My Seminar on Power System Protection and Control
- Jun 6, 2017
- 8 min read
CAREER GOAL: To contribute the knowledge of Trending Technology in Protection and Control systems of Power Substations with electric utilities by designing and implementing a more reliable digital Automation scheme to overcome the existing Analog relays in our substations and Line bays in the Grid system.
In other to achieve a maximum Protection and Control of HV Transmission lines and Power Substations after Power and Control Cables laying and Terminations and Interfacing of the Control and the Protection panels to the outdoor switchyard equipment through the marshalling Kiosk or Junction Boxes, the following processes have to be in place also for an effective system Viz: Configuration of the Relays, Configuration of the BCU’s, Setting up of the SCADA System, Configuration of the Protocol Converter, Installation of the GPS Antenna and the Cables
Laying and Termination of the RS 232 Cable from the Watt meter and Other devices to the Protocol Converter.
Integration of the Automation/SCADA system with the outdoor switchgears relays for Proper opening and closing of such equipment from the control room.
Benefits:
Creates a more sustainable, reliable and secure grid.
Achieves the desired level of power quality and resilience in the most cost-effective manner.
Establishes a user-friendly monitoring system with the Use of Digital relays and full automated system.
Enhances the life span of the substation switchgears because maximum monitoring of the system.
Easier tracking of faults along the transmission lines.
BACKGROUND: The power system, built on century-old technology and approaches, was designed to deliver electricity from large, remote power plants across significant distances to the cities and towns where electricity is used. For that reason, there is great need for an effective Protection and Control of the System to complete the chain of Generation, Transmission and Distribution to the users.
METHODOLOGY: We shall use the devices; PCS-9881 and PCS-9882 Ethernet switch, RCS-9698G/H Communication Gateway, RCS-9700 automation system, RCS-9785 GPS Synchronization Clock and RCS-9794A/B Protocol Converter and the Automation Architecture module to achieve the maximum Protection and Control of he Substation and the 2x132kV HV Transmission lines from the Bay extension to the Substation.
PCS-9881 and PCS-9882 Ethernet switch
PCS-9881 and PCS-9882 Ethernet switch is intended for interconnection of 10/100/1000M adaptive Ethernet devices using twisted wire/Fiber optical connection in substation automation system. It adopts industrial level components and chips to ensure the reliable and
high-speed data exchange, which makes it a compensation of insufficient application of commercial switch in a substation automation system. PCS-9881 and PCS-9882 are fully compatible with IEC 61850 and GOOSE communication in a digital substation automation
system with distributed network or ring network.
Ethernet Switch PCS-9881/ PCS-9882
Functions:
Fully compatible with IEC 61850, GOOSE and digital substation
Performance data meets the requirements in IEC 61850-3.
Suitable for -40°C to +85°C environment.
Support QoS (IEEE 802.1p) message priority control, four queues are provided to ensure the priority of important message in GOOSE.
Support flexible VLAN configuration, the process mode of message with VLAN tag can be configured as per specified application.
Message from two or more interfaces can be integrated to supervisory port via mirror image technology, meet the requirement of wave data communication in digital substation.
Single-mode and multi-mode optical transceiver are optional to meet different application.
Ethernet Interfaces
10/100M adaptive electrical interfaces are compatible with 10BASE-T/100BASE-TX and support MDI/MDIX identification.
10/100M adaptive optical interfaces adopt SFP slots.100BASE-FX optical Ethernet transceiver compatible with IEEE 802.3 can be used. Hot plugging is supported.
10/100/1000M adaptive optical interfaces adopt SFP slots.1000BASE-SX optical Ethernet transceiver (1.25GBd) compatible with IEEE 802.3 can be used. Hot plugging is supported.
Non-blocking store-and-forward technology is applied in message exchange.
Support IEEE 802.3x Flow Control.
RCS-9698G/H Communication Gateway
RCS-9698G/H is used to establish a communication links between substation and Load Dispatching Centers or Grid Control Centers to achieve data exchange. It is capable to
communication with several dispatching centers simultaneously via different telecommunication channels according to the applied protocol. Industrial hardware with embedded components are adopted instead of PC technology with weak rotary machinery (Hard disk, Cooling Fan, etc.). RCS-9698G/H supports both conventional communication channels and modern powerful Ethernet, and is fully complied with IEC 61850 international standard communication protocol. RCS-9698G can be used independently, while RCS-9698H adopts duplicated
scheme with two RCS-9698G units to realize HOT-STANDBY or Dual-HOT running mode.
