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NR keeps the lights on Practice, Improvement, Cooperation and Innovation

Copyright Copyright Š NR Electric 2013.12. All rights reserved We reserve all rights to this document and to the information contained herein. Improper use in particular reproduction and dissemination to third parties is strictly forbidden except where expressly authorized. The information in this manual is carefully checked periodically, and necessary corrections will be included in future editions. If the user nevertheless detects any errors, he is appreciated any suggested correction or improvement. We reserve the rights to make technical improvements without notice.

NR Electric Co., Ltd. 69 Suyuan Avenue, Jiangning, Nanjing 211102, China Tel: +86 25 8717 8888 Fax: +86 25 8717 8999 Website: www.NR Electricelect.com E-mail: NRsales@nrelect.com NRservices@nrelect.com


NR Electric Co., Ltd.

NR Electric Co., Ltd.

CONTENTS Company Profile

Product Spectrum

.............................

6

........................... ..........................................................

9

Power Electronics Applications

.........................................................

16

.................................................................

25

Technology Innovation

...................

31

Solution for Renewable Energy Interconnection .....................................

33

Solution for Protection Management System ...........................................

36

Solution for Industrial Energy Management .............................................

37

Solution for Flexible AC Transmission System

........................................

39

......................................................

40

Engineering Service, Design & Training

........... 41

Engineering Service

......................................................................................

42

Engineering Design

.......................................................................................

44

Engineering Training

.....................................................................................

Integrated Secondary System Transmission Line Protection

Circuit Breaker Protection

PCS-9830

Point-on-Wave Controller of Breaker

Generator Protection

..............................................

Line Distance Protection

PCS-931

Line Current Differential Protection

PCS-924

T-zone Current Differential Protection

45

...........................................................

Generator & Excitation Protection

PCS-985T

Main Transformer & Auxiliary Transformer Protection

RCS-985U

External Source for Stator Earth Fault Protection

PCS-985RE

Rotor Earth Fault Protection with Voltage Injection

Feeder Protection

...............................................................

PCS-9613

Feeder Differential Relay

PCS-9691E

Overcurrent Protection

PCS-9641

...........................

Automation System

80

PCS-9700

HMI Software

PCS-9700F

Power Forecast System

PCS-9705

Bay Control Unit

82 86

Transfer & Synchronization

101

102 104 107

................................................

110

113

................................................. 116

PCS-9651

Automatic Transfer Relay

PCS-9655

High Speed Transfer Device

PCS-9659

Auto Synchronizer

............................................

............................................. ........................... ......................

47 49

Arc Protection

118

.......................................

120

........................................................

122

PCS-9656

...............................................................

..................................................................... Arc Protection System

56

Digital Substation

125

................................................................ 128

Merging Unit

..................................................................

58

PCS-222

Intelligent Control Unit

CB Online Monitoring Unit

Centralized Busbar Protection

...................................

60

PCS-223

PCS-915ID

Distributed Busbar Protection

....................................

63

PCS-9250-EGI/EAI Electronic CT/VT PCS-9250-OAI

66

PCS-978

Transformer Protection

................................................

68

PCS-974

Mechanical Protection

.................................................

73

PCS-9671

Transformer Current Differential Protection

............

124

52

PCS-915IC

.......................................................

.................................................

75

Optical CT

................................................. ..........................................

PCS-9799

Static Synchronous Compensator

PCS-9570

Series Compensation

............................................................

157

PCS-9590

DC De-Icer

.........................................................................

162

PCS-9563

Photovoltaic Interconnection System

..................................................

166

PCS-9561

Wind Energy Converter

...........................................................

172

PCS-9400

Generator Excitation System

.......................................................

176

129 134 137

.................................................

139

.............................................................

143

Ethernet Switch

.............................................................

Clock Extension Unit

MUX-2M/64

Communication Interface

Recording

........................ 233 ...........................................

PCS-9583

RCS-9785E

PCS-996

Static Var Compensator

153

RCS-9785C/D GPS Synchronization Clock

Measurement

PCS-9580

156

Station Manager

PCS-9882

Power Electronics Applications

145

..............................................

.................................................................

RCS-9794A/B Protocol Converter

.............................................

............................................................

RCS-9698G/H Gateway

......................................................

RCS-9698M/N Remote Terminal Unit 94

.................................................................. 112

Motor Protection

............................................................. 144

PCS-9700

98 .............................

Automation System

78

...........................................

Directional Overcurrent Protection

Motor Protection

.............................

.....................................

PCS-9611

PCS-221

Transformer Protection

........................

77

.......................... 46

PCS-902

Busbar Protection

...........................................

PCS-985

30

Solution for Digital Substation .....................................................................

Solution for Flexible DC Transmission

...................................................

PCS-921

8

Integrated Secondary System

Flexible DC Transmission

Circuit Breaker Protection

.......................................

234

.........................

238

...............................................

240

..................................................................

242

...................

244

............................................

246

..................................

249

180 186

Flexible DC Transmission

................................ 251

190

PCS-9550

LCC-HVDC Control and Protection System .........

252

...........................................

194

PCS-9520

VSC-HVDC Control and Protection System ........

255

PCS-8100

VSC-HVDC IGBT Valve

257

......................................................................

197

PCS-9250

DC Yard Electronic Transformer

....................................................

Phasor Measurement Unit

..........................................

198

...........................................................................

201

Software Tool

PCS-9013

DFR Management System

.........................................

202

PCS-Explorer Assistant Software

Disturbance Fault Recorder

........................................

203

PCS-PC Assistant Software

PCS-996S

Disturbance Fault Recorder

........................................

205

SCL Configuration Tool

PCS-986

Disturbance Fault Recorder

........................................

207

...................................................... 209

261 262

.............................................................................

263

..................................................... 264

MD1501

Auxiliary Relay

..............................................

213

MD1701

Test Block

PCS-993

Out-of-Step Controller

PCS-994

Frequency & Voltage Controller

Energy Management

Accessories

...........................................................

210

Power Stability Control System

.............................

PCS-9000

Energy Management System

Distribution Management System

PCS-9720

Management Unit

PCS-9721A

Distribution Terminal Unit for Switchyard

PCS-9721B

Distribution Terminal Unit for Ring Main Unit

PCS-9721C

Feeder Terminal Unit

................................. .........................

......................................................

...........

..............................................................

265

.......................................................................

267

215

........................................................... 217

PCS-9000

258

.....................................................................

..............................

PCS-990

............................

................................................... 260

PCS-996R

Stability Control System

...........................................

Appendix

.......................................................... 269

218

Appendix 1

Relay Technical Data

225

Appendix 2

Device Dimension

229

Appendix 3

Panel Design

230

Appendix 4

Relay Connection Terminals

......

231

................................................

232

................................................

269

.....................................................

276

..............................................................

278

...................................

281


NR Electric Co., Ltd.

NR Electric Co., Ltd.

NR Electric is a leading solution provider specializing in electric power generation, transmission, and distribution for customers worldwide. The company is one of the largest protection and control manufactures in the world. NR Electric occupies an important position in Power Electronics Applications and in the Flexible HVDC transmission fields.

Built on cutting-edge technology, NR Electric serves power utilities and industrial enterprises with world-class products, all-around solutions and superior services. Our innovative and proven solutions improve the safety, reliability, efficiency and environmental friendliness of any power system.

NR Electric focuses on the research and development of innovative products and solutions with unique patents and know-how. We combine products, systems and services, to provide comprehensive solutions in the following fields: •

Integrated Secondary System Solutions: Integrated Secondary Systems consist of a full spectrum of hardware and software solutions for power system protection, automation and management.

Power Electronics Application Solutions: NR Electric's power electronic-based equipment provides proven and cost-effective solutions to achieve a Flexible AC Transmission System (FACTS). NR Electric's power electronics solutions increase capacity, enhance flexibility, and improve the reliability and quality of the smart grid.

COMPANY Chapter 1

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Flexible HVDC transmission Solutions: LCC-HVDC and VSC-HVDC (Voltage Source Converter based HVDC) are efficient alternatives for bulk power transmission. Based on years of experience working with voltage levels of up to +/800kV, thyristor and IGBT control technology, NR Electric has developed LCC-HVDC and VSC-HVDC solutions that are reliable, economical and field-proven.

NR Electric commitment is to continuously provide excellence to our global customers. Our core mission is to solve practical problems, and to enhance the security and reliability of power systems with our down-to-earth attitude, innovative solutions, products and services. In recent years, NR Electric has been continuously improving its localization level to realize fast and professional pre-sale and after-sale services. So far, NR Electric has founded subsidiaries and established technical service centers in different regions all over the world.

PROFILE

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Integrated Secondary System

Built upon decades of research, development, and leveraging numerous operational experiences in secondary power systems, NR Electric has developed a unified and integrative solution for the secondary system; from the station level to the grid level, including communication infrastructure. The consumers can benefit from the Integrated Secondary System (ISS). This technology is sure to optimize energy generation, transmission, distribution and consumption. At a station level, the ISS solution integrates protection, control, monitoring, metering, recording, video surveillance (CCTV) and communication in each substation. At a network level, it provides the following: •

Energy Management System (EMS)

Distributed Management System (DMS)

Tele-Meter Reading System (TMR)

Power Stability Control System (PSCS)

Wide Area Measurement System (WAMS)

Disturbance & Fault Management System (DFMS)

Relay Management System

CCTV Management System.

Furthermore, the communication infrastructure between substations and dispatching centers are compatible with our system. The Local Area Network (LAN) is used for the internal communication between substations and dispatching centers. The Wide Area Network (WAN) and/or Synchronous Optical Networking (SONET)/Synchronous Digital Hierarchy (SDH) networks can be adopted for the inter-station communications according to the specific application requirements. With the ISS solution, the utilities operators can unify the management system of dispatching centers and substations. Based on the IEC 61850 and the IEC 61970 standards, and other communication protocols, data is classified and can be shared by several applications within the ISS system. The unified data format allows for easy extension of new applications. The cyber security is acquired via the authorization and hardware security devices.

PRODUCT Chapter 2

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SPECTRUM

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Protection & Control Protection and Control

Automation

NR Electric is dedicated to providing diverse protection and control products with well-proven technologies that have been widely implemented in thousands of projects worldwide. The protection and control solution plans cover all primary assets including: generator, transformer, transmission line, busbar, circuit breaker, reactor, capacitor, motor and beyond. As for hardware architecture, NR Electric's innovative two-outof-two logic is implemented to eliminate mal-operations due to the component failure. The combination of the two-out-of-two logic and the implementation of a redundant scheme ensure the dependability and security of our protection and control solution systems. NR Electric invented the Deviation of Power Frequency Component (DPFC), a protection principle, which can help identify and confirm the fault in milliseconds and aid in the issuing of control commands accordingly. NR Electric's continuous focus on research and development has led to the creation of many innovative technologies and patents that have greatly improved the performance of NR Electric’s protection products.

Protection and Control for Substations NR Electric’s protection and control devices are fully compatible with the IEC 61850 standard protocol, and can be implemented in completely autonomous buildings, in an extension or in renovated conventional substations, and digital substations.

NR Electric can provide automation systems for asset management, power system status monitoring, remote/local control, fault analysis and evaluation, operators’ authorization, history data statistic analysis and communication for dispatching centers. It manages utility assets, monitors operation states and measures load profiles. All the information is collected and visually displayed in the control room. Operators can execute remote control via the workstation.

Power Generation Protection and Control For power generation plants, NR Electric offers the generator protection, the transformer protection and the comprehensive generator-transformer unit protection. The comprehensive generator-transformer protection features the “all-in-one” solution for the protection and control of the generatortransformer unit, the generator, the main transformer, up to 3 auxiliary transformers and the excitation systems.

Uninterrupted power supply is always critical to industrial enterprises and thus highly reliable protection and control is necessary. NR Electric's innovative protection and control solutions are also suitable for application in a variety of industrial fields. Some of the operations that can benefit from NR Electric’s protection and control solutions are the petrochemical, coal, iron, steel, metallurgy and electric railway industries.

