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Prepared for the international conference Power Systems and Communications Infrastructures for the futureBeijing, September 2002

STANDARD IEC 61850 FOR SUBSTATION AUTOMATION AND

OTHER POWER SYSTEM APPLICATIONS

Karlheinz SchwarzSCC, Karlsruhe, Germany

schwarz@scc-online.de

1Introduction

Automation systems in the area of power systems are widely

accepted today. They are mostly based on many proprietary

solutions or (de facto) standards not specifically designed for

substations. To meet todays and future requirements a newstandard with an advanced approach has been requested a few

years ago. As a result of international projects the standard

IEC 61850 (Communication networks and systems in substa-

tions) is under final preparation in 2002. It will be used in the

all over the globe.

It is not sufficient to develop systems that only produce,

transmit, or distribute electric power. Fully automated

remotely supervised systems that require little or no human

intervention seem to be ideal. Technologies bundled into the

power system, therefore, has to include protection and control

equipment, as well as interfaces to supervisory control and

data acquisition (SCADA) of control centers. The standardcovers a wide range of substation applications. At the process

level the IEC 61850-9-1 standard defines a unidirectional se-

rial communication interface connecting current (CT) and

voltage transducers (VT) with digital output to electrical me-

tering and protection devices. This allows the exchange of

synchronized phasor measurements using GPS signals for

synchronization. Another real-time requirement is met by the

GOOSE(Generic Object Oriented System Event) that defines

the transmission of high priority information like trip com-

mands or interlocking information

Additional applications that are necessary for a complete sys-

tem may include: metering, protection and control, remote

monitoring and fault diagnosis, automated dispatch and con-

trol, data retrieval, site optimization of electrical/thermal out-

puts, asset management, as well as condition monitoring and

diagnosis.

The standard IEC 61850 will be used for many other applica-

tion domains outside substations, too. One of the biggest suc-

cess stories in power systems is the deployment of wind

power now the world's fastest-growing energy source. Since

1993, the market for new turbines to generate clean power

from wind has grown at over 40 % per year. Already over

25,000 turbines (some 10,000 in Germany) are producing

electricity world-wide at the end of 2001.

Globally, utility deregulation is expanding and requiring de-mands to integrate, consolidate and disseminate real-time in-

formation quickly and accurately within all kinds of utility

automation systems from power plants to customer inter-

faces. Utilities and vendors spend an ever-increasing amount

for real-time information exchange; costs for data integra-

tionand maintenanceare exploding. Vendors of power sys-

tems have because of the fast growing market or market de-

regulation very limited resources to implement and apply

hundreds of proprietary communication systems. In re-

sponse to this situation, the IEC (International Electrotechni-

cal Commission) and IEEE have developed and published a

suite of (draft) international communication standardsand

a technical report.

The future electricity systems will thanks to a seamless real-

time communication system be smart at the top but smarter

at the bottom, self-regulated by millions of communicating

devices connected to form feedback loops, and permanently

aware of the world around them.

This paper gives an overview on utility's crucial integration

requirements, the IEC standardization and the IEEE UCA

(Utility Communications Architecture) solution, and the

global market acceptance of this new technology.

2The challenge

Imagine if you didn't have common electric outlets and plugs

in your house, and every time you bought a new appliance,

choose a new power provider, or installed a new micro-power

system like a fuel-cell, you had to wire up the appliance to the

wires in your wall. And everybody's wires in everybody's

walls were different. And everybody's appliance wiring was

different. That's really the way it works today trying to inte-

grate device data into applications and these devices into

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power automation systems. Examples for device data are

status, diagnostic information, measurements, metering data,

configuration, description, and control information. This

situation forces developers of application software and de-

vices to write new drivers daily implementing just new

gateways!

Imagine your department has to implement the countlessnumber of proprietary solutions! If you think its not hard to

do think again.

Todays power networks in various regions may realistically

be considered to be the largest machines in the world since

their transmission lines connect all the electric generation,

distribution, and appliances on a continent or part of it. The

electric industry is unique in its critical real-time coordi-

nated requirements.

Many utilities are already faced the problem of islands of in-

formation based on proprietary technologies today, each of

which literally speaks its own language. The challenge is to

integrate all those existing and new information islands of

current and new applications into a functioning utility

automation system (Figure 1). Control center for example

need to know the overall operating conditions (gross load,

plant activity, etc.) but the corporate culture is often resistant

to telephone and fax communication, thus, information flow

between facilities is limited. Utilities use the standards as a

bridge between power plants, substations, and the control

center, and to communicate within substations. They now

have a broader perspective with more information on overall

operating conditions such as change of loads, power produc-

tion schedules, and other plant information.

