Iec 61850 Standard Pdf Free Download

The standard IEC61850 is presented, considering its implementation and application as a platform, from the point of view of electrical engineers rather than software and electronic engineers. This is important since electrical engineers are the staff responsible for the design, construction, operation and maintenance of the electrical substations.

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The IEC 61850 Standard – Communication Networks

and Automation Systems from an Electrical

Engineering Point of View

Yulian Rangelov, Nikolay Nikolaev and Milena Ivanova

Department "Electric Power Engineering"

Technical University of Varna

Varna, Bulgaria

y.rangelov@tu-varna.bg, n.nikolaev@tu-varna.bg, m.dicheva@tu-varna.bg

Abstract — The standard IEC61850 is presented, considering

its implementation and application as a platform, from the point

of view of electrical engineers rather than software and electronic

engineers. This is important since electrical engineers are the

staff responsible for the design, construction, operation and

maintenance of the electrical substations.

Keywords— substation; communications; automation; scada

I.

I

NTRODUCTION

On a global scale, the energy sector is geographically

divided by two main standardization models - IEC

(International Electrotechnical Commission) and ANSI

(American National Standards Institute) [1]. Very often, this is

an obstacle for the development of technologies in the field of

power system automation.

In 2004, the IEC61850 was issued as a global standard for

the control and protection systems of switchgears for medium

and high voltage. It covers both the IEC and ANSI

standardization models [2]. The new standard ensures:

•Unified standard for all substations and power plants;

•Application of common format for description of

substations and making the design approach easier;

•Defining the main services required for data

transmission using different communication protocols;

•Interoperability between devices from different

manufacturers.

IEC61850 provides standardized work-frame for

integration of the specific communication requirements for

substations, functional characteristics, structure of the data

packages in the devices, unifying the names of data packages,

how applications interact with and control the devices, and

conduct standardized tests.

The standard IECE61850 is structured in 10 parts on about

1200 pages [1]. The Bulgarian Institute for Standardization

have harmonized only few parts of it.

II. O

VERVIEW ON THE

D

IFFERENT

IEC

61850

P

ARTS

As mentioned above, the standard consists of many parts.

The relation between them is clarified in fig. 1. Parts 1 and 2

give basic introduction to the ideas, principles, concepts and

the glossary to the standard. Parts 8 and 9 focus on the

mapping between the abstract data classes and services to the

communication protocols and give specifications of the serial

unidirectional communication and samples values transmission

[13-15]. Part 10 is dedicated to the conformance testing of the

client-server communication and the engineering tools [16].

The other parts are more relevant to electrical engineers and

will be explained in the following subsections.

A. Part 3: General Requirements

This part focuses on the construction, design and

environment conditions of the intelligent electronic devices

(IEDs) [3].

Fig. 1. General structure of IEC 61850

B. Part 4: System and Project Management

This part of the standard defines a system for project

management of utility automation systems (UAS), including

substation automation systems (SAS) [4]. The UAS usually

operates in an environment which typically includes the

following (see fig. 2):

•Telecommunication environment: network control

centers, subordinate systems, teleprotection;

•Human as local operator;

•Process environment: switchgear, power transformers

and auxiliary equipment.

In terms of UAS, the "process" is used to denote the

process of generation, transmission and distribution of

electrical energy.

IEDs are the main components of the UAS and could be:

•For the telecommunication environment: gateways,

converters, telecommunication part of RTUs,

teleprotection;

•For human-machine interface (HMI): gateways;

personal computers; workstations, other IEDs with

embedded HMI;

•For the process environment: bay control units, relay

protection, the process part of RTUs, measurement

devices, autonomous controllers, sensors, numerical

interfaces of switchgears, power and instrument

transformers.

The engineering process defines the conditions for the

design and the configuration of a particular power plant or

substation, based on the operation logic and the customer's

requirements. The responsibility is distributed among several

engineers:

•Engineer responsible for the project requirements;

•Engineer responsible for the system architecture, based

on the project requirements;

•Equipment vendors;

•System integrators – engineers who ensure the

interoperability of the different UAS components and

the process environment;

•IEDs parametrization engineer;

•Commissioning engineer.

C. Part 5: Communication Requirements for Functions and

Device Models

The fifth part is focused mainly on the SAS [5]. It

standardizes the communication between IEDs and the

requirements which should be met.

