Ethernet protocol IEC 61850. Disturbance files (COMTRADE 97/2001) and setting data are retrieved on
the same link without disturbing real-time performance, using pass-through technology.
Additional supported standards for data access include web access, SQLTM interface, COMTRADE archives or
Crystal ReportTM.
156
Consistent suite
of operator tools
HMI software tools cover the complete lifecycle of the electrical
application including: system engineering, IED engineering, substation
automation, network analysis, system maintenance and IED maintenance
- all integrated with a consistent look and feel.
The DCS OI can provide access to (as a complement to local HMIs) any
remote connection to present real-time information and any archived
data for maintenance and supervision. Remote access is available
through PSTN, DSL, satellite link as a dedicated application or Web
server.
OI hot redundancy
The DCS OI server redundancy is managed through a set of 2 HMI servers
(named cluster). The OI client can be connected to one of the 2 servers.
Reconfiguration is automatically managed when the preferred server
is reconnected. Each datapoint change is consolidated between the 2
servers (real-time data & historical data are the same on both servers).
KEY FEATURES
Intuitive and secure monitoring and control via Windows® 2000, Windows 7 or XP modules
Real-time communication with following protocols: UCA2, IEC 61850, OPC, IEC 60870-5-103, IEC 60870-5-101,
DNP3, ModBus...
Powerful archiving and reporting facilities (SQL, COMTRADE, etc.)
Universal real-time IEC 61131-3 automation capabilities
Unique system management tool for efficient database version management
Complete system engineering tools for XML database design
Hardware compliant with EMC and environmental electrical constraints
10 s internal resolution and instance
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158
Substation Automation Solutions | DS Agile Gateway
DS Agile
Gateway
Rugged, solid-state,
communications
solution
DS Agile’s A300 communications protocol gateway
is an advanced solution for interfacing substation
networks with digital control systems and network
management systems.
Customer benefits
Fully compliant with IEC 61850
Simple commissioning and maintenance
■■ Hot standby redundancy
■■ Available with additional cyber security tools
■■
■■
159
Combining full IEC 61850 compliance, hot standby redundancy and
simple commissioning, the A300 is a powerful solution for interfacing
bay level devices (protection, control or measurement devices), station
level devices (digital control system client/servers) and upper level
systems (network management systems or digital control systems).
The DS Agile Gateway is ruggedised and solid-state - designed to work
within stringent substation environmental conditions (EMC compliance
as per IEC 61850-3 etc.).
Full compliance
with IEC 61850
Alstom Grid’s A300 provides a
dedicated interface to any other
IEC 61850 enabled device, either
with a single or dual-redundant
communications architecture.
The DS Agile Gateway is also
is also fully compliant with
the different editions of IEC
61850, which ensures backward
compatibility and interoperability ideal for substation refurbishment
or upgrades.
160
Simple
commissioning and
maintenance
The A300 gateway has flexible
communications interfaces
enabling multiple, separate
redundant substation ethernet
architectures. This helps to guard
against the repercussions of
network failure and facilitates a clear
separation of network functions,
simplifying commissioning and
maintenance activities.
Hot stand-by
redundancy
DS Agile A300 is equipped with
two native independent ethernet
ports which can support Alstom’s
H-series dual-redundant ethernet
switches and/or multiple LAN/
WAN connections. Two A300
gateways can also be physically
connected in a redundant hotstandby configuration for high
communications data integrity.
Communications protocols
Alstom’s A300 gateway is compatible with the most
popular communications standards at IED, DCS and
NMS levels: IEC 61850 Client and Server, DNP3.0
serial and IP, MODBUS serial and TCP/IP, Profibus DP,
HNZ 66, IEC 60870-5-101 & 101 NUC, IEC 60870-5104 & 104 NUC, OPC, etc
Tools and cyber security
Supervision of the trip circuit, whether the breaker
is closed or open (preclosing supervision), can be
implemented using opto-coupled inputs and the
programmable scheme logic.
Technical specifications
Dimensions: (W x D x H) 181 x 238 x 177 mm
Mounting kits (optional): wall/ panel/ stand
■■ Weight: 5 kg
■■ Power consumption typical: typical 25 W
■■ Power supply: 24 Vdc; 36 - 60 Vdc; 90 - 350 Vdc; 100 240 Vac/ 50-60 Hz
■■
■■
Communications
LAN: 2 x 10/100Base-T RJ-45 ports
Ethernet switches (optional): 2 x MiCOM H152 or
H162 redundant ethernet boards
■■ Serial Ports: 2 × RS-232, 2 x RS-232/422/485
■■ USB ports: 4 x USB Rev. 2.0 compliant
■■
■■
Environmental conditions
Humidity: IEC 60068-2-3, 95% @ 40°C
(non-condensing)
■■ Operating temperature: IEC 60068-2-1&2,
-20°C to 55°C
■■ Storage temperature: IEC 60068-2-1&2,
- 40°C to 60°C
■■ Shock protection: IEC 60068 2-27
■■ Vibration protection: IEC 60068 2-64
■■ Electromagnetic compatibility: EN55022,
EN55011, EN61000
■■
System hardware
Processor: CPU Intel Atom D510 1.66GHz
Memory: 2GB DDRII SDRAM built-in
■■ Operating system: Microsoft WINDOWS XP
■■ Battery backup RAM: 512 KB
■■ Expansion slots: 4 x PCI V 2.2
■■ Indicator LEDs: power input 1, power input 2,
power fault, IDE, diagnosis, 4 COM ports Tx/Rx
■■ Video: VGA DB15 VGA connector, 1600 x 1200 @
85 Hz
■■ Storage: internal solid state drive
■■
■■
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162
Substation Automation Solutions | DS Agile WACU
DS Agile WACU
Based on the DS Agile gateway, the new DS Agile
WACU A400 allows inter-voltage and inter-substation
control exchange through IEC 61131 PLC automation.
This wide-area automation capability becomes
highly valuable whenever the implementation of
multi-substation control is needed (e.g., among the
multiple substations across railway lines or between
the generation subsystem and the transmission
interconnection substation in a power plant).
Customer benefits
Wide Area Control Units (WACU) for inter-substation and
inter-voltage exchange
■■ IEC 61131 PLC automation
■■ IEC 61850-compliant
■■ Hot stand-by redundancy
■■
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Substation Automation Solutions | DS Agile WACU
164
Substation Automation Solutions | DS Agile bay controllers
DS Agile bay controllers
IEC 61850-compliant substation bay controllers that provide fast
automation, embedded or programmable (automatic voltage regulation,
synchrocheck, autorecloser, busbar transfer), IED interface for legacy
protocol conversion, data concentrator, events and waveform recorder, hot
standby redundancy and are adaptable for individual requirements. Alstom’s
bay controllers, like the MiCOM C264, are proven solutions with more than
30,000 units installed worldwide.
Customer benefits
Substation control, communication, monitoring, protection
and automation functions.
■■ Modular, IEC 61850-compliant solution
■■ Open platform for real-time automation schemes
■■ Both legacy and cutting-edge communication protocols
■■ LCD graphical display for local control, monitoring and
maintenance
■■ Suitable for retrofitting and modernising existing
installations
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Alstom’s C264 Bay Control Unit (BCU) is a sophisticated solution
supporting many applications and functions for substation control,
communication, monitoring, protection and automation.
Flexibility, reliability and ease of use are among the top features required
in a substation computer; the MiCOM C264 has these features. A
combination of dual redundant fibre optic Ethernet, modular I/O, an
expandable design and an extensive library of functions make the C264
the ideal solution for a wide array of applications in substation digital
control systems.
In addition to the traditional data management (inputs and outputs) the
DS Agile BCU can be used as a:
■■ Remote Terminal Unit (RTU)
■■ Bay computer
■■ Feeder manager (protection & control)
■■ Substation automation processor
■■ Sequence of Events Recorder (SER)
■■ Automatic Voltage Regulator (AVR)
■■ Measurement centre
■■ Load shedding controller
■■ Protocol converter
■■ Substation gateway
Seamless modernisation of existing installations
The C264 provides seamless integration with existing substation
assets, thanks to its flexible interfaces and native expandability. Its
powerful processing, communication and configuration facilities make
it the ideal tool for upgrading substation supervision, automation and
maintenance.
Innovative real-time automation schemes
MiCOM C264 enables innovative automation schemes thanks to
extremely fast (event driven) Programmable Scheme Logic (PSL) and
robust Programmable Logic Control (PLC).
Optimised engineering
The multifunctional capabilities of the C264 optimise system engineering
as fewer devices result in less wiring, training and maintenance.
166
Sample logical equations
Applications
Bay/substation interlocking
Alstom’s C264 provides two
methods of interlocking:
■■ A logical equation based method
■■ A topology based method, using
predefined rules and substation
topology
Interlocks are managed as close
to the process as possible in order
to provide the best security of
operation. Interlocking conditions
are graphically displayed in order
to immediately identify the
interlocking conditions (if any)
and make the appropriate changes
before issuing the command.
Trip circuit supervision
The purpose of this function is
to supervise the continuity of the
trip circuit of a circuit-breaker.
Two options are available: two
wires or four wires. The two-wire
option verifies the trip circuit
continuity when the circuitbreaker is closed.
The four-wire option permits
verification of the continuity
whether the CB is open or closed.
In the case of single phase circuitbreakers the C264 can supervise
the continuity of the trip circuit
separately for each phase.
Automatic Voltage Regulation
(AVR)
The Automatic Voltage Regulation
(AVR) function is used to
automatically maintain the
correct secondary side voltage of
a tap changing transformer.
AVR in the MiCOM C264 is a
compact voltage regulation
solution for IEC61850 systems in
electrical substations. It is able to
manage one transformer or up to
four transformers in parallel.
C264 AVR provides:
■■ Active and reactive compounding
in order to maintain the voltage
at a remote location
■■ Homing in order to adjust a
transformer to the voltage of
the busbar to which it will be
connected
■■ For transformers in parallel:
Minimising circulating current
method, master/follower mode
■■ Optimised transformer ratio
Auto-recloser
The MiCOM C264 can manage
one autorecloser per bay (up to
12 bays per unit). The integrated
auto-reclosers can operate in
1 phase and/or 3 phase mode.
Up to four autoreclosing cycles
are available and the time
delay for each is independently
configurable. Auto reclosers can
be initiated either internally in the
bay unit or via external protection
devices using digital inputs.
Synchro-check
The synchro-check function
can be used in conjunction with
automatic or manual reclosure.
The function (limited to one bay)
determines the difference between
the amplitude, phase angles
and frequencies of two voltage
vectors and uses this information
to determine whether or not to
close the breaker. Locking and
coupling modes are available and
a deadline and dead bus logic are
also included.
IED gateway and data
concentrator
One of the main features of
the C264 is to concentrate and
process data. This information can
come from a variety of sources,
both analogue and digital. For
example, when re-using existing
equipment, analogue data can
be acquired directly from current
and voltage transformers and
digital data can be acquired over
serial communication links or via
hardwired links.
The DS Agile BCU manages
many types of data: tap positions,
controls, measurements,
disturbance records, settings,
etc. Each item of qualified data
is uniquely referenced in order
to ensure full consistency of the
information, as well as allowing it
to be reused in other parts of the
system.
MiCOM C264 front view
(40TE variant)
167
Features
Communication protocols
Alstom’s MiCOM C264 is
fully compatible with many
communication standards such
as UCA2/IEC 61850, IEC 608705-104, DNP3, IEC 60870-5101/103, and MODBUS.
Redundancy
At substation level and / or bay
level an optional redundant C264
can be used to avoid the loss of
critical functions.
Digital inputs
The MiCOM C264 offers five types
of digital inputs:
■■ Single point
■■ Double point
■■ Multiple point
■■ System input for internal C264
information
■■ Logical combination of digital
inputs
All inputs are acquired and timestamped with an accuracy of 1 ms.
Digital input processing
In addition to de-bouncing many
customisable filtering functions
can be used to process digital
inputs, including:
■■ Toggle filtering
■■ Persistence filtering
■■ Motion filtering
■■ Undefined state filtering
Additionally a digital input can be
manually suppressed, substituted,
forced invalid and detected as
faulty. Digital inputs can then be
transmitted on the substation LAN
using the desired protocol.
Binary counters
Two types of binary counter are
available; single counters for
single data points and double
counters for double data points.
Counters can be transmitted
periodically or on request. In the
event of a supply interruption the
counters can resume from their
previously stored values.
Digital outputs
Digital outputs can be used to
apply a switching voltage to an
external device. These outputs can
be controlled in one of three ways:
Select Before Operate once
(SBO once)
■■ Select Before Operate many
(SBO many)
■■ Direct execution
The SBO once mode is used for
controls via set points or ancillary
devices, as well as synchronised or
non-synchronised circuit-breakers,
transformers, disconnectors and
earthing switches. The SBO many
(selection, execution, and de-selection)
control sequence is used for the
control of transformers.
■■
Encoded digital data
The C264 BCU can interpret
a group of digital inputs as an
encoded digital value. Binary,
Binary Coded Decimal (BCD),
gray code, decimal and 1 among
N types of encoding can all be
processed. These values can
represent data such as process
measurements and tap positions.
Analogue inputs
Analogue measurements can be
acquired from either an analogue
input board, a transducerless
measurement board (for current
and voltage transformers) or via a
communication network.
Analogue outputs
Analogue outputs can be used
to interface with auxiliary
devices (measurement viewers,
generators, motors, etc). The
Analogue outputs are powered
from an external supply (48VDC)
and can maintain their value even
if the C264 is powered down.
