FORM-2
THE PATENTS ACT, 1970
(39 of 1970)
& THE PATENTS RULES, 2003
COMPLETE SPECIFICATION
(See section 10 and rule 13) DISTRIBUTION SIDE SCADA FOR SMART GRID
ADI INNOVATIVE SOLUTIONS PVT. LTD.,
an Indian Company,
of 201, Rainbow Plaza, Rahatni Pune-411 017,
Maharashtra, India.
THE FOLLOWING SPECIFICATION PARTICULARLY DESCRIBES THE INVENTION AND THE MANNER IN WHICH IT IS TO BE PERFORMED.

FIELD OF THE INVENTION
This invention relates to the field of Supervisory Control and Data Acquisition Systems (SCADA).
DEFINITIONS OF TERMS USED IN THE SPECIFICATION
The expression MIU in this specification is used to refer to Meter interface units that are add-on devices to a meter. It can read the meter and communicate the meter reading to the respective device.
The expression DF in this specification is used to refer to a Data forwarder which is a device that is deployed at the distribution transformer end to collect the meter reading, carry out local audit, generate reading for power system parameters (PF, Line imbalance, per unit impedance) with time stamp and communicate the same to a host computer (HCDC) / data concentrator computer (DCC).
The expression Time Stamp in this specification is used to refer to the time when data is read being stamped / linked to the data which is read.
These definitions are in addition to those expressed in the art.
Acronyms and their details for terms which are known in the art and used in this specification / accompanying drawings:
PLC: Power line communication.
DSSS: Direct sequence spread spectrum
DT: Distribution transformer (11KV / 440V transformer):

WL: Wireless connecting unit.
CTYPT: Current transformer and Potential transformer
AMR: Automatic meter reading system.
KW: Kilowatt, (active power)
KVA: Kilo volt amps.
KVAR: Kilo volt ampere reactive
GSM: Global System for Mobile communication
PSTN: Public Switched Telephone Network
HDD: Hard disk drive
SCADA: Supervisory Control and Data Acquisition System
RTU: Remote Terminal Unit
CB: Circuit Breaker
BACKGROUND OF THE INVENTION
Supervisory Control and Data Acquisition System (SCADA) usually refers to centralized systems which monitor and control entire sites, or complexes of systems spread out over large areas. Most control actions are performed automatically by Remote Terminal Units (RTUs) or by programmable logic controllers (PLCs). Data acquisition begins at the RTU or PLC level and includes meter readings and equipment status reports that are communicated to SCADA as required. Data is then compiled and formatted in such a way that a control room operator using Human Machine Interface (HMI) can make supervisory decisions to adjust or override normal RTU / PLC controls.

Conventional SCADA systems are implemented at the receiving station wherein automation is achieved for managing demand and supply through controls operating at the generating system on the grid at very high voltage. So the main issue that has been addressed by conventional SCADA systems is managing revenue through management of power supply. Scaling these systems to meet distribution network requirements is difficult. As such managing demand side network using conventional SCADA systems is also a challenge.
Presently SCADA systems in power generation are being used for supply side management of the network which in electrical sense is referred to as grid side management. All the controls and control points operate in a supervisory mode and data acquisition is done with suitable protocol catering to the type of network. The controls are implemented though devices called as RTU or remote terminal units. Hence controls are operated through RTUs which operate on the network with a pre - determined protocol. SCADA systems are implemented up to the level of receiving station, implying it is being used for managing supply or feed of power from the generators in the network. Further to this, utility software is implemented on the host in the load dispatch systems for addressing these needs while control of switching generators, protection and relaying systems are implemented on RTUs on the SCADA network. The purpose of this implementation is to manage supply and maximize the return on investment through managing supply.
Thus a need is felt for a reliable SCADA system that can be implemented for managing the distribution / demand side of the power system.

OBJECTS OF THE INVENTION
An object of the invention is to provide a distribution side SCADA system.
Another object of the invention is to provide a distribution side SCADA system wherein the functionality of the system is scaled down to the level of distribution transformers.
One more object of the invention is to provide a distribution side SCADA system to manage demand side requirements.
Still one more object of the invention is to provide a distribution side SCADA system that can be integrated with feeder area metering networks.
Yet another object of the invention is to provide a system for Automatic Meter Reading (AMR) that is efficient.
One more object of the invention is to provide a distribution side SCADA system that enhances the system stability.
SUMMARY OF THE INVENTION
In accordance with the present invention, there is provided a system for Supervisory Control and Data Acquisition (SCADA) in an electrical power network comprising:
• a grid supply;
• a receiving station;
• a substation including at least one power transformer;

