Final paperenhancing distribution system through the use of real time ethernet in smart grid171025

International Journal of Innovative and Emerging Research in Engineering
Volume 3, Special Issue 1, ICSTSD 2016
649

Abstract- With the advent of new technologies, the demand of
connecting IT systems to the Internet is increased. In modern
electric power grid, to have improved operation, reliability and
safety in distribution system through automated control , modern
communication technologies are utilize. The use of
communication architecture in distribution grid allows remote
access to the facility through an IP network with high security,
facilitating the operation and system diagnostics very quickly.
The increased need for effective control turned the development
of smart distribution grid. This paper proposes the comparative
study of effective monitoring, diagnosis and supervisory control
applied to distribution smart grid. The system is based on modern
SCADA operation, the RMU are installed at key location on the
feeder and interface with communication system for quick fault
identification and control of operation. The paper highlight the
network communication architect with the use of Ethernet
TCP/IP and control of substation equipment and various
communication standards use in the system for enhancing the
grid performance.
Index Terms—Supervisory Control and Data Acquisition-
Smart grid.
I. INTRODUCTION
n modern electric power systems which include renewable
energy resources, automated and intelligent management is
a critical aspect that determines the usefulness of these power
systems. The distribution automation offers a variety of
advantages over the current systems in terms of digitalization,
flexibility, intelligence, sustainability which facilitate the smart
grid power system. In the smart grid, reliable and real time
information becomes the key factor for reliable delivery of
power from generating station to the end users [1].
The control centers are expected to monitor and interact the
electric devices remotely in real time, the transmission
infrastructures with communication network are expected to
employ new technologies to enhance the system performance.
Sadhana A.Bhonde, Research Scholar, Dept. of Electrical Engg.
G.H.Raisoni College of Engineering , Nagpur.
(E-mail: sadhanamohod123@gmail.com)
Dr.S.B.Bodkhe, Dept. of Electrical Engg, Ramdeobaba College of Engg.
Nagpur.(sbbodkhe@gmail.com)
Sharad W. Mohod, Dept. of Electronics Engineering, Ram Meghe
Institute of Technology & Research, Badnera. Amravati.
(E-mail: sharadmohod@rediffmail.com )
The communication network plays a vital role in the power
system management. The network is required to connect the
magnitude of electric devices in distributed locations and
exchange their status information and control instructions.
There is an increasing interest in applying technology to
protect and control the electric utilities. At present
conventional centralized control system has limitations, as they
can degrade due to complexity with network events.
Nowadays, intelligent electronic devices and robust
communication processor contain large amount of data that is
available for years. Initial efforts were on supervisory control
and data acquisition [2]-[4].
In conventional SCADA , communications has been Point-
to-Multipoint serial communications over lease line or private
radio systems. With the introduction of Internet Protocol (IP),
IP technology has seen increasing use in modern SCADA
communications. The connectivity can give modern SCADA
more scale which enables it to provide access to real-time data
display, alarming and control by using different
communication network such as Internet, satellite and remote
modem. The distribution automation system includes signal
sensing, control, human machine interface, management and
networking [5].
Wireless sensor network will play a key role in the
development of the smart grid and enables various demand and
energy management, reducing the electricity expenses [6]-[7].
The objective of this study is to enhance the distribution
system through the use of real time Ethernet, architecture of
SCADA which is connected through the internet. Like a
normal SCADA, it has remote terminal unit (RTU), power line
communication (PLC), intelligent electronic control (IED)
along with the Field remote terminal unit (FRTU). This also
includes the user-access to SCADA which enables real time
monitoring of the system under the developed/implemented
supervision.
In this application, the challenges have to establish a
communication system installed in the substation with
individual control to resolve the problem [8].
The paper is organized as follows. Section II provides the
communication architect. Section III modern substation
communication and section IV gives the various standard used
in communication. Section V discusses the comparison of
modern SCADA for enhancing the distribution grid. Finally
Section VI concludes the paper.
Enhancing Distribution System Through the
Use of Real Time Ethernet in Smart Grid
.Sadhana A.Bhonde , S.B.Bodkhe ,S.W.Mohod
I