Basic Communication Protocol
Upward: IEC 60870-5-101, IEC 61850-5-104, MODBUS, CDT,
DNP 3.0, SCI 1801, RP570, ABB33/41
Downward: IEC 61850, IEC 60870-5-103, MODBUS, CDT
It can cooperate with RCS-9794A/B to realize various protocols.
Functions:
Collect Information from IEDs:
Depending on the applied protocol and database configuration, and also owing to its powerful communication interface, RCS-9798G/H can communicate with various IEDs in a substation,
and automatically collect any wanted information from them, e.g. sequence of events (SOE), binary signals, transformer tap position, pulse counting of electricity quantity, communication
states and so on. In addition, all the collected information can be sent to dispatching center.
Small-capacity memory storage:
With small-capacity of industrial-grade NANDFLASH memory (128MBytes for single machine while 256MBytes for dual machine system), information of events (protection relays’ self-checking information, trip event records, fault information, settings modification records and so on), remote command from dispatching center including selecting and executing of the
binary output and setting modifications, remote regulation of transformer tap position, remotely signal reset event and so on are stored, which are automatically collected from various BCU,
protection relays and some other auxiliary IEDs.
Settings management:
RCS-9698G/H can upload/download and modify settings (only the currently activated group of setting can be managed) of various expected protection relays and auxiliary IEDs. Setting
management can be done by Debugging Tool or achieved by dispatching center up to the applied protocol.
RCS-9700 automation system
RCS-9700 is a state-of-the-art automation solution for substations, generations and industrials with many advanced technologies and patents. It can be applied for substations starting from distribution level up to extra high voltage level. It integrates the application of protection, control, Ethernet, IT and communication technology based on the international standard and it is fully compatible with IEC 61850 standard. The system adopts the layered distributed architecture with bay-oriented and object-oriented structure, which is more reliable and easy to extend and maintain.RCS-9700 automation system can be applied in various substations and power plants of all voltage levels. It is suitable for new constructed substation and retrofit substation. The IEDs for protection and control are integrated in RCS-9700 automation
system and the data is transferred to remote control center (load dispatching center) via Gateway. The innovative protocol converter complied with IEC 61850 is integrated for the third party IEDs which is not complied the substation protocol. RCS-9700 helps the customers to realize the automation of local operations and the collection, evaluation and forwarding of data,
and provides the remote control and monitoring functions for power system status. It is suitable for the following applications:
• Transmission and distribution substations, generation and
industrial electrical system.
• Utilities, power plants and industries
• New constructed substations and retrofit substations
• Gas and air isolated switchgear
Functions:
• Real-time data acquisition and processing, the system makes acquisition and processing of real-time data of supervisory and control units installed in bay level.
• Control operation, synchronism checking and interlocking, the system can make sequential operations on circuit breakers, motor-driven isolators, transformer tap changer, reactive power
device group, etc. PCS-9705 and RCS-970x bay control units carry out control operations, synchronous checking and electrical interlocking functions. Interlocking software is used mainly
for implementation of edition, compilation and download of interlocking logic.
• Communication with control center, Communication with control center is independent to local HMI.
Control command can be transmitted directly from control center.
It supports IEC standard protocols and other standard protocols such as DNP3.0 and 1801 as well.
• Time synchronization
The system receives GPS standard time signal for clock synchronism. The absolute time are broadcasted through network. The second or minute pulse signal is inputted to equipment’s by RS-485 port or potential free contact. The IRIG-B signal (AC or DC) is also supported.
• Interfaces with third-party IEDs, Protocol converters complied with IEC 61850 is provided for
integration of third-party IEDs. It can convert non-IEC 61850 protocol to IEC 61850 and realize the full automation of all IEDs in substation.
• Protection and fault information management.
The system can acquire information of protection, fault information, power system stability control and other automation equipment, and make display, analysis and processing locally.