Being part of the SAS, the IEDs should be able to perform

at least one or more functions, which are categorized as either

protection, control, measurement etc. The different functions

are standardized. The functions could be split into independent

pieces which perform specific actions and could be used in

more than one function. These pieces are called Logical Nodes

(LN). The LNs contain the pieces of information which need to

be communicated (PICOM) between the different functions

and IDEs.

The relation between LNs, physical devices (PD) and

functions (F) is depicted in fig. 3. The LN are connected by

logical connections (LC) and the physical devices by physical

connections (PC). The figure shows that one function can

encompass LNs from different PDs and that one PD can have

Fig. 2. Environment of the utility automation system

Fig. 3. Logical nodes, functions and physical devices

many LNs.

The functions are divided in three levels: station, bay/unit

or process (see fig. 4). The process functions interface to the

process itself, i.e. sampled values gathering, switchgear

position monitoring and control, and others. The bay/unit level

consists of the protection and control functions acting mainly

on the primary equipment of their own bay. There are two

types of station level functions: (i) functions related to the

process, which use information from more than one bay and

being able to act upon all of them; (ii) functions providing

interface to the station operator or a remote control center.

The numbers in a circle from fig. 4 denote the different

interfaces between the levels: (1, 2) protection data; (4)

analogue data; (5, 6) control data; (7) data exchange between

substation level and remote engineer's workplace; (3, 7, 8, 9)

data exchange; (10, 11) control data exchange. Interfaces 2 and

11 are not within the scope of IEC 61850.

D. Part 6: Configuration Description Language for

Communication in Electrical Substations Related to IEDs

This part of the standard defines an object-oriented, XML

based language for automation system configuration, named

System Configuration description Language (SCL) [6]. A

configuration file typically starts with the description of the

primary electrical circuit equipment and their interconnections.

After that, the LN, the functions and the communication

between them are defined. The SCL code also contains the

configuration of each specific IED and from that perspective

every IEC 61850 compatible device should be capable to be

configured with an SCL code. The following file types are

defined: ICD – IED capability description; IID – instantiated

IED description; SSD – system specification description; SCD

– system configuration description; CID – configured IED

description; SED – system exchange description. Clause 10 of

this part explains the functionality of the software tools needed

for system specification and configuration.

E. Part 7: Basic communication structure

The main architecture which IEC 61850 adopts is the

division of the data definition and the processes by creating

data objects and processes which are independent from any

protocols [7-12]. Therefore, the particular definitions allow the

organization of the data objects and the processes in terms of

any protocol which is capable to meet their requirements.

Part 7-1 defines the modelling methods, the communication

principles and the information models which are used in the

next subparts.

Part 7-2 standardizes an abstract communication service

interface between client and remote server or between

publishing device and subscribed devices (for sampled values

transmission).

Part 7-3 defines common data classes used to describe

equipment models and functions for substations.

Part 7-4 refines the models by introducing compatible LNs

for the substation equipment and data classes. It contains

detailed information for the used alphabetical designation of

LNs (relay protection equipment, registering devices,

regulators, tap changers, instrument transformers). Also, the

rules for the application of LNs and their associated

information are refined. The LNs are grouped according to the

functions they relate. The name of the group starts with a

specific letter: (A) for automatic control; (C) supervisory

Fig. 4. Topology of substation automation system

control; (P) protection; (X) switchgear, (M) metering and

measurement; and others.

III. C

ONCLUSIONS

The IEC61850 is internationally accepted and gives clear

direction during the process of very intense automation of

substations and power plants. The standard is very exhaustive

and is dedicated to wide range of engineering areas – electric

power, communications and software. For electrical engineers

to be able to understand it, they need to gain same qualification

in the field of communications. To greater extent, this would

increase their ability to design and maintain entirely or partly

the automated electric power plants and substations.

A

CKNOWLEDGMENT

The research presented in this paper is a result of a project

in Technical University of Varna as part of its research

activities funded by the Bulgarian State.

R

EFERENCES

[1] Kirrmann, H. Introduction to the IEC 61850 electrical utility

communication standard, ABBCH-RD, 2012.

[2] L van der Zel, Guidelines for Implementing Substation Automation

Using IEC61850, the International Power System Information Modeling

Standard, Technical Report, 2004.