MiCOM C264 rear view
(40TE variant)
168
Measured and derived values
Directly measured values of voltage and current can
be measured using the transducerless measurement
board. Many different values can be calculated from
the measured values including:
RMS currents and voltages
Network frequency and phase angle
■■ Active, reactive and apparent powers - total and
per phase
■■ Power factor
■■ Sequence components
■■ Derivatives: df/dt, dV/dt, etc
■■
■■
Waveform recording
The MiCOM C264 provides two types of waveform
recording, Fast Waveform Record (FWR), which
stores samples at the maximum sampling frequency
and Slow Waveform Record (SWR), which stores
RMS measurements over a longer period. Both
modes can run simultaneously. Recording can be
triggered by, the change of state of binary digital
inputs/outputs, measurement threshold violations
and a request from an operator. Waveform records
are stored using COMTRADE 2001 binary format.
Power quality
Alstom’s C264 can measure the percentage Total
Harmonic Distortion (THD) (up to and including 15th
harmonic) and the Total Demand Distortion (TDD)
on voltage and currents.
Self monitoring
Comprehensive self-monitoring procedures, including
power-on and continuous testing, ensure that
internal hardware or software errors are detected and
do not cause malfunctions. If a fault is detected an
alarm will be issued and/or the watchdog contacts
will change state depending on the fault severity.
Maintenance web server
The maintenance web server can be used to
visualise maintenance data (Hardware/Software,
Communication, I/O values) and to download the
up-to-date event log. It is directly accessible with a
standard Internet Browser.
Programmable logic
An operator can configure specific control sequences
or automation schemes (e.g. automatic switching,
System Integrity Protection Schemes (SIPS), load
shedding). Such applications can be based on local
or remote data. Similarly the outputs can perform
local or remote actions. Programmable logic can be
implemented in the C264 using either Programmable
Scheme Logic (PSL) or the Programmable Logic
Controller (PLC). PSL is for fast automation
applications (<5ms). It is event driven and so there is
no cycle time. The optional PLC tool is fully compliant
with IEC 61131-3. It can be used for complex or
sequential automation applications.
169
Local interface for control,
operation and display
The control of switching devices
is possible using a keypad and a
graphical backlit LCD. Operations
can be performed in a simple
and intuitive way via up to 12
switchable displays for bay
control. Additionally there are
dedicated panels for monitoring
(i.e. measurements, events
list, alarms, etc.), display and
maintenance. If required the
operator panel can be mounted
separately from the C264 (up to
five meters away). Access barriers
can be used to guard against
inadvertent or unauthorised
operations.
Event logging
Up to 2,000 events can be stored
in nonvolatile memory. The
events are time stamped and
stored in chronological order.
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Substation Automation Solutions | DS Agile switchgear control unit
DS Agile Switchgear
Control Unit (SCU)
Switchgear control units are the fast, real-time interface to switchgear,
mounted close to the plant which they command. They replace the
hardwiring of inputs and outputs with an Ethernet interface to the yard.
They combine full IEC 61850 compliance with hot standby redundancy and
simple commissioning.
Customer benefits
For Ethernet redundant double-star architectures:
Interoperable protocol (PRP)
■■ Gigabit switches
■■ Multiple Gigabit ports and IEEE 1588 supported
■■ Full compliance with electrical installation constraints
(IEC 61850-3)
■■ Hardwired binary I/O in the yard scaleable up to 48
binary inputs and 20 outputs
■■ Fast 1ms GOOSE response time, with high speed, high
break contacts available for time-critical trip commands
■■
171
Substation Automation Solutions | DS Agile switchgear control unit
172
Substation Automation Solutions | MU Agile AMU
MU Agile AMU
Analogue merging unit
The Alstom MU Agile AMU provides a high quality,
cost effective, IEC 61850-9-2LE sampled value
interface to conventional current and voltage
transformers.
Customer benefits
Measures accurate, time synchronised power system data
Communicates sampled values according to
IEC61850-9-2LE
■■ Uses the same transformers for current and voltage
measurement as in the MiCOM Alstom P40 product
family
■■ Compact, cost effective solution
■■ Withdrawable
■■
■■
173
Digital technologies have brought many benefits in the strategic field of transmission networks and
specifically substations. Digital technology at station bus level is today widely spread and has also extended
to process buses at the primary equipment level.
The Alstom MU Agile Analogue Merging Unit goes one step further towards a complete digital substation;
facilitating the connection of conventional current and voltage transformers to modern substation
automation solutions through IEC 61850-9-2LE.
With a space-saving case accommodating four current and four voltage transformers taken from the proven
MiCOM P40 product range, the MU Agile AMU affords a low-risk transition from conventionally connected
substation automation to a fully digital substation.
174
Configuration and status
monitoring
The MU Agile AMU can be quickly and easily
configured using the intuitive MiCOM S1 Agile PC
tool suite via the front USB port.
A visual indication of the IEDs status via 4 tri-colour
LEDs is available on the front panel. These are
used to indicate the health of the IED, the time
synchronisation status, whether it is out of service,
and whether it has raised an alarm.
Hardware
The MU Agile AMU hardware offers:
Support for 4 x CTs and 4 x VTs
Space-saving 4U height and 30TE (6”) case size
■■ A front USB port and a rear fibre optic Ethernet port
■■ Power-up diagnostics and continuous selfmonitoring
■■ Time synchronization via fibre optic 1-PPS
■■ N/O (form A) and N/C (form B) watchdog
contacts
■■ Withdrawability
■■
■■
MU Agile AMU standard hardware
All CT connections have integral shorting, when the IED is withdrawn from the case. This affords additional
safety to personnel who may be working near live apparatus.
175
Sequence of event recording
All events are time tagged to a resolution of 1 ms.
Up to 2048 time-tagged event records are stored
in the flash memory, and can be extracted using
the USB port.
Communications
Two communication ports are standard: a rear
port providing for process bus communications
and a front port for substation staff. The front
USB port facilitates the programming of settings,
and the extraction and viewing of events. The
rear fibre optic LC Ethernet connection offers
the ability to transmit IEC 61850-9-2 sampled
values and to receive SNTP time synchronisation
messages.
Time synchronisation
The high-precision referencing of sampled values
to GPS real time uses the one pulse per second (1
pps) fibre input, typically provided by the MiCOM
Alstom P594.
Alstom Grid agile digital
substations
Alstom Grid agile digital substations are based
on IEC 61850, the unifying communication
standard for complete information sharing
and interoperability. They allow for future
modernisation and the integration of new
systems. Digital Control Systems are connected
with the primary bays through a process bus built
on redundant Ethernet. Merging and control units
collate and convert measurements, indications
and commands (I/O) into sampled values and
GOOSE messages, and vice-versa.
At an advanced level, digital instrument
transformers and condition monitoring systems
integrated with the substation HMI (Human
Machine Interface) can be added, providing
superior substation situation awareness, locally
and remotely.
Cyber-Security
The sophistication of protection schemes,
coupled with the advancement of technology,
increasingly leads to devices and substations
being interconnected with open networks, such
as the internet or corporate-wide networks.
This introduces a potential security risk making
the grid vulnerable to cyber-attack, which could
in turn lead to electrical outages. To secure
communication within such environments, the
MU Agile AMU offers NERC-compliant cyber
security.
MU Agile AMU withdrawability
176
IEC 61850-9-2LE
process bus
IEC 61850-9-2LE facilitates the
integration of non conventional
instrument transformers into
modern substation automation
equipment. It also allows
conventional current and voltage
transformers to be interfaced to
the same equipment via merging
units. It describes how analogue
signals such as phase currents
and voltages can be exchanged
as sampled values.
Benefits of IEC
61850-9-2LE
Asset optimisation
Reduced maintenance cost
■■ Optimisation of new
investments
■■ Reliability and availability
■■ Standardisation and
Interoperability
■■ Ease of refurbishment
■■ Safety
■■ Environmental responsibility
■■
■■
Environmental Responsibility
The MU Agile AMU allows for the substitution of many copper cables
with just a few optical fibres. In a full digital substation wiring can be
reduced by up to 80%.
The IEDs are manufactured in a lead-free soldering process using
lead-free components. This eco-responsibility is demonstrated in
the Product Environment Profile (PEP). The PEP shows claims for
raw material depletion, energy depletion, water depletion, global
warming potential, ozone depletion, photochemical ozone creation,
air acidification, and hazardous waste production. The IED does not
require any resident battery.
Quality Built-In
Quality Built-In methodology is applied throughout the development
and manufacturing of the IEDs. Part stress analysis in R&D, rigorous
component supplier selection, and a shipping carton compliant
with ISTA protection requirements all are examples of best-practice
to maximise long-life reliability. All circuit boards have harsh
environmental coating, to resist moisture, salt, corrosive atmosphere
and industrial ambient pollution – as standard. Circuit board
production uses in-circuit tests, boundary scanning, built-in self-test,
automated optical inspection, and X-ray scanning to achieve
maximum test coverage.
177
178
Substation Automation Solutions | Protection Relays
Introducing
Protection Relays
No matter how well designed, faults will always
occur on a power system, and these faults may
represent a risk to life and/or property. The
destructive power of a fault arc carrying a high
current is very large; it can burn through copper
conductors or weld together core laminations in a
transformer or machine in a very short time – some
tens or hundreds of milliseconds. Even away from
the fault arc itself, heavy fault currents can cause
damage to plant if they continue for more than a
few seconds.
Uncleared faults would also pose a risk to system
stability, resulting in unwanted disconnection of
generation or interruption of supplies to consumers.
The provision of adequate protection to detect and
disconnect elements of the power system in the
event of faults is therefore an integral part of power
system design. Only by doing this can the objectives
of the power system be met and the investment
protected.
179
Substation Automation Solutions | Protection Relays
180
Substation Automation Solutions | MiCOM Alstom P40
MiCOM Alstom P40
Protection platform
devices
The MiCOM Alstom P40 range offers a suite of relay
functionality and hardware options to best suit the
protection requirements, while allowing the customer
to choose the most cost-effective solution for their
application.
Customer benefits
Unparallelled speed, security and selectivity
Comprehensive models, hardware options, protection and
control functions
■■ Graphical programmable scheme logic (PSL) eases
protection scheme creation, and avoids the need for
external logic controllers
■■ Ease of integration into DCS, SCADA and engineering
workstations
■■ Comprehensive communication options including IEC
61850 and redundant Ethernet ports
■■ IEC61850-9-2 process bus applications: deploy in digital
substation architectures
■■ MiCOM S1 Agile software manages your IEDs
■■
■■
181
The 40 series platform, incorporating a full complement of utility,
generation and industrial-focussed models is the principal building
block of Alstom Grid’s offer, hosting the wide variety of protection,
control, measurement, monitoring and communication functions
demanded.
Typical device in small case
size variant
The versatile hardware allows deployment with confidence and the
PC tool, S1 Agile, makes for easy configuration, application and
management of the installed base.
A fresh and intuitive user interface makes the 40 series ideal for any
environment and suits all skillsets of headquarters and field personnel.
Numerous integrated communication protocols allow easy interfacing
to substation control or SCADA systems. From simple wired serial
buses, to Ethernet station and process bus architectures with IEC
61850 - MiCOM Alstom protection has the solution.
The MiCOM Alstom P40 range offers comprehensive solutions for all
power system protection applications, including:
Generation
■■
Integrated generator protection
Industrial
Motor management
Feeder management
■■ Interconnection protection
■■
■■
Rail
Trackside AC Grids
Catenary distance protection
■■ Transformer management
■■ Transformer-rectifier units
■■
■■
182
Transmission and
distribution
Distance protection
Line differential
■■ Transformer management
■■ Busbar protection
■■ Feeder management
■■ Voltage and frequency
protection
■■ Loadshedding
■■ Breaker fail and reclosing
■■ Line phase comparison
■■ Phasor Measurement Units
(PMU)
■■
■■
Scope
The P40 range fulfills the requirements at all voltage levels from MV to EHV/
UHV for industrial, distribution, generation, transmission and railway systems.
Common features
1 A/5 A dual rated CTs for simplified inventories
Event and disturbance recording for post-fault analysis
■■ Rear ports with choice of protocols, and front port for local setting
■■ Full Programmable Scheme logic for customer-specific automation
■■ Scalable input / output hardware depending on requirements
■■ Operating voltage user programmable for opto inputs
■■ Hardware accessories available for easy mounting in racks or panels
■■
■■
Applications
Feeder protection
A full range, with directional and
non-directional applications of
overcurrent and earth fault at its
heart:
■■ P14x - Feeder management
relay suitable for MV systems
and HV system backup,
with autoreclose, and check
synchronism within the model
option selection
■■ P341 - Grid interconnection
protection, at the point
of coupling systems with
embedded generation.
Line protection
A full range extending up to
the most demanding sub-cycle
technology for EHV and UHV
transmission:
■■ P44* - Full scheme distance
protection relays for HV, EHV
and UHV systems
■■ P54* - Line Differential
protection relays for direct fibre
and multiplexed communication
options as well as phase
comparison protection for use
with power line carrier
■■ P84* - Transmission line
terminal devices for backup,
reclose and breaker fail with
single, dual, breaker and a
half and mesh circuit-breaker
toplogies.
Substation plant protection
Applicable at all voltage levels, to
safeguard the most costly system
assets:
■■ P64* - Transformer
management and protection,
for between two and five-ended
schemes
■■ P74* - Numerical busbar
protection (biased principle)
suitable for application on MV,
HV and EHV busbars
■■ P14* - Numerical highimpedance busbar and REF
protection schemes, deployed
with varistors.
Rotating machine protection
Specialist devices for protection,
control and monitoring of all
machine types and ratings:
■■ P24* - Rotating machine
management relay for
application on a wide range
of synchronous and induction
machines
■■ P34* - Generator protection for
small to sophisticated generator
systems, and interconnection
protection.
System monitoring and stability
devices
Fast-acting devices to take local
decisions and input to wide area
schemes:
■■ P14* - Voltage and frequency
protection for load shedding,
load restoration and generator
abnormal detection
■■ P84* - System stability devices,
including a P847 Phasor
Measurement Unit (PMU) for all
grid applications.