• a plurality of distribution transformers receiving stepped down power supply from the power transformer; and
• a plurality of end user groups, each group receiving further stepped down power supply from distribution transformers, each distribution transformer in a one to one correspondence,
the system is characterized in that:
• a first data acquisition and control means is provided between each distribution transformer and its corresponding user group; and
• a second data acquisition and control means is provided between the power transformer and the distribution transformer.
Preferably, in accordance with this invention, the first data acquisition and control means includes at least one Remote Terminal Unit (RTU).
Preferably, in accordance with this invention, the second data acquisition and control means includes at least one Remote Terminal Unit (RTU).
Additionally, in accordance with this invention, wherein the first data acquisition and control means and the second data acquisition and control means communicate data using DNP3 protocol.
Typically, in accordance with this invention, the first data acquisition and control means and the second data acquisition and control means communicate data using IEC608170-5 protocol.
Furthermore, in accordance with this invention, the first data acquisition and control means selectively communicates with the second data acquisition and control means.

Preferably, in accordance with this invention, the first data acquisition and control means selectively communicate with each other.
Additionally, in accordance with this invention, the second data acquisition and control means selectively communicate with each other.
In accordance with the present invention, there is provided a method for Supervisory Control and Data Acquisition (SCADA) in an electrical power network comprising:
• receiving power supply from the grid;
• stepping down the received power supply using at least one power transformer;
• supply power to end user groups, each group receiving further stepped down power supply from distribution transformers; and
• associating each distribution transformer with a corresponding end user group;
the method comprising the following steps:
• providing a first data acquisition and control means between each distribution transformer and its corresponding user group; and
• providing a second data acquisition and control means between the power transformer and the distribution transformer.
Preferably, in accordance with this invention, the steps of providing a first data acquisition and control means and second data acquisition and control means include providing Remote Terminal Units (RTUs).

BRIEF DESCRIPTION OF ACCOMPANYING DRAWINGS
The invention will now be described with the help of accompanying drawings, in which:
FIGURE 1 illustrates a schematic representation of a power system network in accordance with the present invention;
FIGURE 2 illustrates a schematic representation of the SCADA functionality at substation level in accordance with the present invention;
FIGURE 3 illustrates a layered architecture of the SCADA functionality extended to the distribution level in accordance with the present invention; and
FIGURE 4 illustrates a schematic representation of the overall SCADA functionality in layered architecture in accordance with the present invention.
DESCRIPTION OF THE INVENTION
The invention will now be described with reference to the embodiments shown in the accompanying drawings. The embodiments do not limit the scope and ambit of the invention. The description relates purely to the exemplary preferred embodiments of the invention and its suggested application.
Conventional SCADA systems for electrical power networks known in the art are aimed at managing power at the supply side. There are scalability and

internetworking issues when such conventional SCADA systems are extended to the distribution side. The conventional SCADA systems need to cater to a single network on the supply side. In contrast, the supply side or the distribution network comprises many smaller networks.
In accordance with the present invention a distribution side SCADA system is envisaged that caters to the demand side of the electrical power network. Implementing the SCADA system on the distribution side allows management of the power distribution network, provides supervisory control through Remote Terminal Units (RTUs) for restructuring the distribution network, protection, relaying, power factor improvement by capacitor bank switching and enhancing the system stability. Hence to implement the SCADA functionality on the distribution side, it is necessary to enhance the architectural frame work from the system side, develop Remote Terminal Units (RTUs) on distribution side, develop Remote Terminal Units (RTUs) to implement demand side controls, develop principles for demand side management and incorporate the same at the SCADA system at the substation level.
The system in accordance with the present invention is described with reference to FIGURES 1 to 4 herein below.
FIGURE 1 illustrates a schematic representation of a power system network in accordance with the present invention. In accordance with the present invention, a system for Supervisory Control and Data Acquisition (SCADA) is envisages for an electrical power network that typically comprises following components: • a grid supply GRD;

• a receiving station RS;
• a substation SS including one power transformer having an input feeder I/P FDR and an outgoing feeder O/G FDR;
• distribution transformers DT receiving stepped down power supply from the power transformer; and
• end user groups, each group receiving further stepped down power supply from distribution transformers; each distribution transformer corresponds to a user group.
The system in accordance with the present invention is provided with
• a first data acquisition and control means between each distribution transformer and its corresponding user group; and
• a second data acquisition and control means between the power transformer and the distribution transformer.
The first data acquisition and control means and the second data acquisition and control means include Remote Terminal Units (RTUs). The Remote Terminal Units (RTUs) serve to provide the functions of device control and network control in the distribution side SCADA system in accordance with the present invention.
FIGURE 3 illustrates a layered architecture of the SCADA functionality extended to the distribution level in accordance with the present invention. Here each layer is a subnet by itself. The layers include the Load Flow Centers LF, the Receiving Station RS, the Substation Network SS, the Feeder Area Network FDR and the Automatic Meter Reading (AMR) Network AMR. The figure also illustrates the main functions that form part