[3] IEC 61850-3:2014. Communication networks and systems for power

utility automation – Part 3: General requirements

[4] IEC 61850-4:2011. Communication networks and systems for power

utility automation – Part 4: System and project management

[5] IEC 61850-5:2013. Communication networks and systems in substations

– Part 5: Communication requirements for functions and device models

[6] IEC 61850-6:2010. Communication networks and systems for power

utility automation – Part 6: Configuration language for communication

in electrical substations related to IEDs

[7] IEC 61850-7-1:2011. Communication networks and systems for power

utility automation – Part 7-1: Basic communication structure - Principles

and models

[8] IEC 61850-7-2:2010. Communication networks and systems for power

utility automation – Part 7-2: Basic communication structure - Abstract

communication service interface (ACSI)

[9] IEC 61850-7-3:2011. Communication networks and systems for power

utility automation – Part 7-3: Basic communication structure - Common

Data Classes - Ed.2

[10] IEC 61850-7-4:2010. Communication networks and systems for power

utility automation – Part 7-4: Basic communication structure -

Compatible logical node classes and data classes

[11] IEC 61850-7-410:2012. Communication networks and systems for

power utility automation - Part 7-410: Basic communication structure -

Hydroelectric power plants - Communication for monitoring and control

[12] IEC 61850-7-420:2009. Communication networks and systems for

power utility automation – Part 7-420: Basic communication structure -

Distributed energy resources logical nodes

[13] IEC 61850-8-1:2011. Communication networks and systems for power

utility automation – Part 8-1: Mappings to Specific communication

service mapping (SCSM) - Mappings to MMS (ISO 9506-1 and ISO

9506-2) and to ISO/IEC 8802-3

[14] IEC 61850-9-1:2003. Communication networks and systems in

substations – Part 8-1: Specific communication service mapping

(SCSM) - Sampled values over serial unidirectional multidrop point to

point link

[15] IEC 61850-9-2:2011. Communication networks and systems for power

utility automation - Part 9-2: Specific communication service mapping

(SCSM) - Sampled values over ISO/IEC 8802-3

[16] IEC 61850-10:2006. Communication networks and systems in

substations – Part 10: Conformance testing

... In Lu et al. (2011) and Lu et al. (2014) the authors propose and implement a timecritical jamming-tolerant wireless application over the smart grid (Gao et al. 2012). In particular, they implement a "raw data sampling" (Rangelov et al. 2016) application where a device known as the "merging unit" periodically samples a power signal and transmits the sampled data to protection devices that are programmed to instantly respond to events conveyed by the received data. To ensure a timely response, the sampled data is required to be delivered within 100 ms. ...

... To ensure a timely response, the sampled data is required to be delivered within 100 ms. To meet the stringent time requirements, the authors follow the IEC 61850 (Rangelov et al. 2016) protocol in their implementation . IEC 61850 (Rangelov et al. 2016) is a communication standard for power substation protection and automation. ...

... To meet the stringent time requirements, the authors follow the IEC 61850 (Rangelov et al. 2016) protocol in their implementation . IEC 61850 (Rangelov et al. 2016) is a communication standard for power substation protection and automation. The protocol defines various message types with different end-to-end time constraints. ...

• Rami Halloush

Many of the failures suffered by wireless systems are not accidental; they are actually caused by security breaches. Therefore, the conventional QoS measures are not sufficient for quantifying the performance of wireless systems. In fact, there is a need for security-related QoS measures that describe the performance of wireless systems under security-breaches. In this paper we focus on Jamming which is one of the most common security breaches in wireless systems. We propose a mathematical model for jamming-tolerant wireless systems. Our model is based on the theory of semi-Markov processes (SMPs). By analyzing the steady-state behavior of the proposed SMP, we derive security-related performance measures such as the steady-state availability and the "mean time to process a packet" (MTTPP). By studying the transient behavior of the proposed SMP, we derive the "probability of packet failure" (PPF) and the "mean time to packet failure" (MTTPF) performance measures. With the proposed model, we analyze the performance of a real jamming-tolerant wireless system for smart grid applications and the numerical results are presented.

... However, the relay protections must trip and signal for the fault or the abnormal mode without creating conditions for cascade failures. The main protections used in MVDG are the instantaneous protection (IP), time overcurrent protection (TOCP) and earth fault protection (EFP), with codes ANSI 50/51 and 50N [3], [4]. The number of earth faults in MVDG is higher than the number of phase-to-phase faults and a fault research would reduce the grid's failure rate [5][6][7][8][9][10]. ...