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Network Control System (NCS) for Power Plant Station A Network Control System is intended for the control of transmission lines, substations and generators with the capacity of up to 1000MW in a power plant. It provides advanced automatic functionality including safety monitoring of primary devices and real-time monitoring of electric parameters. The system adopts layered distributed architecture to replace the traditional centralized structure, enhancing reliability and easy maintenance.

Distributed Control System (DCS) for Thermal Control A Distributed Control System provides a control process for all types of power plants. It integrates NR Electric's technological advances in power plant and thermal metering to form a comprehensive control platform. It adopts distributed architecture and provides diagnosis in each branch circuit. So far, NR Electric's DCS has been put into service in many power plants with an installed capacity of up to 600MW.

Industrial Automation NR Electric's innovative automation solutions for industrial needs consist of a system automation that is applicable to industrial power systems, and the industrial-class devices. Automation provides fast and real-time control and monitoring of electrical power systems in different industrial fields.

Substation Automation

Protection and Control for Industrial Enterprises

10

NR Electric provides the integrated automation solution for new substations and/or retrofit substations. The solution complies with IEC 61850 standards over double-star LAN or ring LAN. NR Electric has set up its own IEC 61850 Level B Laboratory in which it can test its own products in-house and ensure compliance with IEC 61850 standards. NR Electric’s IEDs have been certified by KEMA for IEC 61850 conformance. NR Electric supplies complete products for substation automation systems, including Bay Control Unit, Protective Relay, Fault Recorder, PMU, Protocol Converter, Gateway, GPS Receiver, Gigabit Switch and HMI Software. NR Electric can also integrate metering and CCTV devices into the automation system.

Power Plant Automation •

Electrical Control System (ECS) for Auxiliary Power System The Electrical Control System is a cost-effective automation system for application in auxiliary power system with a capacity of up to 1000MW in a power plant. It provides high performance control and monitoring for feeders, startup/standby transformers, auxiliary transformers and other intelligent devices.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Digital Substation

Energy Management

The Energy Management System (EMS) and Distribution Management System (DMS) monitor, manage and optimize energy generation, transmission, distribution and consumption in order to help utility or industrial customers to maximize efficiency and minimize cost. It supervises the whole power network and produces the accurate control strategies to accomplishenergy optimization.

Through the development of protection, control, automation and communication technology, NR Electric’s digital substation technologies offer a fully digitalized solution that fully connects the control room to the switchyard with optic fiber links. This proven solution reduces your capital investment, operational and maintenance costs. It also offers unmatched information integration, and provides better reliability and security for substations. Our digital substation includes: •

Electronic/Optical measurement transformer (ECVT/OCT)

Energy Management System

Merging Unit (MU)

Intelligent Circuit Breaker Controller (ICBC)

Network enabled Intelligent Electronic Devices (IED)

NR Electric’s Energy Management S ystem provides versatile interfaces and protocols for RTU or Gateway in substations, such as IEC 61870-5-101, IEC 61870-5-104 and DNP 3.0. Redundant scheme is adopted for server, database and communication systems to improve reliability. It fully complies with the IEC 61970 standard, providing a unified data platform based on Common Information Model (CIM).

The baseline communication topology of NR Electric’s Digital substation Solution consists of a process bus and a station bus. Other communication topologies, such as optical Point-toPoint network, are also supported. The process bus employs

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IEC 61850-9-2 Sampling Value, IEC 61850-8-1 GOOSE for time-critical message and IEEE 1588 protocols. The station bus employs IEC 61850-8-1 MMS, GOOSE message and SNTP protocols. Communications between equipment can be realized by fiber links in the entire substation. This unique and smart solution is suitable for newly constructed and refurbishment substations. The merging units not only support connections to electronic CT/VT and optical CT, but also conventional CT/VT. NR Electric also offers full product series to support the implementation of digital substation solutions, including: •

10kV-800kV Electronic CT/VT and Optical CT for GIS and AIS

Merging Unit supporting conventional and Nonconventional CT/VT

Circuit Breaker Controller executing binary inputs/outputs for Breaker/Isolator/Earth Switch via GOOSE message

Protection and Control complying with IEC 61850-9-2 and GOOSE message

Gigabit Ethernet Switch for process bus and station bus

IEC 61850 Protocol Converter for third-party IED

Clock Receiver providing IRIG-B/SNTP and IEEE 1588 clock signal

Gateway supporting IEC 61850

HMI Software for IEC 61850 substation

NR Electric’s EMS solution provides diverse functions that are tailored to specific project requirements. These include but are not limited to Supervisory Control and Data Acquisition (SCADA), Automatic Generation Control (AGC), versatile Power Application Software (PAS), Dispatcher Training Simulator (DTS), Wide Area Measurement System (WAMS) and TeleMeter Reading (TMR).

Distribution Management System NR Electric's Distribution Management System(DMS) features complete automation of dispatching, distribution, operation and service. Therefore, ensuring the reliable and economical operation of the distribution system. The system complies with IEC61970 and IEC61968 standards.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Power Stability Control

Blackouts can severely impact the flow to modern society in many ways, from economic repercussions to life setbacks. Blackouts can be particularly damaging to enterprises such as hospitals, underground mining operations, gas stations, sewage treatment plants, etc. NR Electric provides the innovative Power Stability Control System (PSCS) to improve power system stability and significantly reduce possible blackouts. This technology differs from other System Protection Schemes (SPS) because the PSCS relies on instability prediction instead of instability measurement. Before installation, the tactic table is predetermined and simulated according to the previous stability studies and strategy analysis. After installation, PSCS acquires all the necessary real-time data from substations or power plants and seeks appropriate remedy actions in the tactic table to pull the power system back to a stable state before it goes into a state ofinstability. Out-of-step controllers and frequency/voltage controllers detect the system’s parameters and take actions to prevent the expansion of instability. Generally a basic requirement for these controllers is that they should not operate during short-circuit

Recording & Measurement

fault, which would be cleared by protective relays. Vice versa, the relay should not operate during system instability;allowing the controllers to take measurements. The after-disturbance analysis is important for discovering potential problems in a power system and help customers enhance the system’s reliability.

Power Stability Control System NR Electric’s Power Stability Control System (PSCS) is used to prevent and reduce the possibility of system oscillations. Imbalance between loads and power generations can result in system frequency and voltage changes that could ultimately lead to system collapse. Power stability control can quickly restore a system’s balance by load shedding or generator shut down based on the preset control tactic. Ultimately, bringing voltage and frequency back to an acceptable value, so as to minimize the affected area and avoid cascading instability. A Power Stability Control System is composed of one master station, several sub-master stations and execution stations. Communications between master station and sub-master stations are implemented by optical fibers.

Disturbance and Fault Recorder (DFR)

Wide Area Measurement (WAMS)

The Disturbance and Fault Recorder (DFR) is a multifunctional data acquisition system designed to address the data recording requirements of transmission or distribution power substations. It captures the curves of monitored quantities and aligns the values of different supervised objects to build disturbance records. DFR helps users to simplify disturbance analysis by combining the discrete records in different protective relays.

NR Electric provides Wide Area Measurement System (WAMS), Phasor Measurement Unit (PMU) and Phasor Data Concentrator (PDC) for the real-time monitoring and visualization to keep track of the state of a power system. Stability estimation and remedial control functions can be integrated into this system.

Disturbance, Fault Management and Recording System (DFMR) To enhance the analysis capabilities, NR Electric provides the DFMR system to manage DFRs in the regional network. It collects the disturbance data of a whole power network and provides real-time monitoring and waveform analysis based on the information collected. Operators in local substations are capable of modifying settings, viewing alarm information and analyzing waveforms. Brief information is available for retrieving upon request. The DFMR system adoptsSDH/SONET or WAN in order to comply with IEC61850, FTP and IEC60870-5-103 standards.

NR Electric ‘s The Phasor Measurement Unit (PMU) relies on a GPS time signaling to provide extremely accurate time-stamping signals of the power system information. The measured vector quantities are sent to the control center to provide a basis for monitoring, protecting and controlling power networks. PMUs are installed in substations and power plants as part of the Wide Area Measurement System (WAMS) and the Power Stability Control System (PSCS). It can improve the system’s economical operation and enhance power stability against any severe disturbances. PMUs installed in different locations are synchronized by a GPS clock. If the GPS source is lost, an internal high-precise clock source is used instead. The Phasor Data Concentrators (PDC) receiveand store synchronized phasor data from PMUs through optical fibers, and send the collected information to WAMS in real-time. NR Electric’s phasor data concentrator allows for the communication with more than eight WAMS stations.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Power Electronics Applications

Power electronic technologies, such as valve banks and thyristor control, are widely used in power systems in the areas of Flexible AC Transmission System (FACTS) and renewable energy interconnection. As a comprehensive solutions provider, NR Electric introduces innovative power electronic technologies for use in power system applications to present true break-through solutions. NR Electric’s technological advances modernize the power electronics industry by optimizing existing and new AC systems, increasing system reliability and availability, improving dynamic system stability both during and after faults and increasing power quality for sensitive industries. The power electronics can increase transfer capacity, reduce losses and maintain a voltage profile under many power system operating conditions.

NR Electric provides innovative power electronic products based on both Current-Sourced-Converter (CSC) and VoltageSourced-Converter (VSC), including: •

Static VarCompensator (SVC)

Static Synchronous Compensator (STATCOM)

De-Icer with SVC function

Fixed Series Compensator (FSC)

Wind energy converter for interconnection

Photovoltaic inverter for interconnection

Static Frequency Converter (SFC)

Generator excitation system

Static Var Compensator (SVC)

The Static Var compensator (SVC) system is an effective way to achieve rapid adjustmentsin grid reactive power and improve power quality. It is widely used in power transmission, HVDC converter station, industrial field and wind farm, supporting reactive power control and realizing transient compensation, dynamic damping and other functions. NR Electric provides the ‘all-in-one’ solution for SVC systems including study, design, supply, installation, training, commissioning and operation. The solution adopts innovative valve technologies, a reliable thyristor triggering method, an efficient cooling system and advanced protection and control system. It has gained extensive marketvalue by supplying dynamic reactive power with fast response time and low-cost maintenance schemes. NR Electric's SVC system features: •

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Vertical and free-floating pressstack structure for the valve. A valve block features: small size, convenient layout, low

costs of infrastructure, simple valve block structure, high reliability and simple installation and maintenance. •

Advanced electro-optical trigger mode employs a highvoltage fiber-optic one-to-one trigger. This technology provides strong anti-interference performance; reliable operation and fast trigger speed.

Patented water-cooling technology with high reliability and high thermal efficiency. This cooling method has been widely used for the locomotive and aerospace industries. It has also been used in one million kilowatts generating units, and high-pressure and UHVDC transmission.

High-performance control and protection system. NR Electric SVC system adopts a high-performance decentralized and distributed structure to facilitate functional expansion and remote maintenance.

Short response time and improved voltage flicker.

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NR Electric Co., Ltd.

Static Synchronous Compensator

High-power rapid impact loads and rapid growth of asymmetrical impact loadscan lead to considerable reactive disturbances inpower systems. Ultimately, affecting power stability, power quality and the economic operation of power grids. Additionally, the overcurrent and overvoltage caused by these disturbances may damage the associated electrical apparatuses.

as flexible AC transmission, renewable energy generation, and industrial field load consumption. It helps both utility and industrial customers gain economical benefits through solving voltage unbalance and distortion problems, restraining system overvoltage, supplying damped oscillations and improving power factor.

Severe weather, such as frozen rain, can create ice coating on transmission lines and steel towers.Leading to damage of the power grid and threatening the safe operation of power systems.Possibly even resulting in blackouts and heavy economic losses. Ice coating on transmission lines, steeltowers, and fittings can lead to mechanical damage.

Maintaining voltage stability and reactive power compensation is crucial. The most advanced solution is using high performance Insulated Gate Bipolar Transistor (IGBT) to provide fast and variable reactive power to the grid. The Static Synchronous Compensator (STATCOM) can be considered as an advanced static Var compensator.

NR Electric’s STATCOM system is composed of control panel, power panels, start panel and series-connected reactors. The control panel contains the PCS-9583 master unit and PCS-9589 trigger control unit. The PCS-9583 adopts innovative UAPC platform with embedded CPU, DSP and high-capacity FPGA design. It uses industry standard high-speed Ethernet and IEC standard data collection as the data transmission link. The power panel uses advanced IGBT for power conversion. The circuit adopts a chain structure and redundant design to meet requirements for continuous and optimal operation.