Figure 1 Islands of information

An answer to the challenge has been found in standards-based

communication systems. To show just how important stan-

dards-based communication systems are, consider the exam-

ple of a large electric utility. At present, this utility has more

than 200 different protocols running on intelligent devices

within its distribution network! A well known vendor is proud

of supporting more than 100 different RTU protocols!

Utilities spend an ever-increasing amount for real-time infor-

mation exchange; costs for data integration and maintenance

are exploding. Industry experts say: US $82 billion was spent

on application integration in 1998 (= 40% of corporate IT

budgets; still growing) Forrester, 1999. Any 1 per cent of

the Dollars spent for the integration of devices into applica-

tions costs some US $800.000.000 per year. How many percent this integration costs is not known. The costs of integra-

tion are not well documented. Many companies do not keep

specific records of the cost of integration. The total ongoing

costs for system integration and maintenance for European

utilities (some 220 Million US$) will be 50% higher than

projected for 1999 (Source: Datamonitor).

The cost is not limited to installing new applications, custom-

ers explain. The larger expense in time and money comes

from the overwhelming task of maintaining the APIs to ex-

isting in-house applications. Many customers tell they believe

that savings in maintenance alone is the biggest opportunity

for saving time and money for an enterprise. To reduce the

risk of getting even worse in the future, the integration of

more and more intelligent devices into the enterprise appli-

cations (SCADA, real-time asset, machine diagnostics, ...) is

a real challenge for programmers and engineers.

One of the most interesting development in the field of real-

time monitoring of power systems, is the possibility of IEC

61850 to support synchronized phasor measurements using

GPS satellite for synchronization. Standard compliant meas-

urement units could provide real-time measurements of volt-

ages and currents at substation and send these measurements

to many devices in real-time.

To summarize, the driving force behind the standardization isto effectively and efficiently perform seamless device data

integration and sharing information based on a rich, fine-

grained data-stream about the state of the power world in

any given instant. Every node in the network would have to be

awake, responsive, flexible, and most important intercon-

nected with everything else: A distributed energy web.

3Power systems become decentralized

According to ABBs power experts more than 750 million

homes around the world do not have access to electricity, and

small-scale power generation could change this situation.

Power supplies in the coming decades is therefore likely totake on a decentralized structure. In developing and newly in-

dustrializing countries, decentralized power supply systems

will serve mainly to meet demand in rural areas, out of exist-

ing primary sources, e.g. wind, hydro, solar etc., in an opti-

mized mixture.

In industrialized countries, existing generation centers will be

gradually supplemented by decentralized and communicating

units. Intelligent energy management, allowing generation

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management, load management, billing management and in-

teractive communication on the part of consumers, will be in-

tegrated in the network.

Starting with a forecast, generation management monitors op-

timized use of resources. The task of load management is

control and optimization of the load, including balancing

against generation capacity and costs. Loads that scarcely af-fect supply security can be connected and disconnected ac-

cording to generation process efficiency criteria. This enables

an optimum to be attained in terms of economizing on re-

sources, protecting the environment and keeping costs down.

New generation possibilities to be applied will mainly be:

Wind mills: A new generation of wind power technology that

significantly reduces the cost of power generated by large

wind farms. The technology also allows wind farms to be

built offshore.

Microturbines: These small, efficient and low-emission gas

turbines provide electricity for homes, commercial buildings,hospitals, and small factories. Their compact size and high re-

liability make them suitable for small combined heat and

power installations.

Fuel Cell Systems: Similar to batteries, fuel cells generate

electricity through a chemical reaction, and produce very low

emissions. They are small enough for residential and small

commercial applications, making them ideal for use in areas

without connections to existing power grids.

Solar systems: Providing power by solar pannels.

Microgrids: A microgrid is created by connecting a local

group of small power generators using advanced sensoring,supervising, and control relaying on open communication

systems.

All these systems and micro-systems have to be connected to

the power grid and to the underlying decentralized infor-

mation grid.

4Objectives of the IEC TC 57 standardization

IEC and IEEE provide standards to dramatically improve de-

vice data integration into the information and automation

technology, reducing engineering, commissioning, opera-

tion, monitoring, diagnostics, and maintenance costs andincreasing the agility of the whole life cycle of utility automa-

tion systems. These standards differs from most previous util-

ity protocols in its use of object models that model most

common real devices and device components. These models

define common data formats, identifiers, behavior, and con-

trols, e.g., for substation and feeder devices such as switches,

voltage regulators, and relays.