... With the use of numerical relay protection, the requirements can be expanded with the multifunctionality of protection, registration and processing of mode parameters, telecommunications, adaptability, information and more [4,5,6]. ...

... The main reason for this problem is that each manufacturer's devices have their own communication protocol that makes global information transfer system complicated. The International Electro Technical Commission (IEC) 61850 has developed electric power substation's communication standard [44]. Detail of IEC 61850 standard and its applications are presented in [45]. ...

To provide continuity of balancing demand and generation, renewable sources will be more active than today in near future due to tendency of massive investment on Renewable Energy Sources (RESs) by countries. However, due to uncertain and intermittent nature of renewable energy sources, RESs would create problems on power system operations such as power quality, efficiency, stability, and reliability. Due to having problems with renewable energy sources integration, Virtual Power Plant (VPP) has introduced to make this integration smooth without compromising the grid stability and reliability along with offering many other techno-economic benefits. This paper reviews structures, types, architecture and operations of VPP along with status of present implementations worldwide. The types of VPP is introduced in details with optimization algorithm used with each types. In addition, VPP is linked with the most of the components in power systems such as Distributed Generation (DG), active prosumers, Transmission System Operator (TSO) and Distribution System Operator (DSO), grid services such as fault ride through, reactive power control as well with the help of technology such as communications, control and optimizations. The paper gives a comprehensive outline of transforming Microgrid to VPP that is useful for researchers, consumers, prosumers and utility operators. 1. Introduction The continued strong development of Distributed energy resources (DERs) provides the great opportunity for renewable energy investors around the world. The worldwide DERs integration grows the average rate of 20% by the end of 20 th Century [1]. Due to priorities on carbon footprint reduction and harnessing energy from alternative sources than fossil fuel, DERs integration with existing power grid will be kept to increase more for the time to come. While these growths provide the lots of advantages, it creates new challenges to manage grid in an effective way. From the experiences of TSO and DSO, some problems occur while integrating the DERs with existing grid such as transmission congestion, voltage and frequency stabilities, and reliability problems due to uncertain and intermittency natures of DERs. Microgrid is a localized group of energy sources and loads that may operate at grid connected or islanded modes. The concept of microgird is getting popular since last decade and there are many Microgrids actively operating at different parts of the globe. The major investment in a Microgrid is on its DERs. In many Microgrids, the operators have to handle problems come up with DERs otherwise green energy should be threw away instead of being utilized. These problems create a new research area to seek solutions for integration of DERs without creating grid stability and reliability problems. One of the new solution of eliminating of DERs negative impacts is through the transformation of Microgrid to VPP. VPP coordinates all DERs as in a single agent to integrated them into grid without compromising the grid stability and reliability, adding many other additional benefits and opportunities to consumers, prosumers, and grid operators [2].

... The realization was accomplished in collaboration with company working in the area of design, diagnostics and commissioning of electrical power facilities. The model is intended for demonstrations, training of students and collecting statistical data [1,6,7]. The modeled scheme is applicable for single busbar feeder connection of open -air HV switchyard bay or for compact metal clad MV switchgear as well. ...

• Dimitar Bogdanov
• Ivaylo Popov

The design of the protection and control equipment for electrical power sector application was object of extensive advance in the last several decades. The modern technologies offer a wide range of multifunctional flexible applications, making the protection and control of facilities more sophisticated. In the same time, the advance of technology imposes the necessity of simulators, training models and tutorial laboratory equipment to be used for adequate training of students and field specialists