NR Electric provides the innovative and versatile De-Icer system to help customers solve some of the dangerous problems caused by serious climate. In severe climate situations, the DeIcer serves to melt the ice cover and reduce the risk of tower collapse. In other situations, the De-Icer could be used as SVC to compensate the reactive power in the power grid.

NR Electric provides a Voltage-Sourced Converter (VSC) based STATCOM for reactive power regulation in applications such

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DC De-Icer

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De-Icer adopts thyristor rectifier to convert AC current into DC current. The DC current flows through the line resistance producing heat for de-icing. When de-icing a transmission line, the line should be out of service and the 3-phase conductor should be connected to the De-Icer. At the opposite substation, the 3-phasetransmission line terminalsshould be short-circuited. The DC current is injected into the conductor via Phase Selecting Switches (PSS) in the De-Icer.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Series Compensation

The series compensation (FSC) can improve the transmission capacity of the network and achieve optimal power flow. Ultimately, reducing losses and making full use of power supply at minimum energy cost. Series compensation uses a series of connected capacitive reactors to change line impedance. It can increase the power transfer capability by raising the transient stability limit, improve the voltage profile, and reduce transmission losses. Furthermore, it reduces power transmission costs by using fewer parallel lines and less required shunt compensation.

Renewable Energy Conversion

NR Electric provides a complete set of compensation solutions consisting of a protection and control system,management software, capacitor bank, MOV, spark gap, damping reactor, bypass breaker and insulation platform. NR Electric provides the ‘all-in-one’ solution for series compensation covering design, supply, installation, training and commissioning.

In response to climate change concerns, high fossil fuel prices and increasing government support, utilization of renewable energy sources is critical to the sustainable development of human society. NR Electric values eco-friendly renewable energy and strives to provide innovative and effective solutions for solar power generation projects.

Solar Power Generation NR Electric offers integrated solutions for solar power generation including PV-connection inverters, smart step-up substations, integrated protection control and automation system, reactive power compensation, energy storage management, solar power forecast and a control center for solar farm fleet management. PV Grid-Connection Inverter NR Electric’s self-developed PV grid-connection inverter consists of an advanced multiple-IGBT controlled inverter, protection and control equipment, I/O switchgear, etc. The system power capacity parts consists of several structures, which allow for easy extension, convenient installation and maintenance, optimal layout, and less land occupation.

Wind Power Generation In wind power generation, the output power of wind turbines varies with the wind speed change. To interconnect wind energy into the power grid, adoubly-fed scheme is adopted. NR Electric is capable of providing a converter to over-compensate or under-compensate the power output of wind turbine. Doubly Fed Converter System With the development of converter technology, the control mode has evolved from simplex constant pitch stall control to full blade variable pitch and variable speed control. NR Electric designs the doubly fed converter system with variable speed constant frequency control for wind farms.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Static Frequency Converter

The Static Frequency Converter (SFC) is used for the starting and speed control of large capacity synchronous machines (generator/motor) to improve efficiency and reduce cost. It supplies current with varying frequency to the stator of each motor, which control the motor speed. SFC is suitable for pumped storage power plants, gas turbine power plants and some industrial enterprises. NR Electric provides the advanced SFC products for power plants and industrial customers. The SFC provides variablefrequency current to the stator winding of synchronous machines to produce a varying magnetic flux. The SFC is composed of rectifier, inverter and controller. It can detect the initial position of the rotor without any external sensor.

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Generator Excitation System

Pumped Storage Power Station SFC is used to control the motor startup from 0Hz to 50Hz (or 60Hz) before it enters pump mode. SFC makes the motor switch smoothly without impact on grid operation.

Gas Turbine Power Plant In gas turbine power plants, the SFC system is used to drive the generator unit through purging, warming, firing and acceleration.

The excitation system is an important part of any generator that needs to maintain a steady voltage level and act on power system static and transient conditions.

various specifications based on project needs. The current rating is available from 100A up to 7000A and the voltage rating is available from 100V to 700V.

NR Electric provides a microprocessor-based excitation system to improve generator performance and reduce maintenance costs. It offers the comprehensive control functions for different applications, such as power system stabilizer, optimum control or adaptive control, etc. It can be customized to meet the

NR Electric’s excitation system consists of numerical excitation regulation system, thyristor rectifier, diode valve rectifier, deexcitation equipment and auxiliary cabinets. According to the different requirements of each excitation mode, the equipment can be flexibly tailored to accommodate a variety of needs.

Other Industrial Enterprise SFC system can be used for initial start and speed control in industrial enterprises where synchronous motors with large capacities are widely used.

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NR Electric Co., Ltd.

Flexible DC Transmission

Electronic CT/VT & Optical CT

HVDC power transmission systems may be less expensive and suffer less electrical losses for long-distance transmission. HVDC systems avoid the heavy current requirements of cable capacitance for submarine power cables. Enabling power transmissions between asynchronous AC power grids, and supplying power to urban heavy load centers.

NR Electric has pursued advanced research in electronic CT/VT and optical CT technologies to ensure maximum reliability and availability in the applications of metering and protection relays. NR Electric's ECTs/EVTs have the advantages of no magnetic saturation, no ferromagnetic resonance, large dynamic measuring scope, wide frequency band and compact structure. The solution is suitable for both gas-insulated switchgears, air-insulated switchgears and has been successfully put into service in real substation applications worldwide.

NR Electric is continuously improving its power transmission solutions based on years of practical experience andindustry leading technologies. NR Electric’s HVDC power transmission solution is the gateway to high efficiency, true reliability and flexibility. The outstanding HVDC control and protection solution includes control and protection for classic HVDC transmission through overhead lines or submarine cables, back-to-back HVDC transmission and Voltage-Sourced Converter (VSC) based HVDC transmission.

Electronic CT/VT in GIS/AIS Application NR Electric’s electronic CT/VT can be used to connect 110kV, 220kV, 330kV or 500kV gas insulation switch (GIS) and airinsulated switchgears (AIS) for measuring primary current and voltage. The output signals are sent to digital measurement devices, bay control units and protective relays.

DC Electronic CT/VT NR Electric provides DC electronic CT/VTs for HVDC converter station. It measures DC current, harmonic current, and output digital signals for protection and control devices in the converter station.

Medium and Low Voltage Electronic CT/VT NR Electric’s medium and low voltage electronic CTs/VTs can be installed in 10kV-35kV switchgear cabinets or outdoor cabinets for primary current and voltage measurement. The output signals are delivered to digital measurement devices, by control units and protective relays.

Optical CT Optic CT(OCT) is a passive optical current transducer, which uses light to accurately measure current in high voltage systems. NR Electric’s OCT was designed based on Faraday magneto-optical effect theory and uses special optical fibers as current sensing mediums. Connections between components rely on optical fiber communication, which has advantages of strong anti-vibration capacity and long-term reliability and stability.

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NR Electric Co., Ltd.

LCC-HVDC Transmission

Conventional HVDC transmission technology is used in long distance bulk power transmission through overhead lines or submarine cables. It is also used in asynchronous interconnection to AC networks. NR Electric’s solution to conventional HVDC transmission focuses on the control and protection system. The control and protection system is the key to the overall performance of the HVDC transmission system. It guarantees a safe and steady system operation, provides flexible operating modes and accurate control effects. Furthermore, it helps to clear faults and assist in system recovery during system disturbances. A well-designed control and protection system can maximize the productivity of HVDC transmission technology in the following aspects:

VSC-HVDC Transmission

Long distance bulk power transmission

Underground or underwater cable transmission

Asynchronous interconnection of AC system

The PCS-9550 control and protection system is designed based on very powerful and flexible building blocks built with a stateof-art UAPC platform and connected by high performance fiber optic communication links. It brings the biggest convenience to new and retrofit HVDC transmission projects. The design criterion for the control system is to reach 100% availability for the transmission system. The NR Electric's HVDC control and protection system is equipped with parallel redundancy at all levels. All system parts that are involved in the power transfer of the HVDC link are made redundant.

The VSC-based HVDC transmission system is state-ofart technology. This system is based on novel switching-off semiconductor technology such as IGBT, this aids in achieving high efficient power transmissions and supplying a dynamic reactive power to an interconnected HVAC power grid. As one of the key technologies in smart grid construction, the VSCbased HVDC transmission has many advantages such as: fast response, stability control, flexible operation modes, strong antiinterference capabilities and improvements on the low voltage ride through capabilities.. In comparison with traditional HVDC transmission, this new technology can reduce a system’s short circuit current and supply power to a passive power grid. It is an effective way to prevent large area blackouts and deliver power to offshore platforms or electrical islands. The VSC-based HVDC transmission can be connected to an asynchronous grid, providing grid access to wind farms and supporting the establishment of a city’s distribution power grid.

AC Yard Equipment

The turnkey services consist of consulting, designing, supplying, procuring, testing, installing, commissioning, maintaining and training for consumer.. The converter valve is the cornerstone of the VSC-HVDC station. The capacitor and IGBT-based switching devices are key components of a sub-module. Each valve phase bridge is composed of several sub-modules and a series of connected reactors. By setting the quantity of sub-modules, the converter’s output voltage and power levels are flexible to manage. Making it easy to extend the output levels with low harmonic distortion and low switching frequency, so as to reduce operational losses and improve system efficiency.

The NR Electric PCS-9520 for the VSC-HVDC transmission system provides many advantages. Among these are low switching frequency, small running loss, easily extensible, stable and with a long life cycle. It is suitable for many applications such as:

Renewable energy grid-connection

Island and offshore platform power supply

City DC transmission and distribution grid

Asynchronous power grid interconnection

Multi-terminal DC power transmission grid

NR Electric company undertakes turnkey projects for VSCHVDC transmission utilizing our own innovative products and third party qualified products. The equipment supplied includes:

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VSC Valve

Electronic CT/VT

Control & Protection

Power Transformer

Phase-Bridge Reactor

Insertion Resistor

DC Yard Equipment

The control and protection system is the brain of the VSCHVDC transmission system. It monitors, controls and protects all equipment in the VSC-HVDC transmission system and converter station. The switching of IGBT valves depends on the pulse-width modulation (PWM) pattern. PCS-9520 control and protection system adopts a distributed structure. It consists of flexible HVDC control and protection units, distributed I / O units for the field device and fiber optical field bus, which connects the master unit to I / O devices. The control and protection system includes state-of-the-art computers, micro-controllers and digital signal processors. Each VSC-HVDC project has two independent control and protection systems for redundancy to ensure high reliability. Multiple

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NR Electric Co., Ltd.

DC Measurement Devices

NR Electric provides DC electronic CT, VT and filter imbalance ECT for both conventional and VSC-HVDC transmission projects. The DC electronic transformers have the advantages of small size, light-weight and no ferromagnetic resonance problems.

DC Filter Imbalance Electronic CT The DC filter imbalance electronic CT uses the low power CT (LPCT) to convert primary current to digital signals. It is composed of LPCTs, remote-end modules, fiber optic insulators and merging units.

DC Electronic CT/VT The DC electronic CT/VT is used in the HVDC converter station to convert the DC current/voltage and transmit the signals to control and protect devices. So far, the DC electronic CT/VT has been used in ± 800kV and ± 500kV HVDC converter stations.

transient fault recording (TFR) functions are for fault tracing in the control and protection system. The recording settings are flexible to accommodate the consumer’s requirements. Therefore, it provides complete a picture of the dynamic performance of the converter.

Features

NR Electric PCS-9520 VSC-HVDC Control and Protection system incorporates highly reliable hardware and software. The NR Electric PCS-9520 VSC-HVDC system features the following components::

Multilevel technology with low switching frequency and low operating losses

Low voltage ride-through capability

Capability for application in high voltage and large capacity engineering projects

flexibility for investments and construction in phase

Less harmonic components and less land resource occupation

Independent, fast and continuous adjustment of active and reactive power

Improving AC power angle stability

Embedded Systems

No operating system in real time applications

Overall enclosed design without fan

Advanced system monitoring and fast switching

Reliable configuration for protection

Dedicated high-speed data bus

Independent control of reactive power and active power

Overall dependable design

System electromagnetic shielding with high immunity

Provides power to passive power networks without commutating failure

Well black start capability

Fast current reverse capability without need for stations communications

Easy to form a multi-terminal HVDC power system

Capable of providing dynamic reactive power for AC power grid.