The standards selected, e.g., Ethernet, TCP/IP, and MMS

(ISO 9506), make use of advanced IT solutions, the reduced

bandwidth costs and increased processor capabilities in the

end devices to define and carry metadata: more than 3,000

standardized names and type information which can be (re-

)used by applications for on-line verificationof the integra-

tion and configuration of databases throughout the utility.This self-description significantly reduces the cost of data

management, and reduces system down times due to configu-

ration errors.

Examples for measurement metadata are "unit", "offset",

"scale", "dead band for reporting", and description. This fea-

ture significantly reduces the cost of data integration, data

management, and reduces down time due to configuration er-

rors.

The standard information models of real-world devices (e.g.

switches, disconnectors, transformer, measurement unit, ...)

can be (re-)used by applications for self-description and on-

line verification. The standards improve device data integra-tion into the information and automation technology, reduce

engineering, commissioning, operation, monitoring, diagnos-

tics, and maintenance costs.

The objective of IEC 61850 and IEC 60870-6-TASE2 is to

provide for seamless information integration across the

utility enterprise using off-the-shelf international standards to

reduce costs in several phases of a system life cycle (Figure

2). These standardized models allow for multivendor

interoperability and ease of integration.

UCA has been incorporated into the draft standard series IEC

61850 (Communication networks and systems in substations)

published by IEC TC 57 in March 2001. The first parts of IEC61850 have been published as international standards end of

2001.

Figure 2 Seamless information integration based on

IEC 61850/UCA

The object models are defined in terms of standardized types

and services. These services (such as reporting by exception

and select before operate controls) are defined in abstract

IEC 61850

IEC

614

00-25

IEC 61850

IEC 60870-6 TASE2

IEC 60870-6 TASE2

IEC

614

00-25

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terms, then mapped to messages in the underlying application

layer protocol (ISO 9506 Manufacturing Message Specifi-

cation, MMS). The use of the standardized service definitions

above MMS allow for future-proofing, in that new innova-

tions in application layer protocols can be incorporated in the

future without disturbing the object model definitions.

The MMS protocol, developed by the manufacturing commu-nity, supports real-time control and data acquisition. MMS de-

fines a message structure supporting access to data, programs,

journals, events, and other constructs common to real-time

devices. These messages may be transported using many dif-

ferent underlying protocol stacks.

The Standard IEC 61850/UCA is developed in an interna-

tional co-operation with broad vendor and utility participation.

The primary target is the electrical substation automation

(switchyards and transformers in the medium and high voltage

transport and distribu-

tion). Most major utili-

ties (e.g. AEP, EdF,E.ON, ENEL, RWE, ...

) and system suppliers

(ABB, Alstom, General

Electric, SAT, Siemens,

... ) contribute to the

development of the

standard.

IEC 61850 is defined so that it fulfils the special requirements

of substation automation but the "specialties" are to a large

extent isolated, making the better part of the standard generic.

The "specialties", e.g. the modeling of a high voltage breaker,

are defined separately.The general definitions of IEC 61850 can be applied in all ar-

eas where there is a need to exchange any structured process

information in real-time. The general exchange methods, like

direct access (read and write), reporting (spontaneous and cy-

clic; with change detection), sequence of events (SOE), device

event archives, control, and upload of the self-description of

the device, are implemented in the general and commonly

known ways.

The communication networks, that are independent of the in-

formation and exchange models, are separated as well. This

provides for the use of independent communication networks

(e.g. TCP/IP, Ethernet ... ) or simple point-to-point connec-tions.

IEC 61850 is, due to its modular structure, its generic basic

information for process control, and due to its general func-

tionality, almost predestined for the use in (almost) all areas

of industrial automation to achieve unified definition and ex-

change of any process information.

The gas and water industry in the USA has decided to pro-

mote and introduce the IEC 61850. The IEC TC 88 (Wind

turbine generator systems) specifies currently a standard for

communication systems (IEC 61400-25); IEC 61850 is used

as a basis in the first official working draft.