183
Protection and control features
Protection elements
All algorithm and hardware know-how is the culmination of decades of advances in Alstom’s centres of
excellence. The platform has vast experience in test and in-service operational environments, proving the
technical integrity.
The comprehensive and advanced library of protection and control functions in each device allow it to
meet the exact application requirements. Multiple protection functions, logic and control functions may be
enabled, without deterioration in performance – the platform is fully deterministic.
Independent protection settings groups
The 40 series can offer up to four independent settings groups. These can be activated locally, remotely or via
a dedicated input and are used to allow for different system operating conditions and where adaptive relaying
is applied.
Programmable scheme logic
Powerful logic available in the 40 series relays allows the user to customise the protection and control
functions of the relay. It is also used to program the functionality of the opto-isolated inputs, relay outputs,
LED and user alarms.
The programmable scheme logic can be used to implement additional supervision features, such as trip circuit
supervision or implement complex logic such as frequency restoration schemes. Schemes have been developed
capable of supervising the trip coil and circuit with the circuit-breaker open or closed.
The Px40 gate logic includes OR, AND, NOT and MAJORITY gate functions, with the ability to invert the inputs
and outputs, and provide feedback. A number of general purpose logic timers are also available as well as
those timers used to condition the relay contacts.
The system is optimised (event driven) to ensure that the protection outputs are not delayed by the PSL
operation. The programmable scheme logic is configured using the graphical S1 Agile PC software,
as shown in Figure 1.
Figure 1
Programmable logic for P40
184
Substation Automation Solutions| MiCOM Alstom P40
Measurements,
recording and post
fault analysis
Measurement & post fault
analysis
The relays are capable of
measuring and storing a wide
range of system quantities
such as current, voltage,
frequency, power, distance to
fault etc. depending on the relay
functionality. These measured
values can be displayed on the
front LCD display or transferred
locally or remotely per user
requirements.
All event, fault and disturbance
records are time tagged to a
resolution of 1ms using the
internal real time clock and are
stored in non-volatile memory.
Where relays are communicating
with a SCADA system, the
protocol’s telegrams can be used
for external time synchronisation
or alternatively an optional
IRIG-B port is available for
accurate time synchronisation on
all P40 relays. Relays can also
use an opto input to synchronise
the internal clock.
Event records
These are generated for status
changes to logic inputs and
outputs, modifications to one
or more setting parameters and
alarm signals.
All events are time-tagged and
stored in chronological order in
cyclic memory. These are readily
available for viewing on the
LCD, or by extraction via the
communication ports.
Fault records
Up to 15 records are supported
for every fault (5 on some
models), with the following
information captured:
■■ A fault number
■■ The date and time
■■ The active setting group
■■ The function that issued the trip
■■ The magnitude of the current/
voltage that gave rise to the trip
command
Distance to fault calculation is
provided on most feeder and line
protection models.
Disturbance records
The internal disturbance recorder
will record the sampled values
of all analogue input variables
such as phase currents and
voltages where applicable during
a fault. Oscillographic analysis
can be performed using the S1
Agile PC tool which will provide
the means to quickly analyse
analogue and digital signals
on the same time scale for
convenience. (Figure 2 on next
page) Disturbance records can
be extracted from the relay via
the communication ports and
saved in the COMTRADE format.
as an option on relays providing
easy access to settings,
records and measurements for
protection engineers. A main
rear communications port is
also available for interface to
a SCADA system. A number of
protocols are available as an
option for this purpose, with
different media such as wired
serial, fibre serial, RJ45 Ethernet,
and fibre Ethernet.
Local communication
The front EIA(RS)232
communication port has been
designed for use with the S1
Agile software and is primarily
for configuring the relay settings
and programmable scheme logic.
It is also used to locally extract
event, fault and disturbance
record information and can be
used as a commissioning tool by
viewing all relay measurements
simultaneously.
Communication
The rear communication
port is based on EIA(RS)485
voltage levels and is designed
for permanent multidrop
connection to network control
and data acquisition systems.
Optional fibre optic and ethernet
communications ports are also
supported on the 40 platform, the
latter available with redundancy.
Relay communications
As standard, a front communication
port is available for local access
to the relay. An auxiliary rear
communication port is available
185
The following protocols are
available:
■■ Courier/K-Bus
■■ Modbus
■■ IEC 60870-5-103
■■ DNP 3.0
■■ IEC 61850
This flexibility allows the MiCOM
Alstom P40 range of relays to be
integrated into a SCADA system
as well as to provide engineering
data for remote access by utility
engineers.
Redundant Ethernet
communication
MiCOM Alstom P40 series
includes several redundant
Ethernet options for IEC 61850 or
DNP3/IP:
■■ Parallel Redundancy Protocol
(PRP) according to IEC 62439-3
■■ Rapid Spanning Tree Protocol
(RSTP)
■■ Alstom Self Healing Ring
■■ Alstom Dual Homing
PRP has the advantage of taking
zero time to recover from a failure,
as parallel alternative paths are
continually operative. All settings
are configurable with the use of
MiCOM S1 Agile.
User interfaces
The ability to customise the menu
text and alarm descriptions are
supported on P*40. The front
panel user interfaces, as per
the example shown in Figure 3
comprise:
(1) A back-lit liquid crystal display
(2) Four fixed function LEDs
186
Figure 2 Oscillography analysis using S1 Agile software for optimum results
(3) Up to 18 user programmable LEDs
(4) Menu navigation and data
entry keys
(5) “READ” and “CLEAR” keys for
viewing and reset of alarms
(6) An upper cover identifying
the product name, which may be
raised to view full product model
number, serial number and rating
information
(7) A lower cover concealing
the front EIA(RS)232 port and
download/monitor port
(8) Facility for fitting a security seal
(9) Up to ten programmable
function keys with tricolour
LEDs – for control and
test applications and easy
annunciation (not visible in the
40TE example shown)
Figure 3
P40 series user interface
Self monitoring
Comprehensive self-monitoring
procedures within the device
ensure that internal hardware and
software errors are detected, thus
ensuring a high degree of reliability.
Automatic tests are performed
during start-up and cyclic selfmonitoring tests are performed
during operation. Any deviations
are stored in non-volatile memory
and the result of the fault diagnosis
determines whether a blocking of
the device will occur or whether
only an alarm is issued.
Supervision of the trip circuit,
whether the breaker is closed or
open (preclosing supervision),
can be implemented using
opto-coupled inputs and the
programmable scheme logic.
functionality within the product.
Communication ports and model/
serial number information are
concealed by upper and lower
covers.
Physical protection of the front
panel user interface and prevention
of casual access is provided by an
optional transparent front cover,
which can be fitted or omitted
according to choice, since the
front panel was designed for IP52
protection against dust and water.
The 40TE case width is often
narrow enough to allow a retrofit
of legacy vertically-mounted relays.
Wiring
External connections are made
via ring type terminals, for the
peace of mind of secure ring lug
and screw-through fastening.
Ring terminals accommodate one
or two lugs per terminal.
The cases are suitable for either
rack or panel mounting as shown
in Figure 4.
Taking into account the differing
case widths, relays can be
combined with or without the use
of standard blanking plates to
form a complete 19” mounting.
This saves space and allows for
a neat installation, especially in
conjunction with MiCOM ALSTOM
P*90 series interfaces, P991 and
MMLG test blocks, and MIDOS
auxiliary relays – all of which
share the same 4U mounting
dimensions.
Mechanical
description
Cases
The Px40 series relays are
housed in a specially designed
case providing a high density of
Figure 4 Typical case dimensions
Case dimensions
Px40
A
40TE
60TE
B
C
D
E
240 (inc wiring)
270 (inc wiring)
157.5 max
206
177
309.6
80TE
413.2
80TErack
483
Note: Maximum sizes for guidance only, for specific product information please
check the relevant product documentation. (All dimensions in mm)
187
Technical data
Measuring inputs – analogue
All CT inputs are dual-rated at 1A
and 5A to simplify ordering and
strategic spares inventories.
The heavy duty terminal block
features integral current
transformer shorting to prevent
dangerous voltages being present
should the block be removed;
a maintenance error could
otherwise lead to a potentially
unsafe/lethal scenario.
Measuring inputs – process bus
IEC 61850-9.2
Many models in the range are
available with an IEC 61850-9.2
process bus interface to replace
traditional analogue inputs. This
facilitates interoperability with
non-conventional instrument
transformers and merging units,
with the measuring signals
marshalled via Ethernet.
IEC 61850-9-2 process bus
interface
An optional process bus interface
is available in MiCOM P40. It
allows the relay to received
current and voltage sampled
data from non-conventional
instrument transformers such
as optical devices and Rogowski
devices. In other digital substation
architectures, the -9-2 data is
generated by merging units in the
yard, which digitize conventional
1A/5A and 100/120V secondaries,
for safer and more economical
cross-site communication to
IEDs by fibre optic. Alstom’s -9-2
188
implementation has been designed
to be especially resilient and
reliable in the presence of “noise”,
such as latency, jitter or missing/
suspect data.
Power supplies
Three ranges of power supply
options are available at the
ordering stage to balance ease of
deployment with energy efficiency.
Digital inputs (Optos)
The digital status input pickup
thresholds are programmable,
so specifying the inputs is just a
question of counting how many
are needed.
General Series Data
Px40
Frequency 50/60Hz
x
Dual rated 1A/5A
x
CT Thermal Ratings Continuous: 4 Inom
for 10s: 30 Inom
for 1s: 100 Inom
x
Opto Inputs
max 48
Output Contacts
max 46
Carry: continuous
10 A
Make and Carry
30 A for 3s
LED Indication (freely programmable)
12 (8) - plus those with function keys
Function Keys/Hot keys
10 functions/2 hotkeys (available on some
models)
Settings Groups
4 (2)
Fault Records
15 (5)
Event Records
up to 1024
Disturbance Records
75 s max
Programmable Logic
Fully programmable
IRIG B
Option
LCD Display
Alphanumeric
Front Port (RS 232)
Yes
Rear Port
Yes, 2nd rear port option
Courier
K-Bus/ EIA(RS) 485 or fibre (some models only)
Modbus
EIA(RS) 485 or fibre (some models only)
IEC 60870-5-103
DNP3.0
IEC 61850
Available on most models
Terminals
Ring
Extended temperature range
operation
In addition to the standard -25oC
to +55oC operating temperatures
claim as per IEC 60255-6, the
P40 range has proven withstand
capability at extremes of
temperature as per IEC 600682. These onerous tests were
passed at -40oC and +85oC for 96
continuous hours in each case.
Application tips
P141 - for cable feeders and
overhead line circuits without
reclosing
■■ P142 - for radial overhead line
circuits employing reclosing
■■ P143 - used where reclosing is
used with check synchronism,
or in applications where the
larger case width is required to
accommodate a larger binary
I/O count
■■ P145 - used where F-keys assist
engineering of the scheme
■■
Nominal
Voltage Vx
Px40
DC
AC
24-48
19-65
-
48-125
37-150
24-110
110-250
87-300
80-265
Overcurrent and feeder management relays
Device
CT inputs
Px40
24/27, 30/34, 48/54, 110/125
and 220/250 (software
selectable)
P142
P143
P145
5
5
5
VT inputs
3
3
3/4
3/4
Opto inputs (max)1
8
16
32
32
32
Output contacts (max)1
7
15
30
Function keys/Hotkeys
2
2
2
12
Interlocking logic
x
x
x
x
Protection
Autoreclose
79
-
x
x
x
Check synchronising
25
-
-
x
x
3 Phase overcurrent
50/51P
x
x
x
x
Ground fault
50/51N
x
x
x
x
Phase directional
67P
x
x
x
x
Ground fault directional
67N
x
x
x
x
Sensitive directional Earth fault
67N
x
x
x
x
Wattmetric Earth Fault
67W
x
x
x
x
Neutral Admittance
YN
x
x
x
x
Restricted Earth fault
64
x
x
x
x
Voltage dependent overcurrent
51V
x
x
x
x
Negative sequence overcurrent
46
x
x
x
x
Thermal overload
49
x
x
x
x
Undercurrent
37
x
x
x
x
Over/Under Voltage
27/59
x
x
x
x
Residual overvoltage
59N
x
x
x
x
Negative sequence overvoltage
47
x
x
x
x
Over/Under Frequency
810/U
x
x
x
x
Rate of Change of Frequency
87R
x
x
x
x
Lock-out
86
x
x
x
x
Directional power
32
x
x
x
x
Circuit-breaker failure
50BF
x
x
x
x
Broken conductor
46BC
x
x
x
x
Voltage Transformer Supervision
VTS
x
x
x
x
Current Transformer Supervision
CTS
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Cold load pick-up
Inrush Blocking
Auxiliary Voltage Vmin/Vmax
thresholds
P141
5
Switch On To Fault
SOTF
Circuit-breaker monitoring
Trip Circuit Supervision
InterMiCOM
TCS
1: Please note that some relays may have a limit on max. I/0 when used as a combination
189
Motor and generator management relays
P241
P242
P243
P341
P342
P343
P344
P345
P346
CT inputs
Device
4
4
7
4
5
8
8
9
8
VT inputs
3
3
3
4
4
4
5
6
4
Opto inputs (max)1
8
16
16
16
24
32
32
32
32
7
16
16
15
24
32
32
32
32
RTDs(option)
10
10
10
-
10
10
10
10
10
Analogue I/O(option)
4/4
4/4
4/4
4/4
4/4
4/4
4/4
4/4
4/4
Function Keys/Hotkeys
x
x
x
x
x
x
x
x
x
Interlocking logic
x
x
x
x
x
x
x
x
x
x
x
Protection
Motor Protection
Short circuit
50/51
Motor differential
87M
x
Locked rotor
50S/51LR/51S
x
x
x
-
-
-
-
-
-
Reverse power
32R
x
x
x
-
-
-
-
-
-
Reacceleration/LV ride-through/
Autorestart
27LV
x
x
x
-
-
-
-
-
-
Startup monitoring/Excessive long start
66/48/51
x
x
x
-
-
-
-
-
-
47
x
x
x
-
-
-
-
-
-
Out of step
55
x
x
x
-
-
-
-
-
-
Loss of load
37
x
x
x
-
-
-
-
-
-
Undercurrent
37P/37N
x
x
x
-
-
-
-
-
-
Unbalance/Lock-out
30/46/86
x
x
x
-
-
-
-
-
-
Speed switch inputs
14
x
x
x
-
-
-
-
-
-
Anti backspin
27ABS
x
x
x
Generator/Transformer differential
87G/T
-
-
-
-
-
x
x
x
x
Check synchronising
25
-
-
-
-
x
x
x
x
x
Interturn/split phase
50DT
-
-
-
-
-
x
x
x
x
Underimpedance
21
-
-
-
-
x
x
x
x
x
Pole slipping
78
-
-
-
-
-
x
x
x
-
Directional power
32
-
-
-
x
x
x
x
x
x
Loss of field
40
x
x
x
-
x
x
x
x
x
Restricted earthfault
64
-
-
-
x
x
x
x
x
x
100% stator earth fault(3rd harmonic)
27TN/59TN
-
-
-
-
-
x
x
x
-
100% stator earth fault(Low Freq.