In a VSC converter station, electromagnetic interference can seriously affect measurement accuracy. NR Electric’s provides high performance DC electronic CT/VT to solve this problem.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Digital Substation

Now days, with the increasingly rapid development of new technologies, people are no longer satisfied with the current micro-computerization of protection devices. This in turn has led to the development of digital substations. Modern digital substations are designed to comply with IEC-61850 standard. New advances in technology have ushered in an era of work digitalization in which it is possible to transfer heavy physical labor for completion to computer systems. Construction of digital substations based on model configuration makes the interoperations between devices easier and more flexible. Digital substations comprised of intelligent primary devices and secondary networking devices, based on IEC-61850 protocols aim at facilitating information sharing and interoperations. In comparison to conventional substations, the new communication interfaces and communication protocols have changed at the bay level and the station level. However, the major difference between the two is the process bus of the digital substation. Traditional CT/VT, primary devices, and conventional cable wiring are substituted with intelligent primary devices, merging units and optic fiber connections.

TECHNOLOGY Chapter 3

INNOVATION

Digital substations introduce the GOOSE scheme, which replaces traditional binary inputs and binary outputs with new digital models. All of the digital BI and BO are configurable and can be delivered to the Ethernet switch via one optic fiber. This process significantly reduces the amount of cable wiring in a modern substation. The use of Sampled Value (SV) makes the current/voltage sampling at primary side easier and more reliable. The voltage and current signals are captured at the primary side, converted to optic signals and transferred to the protection and control devices via optic fibers. This can lower the requirements of the transformer insulation and reduce the interference experienced in analog signal transmissions. The digital substation uses innovative Ethernet technology to share information at the process bus and station level. Currently, NR Electric's digital substation solution can be classified into 3 modes. IEC61850 adopted at IEC61850 adopted at Electronic CT/VT are station level process bus used

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Scheme 1

Scheme 2

Scheme 3

Scheme 1: Digital substations with IEC-61850 in station level The configuration of the substation automation system described in Scheme 1 is similar to the conventional substation automation system (SAS). The Intelligent Electronic Device (IED) can be installed in the bay level and communicate with station level using the IEC-61850 protocol. This mode can solve the intercommunication and information interoperation problems between IEDs and traditional substations. Since the communication and the functions of IEDs are restricted by IEC-61850 standard, the information transmission between each node is standardized; this improves the maintainability and extensibility of the entire system. The interlocking GOOSE signals and the cooperating signals between relays can be realized by the network in station level as well.

Scheme 2: Digital substations with traditional transformer and GOOSE information exchange in process bus In comparison to Scheme 1, Scheme 2 introduces the independent process bus and adopts the IEC-61850 protocol for information exchange at the station level. Intelligent control units are used in the process bus for each bay allowing for communication between IEDs via optic Ethernet network. IEDs may be installed anywhere in the substation according to the project requirements. Large amounts of copper wiring between IEDs and primary devices in conventional substations are replaced with optical fibers.

Scheme 3: Digital substations based on the full information exchange in station level and process bus In Scheme 3, electronic CT/VTs are used instead of conventional CT/VT. Electronic CT/VTs include active CT/ VT, passive CT/VT and built-in GIS. The voltage and current signals are captured at the primary side, converted into optic signals and transferred to the protection and control devices via optic fibers. This can lower the requirement of transformer insulation and reduce the interference suffered in analog signal transmission. So far, electronic CT/VT is widely used in many 220kV and 110kV digital substations in China.

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NR Electric Co., Ltd.

Recommended Networking Scheme

Features of SV network

The operation of a digital substation relies on a reasonable communication frame. Communications in and between process bus, bay level and station level are accomplished by a high speed Ethernet network. The entire communication network includes:

• •

• •

Station level communication network between bay level and station level Process bus communication network between bay level and process bus

The communication protocols at the station level network, the process bus GOOSE network and analog sampling SV networks are independent and are assigned to serve in different tasks. Features of MMS network data in station level • • •

Strong abruptness Massive volumes of data Low requirements on real-time transmission

MMS network is the communication bridge between SCADA, dispatching centers and IEDs at bay level. The interlocking GOOSE is also implemented in this layer. The Ethernet switch serves to process messages, sorting and delivering them between IEDs according to priority. Features of GOOSE network data in process bus • • • •

Small volumes of data Certain level of abruptness High requirements on transmission reliability and real-time performance GOOSE network in process bus can be configured together with SV network or independently

Renewable Energy Interconnection

Highly reliable volumes of data Real-time, stable and reliable data transmission

NR Electric’s PCS series protection and control devices are fully compliant with IEC-61850 protocol and can be directly connected to SCADA, Gateway and Protection Management Units. The perfect IEC-61850 engineering configuration tools can generate SCL files, which can be used for data and information exchange between a diversity of engineering tools from third party manufacturers. NR Electric has developed the digital substation networking schemes to address diverse customer requirements. The MMS network is configured independently, GOOSE and SV are combined to form the network. Some of the advantages of this scheme are the excellent communication quality and the simple network structure. The SV network and the GOOSE network are configured to work together in order to increase efficiency. The SV represents large and stable data flow, while the GOOSE typifies small bursts of data.

NR Electric values environmentally friendly and renewable energy projects. NR Electric is committed to the protection of the environment. Our integrated renewable energy offerings include major solar farm equipment and systems such as photovoltaic inverters, wind energy converters, SVC/STATCOM, protection, automation, SCADA, and renewable generation management systems. The strength of NR Electric’s solar solution is based on our deep knowledge of electrical grids and over twenty years of experience as a key power system solutions provider. Our technologies, unique patents and know-how are at the heart of our solutions.

NR Electric’s full portfolio of products and expertise enable us to provide “All-In-One” turnkey services. We serve our customers during the entire lifecycle of the solution and our services include consulting, designing, manufacturing, installation, commissioning, training and maintenance support services. NR Electric believes quality products and services are essential. We implement stringent quality control processes through our procurement, manufacturing, configuration, delivery and customer care services. Every step of the process is performed by our professional technicians, verified by our testing engineers and monitored by our quality control managers. Our quality control processes are governed and certified by the international ISO program. NR Electric’s products and solutions quality are unsurmounted in the industry.

The GOOSE network and SV network can form different networks according to the voltage levels. For example, the PCS-978 transformer protection device, can provide optional modules to support the independent process bus networks with different voltage levels. This configuration scheme can simplify the network design, ease commissioning and optimize the reports. Each MMS, GOOSE and SV boards in PCS series devices is equipped with two mega bytes fiber optical Ethernet ports to support double network structure.

Figure 1. Overview of NR Electric PV Power Solution

Figure 2. Overview of NR Electric Wind Power Solution

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The main products of NR Electric renewable energy generation solution include: • Wind power converter PCS-9561 •

Energy Storage Converter PCS-9562

PV Grid-connected Inverter PCS-9563

SVC/STATCOM PCS-9580,PCS-9583

VSC-HVDC PCS-9520

Renewable Energy Power Forecast System PCS-9700F

Renewable Energy Management System PCS-9700

Monitoring and Control Unit PCS-9721

PMU PCS-996

Stability Control Device PCS-992/993/994

NR Electric is an independent innovator in renewable energy technology and a leader in power system protection & control. NR Electric offers integrated solutions for PV inverters, wind power converter, substation monitoring and power prediction, renewable power stations, centralized monitoring and control. With the rich experience gained from years in grid safety and stability control, NR Electric’s products and services feature superb performance, low cost, safety and reliability. NR Electric will fully protect your renewable energy station and make your renewable energy system as effective as possible.

NR Electric Co., Ltd.

PV Grid-Connection Inverter/ Wind Power Converter The PV grid-connection inverter and wind power converter consist of advanced IGBT controlled inverters, protection & control equipment, I/O switchgear, etc. The system power capacity portion was designed in a modularized structure featuring easy extension, convenient installation and maintenance, optimal layout, and less land occupation. The system control portion is based on the professional control and protection platform, it features abundant hardware resources, complete software functions, and flexible configuration for control/operation parameters. The control portion was designed to meet the extension demands and the system’s flexibility and extensibility.

Reactive Power Compensation The renewable energy power station Var compensation solution is implemented by Static Var compensator (SVC) and Static Synchronous Compensator (STATCOM). SVC/STATCOM serves as a Var source and it can supply reactive power to the grid or absorb the excessive reactive power from the grid.

Renewable Energy Power Forecast The renewable energy power prediction system is used to predict the output power of renewable energy power station in an upcoming period. The system computes reliable prediction based on highly accurate numerical weather prediction (NWP), with acquired site monitoring data, environment data and historical statistical data through the process of physical model and artificial neural network (ANN) model.

Smart Step-Up Substation The digital step-up substation consists of intelligent primary equipment and network-based secondary equipment in layers based on IEC 61850 standards. In this scheme, information sharing and interoperability can be realized among the intelligent equipment. Compared with traditional step-up substations, the digital one has the following changes: The equipment and network interfaces in the substation/bay control layer have changed only in the interface and communication models. However, great changes have taken place in the process layer. These changes include the traditional CT/VT, cable connection among primary equipment and between the primary equipment and the secondary equipment have been replaced by ECT/EVT, intelligent primary equipment, merging unit, FC, etc. The process level within the substation is provided with optical double star networks, which are independent from the stepup substation CSCS network. An advanced network sharing technique is adopted for process level GOOSE and digital sampling SMV issuing message. It simplifies network equipment while assuring system reliability and security.

Integrated Automation System The renewable energy power station solution is based on PCS9700 CSCS and takes into account the characteristics of PV or wind energy power stations. The system can perform realtime monitoring and control on the PV solar array, DC current convergent cubicle, DC distribution cabinet, grid-connected inverter, wind energy converter, step-up substation, and environmental monitoring system. It is designed with rich user interfaces, strong analysis and processing functions as well as complete monitoring alarm mechanisms.

Centralized Control Center More and more renewable energy power stations are built and put into service. Accordingly, when the need to centralize monitoring and control the operation of PV power stations arises, the task can be accomplished by acquiring data and performing storage, display, analysis and statistics. Centralized

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monitoring and control ensure that real time conditions of running equipments, power generation and running level of the renewable energy station are understood and used as reference for future construction, design, equipment selection and economical operation of PV power stations.

Phasor Measurement Unit (PMU) To improve the dynamic monitoring and analysis of a power system, a synchronous phasor measurement equipment is installed in the key PV power station to establish the real-time dynamic monitoring of the power system after the PV power station is connected to the grid. The system will become one of the major data sources in the dynamic real-time data platform for the power system dispatching center. In addition, it will be gradually combined with EMS and the security automatic control system to strengthen the supervisory control over the power system dynamic security and stability. Improving the dispatching center’s capacity for understanding system running conditions, and facilitating the study of the dynamic process in large grids. Ultimately, offering references for control strategy, design, running, and scheme planning of power systems.

Power Stability Control System Solar power, a renewable clean energy, has drawn more and more attention in recent years. The PV power generation is faced with the need for large scale infrastructure construction and grid-connection. The impact of PV power on the grid cannot be fully taken into account until the PV power accounts for a significant percentage in the grid. The PV output is closely related to the amount of sunlight. The intermittent output and single-peak curve results in complex load flow distribution and voltage characteristics as well as big effect on transient stability. If a system has severe faults, it may result in disastrous consequences. Therefore, a security and stability control system is necessary for a grid with large scale PV power.

VSC-HVDC Transmission VSC-HVDC is state-of-the-art technology in power electronics around the world. It has strong technical advantages in power system stability, dynamic Var storage, power quality, non-linear loading, effect of impulse load on system, sensitive equipment power supply security, etc. Due to its technical characteristics, VSC-HVDC is applicable to renewable energy grid-connection, distributed power stations grid-connection and island power supply. It has more obvious advantages in wind power gridconnection, offshore platform power supply and power supply for grids in metropolitan areas. It is undoubtedly useful in grid connection for PV power stations.