5Primary application of the standard IEC 61850

Figure 3shows a typical example of a substation automation

system with its common three levels. At process level there

are the process interfaces hard-wired in the past and serially

linked by the process bus in the future. Protection and control

at bay level may reside commonly in one device or in dedi-

cated ones. These devices are connected in between and with

the station level by the interbay/station bus. At station level,

there is very often a station computer with HMI (human ma-

chine interface) and a gateway to the control at the higher

network level. There exist a lot of variations of this example

but all substation automation systems have to provide all or at

least a subset of the following functions with some domainspecific performance, heterogeneity and life-time conditions.

Figure 3 Seamless information integration based on

Important function groups and functions are:

System management

- Self-supervision, communication management, time syn-

chronization

Operation and control

Access security management

Switchgear operation

Measurement (rms, power, etc.)

Event and alarm handling

Parameter

Data/disturbance records retrieval

Logging and archiving

The general definitionsof IEC 61850 can be ap-plied in all areas wherethere is a need to ex-change any structuredprocess information inreal-time.

Bay Level

Protection Control

Station Level

Function A Function B

Bay Level

Protection Control

other Services (e.g. SSto CC commuication)

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Local and distributed automation

Protection and busbar protection (remote phasors)

Protection adaptation

Interlocking

Local/distributed synchrocheck and synchronised

switching

Sequences Voltage control

Load shedding

The 10 Parts of the standard IEC 61850 are as listed in the

following tables.

The following parts define how the IED behaves:

Among these models, two are dedicated to the transmission of

information with high priority:

GOOSE (Generic Object Oriented System Event) is used to

model the transmission of high priority information like trip

commands or interlocking information. The model is based on

cyclic and high-priority transmission of status information. In-

formation like a trip command is transmitted spontaneously

and then cyclically at increasing intervals.

SMV (Sampled Measured Value) is used to model the ex-

change of the sampled measured values from current and volt-

age transducers to any IED that need the samples. The model

is based on an unconfirmed transmission of a set of sampledvalues. A counter is added to time correlate samples from dif-

ferent sources and to detect the loss of a set of samples.

GOOSE and SMV service models are defined in IEC 61850-

7-2. The mapping of the SMV model to a concrete communi-

cation system is specified in IEC 61850-9-1.

IEC 61850-9-1 defines a unidirectional serial communication

interface connecting current/voltage transducers with digital

output to electrical metering and protection devices. The goal

of the standard is to support interoperability between such de-

vices from different manufacturers. With devices supporting

this standard, the customer has the possibility to select a cur-

rent/voltage transducer of one manufacturer and connect it to

a protection device or a meter of another manufacturer. Being

convinced that this is a real benefit for the customer, ABB and

SIEMENS decided to support this standard. In order to dem-

onstrate the feasibility, the real time exchange of sampled

measured values between ABB and SIEMENS devices was

shown at the UCA user group and utility initiative meeting in

Dana Point, CA (USA) in January 2002.

Both ABB and SIEMENS developed each a device called

Merging Unit converting their own proprietary signals from

the current/voltage transducers (CT/VT) to messages accord-

ing to IEC 61850-9-1 transmitted over Ethernet. Each mes-

sage contains sampled values of currents and voltages for thethree phases and neutral.

On the data sink side, ABB and SIEMENS developed each a

distance protection relay, supporting the IEC 61850-9-1 mes-

sages as input signals. In addition SIEMENS developed a

meter with the same interface.

An overview of the five devices is given in Figure 4.

Testing

Part 10: Conformance Testing

ConfigurationPart 6: Configuration Language

for electrical Substation

IEDs

System Aspects

Part 1: Introduction and

Overview

Part 2: Glossary

Part 3: General Requirements

Part 4: System and Project

Management

Part 5: Comm Requirements forFunctions and Device

Models

Mapping to real Comm. Networks (SCSM)

Part 8-1: Mapping to MMS

Part 9-1: Sampled values over serial unidirectional

multidrop point to point linkPart 9-2: Sampled values over ISO/IEC 8802-3

Data Models Basic Communication Structure forSubstations and Feeder Equipment

Part 7-4: Compatible Logical Node Classes and Data

Classes

Part 7-3: Common Data Classes

Abstract Communication

Basic Communication Structure for

Substations and Feeder Equipment

Part 7-2: Abstract Communication Services (ACSI)

Part 7-1: Principles and Models

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Figure 4 Devices with IEC 61850-9-1 interfaces

Each merging unit transmits synchronized samples with atransmission rate of 1000 messages/sec. Two sample rates -1000 samples/sec and 4000 samples/sec - are supported. In thecase of 4000 samples/sec, four sets of samples are transmittedin one message.