Injection)
64S
-
-
-
-
-
-
-
x
-
Overfluxing
24
-
-
-
-
x
x
x
x
x
Unintentional energisation at standstill
50/27
-
-
-
-
x
x
x
x
-
Voltage dependent O/C
51V
-
-
-
-
x
x
x
x
x
Rotor earth fault
64R
-
-
-
-
x
x
x
x
x
x
Generator Protection
190
Motor and generator management relays continued
Device
P241
P242
P243
P341
P342
P343
P344
P345
P346
Phase overcurrent
50/51P
x
x
x
x
x
x
x
x
x
Phase directional
67P
-
-
-
x
x
x
x
x
x
Ground fault
50N/51N
x
x
x
x
x
x
x
x
x
Sensitive directional earth fault
67N
x
x
x
x
x
x
x
x
x
Wattmetric earth fault
64N/32N
x
x
x
x
x
x
x
x
x
460C
x
x
x
-
x
x
x
x
x
Negative sequence thermal
46T
-
-
-
-
x
x
x
x
x
Thermal overload
38/49
x
x
x
x
x
x
x
x
x
Under/Over voltage
27/59
x
x
x
x
x
x
x
x
x
59N
x
x
x
x
x
x
x
x
x
47
x
x
x
x
x
x
x
x
x
Under frequency
81U
x
x
x
x
x
x
x
x
x
Over frequency
81O
-
-
-
x
x
x
x
x
x
Turbine abnormal frequency
81AB
-
-
-
-
x
x
x
x
x
Voltage vector shift
dV
-
-
-
x
-
-
-
-
-
Rate of change of frequency
81R
-
-
-
x
x
x
x
x
x
Circuit-breaker fail and monitoring
50BF
x
x
x
x
x
x
x
x
x
Loss of life/Thru fault monitor
LoL/Thru
-
-
-
x
x
x
x
x
x
Dynamic line rating
49DLR
-
-
-
x
-
-
-
-
-
TCS
x
x
x
x
x
x
x
x
x
Protection
Ancillary Functions
1: Please note that some relays may have a limit on max. I/0 when used as a combination
Application tips
P241 - for small/medium motors where the scheme requires only a
small binary I/Ocount
■■ P242 - used in applications where the larger case width is required to
accommodate a larger binary I/O count
■■ P243 – for motor applications requiring differential protection
■■ P341 - used at a grid main interface to a local network having
embedded generation
■■ P342 – for smaller generators not requiring per phase differential
protection
■■ P343 – the standard choice for large generator protection
■■ P345 – for large generators, where the customer requires 100% stator
earth fault by low frequency injection
■■ P346 – for smaller generators requiring differential protection
■■
191
Application tips
Distance and phasor measurement
Device
CT inputs
P441 P442
P443 P444 P445
P446 P847
4
4
8
4
4
4
3/12
VT inputs
4
4
4
4
4
5
3
Opto inputs (max)1
8
16
32
24
16
24
24
14
21
32
46
16
32
24
x
x
x
x
x
x
x
Protection
Distance protection
21/21N
x
x
x
x
x
x
-
- Phase Mho/Quad
21P
-/x
-/x
x/x
-/x
x/-
x/x
-
- Ground Mho/Quad
21G
- Autoreclose
79
- Power swing blocking
78
3 pole
1/3 pole
-/x
-/x
x/x
-/x
x/x
x/x
-
x
-
-
-
x
-
-
-
x
x
x
-
2
-
x
x
x
x
x
x
-
- Out-of-step tripping
68
-
-
x
-
-
x
-
- Check synchronising
25
x
x
x
x
x
2
-
- Switch on to Fault
50/27
- Mutual compensation
Phasor Measurement
PMU
x
x
x
x
x
x
-
x
x
x
x
-
x
-
-
-
-
-
-
-
x
P441 and P445 – for
smaller device size and
optimum functionality
for subtransmission and
distribution
■■ P442 and P444 – distance
relay for transmission
applications
■■ P443 – distance relay with
subcycle tripping for fastest
fault clearance
■■ P446 – for subcycle tripping
applications with dual circuitbreaker topologies (eg.
breaker and a half)
■■ P847 – for phasor
measurement applications
■■
Ancillary functions
Phase overcurrent
50/51P
x
x
x
x
x
x
x
Phase directional
50BF
x
x
x
x
x
x
x
Delta directional Comparsion
ΔI/ΔV
-
-
x
-
-
x
-
Ground fault
50/51N
x
x
x
x
x
x
x
Ground fault directional
67N
Negative sequence overcurrent 46
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Directional negative sequence
46/67
x
x
x
x
x
x
x
Thermal overload
49
x
x
x
x
x
x
x
Under/Over voltage
27/59
x
x
x
x
x
x
x
Redsidual over voltage
59N
x
x
x
x
x
x
x
Under/Over frequency
81U/O
-
x
x
x
x
x
x
Rate of change of frequency
81R
-
-
x
-
x
x
x
Circuit-breaker Failure
50BF
x
x
x
x
x
2
x
Broken Conductor
46BC
x
x
x
x
x
x
x
Stub Bus Protection
50ST
x
x
x
x
x
x
x
Voltage/Current Transformer
Supervision
VTS/CTS
x
x
x
x
x
x
x
Capacitive Voltage
Transformer Supervision
CVTS
x
x
-
x
-
-
-
Channel Aided Scheme Logic
85
x
x
x
x
x
x
-
TCS
x
x
x
x
x
x
x
InterMiCOM
46BC
-
x
x
x
x
x
-
192
1: Please note that some relays may
have a limit on max. I/O when used
as a combination.
2: Denotes functionality for two
circuit-breakers per line
Line differential, transformer and busbar protection relays
Device
CT inputs
P541 P542 P543 P544 P545 P546 P547 P642 P643 P645
P741 P742 P743 P746
P747
4
4
18
4
5
8
5
8
4
8
12
18
4
4
18
VT inputs (max)
-
-
4
5
4
5
4
1
4
4
-
-
-
3
3
Opto inputs (max)1
8
16
16
16
32
24
8
12
24
24
8
16
24
40
48
7
14
14
14
32
32
8
12
24
24
8
8
21
32
32
Analogue I/O (option) 1
-
-
-
-
-
-
-
4/4
4/4
4/4
-
-
-
-
-
RTDs (option) 1
-
-
-
-
-
-
-
10
10
10
-
-
-
-
-
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Interlocking Logic
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
-
-
-
-
-
-
-
-
-
Protection
Line differential
- 2 terminal
87P
- Neutral differential
87N
- 2/3 terminal
- FO signalling
-
-
x
x
x
x
-
-
-
-
-
-
-
-
-
x
x
x
x
x
x
-
-
-
-
-
-
-
-
-
x
x
x
x
x
x
-
-
-
-
-
-
-
-
-
- SDH/Sonet networks
78
-
-
x
x
x
x
-
-
-
-
-
-
-
-
-
- In-zone transformer
68
x
x
x
-
x
-
-
-
-
-
-
-
-
-
-
x
x
x
-
x
-
-
-
-
-
-
-
-
-
-
- 2nd harmonic restraint
x
x
x
-
x
-
-
-
-
-
-
-
-
-
-
2 breaker configuration
- Vector compensation
50/27
-
-
-
x
-
x
-
-
-
-
-
-
-
-
-
- Direct/permissive
intertripping
x
x
x
x
x
x
-
-
-
-
-
-
-
-
-
Phase comparison
87PC
-
-
-
-
-
-
x
-
-
-
-
-
-
-
-
- PLC signalling
0
-
-
-
-
-
-
x
-
-
-
-
-
-
-
-
Transformer Differential
87T
-
-
-
-
-
-
-
x
x
x
-
-
-
-
-
- Windings/Bias inputs
0
-
-
-
-
-
-
-
2
3
5
-
-
-
-
-
Restricted Earth fault
87G/64 -
-
-
-
-
-
-
2
3
3
-
-
-
-
-
- Overfluxing/5th harmonic
0
-
-
-
-
-
-
-
x
x
x
-
-
-
-
-
- Overexcitation
24
-
-
-
-
-
-
-
x
2
2
-
-
-
-
-
- 2nd harmonic restraint
0
-
-
-
-
-
-
-
x
x
x
-
-
-
-
-
Busbar Protection
87BB
-
-
-
-
-
-
-
-
-
-
x
x
x
x
x
- Central unit feeders
0
-
-
-
-
-
-
-
-
-
-
2B
-
-
6/18
18
- Peripheral units
0
-
-
-
-
-
-
-
-
-
-
-
x
x
-
-
- Phase-segregated
differential zones
87P
-
-
-
-
-
-
-
-
-
-
8
-
-
2
4
- Sensitive Earth fault
differential zones
87N
-
-
-
-
-
-
-
-
-
-
6
-
-
-
-
- Check zone
87CZ
-
-
-
-
-
-
-
-
-
-
8
-
-
x
x
- CT supervision
CTS
x
x
x
x
x
x
x
x
x
x
x
x
- CT saturation immunisation
0
-
-
-
-
-
-
-
-
-
-
-
x
x
x
x
- Fibre optic signalling
0
-
-
-
-
-
-
-
-
-
-
x
x
x
-
-
Continued on next page...
193
Line differential, transformer and busbar protection relays (...continued)
Device
P541
P542
P543 P544 P545 P546 P547 P642 P643 P645 P741 P742 P743 P746
P747
Ancillary Functions
Phase Overcurrent
50/51P
x
x
x
x
x
x
x
x
x
x
-
x
x
x
x
Phase Directional
67P
-
-
x
x
x
x
x
-
x
x
-
-
-
-
x
Ground Fault
50/51N x
x
x
x
x
x
x
x
x
x
-
x
x
x
Ground Fault Directional
67N
-
x
x
x
x
x
-
x
x
-
-
-
-
-
CT Supervision/ Differential CTS
CTS
-
-
x
x
x
x
x
x
x
x
x
x
x
x
x
Sensitive Directional Earth Fault
67N
-
-
x
x
x
x
x
-
-
-
-
-
-
-
-
Wattmetric Earth Fault
64W
x
x
x
-
x
-
-
-
-
-
-
-
-
-
-
Distance Protection
21
-
-
x
x
x
x
x
-
-
-
-
-
-
-
-
Power Swing Blocking
78
-
-
x
x
x
x
x
-
-
-
-
-
-
-
-
Check Sync
25
-
-
x
-
x
-
x
-
-
-
-
-
-
-
-
Negative Sequence
Overcurrent
46
-
-
x
x
x
x
x
x
x
x
-
-
-
-
-
Thermal Overload
49
x
x
x
x
x
x
x
x
x
x
-
-
-
-
-
Loss of life and Through Fault
LOL
-
-
-
-
-
-
-
x
x
x
-
-
-
-
-
Under/Over Frequency
81U/O
-
-
x
x
x
x
x
x
x
x
-
-
-
-
-
Circuit-breaker Failure
50BF
x
x
x
2
x
2
x
2
3
5
x
x
x
6/18
18
Autoreclose
79
-
3
pole
1/3
pole
-
1/3
pole
-
-
-
-
-
-
-
-
-
-
Over/Under Voltage
27/59
-
-
x
x
x
x
-
-
x
x
-
-
-
-
x
TCS
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
1: Please note that some relays may have a limit on max. I/O when used as a combination.
2: Denotes functionality for two circuit-breakers per line
Application tips
P145 – the typical high impedance busbar
protection choice
■■ P541 – for cable and line differential in an
economical device size for distribution
■■ P543 – the standard choice line differential for
subtransmission and transmission applications
■■ P545 - used in applications where the larger case
width is required to accommodate a larger binary
I/O count
■■ P547 – for phase comparison line unit protection
operating via power line carrier
■■ P642 – for two winding transformer differential
with one set of CTs per side
■■
194
P643 – for three sets of phase CTs in a transformer
differential scheme, or where 3-phase voltagebased functionality is required
■■ P645 – for transformers requiring four or five CT
bias input sets to the scheme
■■ P741 – central unit in a busbar scheme typically
with three or more discrete zones
■■ P742 – the typical busbar protection peripheral unit
used per feeder bay
■■ P746 – for simple busbar topologies with one or
two discrete protection zones
■■ P747 - centralised busbar protection for up to 18
feeders and four zones
■■
Autoreclose relays
P841
P842
CT inputs
Device
4/9
-
VT inputs
4/5
4
Opto inputs (max)
32
48
Output contacts (max)
32
32
Protection
Breaker Failure Protection
50BF
x/2
-
- 2-stage
c
x
-
x
x
- Pole discrepancy
Typical application
advice:
P841 – for autoreclose,
check synchronism, breaker
fail and backup protection
of transmission and
subtransmission circuits
■■ P842 – UK-specific mesh
corner reclosing device
■■
Product selector
Up-to-date guidance on the
best protection product can be
explored within our product
selector, available from:
http://www.alstom.com/
grid/products-and-services/
Substation-automation-system/
protection-relays/MiCOMAlstom-product-selector/
Autoreclose
79
x/2
- Mesh corner/Single switch
78
-
x
- Check sync
25
x/2
x
-
x
- Ferroresonance suppression
Voltage and Frequency Protection
50/27
- Undervoltage
27
x
-
- Overvoltage
59
x
-
- Residual overvoltage
59N
x
-
- Under/Over frequency
81U/O
x
-
- Rate of Change of Frequency (df/dt+t)
81R
x
-
- Frequency Supervised Rate of Change of
Frequency (f+df/dt)
81RF
x
-
- Frequency Supervised Average
Rate of Change of Frequency f+Δ f/ Δt)
81RAV
x
-
- Trip Circuit Supervision
TCS
x
x
1: Please note that some relays may have a limit on max. I/O when used as a combination.