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NR Electric Co., Ltd.

Protection Management System

The Protection Management System is a data support platform to realize the realtime monitoring and management of protection devices in a certain region. When abnormal situations or fault trips occur, the protection management system can rapidly response to fault alarms and event information and collect protection wave records. NR Electric's PCS-9010 protection management system can operate under abnormal conditions, acquiring and processing all kinds of secondary device information for the control and management of protection devices. The Protection Management System provides users with fast fault clearance schemes and optimized system operation strategy. The use of protection management system can avoid the spread of fault and reduce power losses caused by fault. The protection management system also provides a power grid failure information support, auxiliary analysis and decisionmaking. Utilizing the protection management system can improve system stability and enhance the management of all secondary devices.

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Functions •

Model maintenance, graphics import

Front –end

Communication monitoring

Alarm monitoring

Settings enquiry and comparison

System fault report

Wave record file call and analysis

Historical alarm event

Web publication

Data statistics

Report management

Running environment monitoring

Authority management

Fully Complied with IEC 61850

Industrial Energy Management

As of today, energy shortage and environmental deterioration are some of the biggest problems facing the world. These problems, largely byproducts of human development, require both individuals and companies to bear the social and environmental responsibilities. Furthermore, we should adopt strong measures to lower energy consumption. NR Electric’s PCS-9000 Energy Management System (EMS) can comprehensively consider the generation, transmission, and consumption of various energy fuels during the production process. It provides an integrated platform for monitoring energy usage and allows clients to control the dispatching, production, analysis, and energy information management. And it provides an effective method for companies to save energy and optimize resource dispatching. The system achieves: •

Scattered data acquisition and control of the energy system;

Optimization of energy dispatching and centralized management of energy supply and demand balance;

Real-time forecasting and analysis of energy as needed

Onsite training simulation and basic energy management for dispatchers

Lower Energy Consumption

Improve efficiency and safety of the energy system

The PCS-9000 EMS Data Flow Diagram is as follows: •

High-performance, cross/hybrid platform, and a distributed operational system --

Self-developed software system. The EMS is an open and unified platform, which complies with international and industrial standards.

--

Transplantable system, which supports various hardware platforms, operating systems.

--

Distributed architecture with a master node and several standby nodes.

--

High capacity architecture design for the real-time database. The system’s acquisition data capacity can reach 0.5 million. These features have been tested by third party authorities.

--

High-efficiency real-time history database, which supports data reading, writing and SQL query operation.

--

Easy maintenance and reliable operation without interruption.

--

High availability and high performance in real-time.

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Plug-in protocol and online expansion --

Supports various protocols such as DNP, IEC101, IEC102, IEC103, IEC104, CDT, MODBUS, OPC, etc; and the online expansion of protocols.

--

Multiple connections for collecting data with each channel operating independently.

--

Multithreading technology allows for summarization and distribution of multi-professional data.

Optimized dispatching of combined supervision, forecast and fault emergency linkage --

Supports real-time data acquisition and electric energy measurement

--

Online forecast and analysis

--

Both auto-generation and management of emergency scheme in the event of fault, offering reference for dispatchers to use.

--

Full-scale fault recalling function, which can reproduce fault scenarios.

--

Multi-responsibility management area and authority management.

--

Optimal generation planning.

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Onsite dispatcher training simulation --

Power Dispatcher Training Simulation on 3D panorama.

--

Process simulation of production, transmission and consumption of water, and gas production systems

Balanced and complex energy circulation use --

Real-time online energy balance, generation and display of automatic analysis data for energy consumption.

--

Utilization of historic records to assist in drawing up production plans

--

Management of dispatching and operation.

--

Optimization analysis of production link, providing a planning guide.

Flexible AC Transmission System

FACTS (Flexible Alternating Current Transmission Systems) is a well-known term for higher controllability in power systems by means of power electronic devices. Its basic applications are related to power flow control, increase transmission capacity, voltage control, reactive power compensation, power conditioning, and interconnection of renewable and distributed generation. These applications are achieved by FACTS through switched or controlled shunt compensation, series compensation or phase shift control. The FACTS solution is used to avoid cost intensive or landscape requiring extensions of power systems, for example upgrades of substations and power lines. With FACTS, power providers will be able to better utilize their existing transmission networks, substantially increase the availability and reliability

of their line networks, and improve both dynamic and transient network stability. So FACTS technology can be employed at comparatively little expense over short and medium term, to minimize the bottlenecks and substantially improve the availability, reliability, stability and quality of power supply. As a world-class supplier in the power transmission and distribution industry, NR Electric has developed a number of modern, flexible, high-capacity FACTS for efficiently and reliably regulating voltage, impedance, and phase angle when transmitting power over high-voltage lines. NR Electric offers many FACTS solutions, like static Var compensator (SVC), static synchronous compensator(STATCOM), series compensation (SC), and direct current de-Icer (DC-Deicer).

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Flexible DC Transmission

A high-voltage direct current (HVDC) electric power transmission system uses direct current for the bulk transmission of electrical power. For long-distance transmission, HVDC systems may be less expensive and suffer lower electrical losses. For underwater power cables, HVDC avoids the heavy currents required to charge and discharge the cable capacitance in each cycle. HVDC allows power transmission between unsynchronized AC transmission systems. Since the power flow through an HVDC link can be controlled independent from the phase angle between source and load, it can stabilize a network against disturbances due to rapid changes in power. HVDC also allows transfer of power between grid systems running at different frequencies, such as 50 Hz and 60 Hz. This improves the stability and economy of each grid, by allowing exchange of power between incompatible networks. Most of the HVDC systems in operation today are based on linecommutated converters. The basic line commutated converter (LCC) configuration uses a three-phase bridge rectifier , each connecting one of the three phases to one of the two DC rails. A complete switching element is usually referred to as a valve, irrespective of its construction. Each thyristor valve typically contains tens or hundreds of thyristor levels, each operating at a different potential with respect to earth. In a line-commutated converter, the DC current flows in one direction. It flows through a large inductor and can be considered almost a constant flow. On the AC side, the converter behaves as a current source, injecting both gridfrequency and harmonic currents into the AC network. For this reason, a line commutated converter for HVDC is also considered as a current-source converter. NR Electric has undertaken nearly twenty HVDC projects in total while utilizing the UAPC platform.

Because thyristors can only be turned on by control action, the control system only has one degree of freedom. This is a substantial limitation in some circumstances. In contrast, some types of semiconductor devices, such as the insulated-gate bipolar transistor (IGBT), can both turn-on and turn-off providing a second degree of freedom. As a result, they can be used to make self-commutated converters. In such converters, the polarity of DC voltage is usually fixed, and the DC voltage which is smoothed by a large capacitance can be considered constant. For this reason, an HVDC converter using IGBTs is usually referred to as a voltage sourced converter. The additional control gives many advantages, notably the ability to switch the IGBTs on and off many times per cycle in order to improve the harmonic performance. Being self-commutated, the converter no longer relies on synchronous machines in the AC system for its operation. A voltage sourced converter (VSC) can therefore feed power to an AC network consisting only of passive loads, which is impossible with LCC HVDC.

ENGINEERING Chapter 4

SERVICE, DESIGN & TRAINING

Today most new VSC-HVDC systems are being built with some form of multi-level converter. Most commonly the Modular Multi-Level Converter (MMC) in which each valve consists of a number of independent converter sub-modules, each containing its own storage capacitor. NR Electric’s HVDC SuperCon technology also uses MMC topology for grid interconnection and renewable energy generation. So far, NR Electric has provided the HVDC SuperCon based on IGBT semiconductor for three projects, and one of them is the five multi-terminal HVDC transmission project.

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NR Electric Co., Ltd.

Engineering Service

NR Electric’s full portfolio of products enables us to provide “All-In-One” turnkey services that cover the entire lifecycle of the solution. We value comprehensive services, long-term warranty and long-lasting spare part supply for our customers. Experienced engineers and experts from NR Electric deliver services such as consulting, study analysis, design, installation, configuration, integration, verification, commissioning, operation, troubleshooting, training and maintenance services for our global customers.

Field Testing and Commissioning NR Electric's regional engineering teams are always working in close cooperation with users to reduce commissioning time and cost. These services enable customers to work with our factory-trained technician staff on-site to support testing and commissioning efforts and provide hands-on training for your personnel. •

Power stability study

Data migration from legacy systems

On-site commissioning

Solution and product customization to meet the needs of customer-specific requirements

Software maintenance

Relay Scheme and Setting Calculation Based on the deep understanding of each specific project, NR Electric provides relay scheme design from the conceptual phase to the execution. A series of professional software is used to implement system analytical study in order to optimize relay schemes and calculate relay settings.

Fault Tracing and Analysis

Spare Parts Supply and Warranty

NR Electric assigns experienced engineers to assist customers to trace and analyze fault data. The fault causes can be determined in short period and analyzed in detail. The analysis results can help to improve the protection performance.

NR Electric provides 15 years’ spare parts supply and longterm product warranty from date of shipment as per customer's requirement. The product warranty coverage includes relays, control devices, channel devices and accessories, automation systems, fiber optic communication systems and special protection systems for power stability control.

NR Electric has set up independent project management teams consistent with PMBOK (Project Management Body of Knowledge) standards based on matrix work organization. The project management optimizes the work coordination and facilitates smooth project-delivery.Our oversea subsidiaries and Technical Service Centers (TSC) enable NR Electric to provide effective and efficient services for local customers.

Closed-loop Digital System Testing NR Electric utilizes real time simulators (RTDs) lab to simulate the real power grid according to each project. The protection coordination and the relay settings are validated by the closedloop test between RTDs and the protection equipment.

Dynamic Physical Model Testing

Consulting Service NR Electric's experienced engineering service teams provide a wealth of telecom consulting and on-site commissioning for customers all over the world. Their abundant on-site experienceand expert skills help users solve any emergencies and potential problems. The dedicated service group offers a wide range of professional consulting services, including:

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To guarantee and enhance the safe operation of our products, NR Electric has built a world-class precise analogue lab with small-size electric power apparatus, including generators, transformers, motors and distributed transmission lines. These physical models have the same dynamic characteristics as the on-site equipment, such as the transformer, can be used to simulate the inrush current and saturation case.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Engineering Training

Engineering Design

NR Electric’s professional engineering design teams have a deep understanding of power systems. We believe that an elaborate system design is the foundation of a successful project. We strive to create customized solutions that help users recognize system weakness, thus avoiding potential problems and achieving maximum economic benefits. Engineering design includes: •

Transmission and Distribution secondary system planning

System analysis and design for power electronics (SVC, STATCOM, FSC and PV)

Secondary system planning for generating stations in power plants

System analysis and design for VSC-HVDC transmission

systems. NR Electric's expert engineers are involved in the system studies of system structure, power flows, generation and consumption, etc. By analyzingdiverse disciplines NR Electric’s engineers are able to draw up the offline tactic table for power stability control.

Advanced Training Center NR Electric has founded a training center with samples of all products to provide professional training for domestic and oversea customers. At our advanced training center, we study the needs of clients in the field of protection and automation system, and develop the training program to meet their requirements. We offer regularly scheduled classes containing theoretical courses and hands-on interaction using relays & meters, relay test tools, automation software, communication equipment and personal computers. Every year over 2000 electrical engineers are trained in NR Electric training center.

project

System Analysis NR Electric’s engineers participate in system analysis basing their decisions on the deep understanding of thecustomers' requirements. This awareness enables engineers toanalyze detailed system scenarios for each specific case and allows them to customize system solutions to fit the customers' demands. NR Electric's system analysis services include fault analysis, power flow calculation, stability analysis, reliability analysis, Var compensation analysis, etc. Our engineering and design teams perform system studies, such as system settings calculation, complete design and drawing packages. The unique system study and design of power quality focus on stabilizing weak systems and improving dynamic voltage control in industrial

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Theory plus Hands-On Exercise Solid theory knowledge and hand-on skills are both important to electrical engineers. NR Electric’s training program not only addresses the theory, we also ensure each trainee has sufficient hands-on time with the equipment. Trainees receive theoretical course manuals and detailed lab exercise guidelines to ensure they can utilize this knowledge in their workplace. Our training center has set up several hands-on training labs with various equipment and panels. Testing tools such as Omicron and HMI software are provided to perform the static electrical test for further understanding. Trainees can manipulate and test the protection and automation devices in laboratories to gain operating experiences.

