Hello learners, welcome to this topic on introduction to supervisory control and data acquisition system that is corrupt. Let us know stock to understand what is the goal of India with regard to the distribution which is mentioned in the national electricity policy. The requirements to be fulfilled are to improve reliability and quality of service of distribution system. By reducing the duration of power interruptions in part with the international practice. By reducing the frequency of power interruptions in power with the international practice. Maintaining power quality with respect to voltage and frequency excursions to operate efficiently and safely. Minimizing the power losses. A playing manpower resources effectively. In order to achieve the school, we need to start implementing the following measures. Improve the efficiency of the distribution system to keep the distribution system in line with the national electricity policy. To sustain successful distribution companies. To help customers delay and to analyze. Let us try to have a swat analysis stink. We have an and dynamic human results. We have robust information technology. We have a strong operation technology and integration of IT and OT is extremely essential. What are all our weaknesses? More losses, poor metering and collection, poverty theft agent, inadequate infrastructure causing longer out each time. What is there as an opportunity, integration of IT and OT. Time bring in customer delay. To improve the infrastructure to match the future requirements. What is the thread? If we are not trying to improve it then the viability of the distribution company itself will be under question mark based on the swat result. Automation in operation is to reduce losses down time. Automation in metering is to increase the revenue profitability to have smart grid with the highest efficiency. Let us start with automation in distribution feeders and military. This image shows how the evaluation from a manual process to yes, semi automatic or automatic process took place over the years with the invention of the technology. Next, we will see with an example, the outage management without an automation system in place versus outage management system with some level of automation system included in the system. Here you see a timeline of default occurrence and the time required to correct the same. The duration taken from the fault occurrence to bringing back the feeder to the original functional condition is depicted in the animation. The duration is considered in the X-axis as a rectangle block. Let's go through the detailed steps to analyze the situation default occurs. Usually, the customer will not launch the complaint immediately. He will wait for some time to understand whether the fault, ease of temporary nature are permanent nature. In between, from the source and understanding that the fielder is down, the operator will try to inject the source to assess the nature of default. Approximately the time is taken for assessment of nature of fault, maybe 15 minutes. Either the operator assesses that this is a permanent fault or a consumer registers as a complaint about the non-availability of the power supply. Soon after registering the complaint, the officer in charge of the substation instructs the team to investigate the location and nature of default. Depending on the length of the feeder line and the mode of transportation. This exercise may consume 30 minutes to 15 minutes. The fault is located and the information is passed on to the substation. The officer in charge and the field team, proven to possibility of providing power through an alternative route. Our source isolating the faulty zone and restoring power to the customers. This activity consumes a minimum of 15 minutes. In the meanwhile shadow, no activities required to attend to default that is repairing the system is completed and repair activity starts. Repair is completed and healthiness of the system is checking and the poverty is resumed through the normal route. This takes a minimum of 1 to 4 hours. Sometimes it may be more. The time taken for step 1 to 4 is 45 minutes. After going through this automation session, we will come back and see how the timing for step one to step four is getting reduced. The above scenario is an ideal situation and in reality depending upon the severity of the fault and the availability of the resources it may take more time. Now, with the invention of automation in the existing system, we are reducing the time greatly. Any customer will face a power outage while the fault shall be resolved later without disturbing the system as a whole. With this, we will start automation in detail. To provide supervisory control and data accusation, your framework of equipment capabilities and necessary protocols of communication are integrated, which will deliver the required result. Collected data and implemented controls are the arteries of a monitoring system that is automated. Systems, computers and equipment having embedded processes configured for exchanging data using standardized comments and responses. Shown here is discard a complete process. Sensors, sensors since the data to PLC's RRTU's, which it is receiving from the equipments. This data is being sent to PLC's. That is programmable logical controllers are RTU's which receives this data, transform it into the farm which is readable by this card our system and send the same to this kata. Scholars panel, R human mission interface receives this and project the data on the screen in readable form. Similarly, manual inputs are also being provided to the PLC's are RTU's, which in turn comes to the SCADA panel are the computer and through human mission interface. Such data's are being projected on the screen in the readable form. In the human mission interface screen. Similarly, any comments are any response which are to be provided by the operator. He provides the same in this card, a computer or the panel, which in turn goes and reaches the manual input are the sensors where are the same route. The image shows how the substation SCADA relates to this switchgear. The connection from the sushi gear to the substation remote terminal unit is either through hardware or standard industrial communication protocol. The substation information is possible to discover our station. Mission interface enables an operator to see a large substation data on a single location, further through any SCADA Communication Protocol. The shown diagram is a basic architecture. Here, you will see a similar setup to that desire earlier but now on a bigger scale plus with complex systems all constituting the concentration of the data at a single location. We have covered many of the components shown in the previous topics. In this, we will learn how they all will be connected to this central system. We will see all the system components in the upcoming topics. Before we go deep into that, we will see the history of SCADA. With this, we come to the end of this topic. Thank you.