of each layer of the SCADA architecture and how the Remote Terminal Units (RTUs) communicate data using DNP3 / IEC608170-5 protocol.
Furthermore, in accordance with this invention, the first data acquisition and control means selectively communicates with the second data acquisition and control means. The Remote Terminal Units (RTUs) forming the first data acquisition and control means can also selectively communicate with each other. Likewise, the Remote Terminal Units (RTUs) forming the second data acquisition and control means also selectively communicate with each other. A control means / selection means is provided for achieving this functionality.
FIGURE 2 illustrates a schematic representation of the SCADA functionality at substation level in accordance with the present invention.
FIGURE 4 illustrates a schematic representation of the overall SCADA functionality in layered architecture in accordance with the present invention. The last distribution point namely the distribution transformer level has SCADA implementation with feeder area metering and supervisory control. This feeder area metering network is connected to Automatic Meter Reading (AMR) network which can be adhoc and scalable in nature. This is followed by the feeder level SCADA implementation which in turn is followed by the substation level SCADA implementation thereby resulting in a scaled SCADA system.
The system in accordance with the present invention provides the following features:
• system for a scaled SCADA implementation;

• methods for implementation of scaled SCADA at feeder level;
• methods for implementation of scaled SCADA at distribution transformer level along with feeder area metering network;
• layering methods under subnet scheme along with supervisory system at network level up to distribution transformer level;
• methods for RTU control in supervisory mode in the subnet of SCADA; and
• methods for distributing set objective for the SCADA subnet.
TECHNICAL ADVANCEMENTS AND ECONOMIC
SIGNIFICANCE
The system as described in the present invention has several technical advantages and economic significance including but not limited to the realization of:
• a distribution side SCADA system;
• a distribution side SCADA system wherein the functionality of the system is scaled down to the level of distribution transformers;
• a distribution side SCADA system to manage demand side requirements;

• a distribution side SCADA system that can be integrated with feeder area metering networks;
• a system for Automatic Meter Reading (AMR) that is efficient; and
• a distribution side SCADA system that enhances the system stability.
The numerical values given for various physical parameters, dimensions and quantities are only approximate values and it is envisaged that the values higher than the numerical value assigned to the physical parameters, dimensions and quantities fall within the scope of the invention and the claims unless there is a statement in the specification to the contrary.
While considerable emphasis has been placed herein on the particular features of this invention, it will be appreciated that various modifications can be made, and that many changes can be made in the preferred embodiment without departing from the principles of the invention. These and other modifications in the nature of the invention or the preferred embodiments will be apparent to those skilled in the art from the disclosure herein, whereby it is to be distinctly understood that the foregoing descriptive matter is to be interpreted merely as illustrative of the invention and not as a limitation.

We Claim:
LA system for Supervisory Control and Data Acquisition (SCAD A) in an electrical power network comprising:
• a grid supply;
• a receiving station;
• a substation including at least one power transformer;
• a plurality of distribution transformers receiving stepped down power supply from the power transformer at the substation; and
• a plurality of end user groups, each group receiving further stepped down power supply from distribution transformers, each distribution transformer in a one to one correspondence,
said system characterized in that:
• a first data acquisition and control means provided between each distribution transformer and its corresponding user group; and
• a second data acquisition and control means provided between the power transformer at the substation and the distribution transformer.

2. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said first data acquisition and control means includes at least one Remote Terminal Unit (RTU).
3. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said second data acquisition and control means includes at least one Remote Terminal Unit (RTU).

4. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said first data acquisition and control means and said second data acquisition and control means communicate data using DNP3 protocol.
5. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said first data acquisition and control means and said second data acquisition and control means communicate data using IEC608170-5 protocol.
6. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said first data acquisition and control means selectively communicates with said second data acquisition and control means.
7. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said first data acquisition and control means selectively communicate with each other.
8. The system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 1, wherein said second data acquisition and control means selectively communicate with each other.
9. A method for providing a system for Supervisory Control and Data Acquisition (SCADA) in an electrical power network comprising:

• receiving power supply from the grid;
• stepping down the received power supply using at least one power transformer at the substation;

• supplying power to end user groups, each group receiving further stepped down power supply from distribution transformers; and
• associating each distribution transformer with a corresponding end user group;
said method comprising the following steps:
• providing a first data acquisition and control means between each distribution transformer and its corresponding user group; and
• providing a second data acquisition and control means between the power transformer at the substation and the distribution transformer.
10. The method for providing a system for Supervisory Control and Data Acquisition (SCADA) as claimed in claim 9, wherein the steps of providing a first data acquisition and control means and second data acquisition and control means include providing Remote Terminal Units (RTUs).