Panel Design NR Electric provides unique panel design for each specific project. The panel design includes the design of internal structures considering dissipation problems based on customers' requirements, wiring between each device and terminal distributions inside the panel. A well-designed panel can facilitate the on-site installation, future commissioning and maintenance of the project.

Experienced Instructors The key to the success of the training program is qualified and expert instructors. At NR Electric’s training center, a group of well trained instructors with years of practical experience in the protection field is dedicated to bringing high quality technical topics in different languages, including English, Russian, French and Spanish.

Customized Trainings System Integration With the experiences gained from many turn key projects, NR Electric provides complete system integration services for turn key projects. Among these services are integrated secondary systems for substations or power plant, power electronics applications such like SVC, STATCOM, SFC and DC de-Icer, and VSC-HVDC transmission. In a turnkey project, NR Electric offers complete system solutions based on deep system analysis and implements these solutions by integrating high quality products and third party devices.

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To keep up with the pace of rapid developing technology and product innovation, NR Electric is committed to providing customers with numerous and comprehensive training courses throughout the year as well as on-demand training. The training is a combination of tutoring, factory training and "on-the-job" training, including fundamental knowledge of power systems, and introduction to Integrated Secondary System (ISS), Power Electronics Applications (PEA) and HVDC power transmission.

A range of training courses can be customized for clients in accordance with their requirements. The training courses are closely follow clients’ actual demands to raise clients’ technological level to the largest extent in a short period of time.

On-site Training To maximize customers' benefits from our training, NR Electric offers the option of conducting training courses at a consumer’s facility. These on-site courses can be tailored based on specific engineering projects and requirements. All the necessary testers and literature will be provided on-site for operational practice.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Transmission Line Protection

PCS-902 Line Distance Protection The PCS-902 provides comprehensive protection and control solutions for transmission lines with high-speed sub-cycle distance element. The PCS-902 is intended for application on overhead lines and underground cables with diverse voltage levels.

PCS-931 Line Current Differential Protection The PCS-931 relay provides full-scheme current differential and distance protection solutions for transmission lines with high-speed sub-cycle distance element. As well, the pilot scheme of distance protection and earth fault protection are integrated to provide a complete protection solution for the transmission line.

PCS-924 T-zone Current Differential Protection

INTEGRATED Chapter 5

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The PCS-924 is designed to provide current differential protection, sum-of-current protection and feeder end fault protection for the T-zone. It provides three groups of CT input for direct connections to three terminal CTs.

SECONDEARY SYSTEM

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Function Index Function

Functional Code

PCS-902

PCS-931

Phase-segregated DPFC differential protection

87D

Phase-segregated current differential protection

87P

Neutral current differential protection

87N

Pilot scheme of phase-to-phase distance protection (one independent zone)

85/21P

Pilot scheme of phase-to-ground distance protection (one independent zone)

85/21G

Pilot scheme of directional earth fault protection

DEF

High-speed DPFC distance protection

21D

Five zone phase-to-phase distance protection

21P

Five zone phase-to-ground distance protection

21G

Four stage phase overcurrent protection

67P, 50/51P

Four stage neutral overcurrent protection

67N, 50/51N

50BF

Breaker failure protection for single-/dual- breaker T-zone current differential protection (3-terminal/2-terminal)

87S

Stub overcurrent protection

50S

Sum overcurrent protection

50P SUM

Two stage undervoltge protection Two stage overvoltage protection Four stage underfrequency protection Four stage overfrequency protection

27

PCS-902

Line Distance Protection

√ √

59

81U

√ √

81O

Phase overcurrent protection during VT failure

51P VT

Neutral overcurrent protection during VT failure

51N VT

Switch-onto-fault logic

PCS-924

SOTF

Power swing blocking logic

68

Broken conduct protection

46BC

Dead zone protection

50DZ

Thermal overload protection

49

Pole discrepancy protection

62PD

79

Voltage and current drift auto adjustment

Frequency tracking

Voltage control element for overcurrent protection

Directional element for overcurrent protection

IDMT characteristic for overcurrent

CT failure supervision

VT failure supervision

Fault locator

Programmable logic

Single-/dual- pilot channels complying C37.94 & G.703

Up to four Ethernet ports using IEC 61850, DNP 3.0 or IEC 60870-5103 over TCP/IP

Up to two serial ports using IEC 60870-5-103

Optional sampling Value & GOOSE module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

1/3 pole auto-reclosing for single-/dual- breaker Remote/local control Synchronization check

25

The PCS-902 provides comprehensive protection and control solutions for transmission lines with high-speed sub-cycle distance element. The PCS-902 is intended for application on overhead lines and underground cables with diverse voltage levels. These include series compensated, doublecircuit, heavily loaded, weak in feed (WI), short and long lines. It can meet the requirements of single-pole or threepole tripping; it also provides single and/or three-pole autoreclosing functions. The PCS-902 is suitable for single and dualbreaker applications, providing optional dual CT inputs, dual breaker failure protections, dual breaker auto-reclosing and dual synchro-checks. Additionally, the relay integrates the remote/ local control of circuit breaker, disconnector and earth switch. The PCS-902 employs a wide range of innovative patented technologies, such as DPFC (Deviation Power Frequency Component) distance protection and unique power swing blocking logic. Thus, guaranteeing accurate and reliable operations. The PCS-902 is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is provided for testing and setting, allowing for

Functions Protection and Control •

smoother commissioning and maintenance.

Five zone phase-to-phase distance protection (21P) Directional, load encroachment, power swing blocking and unique low-voltage elements are provided for phase-tophase distance protection. One zone phase-to-phase distance protection for pilot scheme (85/21P) The relay provides an independent zone for pilot scheme of PUTT, POTT, Blocking, Unblocking, DTT & Zone Extension. The scheme integrates current reversal logic, weak-infeed echo and open breaker echo.

Fault recorder GPS clock synchronization (IRIG-B, SNTP, PPS, PPM) Configurable I/O and LED

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Five zone phase-to-ground distance protection (21G) The reactance characteristic, directional, load encroachment, power swing blocking and unique lowvoltage elements are provided for phase-to-ground distance protection.

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NR Electric Co., Ltd.

One zone phase-to-ground distance protection for pilot scheme (85/21G) The relay provides an independent zone for pilot scheme of PUTT, POTT, Blocking, Unblocking, DTT & Zone Extension. The scheme integrates current reversal logic, weak-infeed echo and open breaker echo. High-speed DPFC distance protection (21D) Innovative Deviation of Power Frequency Component (DPFC) distance protection quickly clears faults in a subcycle. DPFC is immune to the load fluctuation, weak-infeed and power swing. Pilot scheme of directional earth-fault protection (DEF) The relay includes directional zero sequence comparison element for earth faults. The pilot scheme integrates current reversal logic, weak-infeed echo and open breaker echo. Four stage phase overcurrent protection (67P, 50/51P) Selectable time characteristics (definite-time or inversetime) and directional elements (forward, reverse or nondirectional) are provided. A harmonic blocking function is integrated to restrain each stage independently. Four stage neutral overcurrent protection (67N, 50/51N) Selectable time characteristics (definite-time or inversetime) and directional elements (forward, reverse or nondirectional) are provided. A harmonic blocking function is integrated to restrain each stage independently. Breaker failure protection for one or two breakers (50BF) Breaker failure protection can be applied to single-breaker and dual-breaker applications.

NR Electric Co., Ltd.

Unique power swing blocking logic (68) The power swing blocking logic prevents mal-operations during external faults in power swing situations. It quickly clears the internal faults in power swing scenarios.

Broken conductor protection (46BC) The ratio of negative to positive sequence current (Ι2/Ι1) is adopted to detect the broken conductor.

Dead zone protection (50DZ) It is provided to clear the dead zone faults between CT and breaker.

Thermal overload protection (49) Thermal accumulation using thermal models is implemented for overload protection. Two stages for alarm and two stages for tripping are provided.

Pole discrepancy protection It is used to prevent overheating of generators/motors due to pole discrepancy.

Single and/or three-pole auto-reclosing (single-breaker or dual-breaker ). (79) Single/three pole auto-reclosing is provided for single- and dual-breaker applications. Priority logic is integrated for the applications of one-and-a-half breaker and ring breaker arrangements.

Stub overcurrent protection (50S) Stub protection is introduced to protect the T-zone in oneand-a-half breaker and ring breaker arrangements.

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Two stage undervoltage protection and two stage overvoltage protection (27/59) Phase under/over voltage protection and negative/zero sequence overvoltage protection are provided. Four stage underfrequency protection and four stage overfrequency protection (81) Frequency is calculated by using the positive sequence voltage. The df/dt element is provided for the supervision of underfrequency protection. Phase overcurrent protection during VT failure (51P VT) Independent phase overcurrent protection is automatically enabled to substitute the phase-to-phase distance protection, which is blocked during VT failure.

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Switch-onto-fault (SOTF) logic Switch-onto-fault logic is used to clear the faults during manual closing and auto-reclosing.

• •

Neutral overcurrent protection during VT failure (51N VT) Independent neutral overcurrent protection is automatically enabled to substitute the phase-to-ground distance protection, which is blocked during VT failure.

Remote/local control The control of circuit breaker, disconnector and earth switch can be implemented via communication, LCD menu and binary inputs. User programmable interlocking logics are available by PCS-Explorer.

Synchronism check (25) Synchro-check can be used for auto-reclosing and manual closing for single-breaker and dual-breaker.

Voltage and current drift auto adjustment. The relay continually and automatically traces the voltage and current drifts and adjusts the zero point to acquire accurate measurements.

Frequency tracking. Frequency tracking is provided to accommodate the frequency shifts in power system.

Monitoring and Measurement •

Energy measurement (active and reactive energies for import and export)

CT failure supervision

VT failure supervision

Fault phase selection

Fault Locator with parallel-line compensation

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events, 256 control logs and 1024 device logs

Disturbance recorder including 32 disturbance records with waveforms (The format is compatible with COMTRADE.)

Pilot communication channel supervision

System frequency supervision

Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

Features •

The unique DPFC protection principle, firstly introduced by NR Electric, employs superimposed increscent quantities as protection criteria, which provides high speed fault clearance and is immune to power swing and load fluctuation.

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Self-adaptive floating threshold which only reflects deviation of power frequency components improves the sensitivity and reliability during load fluctuation and system disturbance.

The unique power swing blocking logic can properly supervise the distance protection during power swing, which ensures the distance protection will operate correctly for internal faults during power swing, and prevents distance protection from mal-operation during power swing.

Fast clearance of the faults within the protected zone is achieved by this relay. The typical operating time is less than 10 ms for close-up faults, less than 15ms for mediumzone faults and less than 25ms for remote-end faults.

Comprehensive flexibility is achieved via modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. It allows users to create customized schemes for the specific projects. 2 fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/ Red) are provided.

The relay is fully compatible with IEC 61850, including station bus communication and process bus communication. It provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

Powerful disturbance recording function is integrated in the relay for post-fault analysis. Up to 64 disturbance records can be stored in non-volatile memory. Each report includes 250-cycle to 500-cycle waveform records with 12-cycle

Communication •

Optional single- or dual- pilot channels (fiber optic), complying with G.703 and C37.94

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

pre-fault waveform.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

NR Electric Co., Ltd.

PCS-931

Line Current Differential Protection

Five zone phase-to-phase distance protection (21P) Directional, load encroachment, power swing blocking and unique low-voltage elements are provided for phase-tophase distance protection.

One zone phase-to-phase distance protection for pilot scheme (85/21P) The relay provides an independent zone for pilot scheme of PUTT, POTT, Blocking, Unblocking, DTT & Zone Extension. The scheme intergrates current reversal logic, weak-infeed echo and open breaker echo.