• Dad Cherifa

L'apparition des réseaux électriques intelligents, ou « Smart Grids », engendre de profonds changements dans le métier de la distribution d'électricité. En effet, ces réseaux voient apparaître de nouveaux usages (véhicules électriques, climatisation) et de nouveaux producteurs décentralisés (photovoltaïque, éolien), ce qui rend plus difficile le besoin d'équilibre entre l'offre et la demande en électricité et qui impose d'introduire une forme d'intelligence répartie entre leurs différents composants. Au vu de la complexité et de l'ampleur de la mise en oeuvre des Smart Grids, il convient tout d'abord de procéder à des simulations afin de valider leur fonctionnement. Pour ce faire, CentraleSupélec et EDF R&D (au sein de l'institut RISEGrid) ont développé DACCOSIM, une plate-forme de co-simulation s'appuyant sur la norme FMI1(Functional Mock-up Interface), permettant de concevoir et de mettre au point des réseaux électriques intelligents et de grandes tailles. Les composants clés de cette plate-forme sont représentés sous forme de boîtes grises appelées FMU (Functional Mock-up Unit). En outre, les simulateurs des systèmes physiques des Smart Grids peuvent faire des retours arrière en cas de problème dans leurs calculs, contrairement aux simulateurs événementiels (unités de contrôle) qui, bien souvent, ne peuvent qu'avancer dans le temps. Pour faire collaborer ces différents simulateurs, nous avons conçu une solution hybride prenant en considération les contraintes de tous les composants, et permettant d'identifier précisément les types d'événements auxquels le système est confronté. Cette étude a débouché sur une proposition d'évolution de la norme FMI. Par ailleurs, il est difficile de simuler rapidement et efficacement un Smart Grid, surtout lorsque le problème est à l'échelle nationale ou même régionale. Pour pallier ce manque, nous nous sommes focalisés sur la partie la plus gourmande en calcul, à savoir la co-simulation des dispositifs physiques. Ainsi, nous avons proposé des méthodologies, approches et algorithmes permettant de répartir efficacement et rapidement ces différentes FMU sur des architectures distribuées. L'implantation de ces algorithmes a déjà permis de co-simuler des cas métiers de grande taille sur un cluster de PC multi-coeurs. L'intégration de ces méthodes dans DACCOSIM permettraaux ingénieurs d'EDF de concevoir des « réseaux électriques intelligents de très grande taille » plus résistants aux pannes.

Communication networks and systems for power utility automation -Part 3: General requirements

IEC 61850-3:2014. Communication networks and systems for power utility automation -Part 3: General requirements

Introduction to the IEC 61850 electrical utility communication standard

• H Kirrmann

Kirrmann, H. Introduction to the IEC 61850 electrical utility communication standard, ABBCH-RD, 2012.

Guidelines for Implementing Substation Automation Using IEC61850, the International Power System Information Modeling Standard

• L Van Der Zel

L van der Zel, Guidelines for Implementing Substation Automation Using IEC61850, the International Power System Information Modeling Standard, Technical Report, 2004.

Communication networks and systems in substations -Part 5: Communication requirements for functions and device models [6] IEC 61850-6:2010. Communication networks and systems for power utility automation -Part 6: Configuration language for communication in electrical substations related to IEDs

IEC 61850-5:2013. Communication networks and systems in substations -Part 5: Communication requirements for functions and device models [6] IEC 61850-6:2010. Communication networks and systems for power utility automation -Part 6: Configuration language for communication in electrical substations related to IEDs

Communication networks and systems for power utility automation-Part 4: System and project management

IEC 61850-4:2011. Communication networks and systems for power utility automation-Part 4: System and project management

Communication networks and systems in substations-Part 10: Conformance testing

IEC 61850-10:2006. Communication networks and systems in substations-Part 10: Conformance testing

Communication networks and systems for power utility automation -Part 7-3: Basic communication structure -Common Data Classes

IEC 61850-7-3:2011. Communication networks and systems for power utility automation -Part 7-3: Basic communication structure -Common Data Classes -Ed.2

Communication networks and systems for power utility automation -Part 8-1: Mappings to Specific communication service mapping (SCSM) -Mappings to MMS (ISO 9506-1 and ISO 9506-2) and to ISO

IEC 61850-8-1:2011. Communication networks and systems for power utility automation -Part 8-1: Mappings to Specific communication service mapping (SCSM) -Mappings to MMS (ISO 9506-1 and ISO 9506-2) and to ISO/IEC 8802-3

Communication networks and systems in substations -Part 8-1: Specific communication service mapping (SCSM) -Sampled values over serial unidirectional multidrop point to point link

IEC 61850-9-1:2003. Communication networks and systems in substations -Part 8-1: Specific communication service mapping (SCSM) -Sampled values over serial unidirectional multidrop point to point link

Communication networks and systems for power utility automation-Part 9-2: Specific communication service mapping (SCSM)-Sampled values over ISO

IEC 61850-9-2:2011. Communication networks and systems for power utility automation-Part 9-2: Specific communication service mapping (SCSM)-Sampled values over ISO/IEC 8802-3

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