2: Denotes functionality for two circuit-breakers per line
Device track record
P14x series introduced in 1999. Worldwide application, with over 95 000 units delivered.
P64x series introduced in 2009. Worldwide application, with over 4600 units delivered.
P74x series introduced in 2002. Worldwide application, with over 2100 schemes delivered.
195
196
Substation Automation Solutions | P847 PMU
MiCOM Alstom
P847
Phasor measurement
unit
MiCOM Alstom Phasor Measurement Units (PMU)
provide high quality, synchronised measurements of
key power system quantities.
Customer benefits
Measures accurate, time synchronised power system data
Communicates synchrophasors according to IEEE C37.118
■■ Available with ancillary protection, control and
recording functions
■■ Galvanic, fibre optic and redundant communication
options
■■
■■
197
Stability and thermal limits, voltage collapse and loop flows are
constraints that electrical power system planners and operators
continually have to deal with. With today’s stretched systems,
often having minimal reserve, cascading events, such as the loss
of generator units or transmission lines, can easily lead to severe
power swings, voltage collapses, possible loss of synchronism and
underfrequency load shedding. Real-time knowledge of system
conditions and changes is at the heart of the battle to maintain
security of supply.
The MiCOM Alstom P847 is a product that can help in this battle by
providing highly accurate, time-synchronised phasor measurements
(synchrophasors) from anywhere in the system.
Use the Phasor Measurement Unit (PMU) as part of a wide area
monitoring and control system to assess key metrics in, or between,
critical areas in the power system. High-speed transfer of key system
parameters, complemented by cutting-edge visualisation tools at the
control centre, enhances the system management capability.
Physical communications
Galvanic or fibre optic Ethernet communication
ports are provided for streaming synchrophasor
data. Redundant Ethernet is available, optionally
managed by the market’s fastest recovery time
protocols: ‘self-healing’ ring and ‘dual homing’ star,
allowing bumpless redundancy. IEC 62439 PRP
and RSTP are also available, offering multi-vendor
interoperability.
198
■■
■■
■■
■■
Anticipate impending system
failures such as angular
instability by monitoring
bus angles between key
generating areas
Predict impending voltage
instability problems by
monitoring high VAR flows
in the network associated
with fast declines in regional
voltage magnitudes
Invoke system wide defence
plans to ensure system
stability is maintained.
Improve control to prevent
the risks of unnecessary
islanding, damage to costly
transmission equipment,
unnecessary load shedding,
and blackouts.
IEEE C37.118 synchrophasor
communications
The MiCOM P847 supports synchrophasor data
transmission according to IEEE C37.118 via UDP/
IP and TCP/IP. Synchrophasors to be transmitted
via IEEE C37.118 can be selected from the available
set, by simply enabling or disabling them in the
PMU configuration column of the menu.
Software tools
Event records
Software tools are available for the configuration,
monitoring and analysis of multiple P847 PMUs.
All PMU settings can be configured using MiCOM
S1 Agile locally or remotely.
Up to 512 time-tagged event records are stored in
battery backed memory.
Dynamic performance
The oscillography can record up to 12 analogue
channels and 32 digital channels at a resolution
of 48 samples per cycle. Disturbance records
can be extracted from the relay via the remote
communications and saved in the COMTRADE
format.
Under dynamic system conditions the PMU needs
to track system parameters very accurately and this
is ensured with an advanced frequency tracking
algorithm able to perform accurately even under
off-nominal frequency and abnormal voltage and
current conditions.
Programmable Scheme Logic
(PSL)
Powerful graphical logic allows the user to create
customised logic schemes using logic gates, latches
and timers. Inputs to the PSL can include digital
inputs and programmable function keys; outputs
can include programmable LEDs, user alarms and
IEEE C37.118 digital data.
User Interface
The front panel user interface consists of an LCD
display, navigation keypad, 10 programmable
function keys, fixed function LEDs and 10
programmable function LEDs.
Disturbance records
Language support
The user interface and menu text are available in
English, French, German and Spanish as standard.
The ability to customise the menu text and alarm
descriptions is also supported.
Quality Built-in (QBi)
Alstom Grid’s QBi initiative has deployed a
number of improvements to maximise field quality.
Harsh environmental coating is applied to all
circuit boards to shield them from moisture and
atmospheric contamination. Transit packaging
has been redesigned to ISTA standard, and the
third generation of CPU processing boosts not only
performance, but also reliability.
Password protection
Password protection may be
independently applied to the front
user interface, front communications
port and rear communications port.
Two levels of password protection
are available providing access to the
controls and settings respectively.
Side view of MiCOM Alstom P847 B/C PMU
199
Related products
Phasor Terminal
Phasor Measurement Units (PMUs), such as the
MiCOM P847, output synchronised phasor data
over an Ethernet network at rates of up to 60
frames per second. This results in large amounts
of data being produced that can be challenging
to handle in real time when commissioning or
troubleshooting an individual PMU or even a small
Wide Area Monitoring System (WAMS).
Phasor Terminal solves this problem; it is a software
tool that provides clear visualisation and archiving
of real time IEEE C37.118-2005 data. Multiple
PMUs can be quickly and easily configured,
connected and graphically compared using an
intuitive drag-and-drop interface.
Phasor Terminal, Synchrophasor visualisation
and archiving tool
Substation Phasor Data Concentrator (sPDC)
In support of the MiCOM P847 PMU, a Substation Phasor Data Concentrator is available to aggregate
and time-align high speed synchronised data from multiple P847s into a single data stream.
The PhasorPoint sPDC offers the following functionality:
Receives multiple PMU streams
Phasor stream rate conversion
■■ Phasor stream time alignment
■■ Multi-rate stream outputs
■■ User defined content for stream outputs
(managing data provided to third-parties)
■■ Local rolling buffer storage
■■ Data recovery for upstream archive
(PhasorPoint Central PDC based systems only)
■■ Cyber-security
■■
■■
PhasorPoint substation phasor data concentrator
200
Applications
Synchronised phasor measurements can be transmitted by the MiCOM Alstom P847 to a PhasorPoint
Phasor Data Concentrator (PDC) or other upstream application using a high speed communications
link. The applications that can be deployed to utilise synchrophasor data include wide area monitoring,
visualisation and alarming, post-event analysis, islanding detection and oscillatory stability management.
Islanding, Resynchronisation and Blackstart (IRB)
The MiCOM Alstom P847 can be applied to make
synchronised measurements of key variables such
as voltages, currents and phase angles at strategic
busses and corridors in the transmission system.
These measurements can be used by the
PhasorPoint Islanding, Resynchronisation and
Blackstart (IRB) application to aid the operator
before, during and after an islanding event.
PhasorPoint Islanding,
Resynchronisation and Blackstart (IRB)
Oscillatory Stability Management (OSM)
Synchrophasor data from the MiCOM Alstom
P847 can be used by the PhasorPoint Oscillatory
Stability Management (OSM) application to allow
power system operators to visualise and analyse
real time power system dynamics. By studying the
oscillatory modes of a power system this application
can be used to detect and manage power system
oscillations which can be a sign of system instability.
PhasorPoint Oscillatory Stability Management (OSM)
Main features
Product variants
Three models of the MiCOM P847 Phasor Measurement Unit are available: A, B, and C.
Model A features a three-phase VT input and a three-phase CT input and provides phasor measurements of
the three-phase voltages, the three-phase currents and the derived sequence components. Basic protection
functions including under and over, frequency, voltage and current, and circuit-breaker monitoring are
included in the P847 A.
As well as the three VT inputs, Models B and C feature twelve CT inputs. The CT inputs can be configured
as 4 sets of three-phase measurements or 12 independent phasor measurements. No protection functions
are available in Models B & C. The functions available in each model are outlined in full in the table overleaf:
201
MAIN FEATURES
ANSI
FEATURES
P847 A
P847 B
P847 C
PMU
Synchronised phasor measurements
-
-
-
Voltage channels
3
3
3
Current channels
3
12
12
Optocoupled logic inputs
8
16
24
Conventional output contacts
8
1A and 5A CT inputs
-
-
-
Direct access menu “Hotkeys”
-
-
-
-
-
24
Multiple password access levels
-
81U/O/R
Under/Over and rate of change of frequency
-
50/51/67
Phase overcurrent stages
-
50N/51N/67N
Earth/Ground overcurrent stages
-
51N/67N/SEF
Sensitive Earth Fault (SEF)
-
67/46
-
46BC
Broken conductor
-
49
Thermal overload
-
50BF
High speed breaker fail
-
VTS
Voltage transformer supervision
-
Fault locator
-
Event records
-
-
-
Disturbance recorder
-
-
-
Circuit-breaker condition monitor
-
Graphical Programmable Scheme Logic
-
-
-
GPS time synchronisation input
-
-
-
IEEE C37.118-2005 communications
-
-
-
-
-
SOE
PSL
GPS
Redundant Ethernet (option)
202
Substation Automation Solutions | P40 Agile
P40 Agile
Feeder management
IEDs
The P14N non-directional feeder, P14D directional
feeder and P94V voltage & frequency IEDs bring
the design rigour and technology of transmission
applications to the entire utility and industrial
market.
The footprints of both the device physical size and the
lifecycle environmental impact have been minimised
using state-of-the-art design, component, and
process selection. Agile solutions from Alstom are
ideal for new-build and retrofit alike.
Customer benefits
Novel I Draw-out I Versatile
Powerful logic, protection and communications
■■ Cost effective IEC 61850 and DNP3 Ethernet solution
■■ High impedance downed conductor element boosts the
safety of the public and livestock
■■ Alstom’s user-centric access tool ‘S1 Agile’ used as the
single PC tool for all MiCOM
■■ NERC compliant cyber security
■■
■■
203
Agility, versatility
MiCOM P40 Agile IEDs provide an integrated solution for the
complete protection, control and monitoring of electrical power
systems. Application for overhead lines, underground cables, busbars,
breakers, transformers, reactors, distributed generation and motors
is supported, right from distribution (as primary protection) to
transmission voltage levels (as back-up). The IEDs are suitable for
application in solidly-earthed, resistance earthed and Petersen coil
systems alike.
The perfect balance:
standardised and adaptable
With a wide range of protection functions as standard, MiCOM P14N,
P14D and P94V IEDs also offer additional pre-configured applications
for smaller generators and a choice of functionality applicable
to overhead lines. This allows the user to conveniently scale the
application, which is then readily adapted via simple enable/disable
feature selection in the configuration menu.
The IEDs offer a universal wide-range power supply, universal 1A/5A CT
inputs (software selectable), and universal binary inputs - the latter with
programmable pickup thresholds. Harmonisation at just one ordering
option is often possible, easing the task of creating standard cubicle
designs and strategic spares holding.
Model
Hardware Base
Intended application
P14NB
P14N
Non-directional feeder
P14NZ(1)
P14N
Non-directional feeder with HIF(2)
P14DB
P14D
Directional feeder
P14DG
P14D
Distributed generation
P14DL
P14D
Advanced directional feeder protection (with autoreclose and fault locator)
P14DZ(1)
P14D
Advanced directional feeder with HIF(2)
P94VB
P94V
Voltage and frequency
P94VP
P94V
Voltage and frequency with check synchronising
(2)
204
(1)
Only with sensitive earth fault CT option
HIF - high impedance (downed conductor) fault
P40 AGILE PROTECTION FUNCTIONAL OVERVIEW
ANSI
FUNCTION
P14NB
50
Definite time overcurrent
6
50N
Neutral/Earth definite time overcurrent
4
P14NZ
P14DB
P14DG
6
6
6
6
6
4
4
4
4
4
Non-Directional
P14DL
P14DZ
51
IDMT overcurrent
3
3
3
3
3
3
51N
Neutral/Earth IDMT overcurrent
2
2
2
2
2
2
50/51SEF
Sensitive earth fault
4
4
4
4
4
4
51V
Voltage controlled overcurrent
*
*
*
*
*
*
*
50 SOTF
Switch on to fault
*
*
*
*
*
*
68
Inrush blocking
*
*
*
*
*
*
Cold load pick up
*
*
*
*
*
*
*
*
4
4
Load encroachment supervision
(Load blinders)
HIF
High impedance earth fault
46
*
46BC
Broken conductor
*
*
*
*
*
*
Programmable curves
4
4
4
4
4
4
4
4
P14VP
Voltage & frequency
Directional
Voltage restrained overcurrent
P14VB
*
4
4
67
Directional phase current
6
6
6
6
67N
Directional neutral current
4
4
4
4
Sensitive directional earth fault
4
4
4
4
Wattmetric earth fault
*
*
*
*
*
*
*
Blocking scheme
*
*
*
37
Undercurrent detection (low load)
*
*
*
32
Phase directional power (Forward / Reverse /
Under / Over)
49
Thermal overload
*
*
*
*
*
*
50BF
CB failure
2
2
2
2
2
2
21FL
Fault locator
*
*
27
Undervoltage
3
3
3
3
3
3
59
Overvoltage
3
3
3
3
3
3
59N
3
3
3
3
3
3
47
*
*
*
dv/dt
Rate of change of voltage
79
Autoreclose (number of shots)
4
*
*
*
2
2
2
*
*
4
4
4
4
*
4
205
P40 AGILE PROTECTION FUNCTIONAL OVERVIEW (...continued)
ANSI
FUNCTION
25
Check synchronising
81O
Overfrequency
81U
81V
P14NB
P14NZ
P14DB
Non-Directional
P14DG
P14DL
P14DZ
P14VB
P14VP
Voltage & frequency
Directional
*
*
*
9
9
9
9
9
9
Underfrequency
9
9
9
9
9
9
Undervoltage blocking of frequency protection
*
*
*
*
*
*
81df/dt
81Rf
81RAV
Rate of change of frequency, with
optional frequency supervision
and averaging
9
9
9
9
9
9
81R
Frequency restoration
9
9
64N
Restricted earth fault
*
*
87B
High impedance busbar
*
*
PSL
Programmable scheme logic
*
*
86
Latching output contacts (Lockout)
*
*
VTS
CTS
*
9
*
*
*
*
*
*
*
*
*
*
*
*
*
*
VT supervision
*
*
*
*
CT supervision
*
*
*
*
*
*
*
*
*
*
4
4
DC supply supervision
*
*
CB condition monitoring
*
*
*
*
*
*
Setting groups
4
4
4
4
4
4
The numbers in the table denote the number of elements or stages available
Intuitive User
Interfaces
The front-panel interface (shown
in Figure 1) allows direct IED
interaction. A USB front port
offers enhanced access by laptop
computers. Integrated user
function keys and tri-colour
programmable LEDs provide a
cost effective solution for control
and annunciation. Numerous,
optional, modern communication
protocols, including IEC 61850,
ensure interfacing to upper-level
Supervisory, Control, Automation
or Data Acquisition systems.