• The PCS-931 relay provides full-scheme current differential and distance protection solutions for transmission lines with highspeed sub-cycle distance element. As well, the pilot scheme of distance protection and earth fault protection are integrated to provide a complete protection solution for the transmission line. The PCS-931 is intended for application on overhead lines and underground cables with diverse voltage levels, including series compensated, double-circuit, heavily loaded, weak infeed (WI), short and long lines. The relay provides dual pilot channels used for redundant tele-communication or three-terminal line application. It can meet the requirements of single-pole or threepole tripping, it also provides single- and/or three-pole autoreclosing functions. The PCS-931 is suitable for single- and dual-breaker applications, providing optional dual CT inputs, dual breaker failure protections, dual breaker auto-reclosing and dual synchro-checks. Additionally, the relay provides the remote/ local control of circuit breaker, disconnector and earth switch. The PCS-931 employs a wide range of innovative patented technologies, such as adaptive restraint threshold, dynamic capacitive current compensation, DPFC (Deviation Power Frequency Component) differential protection and unique power swing blocking logic, guaranteeing accurate and reliable operations. The PCS-931 is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is provided for testing and setting, allowing for easier commissioning and maintenance.

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Functions Protection and Control • •

Phase-segregated DPFC differential protection (87D) DPFC (Deviation of Power Frequency Component) percentage differential protection reflects superimposed quantities which can recognize the sensitive protection for high impedance faults. The relay provides dynamic charging current compensation, adaptive restraint threshold and CT saturation detection to improve the reliability of DPFC differential protection. Phase-segregated current differential protection (87P) Dynamic charging current compensation, adaptive restraint threshold and CT saturation detection are integrated to achieve a combination of both dependability and security.

Neutral current differential protection (87N) Neutral current differential protection is integrated to improve the sensitivity to the earth faults during heavy load state. Dynamic charging current compensation, adaptive restraint threshold and CT saturation detection are integrated for neutral current differential protection.

Five zone phase-to-ground distance protection (21G) The reactance characteristic, directional, load encroachment, power swing blocking and unique lowvoltage elements are provided for phase-to-ground distance protection. One zone phase-to-ground distance protection for pilot scheme (85/21G) The relay provides an independent zone for pilot scheme of PUTT, POTT, Blocking, Unblocking, DTT & Zone Extension. The scheme integrates current reversal logic, weak-infeed echo and open breaker echo. High-speed DPFC distance protection (21D) Innovative Deviation of Power Frequency Component (DPFC) distance protection quickly clears faults in a subcycle. DPFC is immune to the load fluctuation, weak-infeed and power swing. Pilot scheme of directional earth-fault protection (DEF) The relay includes directional zero sequence comparison element for earth faults. The pilot scheme integrates current reversal logic, weak-infeed echo and open breaker echo. Four stage phase overcurrent protection (67P, 50/51P) Selectable time characteristics (definite-time or inversetime) and directional elements (forward, reverse or nondirectional) are provided. A harmonic blocking function is integrated to restrain each stage independently. Four stage neutral overcurrent protection (67N, 50/51N) Selectable time characteristics (definite-time or inversetime) and directional elements (forward, reverse or non-

directional) are provided. A harmonic blocking function is integrated to restrain each stage independently. •

Breaker failure protection for one or two breakers (50BF) Breaker failure protection can be applied to single-breaker and dual-breaker applications.

Stub overcurrent protection (50S) Stub protection is introduced to protect the T-zone in oneand-a-half breaker and ring breaker arrangements.

Two stage undervoltage protection and two stage overvoltage protection (27/59) Phase under/over voltage protection and negative/zero sequence overvoltage protection are provided.

Four stage underfrequency protection and four stage overfrequency protection (81) Frequency is calculated by using the positive sequence voltage. The df/dt element is provided for the supervision of underfrequency protection.

Phase overcurrent protection during VT failure (51P VT) Independent phase overcurrent protection is automatically enabled to substitute the phase-to-phase distance protection which is blocked during VT failure.

Neutral overcurrent protection during VT failure (51N VT) Independent neutral overcurrent protection is automatically enabled to substitute the phase-to-ground distance protection which is blocked during VT failure.

Switch-onto-fault (SOTF) logic Switch-onto-fault logic is used to clear the faults during manual closing and auto-reclosing.

Unique power swing blocking logic (68) The power swing blocking logic prevents mal-operations during external faults in power swing and quickly clears the internal faults in power swing.

Broken conductor protection (46BC) The ratio of negative to positive phase sequence current (Ι2/Ι1) is adopted to detect the broken conductor.

Dead zone protection (50DZ) It is provided to clear the dead zone faults between CT and breaker.

Thermal overload protection (49) Thermal accumulation using thermal models is implemented for overload protection. Two stages for alarm and two stages for tripping are provided.

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53


NR Electric Co., Ltd.

NR Electric Co., Ltd.

Pole discrepancy protection It is used to prevent overheating of generators/motors due to pole discrepancy.

Communication •

Optional single or dual pilot channels (fiber optic), complying with G.703 and C37.94

Single and/or three-pole auto-reclosing (single-breaker or dual-breaker ) (79) Single/three pole auto-reclosing is provided for single- and dual-breaker applications. Priority logic is integrated for the applications of one-and-a-half breaker and ring breaker arrangements.

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Remote/local control The control of circuit breaker, disconnector and earth switch can be implemented via communication, LCD menu and binary inputs. User programmable interlocking logics are available by PCS-Explorer. Synchronism check (25) Synchro-check can be used for auto-reclosing and manual closing of single-breaker and dual-breaker. Voltage and current drift auto adjustment. The relay continually and automatically traces the voltage and current drifts and adjusts the zero point to acquire accurate measurements. Frequency tracking. Frequency tracking is provided to accommodate the

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

The unique DPFC protection principle, firstly introduced by NR Electric, employs superimposed increscent quantities as protection criteria, which provides high speed fault clearance and is immune to power swing and load fluctuation.

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

Self-adaptive floating threshold which only reflects deviation of power frequency components improves the sensitivity and reliability during load fluctuation and system disturbance. The unique power swing blocking logic can properly supervise the distance protection during power swing, which ensures the distance protection will operate correctly for internal faults during power swing, and prevents distance protection from mal-operation during power swing.

Fast clearance of faults within the protected zone is achieved by this relay. The typical operating time is less than 10 ms for close-up faults, less than 15ms for mediumzone faults and less than 25ms for remote-end faults.

Comprehensive flexibility is achieved via modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. It allows users to create customized schemes for the specific projects. 2 fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/ Red) are provided.

The relay is fully compatible with IEC 61850, including station bus communication and process bus communication. It provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

Powerful disturbance recording function is integrated in the relay for post-fault analysis. Up to 64 disturbance records can be stored in non-volatile memory. Each report includes 250-cycle to 500-cycle waveform records with 12-cycle pre-fault waveform.

frequency shift in power system.

Monitoring and Measurement •

Energy measurement (active and reactive energies for import and export)

CT failure supervision

VT failure supervision

Fault phase selection

Fault Locator with parallel-line compensation

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events, 256 control logs and 1024 device logs

Disturbance recorder including 32 disturbance records with waveforms (The format is compatible with COMTRADE.)

Pilot communication channel supervision

System frequency supervision

Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

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Features •

Innovative dynamic capacitive current compensation is introduced to the relay, in order to compensate both steady-state capacitive current and transient capacitive current, which can increases the sensitivity to highimpedance faults in long transmission lines.

Adaptive restraint threshold continuously adjust the restraint current according to the current measurement fluctuation, which improves the security during CT saturation and keeps sensitivity to internal faults.

CT saturation detection is provided to improve the security of current differential protection. It measures the time difference between change-of-differential-current and change-of-restraint-current.

CT ratio compensation is integrated in the relay to deal with the mismatched CT ratios located on different terminals of the transmission line. It allows the selection flexibility of CT equipment and eliminates additional interposing CTs.

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NR Electric Co., Ltd.

NR Electric Co., Ltd.

Monitoring and Measurement

PCS-924

T-zone Current Differential Protection In one-and-a-half breaker and ring breaker arrangements, the T-zone exists between two breakers and line/transformer feeders. The PCS-924 is designed to provide current differential protection, sum-of-current protection and feeder end fault protection for the T-zone. It provides three groups of CT input for direct connections to three terminal CTs. The disconnector is always installed in the feeder to facilitate the maintenance. The relay considers the different operating scenarios for the feeder with the disconnector. 3-terminal and 2-terminal current differential protections are automatically enabled/ disabled to meet different scenarios with closed or opened disconnector. The feeder end fault protection is enabled when the disconnector is opened. It is used to clear faults between CT and disconnector while keeping continuous operation of local breakers. The phase overcurrent protection employs the calculated sum current of two CTs. It can be applied for feeder energization and feeder backup protection.

The PCS-924 is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is provided for testing and setting, allowing for easier commissioning and maintenance.

CT failure supervision

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 device logs

Disturbance recorder including 32 disturbance records with waveforms (The format of disturbance recorder is compatible with COMTRADE.)

Clock synchronization using IRIG-B, SNTP, PPS (Pulse-

Two stage feeder end fault protection (50FLE) This protection is only valid when the feeder disconnector is opened. It is used to clear the faults between CT and the opened disconnector. It will send a transfer trip command to remote end and keep the local breakers in service.

Sum overcurrent protection (50P) Phase overcurrent protection is based on the summed current of two CTs. It can be used as the energizing protection or feeder backup protection.

Current drift auto adjustment The relay continually and automatically traces the voltage and current drifts and adjusts the zero point to acquire

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Comprehensive flexibility is achieved via modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. It allows users to create customized schemes for specific projects. 2 fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/Red) are provided.

The relay is fully compatible with IEC 61850, including station bus communication and process bus communication. It provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

Powerful disturbance recording function is integrated in the relay for post-fault analysis. Up to 64 disturbance records can be stored in non-volatile memory. Each report includes 250-cycle to 500-cycle waveform records with 12-cycle pre-fault waveform.

Communication •

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE.

Protection and Control Current differential protection (87S) The switchover of 3-terminal and 2-terminal current differential protection can be automatically implemented according to the open/close state of feeder disconnector.

Per-Second) and PPM (Pulse-Per-Minute)

Functions •

Features

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

accurate measurements.

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Busbar Proteoction Function Index

Function

PCS-915IC Centralized Busbar Protection

Functional Code

Centralized busbar protection

PCS-915IC

Distributed busbar protection

The PCS-915IC centralized busbar protection provides comprehensive protection solution for various arrangements of all voltage levels. The default busbar arrangements include single busbar with/without section, double busbar with/without section, double busbar with transfer bus, breaker-and-a-half arrangement and ring-breaker arrangement.

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Up to 25 bays protected by one device

Up to 32 bays protected by one device

Phase current differential protection

87P

DPFC differential protection

87D

Check zone and discrimination zone

Voltage control element

PCS-915ID Distributed Busbar Protection

CT saturation inhibition

Breaker failure protection for each bay

50BF

The PCS-924 is designed to provide current differential protection, sum-of-current protection and feeder end fault protection for the T-zone. It provides three groups of CT input for direct connections to three terminal CTs.

Dead zone protection for each bay

50D

√ √

Pole discrepancy protection for each bay

62PD

Phase overcurrent protection for each feeder

50/51P

Neutral overcurrent protection for each feeder

50/51N

Switch-onto-fault logic for bus coupler/section

SOTF

Voltage and current drift auto adjustment

58

PCS-915ID

Frequency tracking

Different CT ratio regulation

Dynamic busbar replica

Isolator contact discrepancy alarm

IDMT characteristic for overcurrent

CT failure supervision

VT failure supervision

Fault recorder

GPS clock synchronization (IRIG-B, SNTP, PPS, PPM)

Configurable I/O and LED

Programmable logic

Up to four Ethernet ports using IEC 61850, DNP 3.0 or IEC 60870-5-103 over TCP/IP

Up to two serial ports using IEC 60870-5-103

Optional sampling Value & GOOSE module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

Application for single-busbar

Application for double-busbar

Application for double busbar with transfer bus

Application for double busbar with bus section

3/2 breaker and ring-breaker arrangements

Configurable I/O and LED

Programmable logic

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NR Electric Co., Ltd.

Functions Protection and Control •

PCS-915IC

Centralized Busbar Protection

Busbar current differential protection (87B) It consists of phase current differential protection and DPFC differential protection. Voltage control element and CT saturation blocking element are available to supervise this current differential protection. --

Phase current differential protection Dual restraint coefficients are provided to enhance the sensitivity of weak-sourced busbar with opened coupler/section.