The information subsystem provides a powerful fault analysis tool. When fault occurs, the information subsystem can transmit protection operation information and fault report to dispatching center quickly and correctly. This helps the dispatching center to get correct fault information at once, make rapid and correct fault analysis as well as decision on fault clearance.
• PLC function based on IEC61131
Programmable control function is designed based on IEC61131
standard. It can complete logic latching of individual device sequential control, group control as well as station-wide control.
• SAS software package (HMI)
The system provides powerful and friendly human machine interfaces software package including:
- Setup and maintenance of data base
- Reactive power and voltage automatic regulation
- Configurable Alarm processing
- Sequence of events record and post-fault review
- Configuration and displaying of graph and chart
- On-line calculation and reports preparing
- Operation management
- Electricity processing
- Self-diagnosis and self-restoration
RCS-9785 GPS Synchronization Clock
RCS-9785 GPS Synchronization Clock is an independent GPS timing device with GPS signal receiving module. It can provide highly reliable and accurate time message to substations. It can be integrated in SAS or RTU via communication ports with IEC 61850 and IEC 60870-5-103 protocols.
Functions
The RCS-9785C/D GPS Synchronization Clock can provide various timing messages, including standard IRIG-B time code, pulse per second (PPS), pulse per minute (PPM) and timing
message. The device can provide fiber optic output, RS-485 and RS-232 output and static empty contact output interfaces through flexible configuration of various expansion cards. Meanwhile, the device also provides network timing function. Moreover, the network is a redundant one, providing timing message through 100M Ethernet.
The RCS-9785C/D device contains a GPS module and at the same time also receive IRIG-B timing code from external timing source. The device will give preference to its internal GPS signal as its time reference. When the GPS module tracks a satellite, it will output the timing message according to the GPS signal.
Otherwise, it will send out timing message according to the IRIG-B time code received. There is clock chip inside the device which checks GPS signal or IRIG-B time code of external clock
source during normal operation. When the internal GPS is out of synchronization and there is no external clock source either, the device can also generate various timing message according to
internal clock and the time message outputted can still maintain a certain degree of accuracy.
To meet the requirement of different applications, RCS-9785C type and D type equipment are different in their functional configurations, where:
The RCS-9785C integrates one GPS module in it, which uses two devices as independent timing source and “Redundant computer and network” operation (Automatic switchover of the one in
operation and the one on back-up) can be realized.
The RCS-9785D integrates two GPS modules in it, where “Redundant computer and network” operation can be realized with one device and the two GPS modules can be used as
independent clock source for automatic switchover of the one in operation and the one on back-up to adapt to the requirement of compact arrangement of the panel assembling.
CONCLUDING REMARKS: Digital Relays and Automation offers significant advantages over the Analog relays. Total Incorporation of These relays and Automation into the existing utility grid, will secures the following benefits:
A stronger local economy: Reliable and resilient Power system will attract private investment, create jobs, and maximize production output.
Reduce Risks: The risk that substation operator faces during manual operating of Breakers and Isolators will reduce drastically, since they will be doing the same by just pushing a button in the control room.
Enhanced Communication between two or More Stations: Communication system of the automation system allows interfacing among different substations.
REFERENCES
Philip Lloyd, Energy Institute Cape Peninsula University of Technology, SAIEEE Conference on Energy efficiency and renewables, 2012.
N. Shinomiya, Distributed Control Based on Tie-Set Graph Theory for Smart Grid Networks, IEEE International Congress on Ultra-Modern Telecommunications and Control Systems (ICUMT), 2010.
K. Nakayama, K. Benson, L. Bic, M. Dillencourt, Complete Automation of Future Grid for Optimal Real-Time Distribution of Renewables, IEEE International Conference on Smart Grid Communications (Smart Grid COMM), 2012.
Mhilu, C.F., Ilemobade, A.A and Olubambi, P.A. 2008. Preliminary study: Engineering education evaluation a desktop study, conceptual framework. Programme 3.2: Building Engineering Capacity for Manufacturing in Nigeria, COREN 2016.
Dr. Ir.Ing. Jan Desmet, Impact of RES on voltage quality and its impact on the yield-Smart microgrids -34,2010.
Comments