206
Figure 1 P40 Agile front panel interface
Environmental responsibility
The IEDs are manufactured in a lead-free soldering process using lead-free components. Power dissipation
is the lowest among comparable products, easing concern on station batteries. Even the product weight
(including packaging) has been optimised to lessen the transit carbon footprint. All such actions boost the
eco-responsibility demonstrated in the Product Environment Profile (PEP). The product does not require any
resident battery.
The PEP shows claims for raw material depletion, energy depletion, water depletion, global warming
potential, ozone depletion, photochemical ozone creation, air acidification, and hazardous waste pollution.
Quality Buit-In
Quality Built-In methodology is applied throughout the development and manufacturing of the IEDs. Parts
stress analysis in R&D, rigorous component supplier selection, and a shipping carton compliant with ISTA
protection requirements are all examples of best-practice to maximise long-life reliability. All circuit boards
have harsh environmental coating, to resist moisture, salt, corrosive atmosphere and industrial ambient
pollution - as standard. Circuit board production uses in-circuit tests, boundary scanning, built-in self test,
automated optical inspection, and X-ray scanning to achieve maximum test coverage.
Figure 2 depicts the software scalability of models, within the overall superset of the range functionality.
The strong P40 family identity offers high customer familiarity, with minimal training requirements.
Cyber-security
The sophistication of protection schemes, coupled with the
advancements of technology, increasingly leads to devices and
substations being interconnected with open networks, such as the
internet or corporate-wide networks. This introduces a potential
security risk making the grid vulnerable to cyber-attack, which could
in turn lead to electrical outage. To secure communication within such
environments, MiCOM P14N, P14D and P94V offer NERC-compliant
cyber security.
Asset life extension
In addition to new-build, P40 Agile IEDs can be used to refurbish
legacy protection schemes. As MiCOM P14N and P14D are pin-to-pin
compatible with KCGG14x and KCEG14x respectively, they can simply
be plugged-in to the K relay cases for an easy upgrade. This draw-out
and substitute strategy dramatically reduces the refurbishment time
and cost.
Figure 2 P40 Agile application scalability
207
Hardware
All models offer:
Space-saving 4U height and
20TE (4”) or 30TE (6”) case sizes
■■ A front USB port and a rear
RS485 port
■■ Power-up diagnostics and
continuous self-monitoring
■■ 8 opto-isolated binary inputs,
and 8 output relays
■■ N/O (form A) and N/C (form
B) watchdog contacts
■■
208
Figure 3
Example P40 Agile standard hardware (P14D)
HARDWARE OVERVIEW
FUNCTIONS
P14NB
Option
P14NZ
P14DB
P14DG
Option
Option
Non-Directional
P14DZ
Option
P14VB
P14VP
Voltage & frequency
Directional
Option
Rear communications port
P14DL
Option
RS485, Fibre optic, or Ethernet
RS485
RS485
2nd Rear port hardware options
RS485
RS485
RS485
RS485
RS485
RS485
RS485
RS485
IRIG-B hardware options
Option
Option
Option
Option
Option
Option
Option
Option
Communication protocols
IEC-103, IEC 61850, Modbus, Courier, DNP3, or DNP3 Ethernet
Digital inputs min./max. hardware options
8/13
8/13
8/13
8/13
8/13
8/13
8
8
Output relays min./max. hardware options
8/12
8/12
8/12
8/12
8/12
8/12
8
8
3ph + N
3ph + N
3ph + N
3ph + N
3ph + N
3ph + N
4
4
4
4
4
4
CT (AC Current inputs: 1 and 5A software selectable
100/120V VT (AC voltage inputs)
IEC-103, Modbus,
Courier, or DNP3
The numbers in the table denote the number of elements or stages available
Alstom Grid: Feeder device track record
CDG - Forerunner of feeder developments undertaken by Alstom in
Stafford since 1949
MCGG - World’s first mass-produced digital relay launched in 1984
and sold over 80,000 units.
KCGG/KCEG - First fully-numerical overcurrent relay launched in
1992 and sold over 100,000 units.
P14x MiCOM series introduced in 1999. Worldwide application,
with over 95,000 units delivered.
Addition of UCA2 protocol and Ethernet port in 2004
Addition of IEC 61850 protocol in 2004
P40 Agile tested in the ILAC-accredited automation product
laboratories in Stafford
MiCOM P40 Agile: | Novel | Draw-out | Versatile
209
210
P60 Agile
Feeder protection
P60 Agile enhances Alstom’s range of IEDs by
providing a ‘One Box solution’ for protection, control
and monitoring of electrical power systems.
Customer benefits
Bay visibility: large HMI with configurable views
One box solution: protection, control and measurements
■■ Integration into existing substation automation:
choice of communication protocols
■■ High performance (1.5 ms) IEC 61850-8-1 GOOSE
■■ Low depth design for installation in switchgear LV
compartment
■■
■■
211
Compact | Multifunction | Versatile
P60 Agile One Box solutions
The P60 range is suitable as main or backup protection for a wide range of typical applications and
covers all common power system earthing arrangements such as solid, resistive, or resonant earthing
and isolated networks. The colour touch-screen HMI with provision for bay mimic display and integrated
control / interlocking functions maximises the application range of the P60 family. The fully programmable
nature of P60 Agile makes it an extremely versatile and cost effective solution for all switchgear applications
with varied protection requirements.
Alstom’s one box solution brings touch-screen technology into the
substation. Switchgear control and single-line diagram presentation is
achieved thanks to the full colour, graphical HMI.
The P16x series comprises the P161, P162 and P163 feeder
management IEDs. Each requires a shallow depth of only 90 mm
behind the panel, for ease of mounting within any switchgear cabinet.
High performance features include 1.5 ms GOOSE, graphical logic,
colour bargraph displays, and optional motor protection. IEC 61850,
Modbus, Profibus DP, CANBUS and IEC 60870-5-103 protocols are
available for full system integration.
Human machine interface
The P60 Agile has a state-of-the-art HMI with intuitive and easy
navigation across the full range of its features and functionality. The
membrane keypad hosts up to 6 configurable function keys and eight
programmable LEDs, in addition to a USB port for communication
with the PC-based configuration software.
The default HMI may be configured to display user preferences such
as the single line diagram or load flow parameters such as voltages or
currents instead of the Main Menu shown. The IED’s touchscreen along
with hotkeys facilitate quick and convenient access to the whole menu
system.
Up to four user-defined pages are available in the home menu, with
easy touch-screen navigation from one to the next.
Main menu screen
212
Switchgear control
The P60 Agile offers comprehensive switchgear control, aided by
the dynamic single-line-diagram display, ON/OFF switching via the
function keys and programmable bay and inter-bay interlocks. Up to
five (5) switchgear elements may be switched by the P60 Agile bay
control models. The single line diagram for the bay or a subset of the
substation, along with relevant data such as measurements or alarms,
may be generated by the user via the P60 configuration tool, aided by
integrated graphical icons. Remote controls are facilitated by the relay’s
SCADA communication interfaces.
Example single line diagram (SLD)
display
The provision of such powerful control capacity within the relay (the
“one box” concept) negates the need for external control, switches
and annunciation on the panel. Equipment cost and panel engineering
time is reduced. For ease of operability and security of the command,
dedicated open and close push buttons are provided on the P60 Agile
front panel.
Protection + Control + Measurement +
Recording = One-box solution
Applications
Feeder protection
All models of P60 Agile provide
full-featured overcurrent and
earth fault protection, with six
stages and a choice of definitetime or IDMT characteristics,
including reset curves.
Applications involving directional
earth fault are covered by the
P162, and the P163 provides
full directional control of phase
and earth fault elements in four
independent stages. Harmonic
stabilisation for inrush, voltage
control and customisable
directional characteristic
boundaries all add to the
versatility of the feeder protection
functions. Sensitive earth fault
(SEF) applications are also
covered by the P60 Agile with a
choice of CTs for the neutral input.
Core balance CTs may be
connected for maximum
sensitivity, also the neutral
displacement voltage may be fed
from a broken-delta VT where
available. The integral multishot autoreclosing function
supplements the application of
feeder protection where transient
faults on overhead lines are
expected.
Distributed generation
protection
The P163 relay features
two-stage voltage vector
surge protection for islanding
applications, with the enhanced
security of supervision by load
current change. Three stages
of df/dt (rate of change of
frequency) are also available
in the P163, with the flexibility
of configurable hysteresis
and supervision by frequency
thresholds and/or direction.
The P163 also features under/
over voltage and under/over
frequency protection with
twelve (12) stages each and
the possibility of assigning the
measurement to any of the threephase VTs signals in the relay
hardware on a per-stage basis,
thereby securing the applications
against the loss of a single VT input.
213
Dynamic grid support
The P60 is designed with the
need for availability of modern
high voltage and medium
voltage networks in mind. In
the event of single or multiple
short circuits in medium or high
voltage networks, immediate
mains decoupling of distributed
generation may be allowed only
under specific conditions defined
by the operators.
The P60 Agile includes custom
functions for fault ridethrough with up to ten (10)
permissible voltage dips and
for reactive power direction
protection, and has been KEMA
certified in accordance with
the requirements of the BDEW
utilities’ standard, Germany.
Functional Overview
Programmable Logic Control
(PLC)
The P60 Agile relays feature
comprehensive programmable
logic, with logic gates, flipflops, counters, timers and
timed switches. Users can
customise the logic associated
with protection functions via the
PLC, combining outputs from
the function block, binary input
signals and and inter-device
signals (IEC 61850 GOOSE) in
the PLC. Up to 500 logic gates
can be programmed.
Configuration of breaker or
switchgear element control
utilises similar logic capability,
214
with customisable triggering
logic, interlocking and bypass
features for each control action
(eg: opening, closing, earthing)
associated with the switchgear
element.
User-programmable alarm
conditions can trigger on-screen
customised text alarms. Each text
field can be up to 40 characters,
enabling alarms to be simple
and explicit for maintenance/
operational personnel.
Each alarm, and each entry in
the event record can be colourhighlighted to correspond
with the urgency, or customer
classification desired.
Four alternative settings groups
are provided, such that P60
Agile may adapt to switched or
emergency feeding scenarios.
Front port setting and
interrogation
The USB front port provided on
the P60 Agile relay is used for
the configuration of settings,
logic, and other downloadable
data. An additional min-USB
port is available at the side of
the housing which provides the
same functionality as the front
USB port. Alternatively, setting
and interrogation may be made
from the menu system accessible
on the front HMI. Password
protection is provided, with the
touch-screen providing a virtual
keypad display for fast entry of
the password.
Simplicity of logic programming
provided by P60 Agile
Rear communications
P60 Agile has 3 rear serial
communications ports, operating
at Baud rates up to 57.6 kbit/s.
Port 1 is dedicated for MODBUS,
Port 2 for IEC 60870-5-103
(optional) and Port 3 for Profibus
DP (optional). IEC 61850 is
available, with single port pointpoint connection, and RSTP
redundant options. Accurate time
synchronisation can be achieved
using IRIG-B or SNTP.
Fast IEC 61850 GOOSE
128 GOOSE inputs and 128
GOOSE outputs are available,
offering best-in-class GOOSE
performance (typically 1.5 ms
response time, class P3).
Overcurrent protection
There are six stages of
overcurrent protection provided
in the P60 Agile family, with
a choice of definite time, IEC
Inverse or ANSI Inverse curves
for time-coordinated tripping.
The overcurrent protection
features also include reset curves,
blocking inputs and harmonic
stabilisation to facilitate a variety
of protection schemes. The
function may be directionalised
in relay models with three-phase
voltage inputs.
Earth fault protection
The earth fault protection
functions in the P60 Agile
include sensitive earth fault,
wattmetric earth fault, neutral
voltage displacement and
neutral admittance protection in
addition to the standard residual
current based protection. All the
functions have multiple stages
and permit flexible scheme
configuration with instantaneous
(start) and timed event outputs.