650
II. COMMUNICATION ARCHITECT
The communications within the grid are based on EPICS
(Experimental Physics and Industrial Control System). It is a
set of open source tools focused on the development of
distributed control systems in real time using the Ethernet to
communicate the different EPICS devices. The communication
architecture allows remote access to the facility through an IP
network with high security, facilitating the operation and
system diagnostics. The fundamental data of the installation
can be viewed in real time through a website; and locally,
using the EPICS tools . For this purpose the system requires
architecture to collect information of the smart grid, measuring
devices across the net and in addition to connect the individual
operator control (IOC) of the energy suppliers, which can be
away from the control centre of the smart grid. Development
of guideline for suitable IP protocol for smart grid application
and identifying domain type is essential for reliability of power
system.
Wide area networks (WAN) form the communication
backbone to connect the highly distributed smaller area
networks that serve the power systems at different locations.
When the control centers are located far from the substations
or the end consumers, the real-time measurements taken at
the electric devices are transported to the control centers
through the wide area networks
The communication architecture is shown as in Fig. 1.
Fig.1. Grid Communication Architecture
III. CONTROL SCHEME OF THE SYSTEM
The electrical substation is an important component in
power systems. It changes the voltages on the electrical
transmission lines and controls the power flow in the
transmission system. A substation is a complex system
composed of many elements such as transformers, capacitors,
voltage regulators, and circuit breakers. Automated substation
control will be implemented extensively in the smart grid
systems to provide real-time monitoring and control through
local area networks. The possible network technologies to be
used in a substation include Ethernet.
The functions of substation are to control and monitoring of
the switch yard, protection of the power equipment, revenue
metering and automation functions for energy management.
The conventional substation is composed with interlocking
logic, RTU (Remote Terminal Unit), Relays, conventional
switchgear and CT/PT (current/potential transformers). Each
component is hardwired connected with wires.
Modern substation is structured in three basic levels. The
station level provides an overview across the whole station and
is located in a shielded control room. Station level includes
Human Machine Interface (HMI) Workstation, Master Station
Computer, Backup Station Computer and GPS (Global
Positioning System) receiver, etc. The bay level conducts
maintenance work only within one bay and it is usually close
to the switchgear. Bay level includes protection and control
IEDs (intelligent electrical devices) of different bays such as
circuit breakers, transformers, and capacitor banks. Equipment
in bay level and station level are called secondary equipment.
Process level provides the interface between the substation
automation system and the switchgear. Process level includes
switchyard equipment such as CTs/PTs, remote I/O, actuators
etc.[9]-[10].
The Substation data communication system plays a critical
role in the real time mission, critical operation of substation
automation system. All secondary equipment within a
substation is interlinked with communication buses. In
conventional substation, communication devices typically rely
on one-way communication. Serial communication buses or
proprietary communication media with associated protocols
are used for local HMI, as well as for remote SCADA
(Supervisory Control and Data Acquisition) communication
To connect the various equipments in a substation,
specialized sensors are attached to the equipments to take their
status samples. The sampled values are then digitalized and
transmitted through the local area network to the control
station in the substation. An example of the communication
network in a substation is shown in Fig. 2.

651
Fig.2. Communication Network in substation
The network technologies to be used in a substation include
Ethernet TCP/IP. To connect the various equipments in a
substation, dedicated sensors are attached to the equipments to
take their status. The control equipment in a substation is
shown in Fig.3.
Fig.3. Control Equipments in substation
The external and real time data requests are served through
the Server. The operator stations and other internal data users
communicate through server. The control executes through I/O
port. Input port gives the information of input signal such as
breaker ON/OFF position , Isolator ON/OFF position , also
analog input cards analog signal such as Voltage , I/O card
consist of analog input card and digital input card which gives
analog and digital signal from substation through RTU. The
digital Output card control the equipment in substation. Digital
input signal from RTU are transmitted through Router and
Modem towards Multi-packet label switching cloud and send
to control center. For controlling substation equipments signals
are transmitted from control center to MPLS cloud towards
Modem at substation and forwarded to RTU. The arrangement
of control center for operating the equipments through the
communication network are shown Fig.4.
Fig.4. Control Centre Equipments through communication network
The operation for Feeder Remote Terminal Unit (FRTU) in
SCADA system is shown in Fig.5. Input signals from FRTU
are transmitted through Modem towards CDMA/GPRS cloud
and then send to control center. For controlling purpose the
output signals are transmitted from control centre to GPRS
Modem through cloud towards FRTU.
Fig.5. Feeder remote terminal unit operation through communication
network
Modern SCADA Software are developed and designed for
the specific hardware .It can be proprietary type or open type
software. Open software systems are designed to communicate
and control different types of hardware.
IV. COMMUNICATION ASPECT
Many standards have been proposed to guide the
development of smart grid electric power systems. These
standards cover a vast number of technical aspects of the
power systems, including power equipments, electricity
services, management automations and system protections.
Our focus is related to communication aspect of the electric
power system.