6The new IEC standard 61400-25 for distributed (wind

power) generation

The IEC Technical Committee 88 has set up a new project to

develop a communication standard for distributed generation

(primary scope per TC 88: wind power plants) in 2001:

IEC 61400 Part 25:

Communications for monitoring and control of wind power

plants

The first official working draft can be downloaded from:

http://www.scc-online.de/std/61400/current.html

This standard defines like IEC 61850 several levels:

information,

information descriptionmethods,

substation configuration method,

information exchange for monitoring and control sys-

tems for wind power plants, and

communicationsprofiles.

The information defined in this standard comprises mainly

wind power plant specific information like status, counters,

measurands, and control information of various parts of a

wind power plant, e.g., turbine, generator, gear, rotor, and

grid.

The object oriented information description methods allow

precise and complete specification of the information.

The information exchangeprovides:

real-time data access and retrieval,

controlling devices,

event/alarm reporting and logging,

self-description of devices,

data typing and discovery of data types, and

file transfer

TheSCL (substation configuration language) describes allinformation exchanged in a substation communication net-

work.

Communication profilesas can be found in the IT world are

applied. Especially the security solutionsavailable in the IT

world (e.g., SSL and STL) can be used as provided off-the-

shelf.

7Re-usability and device modeling

Describing device functionality by specifying the data (syntax

and semantic) and the dynamic behavior (state machines) of

devices (as seem from remote) is one of the fundamentalchallenges in the standardization. Many standardization

groups have started defining different views of domain-

specific device types. The views are e.g.:

Engineering (in the context of a plant),

Commissioning,

Configuration,

Operation,

Asset management,

Maintenance,

De-commissioning

Hardware and software, as well as communication networks

are subject to frequent innovation. Therefore, it is worth-whileto standardize independent (abstract) interfaces for communi-

cation networks and the access to the application objects.

The abstract objects (objects define the semantic of the device

functions) will continuously be used (with minor changes

only). The object definitions will be enhanced in the future to

meet additional requirements, i.e. re-using the definitions

specified in the past (see Figure 5).

Protection relays

Merging units

Point-to-point link

according to

IEC61850-9-1

SIEMENS

SIEMENS

to instrumental transformers

Revenue

meter

Revenue

meter

S

IEMENS

S

IEMENS

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Figure 5 What is important to be standardised?

The most important objective of the device description is to

define re-usable parts to be used for specifying the data mod-

els and behavior of various types of industrial devices. Re-usability has two aspects. First, re-use of a given functionality

in many devices throughout an application domain (we may

call this: horizontal re-use). Second, re-use of a given function

in the definition of an enhanced or specialized function (we

may call this: vertical re-use). The re-usability is a crucial

factor in reducing the costs of the overall system design, engi-

neering, operation, and maintenance. Support of re-usability is

the key issue in the standardization!

The re-usable parts describe for example how a substation can

be configured using part 6 (SCL substation configuration

language. A diagram as shown in Figure 6maps to a XML

file representing the use of the classes defined in part IEC

61850-7-4 (see ).

Figure 6 Application diagram

The application of the SCL allows to

Figure 7 Application of SCL (excerpt)

The real benefit of device modeling is the re-use of (common)

definitions made in the past. This is our daily practice! We are

using common terms at work (key board, laser printer, office,

..) or at home (kitchen, chair, wheel char, bath room, ...). Just

misunderstandings are the result if terms are not understood

uniquely on both sides (sender and receiver). It is not only a

matter to define something completely more important is, tounderstand it uniquely. All technical specifications in the area

of distributed systems have to follow distinct rules for defin-

ing, exchanging, and unique interpreting exchanged informa-

tion.

Interpretation is quite easy if we can re-use common terms

learned in the past. In our daily life we re-use (instantiate) the

term laser printer (more precise we re-use the class defini-

tion that is associated with term laser printer) for a laser

printer next to you laser printer in room 23 or we may re-

use the term for a special type of a laser printer: A4 laser

printer (A4 laser printer in room 23).

Distributed systems should operate in the way they have beentold to do. If they do not? This may have many reasons. A

major issue is, that independently developed devices may

follow the specification of their implementers but the

implementers may have different interpretations of the speci-

fication that describes the co-operation of the devices!

Devices will not operate in the way they should do, if the hu-

man beings (the implementers) do not understand each other!

Device models are collections of terms with associated se-

mantics and a description of the dynamical behavior.