Voltage protection
The P163 provides
comprehensive overvoltage and
undervoltage protection, with up
to twelve stages and phasephase or phase-earth voltage
as the measurand. The voltage
measurement for each stage
may be assigned to any of the
three VT inputs in the relay for
maximum flexibility.
Protection functions are conveniently referenced according to their
IEEE/ANSI function number.
P60 AGILE PROTECTION FUNCTION OVERVIEW
ANSI
FUNCTION
P161
P162
P163
51/51N
IDMT overcurrent/earth fault protection
*
*
*
51SEF
Sensitive earth fault
*
*
*
50/50N
Definite time overcurrent/earth fault protection
*
*
*
68
Inrush blocking
*
*
*
50BF
Breaker failure protection
*
*
*
67
Directional overcurrent protection
67N
Directional earthfault protection
*
*
*
Neutral admittance
*
*
59N
*
*
59
Overvoltage
*
27
Undervoltage
*
27T
Fault ride-through (BDEW)
*
27Q
Reactive power support (BDEW)
*
81O
Overfrequency
*
81U
Underfrequency
*
78
Vector surge
*
81R
Rate of change of Frequency (df/dt)
*
32
Power protection
79
Multishot autoreclose
25
Check synchronising
CTS
CT supervision
VTS
VT supervision
*
*
*
*
*
*
*
*
*
74
Trip circuit monitoring
49
Thermal overload
*
*
*
32N
Wattmetric earth fault protection
*
*
*
46
*
*
*
51V
Voltage dependent overcurrent
*
*
CLP
Cold load pick-up
*
*
*
46BC
Broken conductor
*
*
*
64R
Restricted Earth Fault (REF)
*
*
*
*
215
Platform Overview
The P60 Agile is designed for
reliability with four powerful
microprocessors and an integral
cross-monitoring feature. The
slim profile hardware (< 90 mm
depth) makes it easy to fit into
any switchgear compartment.
The compact design together
with the robust stainless steel
housing provides rigidity, a wide
operating temperature range,
and maximum shock and bump
capability for even the most
demanding applications. The
design pedigree draws from
utility, industry, marine and
genset installed base experience.
■■
■■
HMI
Full colour touchscreen display
*
Programmable hotkeys
*
3 x status LEDs
*
8 x programmable LEDs
*
USB port
*
Communication
MODBUS, RS 485/422
*
PROFIBUS DP, RS485
(O)
IEC 60870-5-103, RS485
(O)
IEC 61850 station bus
(O)
IEC 61850 station bus, RSTP
redundancy
(O)
BINARY INPUTS / OUTPUTS
Digital inputs, wide range
19
The innovative design of the
P60 allows functions to be
distributed between hardware
and software implementation.
For example, the eight freelyprogrammable physical LEDs
can be supplemented with
virtual LEDs on the LCD screen.
Relay outputs
12
Terminal blocks on the rear of
the device are typically pin-type
and encapsulated, for safety of
personnel even when a cabinet
door is even open.
ANALOGUE INPUTS
Phase current inputs, 3 x 1 ph
*
Measurement class current inputs, 3
x 1 ph
(O)
Earth current input, 1 x 1 ph
(O)
Sensitive current input, 1 x 1 ph
(O)
Feeder voltage input, 1 x 3 ph
(M)
Busbar 1 voltage input, 1 x 3 ph
(M)
Busbar 2 voltage input, 1 x 3 ph
(M)
Neutral displacement voltage input,
1 x 1 ph
(M)
GENERAL
Setting groups
4
Event logging
*
Alarm management
*
Disturbance recording
*
* Standard (O) Option (M) Model dependent
216
HARDWARE
Dimension (H x W x D)
250 x 210 x 90 (mm)
Cut out
232 x 192 (mm)
Auxiliary supply
24 V DC, 80-300 V DC or
85-230 V AC
Climatic conditions
Operation -200C to + 700C
Maximum -400C to + 700C
Housing
Front IP54 (IEC529)
Rear IP20 (IEC529)
Measurements, recording, and
post fault analysis
Measurements
Analogue measurement values are clearly displayed on the HMI
screen. A subset of principle values may be placed alongside the
single line diagram, with the full suite of measurements accessible
within the menu. Real-time measurements are shown as accurate
digital quantities, with a corresponding bar graph alongside. Each
bar changes from green to orange and then red, annunciating normal
loading, overloading and excessive loading in a way that is clearly
visible by substation staff. Alternatively, voltage and current vector
(polar) diagram displays may be consulted.
In addition to directly measured
analogues, power, (including
power factor) and energy
measurements are provided for
the P163. Energy measurement
is accumulated in all four
quadrants: kWh, kVArh, import
and export. Frequency statistics
track the present, maximum
and minimum frequencies, in
order to trend the stability of the
network frequency.
Operation logs count the number
of operations of each switchgear
device. For 3-position devices,
the number of open and earthing
operations are accumulated
independently.
High accuracy metering
The P60 Agile platform offers
measurement CT inputs
optionally, for applications where
high accuracy metering is called
for. The measurement CT inputs
are accurate to 0.2% for currents
up to 3 in, and are intended
for use in combination with an
external metering class CT.
P60 Agile: full
colour touch-screen
technology within
the substation
Vector display capability of P60 Agile
217
Records
The P60 Agile relay records up to
3000 sequence of events records
in a FIFO buffer. Time-tagging
is to a resolution of 1 ms.
Disturbance recording stores the
analogue waveforms and binary
signal data to allow in-depth
post-fault analysis. Typically ten
disturbance records are stored.
Alarm management
The P60 features include
extensive alarm management
capability, keeping in view its
role as the protection, control
and measurement device for
a bay. The HMI display has a
configurable Alarms page, which
is opened on occurance of any
alarm. Alarm names may be
configured by the user, along
with a software LED which helps
the user to recognise the alarm
status - whether it is active,
active and acknowledged or
inactive and not acknowledged.
The configuration tool allows
the user to derive alarms as a
combination of events available
in the relay data model; up to
449 alarms may be defined, and
allocated to alarm groups for
efficiency.
ALSTOM GRID: FEEDER DEVICE TRACK RECORD
CDG - Forerunner of feeder developments undertaken by Alstom since 1949
MCGG - World’s first mass-produced digital relay
KCGG/KCEG - First fully-numerical overcurrent relay launched in 1992 and
sold over 20 000 units
P14x MiCOM series introduced in 1999. Worldwide application, with over
95 000 units delivered
P40 Agile launched in 2012
P60 Agile brings one-box protection and control to the range
218
Substation Automation Solutions | DAPserver ™
DAPserver
TM
Digital Automation Platform
The DAPserver™ is a versatile and scalable multi-function
solution designed for electric power substations and
industrial power systems. It is a reliable and efficient system
that enables the integration of field devices, unification of
substation data, interfaces with enterprise applications and
secures delivery of substation information to utility users.
DAPserver™ also provides a truly open migration platform
for upgrading legacy RTU-based systems. It will keep the
user informed on what is happening – or not happening –
at every point on your network nodes and facilitate effective
decision making and quick action to keep the power system
operating smoothly.
Customer benefits
Improves system availability and reliability
Improves system security and risk management
■■ Enables effective decision making
■■ Consolidates substation data and information
■■ Provides role-based visualisation for technical and
management staff
■■ Complements SCADA host with detailed information
■■ Eliminates hardwired annunciator panels
■■ Reduces dependency on expensive mimic control panels
■■ Improves staff safety in substation work
■■ Reduces unnecessary travel to sites
■■ Enables condition-based maintenance and asset management
■■
■■
219
DAPserverTM – product features and functionality
The DAPserver™ provides:
Power PC substation hardened hardware platforms:
■■ DAPmini™, DAP-100, DP-300
■■ Ruggedised substation hardware platforms:
■■ eg. DAP-AT (Advantech UNO)
■■ Embedded Linux Operating System
■■ Real-time and SQL database
■■ Fanless CPU and no rotational or moving machine parts
■■ A hardware watchdog and components for online diagnosis and self-restarting
■■ Built-in real-time database to support the distribution of data for multiple users through serial
and/or TCP/IP network
■■ Provides network security and manages network application services (i.e. SSH/SSL/TLS, IPsec, SFTP,
Firewall, and Routing functions)
■■ Comprehensive redundant architecture:
■■ Redundant server – failover switching between primary and backup server
■■ Redundant communication – failover switching between communication channels
■■ Redundant power supply – available on specific hardware platform
■■
HMI
The DAPview embedded HMI provides users with
measurements, indications, alarm management,
trending, condition monitoring and control at
substation site or from a remote location using
a Web browser. It also allows users to view and
control other remote sites from a local site.
Programmable Logic Control
The DAPlogic module provides soft logic
programming application. It can perform
programmable logic control in user-defined
automation application on a event-driven or periodic
basis. An optional software module for IEC 61131 is
also supported.
220
Protocol Analyser
The DAPstudio software utility provides a protocol
analyser feature in which communication between
remote devices and the server may be analysed. The
DAPserver™ protocol analyser provides a command
line interface through which messages can be sent
to debug the communication channel. The protocol
analyser displays and interprets filtered messages
that contain timing and other relevant information.
It also facilitates effective communication monitoring
between devices.
Device Library
Device templates are full function definitions
including the communication protocol and point
mapping of IEDs. DAPStudio is delivered preloaded
with a set of commonly used device templates.
Users can create additional device templates or
modify existing ones.
How does DAPserverTM fit into utility operations?
1. Substation HMI (HMI)
Graphical User Interface, Single Line Diagram, Annunication
2. Substation Security Gateway (SSG)
Facilitates secure remote access to meet NERC CIP requirements
3. IEC 61850 Gateway (ICG)
Facilitates mapping of 61850 data objects to protocols such as DNP and IEC 60870-5-104
4. Substation Data Gateway
(SDG)/Substation Server (SS)
Multi-function server including including data concentration, IED integration, protocol conversion, serial to IP
conversion
5. DAPmini
A substation server which is custom-designed for upgrading legacy D20/D200-type RTUs.
221
The DAPserverTM product family
Software Applications
DAPcore™ - IED integration and protocol conversion software
■■ DAPview™ - substation HMI software with remote access capability
■■ DAPguard™ - cyber security software to secure remote access to
legacy and new substation devices
■■ DAPgateway™ - IEC 61850 protocol conversion software for mapping
IEC 61850 data objects to standard protocols
■■
Hardware Platforms
■■ DAPmini™ - plug-in module for D20 RTU upgrade
■■ DAP-100 - rugged substation server
■■ DAP-300 - multiple processor system
The ASAT DAPserver™ product line is designed for electric power
substation and industrial power systems. DAPserver™ has the
FLEXIBILITY to build a RELIABLE, SCALABLE and VERSATILE system to
meet your substation automation needs.
Retrofit Substation
Legacy IED integration
■■ Serial-to-IP conversion
■■ Protocol conversion
■■ Integrated HMI function
■■ Substation cyber security
■■
New Substation
■■ Multi-vendor IED integration
■■ IEC 61850 IED integration
■■ User-friendly configuration tools
■■ Substation HMI
■■ Substation cyber security
Asset Management
■■ IED and sensor integration
■■ Secure connectivity from
substation devices to enterprise
applications
■■ Online condition monitoring
■■ Turning data into actionable
information
DAPmini ™
DAP-100
DAP-300
222
How does the DAP
substation server
fit into your utility’s
operation?
Substation Cyber Security
■■ NERC CIP features
■■ Authentication- User credential
■■ Authorisation - Multi-level
access privileges
■■ Audit Trail - Security Event Log
■■ Secure tunnelling to IED
■■ Encrypted data communication
Substation Automation Solutions | Protection
MiCOM S1 Agile
Graphical, universal,
intuitive
MiCOM S1 Agile is the truly universal IED
engineering toolsuite. No-longer are separate tools
required for redundant Ethernet configuration,
phasor measurement unit commissioning, busbar
scheme operational dashboards, programmable
curve profiles or automatic disturbance record
extraction – all applications are embedded.
Customer benefits
Configuration file creation and management, following the
substation topology
■■ Ethernet and IEC 61850 configuration, including SCL
import and export
■■ Programmable logic, menu text and IDMT curve profiles
■■ Settings conversion to the new MiCOM P40 Agile IEDs
■■ Event and disturbance record extraction and viewing
■■ Embedded product selector
■■ Full successor to MiCOM S1 Studio
■■ Zero or minimal training to move from S1 Studio to
S1 Agile
■■
223
Redefining the engineering toolsuite for your IEDs
MiCOM S1 Agile is the next step enhancement from MiCOM S1 Studio, encompassing all of its functionality
plus new tools and features, to become the complete successor. It underlines Alstom’s R&D investment in
usability: assembling all tools in a palette for simple entry, with intuitive navigation via fewer mouse-clicks.
MiCOM S1 Agile supports all existing MiCOM ranges, K-Series and Modulex, including a utility for automatic
conversion of setting files from previous generations of numerical relays like K-series and MiCOM P20 to the
latest P40 Agile models.
MiCOM S1 Agile will automatically import your datamodels and configured systems/projects from Studio and
all files remain backward-compatible.
S1 Agile offers a fresh new look - functions and components are presented as “tiles” rather than menu items
for more intuitive use.
224
Environment
Operating Systems: Windows XP, Vista or Windows 7
Languages: English, French, German, Spanish,
Russian, Chinese.
For more information on MiCOM S1 Agile:
■■ Navigate to the homepage:
www.alstom.com/grid/ms1
■■ Register for the software:
www.alstom.com/grid/micomrequest
The selector application is continually refreshed with
the latest releases, from the P40 Agile overcurrent/
voltage and feeder devices to the latest digital
substation-ready MiCOM Alstom P40 relays.
To get the selector stand-alone, navigate to
Protection Relays on the SAS homepage:
www.alstom.com/grid/sas
Embedded product selector
The product selector eases your choice of the right IED
for each application. In synergy with MiCOM S1 Agile,
the user answers a few questions to choose the latest
applicable full model number, which then allows the
configuration and setting workflow to continue.