652
A. Distributed Network Protocol
The distributed network protocol (DNP3) is
specifically designed for various applications in SCADA. It is
highly standardized, with relatively high compatibility and
inter-operability between devices from different
manufacturers. It support the analog and digital data type.
DNP3 also supports a variety functions commonly used on
control applications, such as pulsed and paired outputs. The
end user can monitor the network and take the required action.
B. IEEE Standard
IEEE has proposed a number of standards related to
the communications in power systems, including C37.1, IEE
1379 ( Recommended practice for interconnection between
IED and RTU), IEEE 1547 (Standard for interconnecting
distributed energy resources with electric power system) and
IEEE 1646.( Standard for communication performance)[11].
C. IEC Standard
The International Electro-technical Commission (IEC) has
proposed a number of standards on the communication and
control of electric power systems. The standard 60870 and
IEC 61850 defines the communication systems used for power
system control.
IEC 61850 is a standard for communication networks and
systems for power utility automation and is being produced by
IEC Technical Committee 57 Working Groups 10. It is
developed based on Utility Communications Architecture 2.0
which is based on the Manufacturing Message Specification
(MMS). IEC 61850 is a lower-layer object-oriented protocol
being implemented over TCP/IP and Ethernet networks. It
defines a vendor independent communication infrastructure
allowing seamless IEDs integration. Compare to DNP3 or IEC
60870-5-104, IEC 61850 is not only another way of providing
the same functions as a traditional SCADA protocol, it also
provides information modes, configuration languages and
abstract services in substation communication.
Main features of IEC 61850 are as follows:
• It translates all in the information in the real substation into
information models in the form of standard naming
conventions structures and formats for easy information
management.
• It provides Abstract Communication Service Interface
(ACSI) and makes it possible for applications and databases to
be unchanged with changes in the communication protocols
and media. provides communication protocols of TCP/IP
based SCADA, real time Generic Object Oriented Substation
Event (GOOSE) and Generic Substation Status Event (GSSE)
and real time sample measured value (SMV). GOOSEs
support system protection applications and run directly over
Ethernet. It defines process bus which is supported by GOOSE
and can minimize substation wiring requirements in the yard
by converting data of CTs/PTs to digital information [12]-[14].
The National Institute of Standards and Technology (NIST)
also published standards to provide guidance to the smart grid
construction. It states the importance and vision of the smart
grid, defines the conceptual reference model, identifies the
implementation standards, suggests the priority action plans,
and specifies the security assessment procedures.
V. MODERN SCADA SYSTEM
A case study of conventional SCADA in the distribution
grid is compared with the incorporation of modern facilities in
the grid.
The present SCADA operations used in 33/11KVsubstation
in distribution system for fault identification and restoration
are shown in Fig . 6 a) .The feeder has incoming supply from
both the side and it is associated with the circuit breaker and
distribution transformer and midway cut point which is
normally open point used in old system so that complete
system get supply from two feeder. In case of fault in the
system, the circuit breaker trips and portion of feeder will get
disconnected, shown with red mark in Fig.6 b). The operators
manually open the isolator and restore the part of supply
portion within 30-45 min after inspection as shown in Fig.6 c).
After the further inspection up to the fault line the operator
opens the isolators between the faulty sections shown in
Fig.6d).
Fig.6a. Fault location Fig.6b.Circuit breaker open
Fig.6c Isolator open Fig.6d. Faulty section open
In modern SCADA operation the RMU are installed at key
location on the feeder and interface with communication
system. The RMU are installed as shown in Fig.7 a). The fault
current information will get with the help of fault passage
indicator (FPI) shown in Fig 7b) at RMU and signals are
transmitted from FRTU towards control centre. The operator
at control centre immediately opens the RMU remotely after

653
receiving the signal from FRTU. The partial restoration of
supply can be done within very short time shown in Fig.7c.
The faulty portion will get isolated by field staff after
identification of location
Fig.7a. System with RMU installed Fig.7b.System with Fault passage
indicator
Fig.7c. partial Restoration Fig.7d.Faulty portion isolation
The modern SCADA operation in the distribution system
enables the real time monitoring, diagnosis and control of the
system effectively.
VI. CONCLUSION
In Modern substation , Human Machine Interface, Master
Station Computer, and GPS are included for the control IEDs
and protection of different equipments such as circuit breakers,
transformers etc. It gives the interface for substation
automation. The substation equipment monitoring and
controlling is very effective with the use of communication
technology.
The different standards and protocols have to be followed
for the development of smart distribution grid . In order to
ensure high communication reliability the Ethernet switch is
used for the control and protection with IEDs
The studies of modern SCADA are compared with
conventional system in fault identification in the distribution
system. Thus modern grid operation control the distribution
system and improves the system problems through monitoring
using sensors and intelligent electronic devices which
enhances the system performance and down time. The paper
presents the study to enhance the distribution network , which
must be planned carefully in order to meet the system
performance and requirement in today’s energy management.
VII. REFERENCES
[1] V. Gungor, D. Sahin, T.Kocak, S. Ergut, C.Buccella, C.Cecati, “Smart
grid technologies: Communication technologies and standards,” IEEE
Trans. Ind. Informat., vol. 7, no. 4, pp. 529–539, Nov.2011.
[2] F. Salvadori, M. De Campos, P. Sausen, R. De Camargo, C. Gehrke, C.
Rech,M. Spohn, and A. Oliveira, “Monitoring in industrial systems
using wireless sensor network with dynamic power management, ”IEEE
Trans. Instrum. Meas., vol. 58, no. 9, pp. 3104–3111, Sep. 2009.
[3] Q. Yang, J. Barria, and T. Green, “Communication infrastructures for
distributed control of power distribution networks,” IEEE Trans. Ind.
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[4] D. Dolezilek and B. McDermott, “Remote data monitoring and data
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[5] Qiu, B., Gooi, H. B., Liu, Y., and Chan, E. K.,Internet-based SCADA
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[6] M. Erol-Kantarci and H. Mouftah, “Wireless sensor networks for cost
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[7] A. Mercurio, A. Di Giorgio, and P. Cioci, “Wireless sensor networks: A
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