Usually models are abstract in the sense that they do describe

only those aspects that are visible to the remote user of a de-vice. It is sufficient to know the external visible data and be-

havior of the device (the WHAT). The concrete realization of

the device, its internal interfaces and programming language

or operating system (the HOW) are not of interest for the

view from outside. To understand the concept of a virtual

system, the following saying may help:

If it's there and you can see it It 's REAL

If it's there and you can't see it It's TRANSPARENT

If it's not there and you can see it It's VIRTUAL

If it's not there and you can't see it It's GONE

Roy Wills

IEC 61400-25 re-uses IEC 61850 instead of developing the

standard from scratch.

8Resume

Deregulation will place greater demands for information on

utilities than they have experienced before. IEC 61850, IEC

61400-25, and IEEEs UCA provide a timely, cost-effective,

"(Abstract) Application Objects"

Methods, Languages, Interfaces

for the description and access to application Objects

Life Cycle of System < 15 years

time

Innovation of HW and SW

no base forStandards

good base forStandards

QA1 QB1L1

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and standardized solution to allow advanced IED functions

and distributed systems to form the foundation for next gen-

eration electric utility systems.

The benefactors of the results of open device data integration

span the entire industry and include all of the stake-holders in

this industry. With the standard IEC 61850 intelligent protec-

tion relays and other real-time devices are becoming morecommon. Utilities could take advantage of these new devel-

opments, and make the power systems safer than before

taking into account that all critical information (status and

measurements) is available (at any time and any where) when

making control decisions.

The customers are in a position to save large sums of money

and time. The vendors who provide solutions that meet or ex-

ceed expectations will become very successful. This is an ex-

citing time in the industry with an inexorable move toward

practical software components.

The most important issues are the models of the real device

data and the rules (service interface) how to access these data.

On the other side it is obvious that an appropriate transport

mechanism (communication profiles), e.g., the TCP/IP or a

point-to-point link, must be used to exchange the messages

between devices.

By providing a common communications protocol stack, IEC

61850, IEC 61400-25, and IEEEs UCA TR 1550 allow an

utility and other industries to plug and play equipment from

different vendors. The specification of the uniquely tagged

semantic of the most important device model data leads to a

tremendous cost reduction during engineering, commission-

ing, operation, asset management, and maintenance. The so-

lution provides plant and enterprise wide seamless integration.

IEC 61850 is based mainly on UCA. The UCA 2.0 specifica-

tion will be harmonized with the final IEC 61850 standard.

An evaluation CD ROM is available that includes original

software of several vendors and documentation helping to get

started applying the IEC 61850, IEC 61400-25, UCA, and

MMS approach (includes also the IEEE TR 1550). For details

see:

www.Nettedautomation.com/solutions/uca/evalkit/index.html

A comprehensive free Demo Software and Tutorial for IEC

61850 / IEC 61400-25 / UCA / MMS (with Web/XML

support) executable on PCs (Win 95, 98, NT, 2000, XP) could

be downloaded from the following URL:

http://www.nettedautomation.com/solutions/demo/20020114/i

ndex.html

9References

- Christoph Brunner (ABB) and Holger Schubert,

(SIEMENS); The ABB - SIEMENS IEC 61850

interoperability projects, (January 2002)

http://www.nettedautomation.com/solutions/uca/products/

9-1/index.html

- IEEE Technical Report 1550 (1999): Utility Communi-

cations Architecture, UCA;

http://www.nettedautomation.com/standardization/IEEE_

SCC36_UCA

- IEC 60870-6-TASE.2: Telecontrol application service

element 2

- Standards and committee drafts IEC 61850: Communica-

tion networks and systems in substations;

http://www.scc-online.de/std/61850

- Working Draft IEC 61400-25: Communications for

monitoring and control of wind power plants;http://www.scc-online.de/std/61400

- Becker, Gerhard; Grtner, W.; Kimpel, T.; Link, V.;

Mrz, W.; Schmitz, W.; Schwarz, K.: Open Communica-

tion Platforms for Telecontrol Applications Benefits

from the New Standard IEC 60870-6 TASE.2 (ICCP),

etz-Report 32, VDE-Verlag Berlin, 1999

www.Nettedautomation.com/standardization/IEC_TC57/

WG07/etz_report.html

- Comparison of IEC 60870-5-101 (-103, 104), DNP3, IEC

60870-6-TASE.2 with the new standard IEC 61850

http://www.nettedautomation.com/news/n_51.html

"UCA" is a Trademark of EPRI, Palo Alto, CA, USA

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