225
226
Substation Automation Solutions | DS Agile H Switches
DS Agile H Series
Secure and reliable
Ethernet switches
The H series Ethernet switches use cuttingedge redundancy protocols to offer superior
automation network availability and extremely fast
reconfiguration in the event of link failure.
Customer benefits
Superior network availability
Very fast network reconfiguration Bumpless with Dual
Homing Star and Parallel Redundancy Protocol (PRP).
■■ Easy to install and configure
■■ Monitoring capabilities
■■
■■
227
Substation Automation Solutions | DS Agile H Switches
Power transmission and distribution networks worldwide depend
on reliable and highly available protection and control systems.
These systems in turn depend on reliable and highly available
communications networks for control, data collection, automation,
monitoring and much more.
Alstom Grid’s H series Ethernet switches use a combination of
advanced redundancy protocols and fibre-optic connections to
ensure the reliability, availability and dependability of substation
communications networks. All this while maintaining the flexibility of
being able to be connected to standard ethernet networks - ideal for
substation refurbishments or upgrades.
The H series switches use either the PRP, Dual Homing Star or Self
Healing Ring protocols and are available in standalone, embedded
and PCI card (for integration into a PC) variants. As part of Alstom
Grid’s Digital Control Systems (DCS), the H series switches are fully
compatible with our protection relays, bay computers and gateways.
KEY FEATURES
■■
■■
■■
■■
■■
Architecture
DS Agile’s H series is a complete portfolio of ethernet switches for
all substation automation applications covering: standalone DIN-rail
switches, embedded switches in protection relays and bay computers
and PCI internal switches for gateways and substation PC’s.
Alstom Grid’s Ethernet network architectures reduce the cost of
ownership, as embedded switches in Intelligent Electronic Devices
(IEDs) reduce the number of external switches required. This has
the advantage of reducing the overall power burden, reducing
the maintenance requirements, reducing the required number of
connections, improving communications availability and reducing
unwanted downtime.
228
Cutting edge redundancy
protocols: PRP, Dual Homing
Star and Self Healing Ring
Flexible connectivity:
Different port variants are
available - copper or fibre
(single mode or multi mode)
with ST, SC or LC connectors
Monitoring capabilities: Set
an alarm to monitor link
failure using either the inbuilt
watchdog relay (contact) or
via communications
Increased reliability:
Standalone switches have
redundant power supplies
Ruggedised: The H series
switches are designed to work
in harsh environments such as
electrical substations
SAS conclusions
The new era of intelligent Smart Grids requires more sophisticated substation
automation systems which allow energy operators to provide a secure,
dependable and cost effective power supply to meet increasing customer
demands for higher standards of power automation.
As a world leader in substation automation solutions, Alstom is at
the forefront of developing systems which help energy operators optimise
the design, operation and maintenance of digital substations to meet the
demands of an ever-changing environment, through realtime intelligent
digital networks.
This interoperable and IEC 61850-compliant solution allows operators
to achieve a high level of availability and enhanced reliability of substation
equipment. It also provides full integration with control room network
monitoring and Smart Grid applications, such as network stability, wide-area
protection plans and online condition monitoring.
Through advanced, expert data processing, Alstom’s DS Agile and DAPserver
digital substation solutions reduce cables, improve flexibility and increase
reliability by preventing failures.
The range continues to grow, with cybersecurity and substation situational
awareness at the heart of the technology
229
230
Online condition
monitoring
231
232
Online condition monitoring | MS 3000
Fact sheet – Online condition monitoring
MS 3000
Online condition
monitoring and expert
system
Transformers are critical to electrical power
systems. Their reliability and availability is the key
to profitable power generation and transmission
and continuous supervision is essential to evaluate
transformer performance and safe operating
conditions.
Customer benefits
Decision-making support
Cost-effective solution
■■ Customised solution based on standardised modules
■■ User-friendly interface
■■
■■
233
Take advantage of our experience
in transformer manufacturing.
Decades of dedicated expert
knowledge has made us a world
leader in power transformer
monitoring systems.
Our commitment to your success gives you a high degree of flexibility
and reliability. While focussing on user-friendly operation, the MS
3000 also provides maximal support to accurately assess your
transformer - and our solution serves new and existing transformers
of all makes.
A practical solution for real needs
The MS 3000 offers a complete solution as a one-stop concept:
Data acquisition - fast and reliable
■■ Lifetime data management – high resolution when demanded;
compressed where reasonable
■■ Data analysis and condition diagnostics – reflecting a high level of
expert knowledge
■■ Interface – visible quality in your own language
■■ Information distribution – a communicative team-player with upper level
systems
■■
The MS 3000 is Alstom Grid’s
next generation of online
condition monitoring systems.
As the successor of the globally
recognised MS 2000 system, it
combines practical experience
with innovative features and
high technological standards.
You get more with MS 3000:
An expert system
■■ A DGA tool
■■ A report generator
■■ A simulator
■■ Sophisticated modelling
■■
234
State-of-the-art communication with
IEC 61850 standard
MS 3000 provides the most efficient solution for communications
with power automation systems using the new IEC 61850 standard.
This is a key factor, reducing overall configuration costs and achieving
improved inter-operability, flexibility and reliability in data exchange.
A comprehensive and smart solution
Our philosophy: a monitoring system should integrate all transformer main components with a
correlation of the analysed acquired data - even for several transformers at the same time.
Our expertise provides the basis
for reliable interpretation of single
or multi-transformer conditions.
Our Expert System with its
diagnostic functions supports
and enables your engineers in
making the right decisions at
the right time for the proper
operation and maintenance of
your valuable equipment. The MS
3000 saves you time, so that you
can concentrate on other tasks
requiring more attention.
Expert system
Algorithms for analysing the online
acquired data are implemented in
the software and reflect our
extensive experience. This
sophisticated tool highlights the
capacities that a state-of-the-art
monitoring system should have.
The Expert System software
provides you with recommendations
and information concerning
transformer operation and service/
maintenance.
Sophisticated
modelling
Thermal model
Aging model
■■ Tap changer model
■■ Moisture model
■■ Bushing model
■■ Overload model
■■ Cooling model
■■
■■
235
A user-friendly solution
MS 3000 software
Our interactive, clearly structured interface is
user-friendly and easy to operate.
The straightforward messaging of alarms, warnings and
diagnostics proposes both a quick key data overview and
a deep look inside the transformer. The implemented web
server in the MS 3000 IED provides multilingual web pages
which can be accessed directly by ethernet, LAN or modem
connection without any proprietary software.
Various password protection levels give only specific users the
permission to access the data or to configure the system.
The visualisation software offers a user-friendly presentation of
online and historical data as well as numerous combinations of
graphs and zoom possibilities.
Using quick links, recommendations for preventive actions can be
obtained to optimise transformer operation or to initiate maintenance.
Report generator
The configurable report generator automatically creates user-friendly protocols with status information about the
transformer and its main components. This protocol can be generated on command or can be periodically created
and sent to a defined email address.
Simulator
The built-in simulator module allows the user to simulate external or transformer events and to study the
transformer’s behaviour as well as the monitoring system’s. The simulator can also be used for training site
personnel and engineers.
DGA-tool
Choose your preferred method to analyse the acquired dissolved gas data
according to MSS, Doernenburg, Rogers, extended Rogers,
IEC 60599, Duval or KeyGas methods. Also a risk classification, including
interaction recommendations, will be carried out according to IEEE
C57.104-1991. This tool allows you to enter and historically store your
transformer-related offline DGA (Dissolved Gas Analysis) data, including
Furfurol determination.
236
The modular and flexible solution for
new and existing transformers
We have the answer for the complete transformer application range:
from power generation to transmission - compatible with all transformers
independent of the transformer manufacturer.
Standard kits
Along with the MS 3000 standard kit, a new concept has been launched.
Depending on transformer design and monitoring comprehension,
different modules can be adapted to a basic kit. This standardised solution
covers your needs in an efficient, cost-optimised package.
Main characteristics
Protection class*
IP 54
Operating temperature* -40°C - +55°C
Power supply
Wide range
Signalisation
Transformer condition display
Data visualisation
Web Server on monitoring IED
Monitoring module
Without moving parts
Sampling rate
20 ms
Data resolution
1 ms
Data storage
Self-compressing historical data storage --> Lifetime storage for all
connected transformers
Protocol*
IEC 60870-5-101/104 / Modbus / DNP 3 / IEC 61850
Architecture
Flexible – different topologies possible
Operating system
State-of-the-art real-time operating system
* others on request
MS 3000 Standard kits:
measured and analysed quantities
Active Part
Apparent power and load factor
Oil temperature
Hot-spot temperature
Gas-in-oil content
Moisture-in-oil content
Moisture of paper
Bubbling temperature and safety margin
Aging rate and lifetime consumption
Breakdown voltage
Actual losses
Overload capacity
Emergency overloading time
Bushings
Operating voltages
Overvoltages
Change of capacitance, online capacitance
Capacitive displacement currents
Load currents
Over-and short-circuit currents
Tap changer
On-load tap changer position
Number of switching operations
Sum of switched load current
Power consumption of motor drive
Assessment of mechanical quality
Contact wear
Tap changer oil temperature
Oil temperature difference OLTC-tank
Cooling System
Operating condition of fans and pumps
Operating time of fans and pumps
Cooling efficiency (Rth)
Ambient temperature
237
Additional features and measurements
Fibre optic hot-spot measurements
■■ Partial discharge
■■ Bushing power factor (tan delta)
■■ Transformer power factor (cos phi)
■■ Transformer efficiency
■■ Bottom oil temperature
■■ Monitoring module temperature
■■ Moisture of OLTC oil
■■ Gas quantity and rate in Buchholz relay
■■ Oil pressure and oil pressure differences
■■ Accelerations (tank wall, OLTC)
■■
Oil level
Humidity of air inside conservator
■■ Air pressure
■■ Cooling power
■■ Intake and outlet cooling equipment temperatures
■■ Differences of intake and outlet temperatures
■■ AVR
■■ Control of cooling equipment
■■ Digital status information, etc.
■■ Others on request
■■
■■
A tribute to quality
One of our key objectives in developing the next generation was to achieve the highest possible reliability
levels. To do this, we used the best available technology and components such as fanless IEDs (Intelligent
Electronic Devices) that operate with a redundant flash memory for life time data acquisition and storage, in
line with a proven bus technology for industrial applications.
The new MS 3000 provides a very reliable solution thanks to consistent project management and continuous
improvement. Multilingual documentation and interfaces are part of the constant quality process.
Type tested acc. to DIN/EN 55011, EN/IEC 61000, EN/IEC 60068,
EN/IEC 61010
Electromagnetic disturbance tests
Temperature and climate tests
■■ Electromagnetic immunity tests
■■ Safety tests
■■ KEMA IEC 61850 Certificate
■■
■■
238
Reference projects
239
Reference Project
With multiple reference
sites in different
countries, Alstom Grid
has been involved in
the development of the
various components of
the digital substation
for many years. We
have gained precious
experience in our IEC
61850 pilot projects
that puts us in a strong
position to meet the
demands of utilities
for instantaneous
operability and
backward compatibility
of multi-vendor
equipment.
240
India
GETCO (India), Jambua AIS Substation
245 kV COSI-CT based on optical sensor technology
(Faraday effect), connected to the merging unit
and interfaced digitally with Alstom Grid distance
protection by IEC 61850-9-2 process bus.
Reference Projects
Reference Project
sites in different
for many years. We
for instantaneous
operability and
of multi-vendor
equipment.
FRANCE
RTE (France), Saumade - 245 kV GIS
substation with hybrid sensors, MU
and distance protection
DIT based on Rogowski coils and capacitors,
connected to the merging unit and interfacing
digitally with distance protection relays provided by
Alstom Grid and a third party.
241
Reference Project
sites in different
for many years. We
for instantaneous
operability and
of multi-vendor
equipment.
242
RUSSia
Federal Grid Company of Unified
Energy System (Russia), Nadezhda
- 110 kV double-bus and 220 kV
breaker and a half substation
Supply of process bus protection relays and bay
controllers, digital control systems, CCS panels,
merging units and engineering.
Reference Projects
Reference Project
The cables are over
20km in length, and the
operational demands are
such that autoreclosing
is required for faults on
the overhead lines, but
not for faults within
the underground cable
sections. The differential
protection is thus used
for fast and precise
detection of faults
within the cables. The
undersea cables run
from stations on the
Jutland mainland, on to
Funen island and then
onwards to Zealand.
The equipment supply
includes 72 optical CT
units, 24 merging units
and 24 line differential
relays which subscribe
to the sampled values in
a process bus protection
scheme. The principal
reason for selecting to
use non-conventional
DENMARK
Energinet, Denmark – Digital Current
Measurement and Protection
One current application is on Energinet’s
transmission system, in a differential protection
application. The protected circuits are hybrid lines,
consisting of 400kV lines, and cabled portions laid
sub-sea.
instrument transformers was due to their low
mass and slimline construction. In the Energinet
substations, the optical CTs are mounted on the same
support structures as the cable bushings themselves.
A single structure and foundation per phase carries
the larger mass of the cable, plus the optical CT
support on a cantilever frame.
243
Grid-Sector-L4-DS_Sales_Handbook-2910-2013_05-EN © ALSTOM 2012. All rights reserved. Information contained in this document is indicative only. No representation or warranty is given
or should be relied on that it is complete or correct or will apply to any particular project. This will depend on the technical and commercial circumstances. It is provided without liability and is
subject to change without notice. Reproduction, use or disclosure to third parties, without express written authority, is strictly prohibited.
ALSTOM Grid Worldwide Contact Centre
www.alstom.com/grid/contactcentre
Tel: +44 (0) 1785 250 070
www.alstom.com

AGILE DIGITAL SUBSTATIONS

Transcription

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