--

DPFC differential protection DPFC differential protection is sensitive to high resistance faults and is immune to load fluctuations.

--

Voltage control element The voltage could be selected to use phase voltage,

zero sequence voltage and/or negative sequence voltage. --

The PCS-915IC centralized busbar protection provides comprehensive protection solution for various arrangements of all voltage levels. The default busbar arrangements include single busbar with/without section, double busbar with/without section, double busbar with transfer bus, breaker-and-a-half arrangement and ring-breaker arrangement. The relay provides flexible configuration of the busbar topologies to meet specific applications. Due to its extensive CT input and I/O capability, the PCS-915IC is capable to protect up to 25 feeders. It provides fast and secure low impedance busbar protection with sub-cycle tripping time. Check zone and discrimination zone of differential protection are equipped in the relay to minimize the outage zone. Advanced and patented technologies are incorporated to improve sensitivity and security, such as weighted CT saturation detection method, DPFC current differential protection.

--

• The PCS-915IC is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is provided for testing and setting, allowing for easier commissioning and maintenance.

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Check zone and discrimination zone Check zone differential element and discrimination zone differential element are provided to minimize the outage zone.

Bus coupler/section protection -- Breaker failure protection (50BF) It can be supervised by voltage control element. Retripping, coupler/section tripping and feeder tripping are executed in sequence. --

Dead zone protection (50DZ) It is provided to clear the dead zone faults between CT and breaker.

--

Dead zone protection (50DZ) It is provided to clear the dead zone fault between CT and breaker.

--

Pole disagreement protection (62PD) Pole discrepancy detection element is used to protect pole disagreement.

--

Overcurrent protection (50/51) Overcurrent protection consists of phase overcurrent element and neutral overcurrent element, each can be set as inverse time or definite-time.

Voltage and current drift auto adjustment. The relay automatically traces the drift and adjusts zero point to normal value for voltage and current.

Frequency tracking. Frequency tracking is provided to accommodate the frequency shift in power system.

Monitoring and Measurement •

Dynamic busbar replica

Isolator contact discrepancy alarm

CT failure supervision

VT failure supervision

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 device logs

Disturbance recorder including 32 disturbance records with waveforms (The format is compatible with COMTRADE.) Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

--

Pole disagreement protection (62PD) Pole discrepancy detection element is used to protect pole disagreement.

--

Switch-onto-fault protection (50SOTF) Switch-onto-fault logic of bus coupler/section is used for bus energizing.

Communication

--

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CT saturation inhibit Two principles for CT saturation detection are provided: patented adaptive weighted anti-saturation algorithm and harmonic algorithm. It keeps the current differential protection stable to external faults and quickly clears internal faults and external-to-internal evolving faults during CT saturation.

Feeder protection -- Breaker failure protection (50BF) It can be supervised by voltage control element. Retripping, bus coupler/bus section tripping and feeder tripping are executed in sequence.

Overcurrent protection (50/51) Phase and neutral overcurrent protection with time delay are both provided.

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

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Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with 32 optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

NR Electric Co., Ltd.

provide fast and reliable CT saturation detection. •

Check zone current differential element and discrimination zone current differential element are integrated in the relay, to select the fault zone and to make a selective trip, so as to minimize the outage area.

The relay detects dynamic connection status of each feeder via disconnector auxiliary contacts, so as to dynamically include or exclude the current inputs for the current differential protection calculations.

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Comprehensive flexibility is achieved via modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. It allows users to create customized schemes for specific projects. 2 fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/Red) are provided.

Features •

Both traditional phase current differential protection and innovative DPFC current differential protection are provided in the relay, to ensure the high speed and high level of sensitivity. The typical operation time of current differential protection is less than 20 ms. Up to 25 feeders can be connected and protected in one device, to provide all-in-one solution for busbar protection. This solution can implement cross-phase algorithms, such as negative/zero sequence voltage blocking element, negative/zero sequence overcurrent element.

CT ratio compensation is integrated to provide users the selection flexibility of CT equipments and to avoid the interposing CTs.

Patented adaptive weighted anti-saturation algorithm is employed, together with traditional harmonic algorithm, to

The relay is fully compatible with IEC 61850, including station bus communication and process bus communication. It provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

PCS-915ID

Distributed Busbar Protection

The PCS-915ID distributed busbar protection is used for protecting and monitoring various busbar arrangement with all voltage levels, including single busbar with/without section, double busbar with/without sections, double busbar with transfer bus, breaker-and-a-half arrangement and ring-breaker arrangement. It adopts distributed structure, consisting of one Central Unit (CU) and a number of Bay Units (BUs). The Central Unit is linked to up to 32 Bay Units via optical fibers in point-topoint communication mode. The Central Unit is responsible for the protection calculation and relay management, the Bay Unit acquires and transmits the analog and binary data and executes the trip/close commands issued by Central Unit. The device provides fast and secure low impedance busbar protection with sub-cycle tripping time. It integrates advanced and patented features to improve its sensitivity and security, such as innovative DPFC current differential protection and unique weighted CT saturation detection method. The PCS-915ID is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is provided for testing and setting, allowing for easier commissioning and maintenance.

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Functions Protection and Control •

Busbar current differential protection (87B) It consists of phase current differential protection and DPFC differential protection. Voltage control element and CT saturation blocking element are available to supervise this current differential protection. --

Phase current differential protection Dual restraint coefficients are provided to enhance the sensitivity of weak-sourced busbar with opened coupler/section.

--

DPFC differential protection DPFC differential protection is sensitive to high resistance faults and is immune to load fluctuations.

--

Voltage control element The voltage could be selected to use phase voltage, zero sequence voltage and/or negative sequence voltage.

--

CT saturation inhibit Two principles for CT saturation detection are provided: patented adaptive weighted anti-saturation algorithm and harmonic algorithm. It keeps the current differential protection stable to external faults and quickly clears internal faults and external-to-internal evolving faults during CT saturation.

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--

Bus coupler/section protection --

--

--

--

--

64

Check zone and discrimination zone Check zone differential element and discrimination zone differential element are provided to minimize the outage zone.

Breaker failure protection (50BF) It can be supervised by voltage control element. Retripping, bus coupler/bus section tripping and feeder tripping are executed in sequence. Dead zone protection (50DZ) It is provided to clear the dead zone faults between CT and breaker. Pole disagreement protection (62PD) Pole discrepancy detection element is used to protect pole position disagreement. Switch-onto-fault protection (50SOTF) Switch-onto-fault logic of bus coupler/section is used for bus energizing. Overcurrent protection (50/51) Phase and neutral overcurrent protection with time delay are both provided.

NR Electric Co., Ltd.

Monitoring and Measurement •

Dynamic busbar replica

Isolator contact discrepancy alarm

CT failure supervision

VT failure supervision

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 device logs

Disturbance recorder including 32 disturbance records with waveforms (The format is compatible with COMTRADE.)

Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

Communication •

Up to 32 optical point-to-point communication ports from Central Unit to Bay Units

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Feeder protection

Two RS-485 serial ports using IEC 60870-5-103

--

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with 32 optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

Breaker failure protection (50BF) It can be supervised by voltage control element. Retripping, bus coupler/bus section tripping and feeder tripping are executed in sequence.

--

Dead zone protection (50DZ) It is provided to clear the dead zone fault between CT and breaker.

--

Pole disagreement protection (62PD) Pole discrepancy detection element is used to protect pole disagreement.

--

Overcurrent protection (50/51) Overcurrent protection consists of phase overcurrent element and neutral overcurrent element, each can be set as inverse time or definite-time.

Voltage and current drift auto adjustment. The relay automatically traces the drift and adjusts zero point to normal value for voltage and current.

Frequency tracking. Frequency tracking is provided to accommodate the frequency shift in power system.

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Features •

Both traditional phase current differential protection and innovative DPFC current differential protection are provided in the relay, to ensure the high speed and high level of sensitivity. The typical operation time of current differential protection is less than 20ms.

Up to 32 feeders can be connected and protected in the relay, to provide all-in-one solution for busbar protection.

CT ratio compensation is integrated to provide users the selection flexibility of CT equipments and to avoid the interposing CTs.

Patented adaptive weighted anti-saturation algorithm is employed, together with traditional harmonic algorithm, to provide fast and reliable CT saturation detection.

Check zone current differential element and discrimination zone current differential element are integrated in the relay, to select the fault zone and to make a selective trip, so as to minimize the outage area and avoid cascading blackout.

The relay detects dynamic connection status of each feeder via disconnector auxiliary contact, so as to dynamically include or exclude the current inputs for the current differential protection calculation.

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Comprehensive flexibility is achieved via modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. It allows users to create customized schemes for specific projects. 2 fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/Red) are provided.

The relay is fully compatible with IEC 61850, including station bus communication and process bus communication. It provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

Read more on the web www.nrelect.com

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Function Index

Transformer Protection

PCS-978 Transformer Protection The PCS-978 provides a full-scheme protection and control solution for any type of transformer as well as shunt reactor applications. The PCS-978 can be implemented across a variety of transformers including, two-winding, three-winding, and autotransformers.

PCS-974 Mechanical Protection The PCS-974 mechanical protection provides sixteen high-power-pickup binary inputs dedicated to the mechanical relays in field, so as to realize the mechanical tripping/alarm with or without time delay.

PCS-9671 Transformer Current Differential Protection The PCS-9671 is a numerical relay designed for the protection of two-winding or threewinding transformers with a maximum of three CT inputs. It also can be used to protect reactors or implemented as a stub current differential protection in a one-and-a-half breaker arrangement.

Function

PCS-974

PCS-9671

Transformer restrained current differential protection

87PT

87UT

Transformer DPFC differential protection

87DT

Reactor restrained current differential protection

87PR

Reactor unrestrained current differential protection

87UR

Reactor DPFC differential protection

87DR

Inrush blocking

CT saturation blocking

Overexcitation blocking

CT failure blocking

Amplitude compensation

Phase angle compensation

√ √

Restricted earth fault protection

REF

Winding differential protection

87W/87N

Inter-turn fault protection for reactor

32G/21G

Overexcitation protection

24

Four stage underfrequency protection

81U

Four stage overfrequency protection

81O

Mechanical protection based on high-power-pickup binary inputs

MR

Temperature protection

26

Phase-to-phase impedance protection

21P

Phase-to-ground impedance protection

21G

68

Phase overcurrent protection

67P, 50/51P

Neutral overcurrent protection

67NP, 50/51N

Power swing blocking

50/51Q

Phase overvoltage protection

59P

Ground overvoltage protection

59G

Positive-sequence undervoltage protection

27P

49

Breaker failure protection

50BF

Pole discrepancy protection

62PD

Phase overcurrent alarm element

50PAlm

Ground overvoltage alarm element

59GAlm

Thermal protection

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PCS-978

Transformer unrestrained current differential protection

Negative sequence overcurrent protection

66

Functional Code

Voltage and current drift auto adjustment

Frequency tracking

IDMT characteristic for overcurrent

CT failure supervision

VT failure supervision

Fault recorder

GPS clock synchronization (IRIG-B, SNTP, PPS, PPM)

Configurable I/O and LED

Programmable logic

Up to four Ethernet ports using IEC 61850, DNP 3.0 or IEC 60870-5103 over TCP/IP

Up to two serial ports using IEC 60870-5-103

Optional sampling Value & GOOSE module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

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NR Electric Co., Ltd.

Functions Protection and Control •

PCS-978

Transformer Protection The PCS-978 provides a full-scheme protection and control solution for any type of transformer as well as shunt reactor applications. The PCS-978 can be implemented across a variety of transformers including, two-winding, three-winding, and autotransformers. It integrates up to 36 current/voltage inputs in order to be suitable for applications like one-and-a-half breaker or ring breaker arrangements. Up to 6 group CT inputs are included in current differential protection. In addition, 288 vector groups are available for 3-winding transformers, as well as 24 vector groups, which available for 2-winding transformer.

protection and to ensure the safety of vital assets. To improve the reliability of mechanical protection, dedicated high-threshold binary inputs are designed for mechanical protection. In addition, automatic CT ratio compensation and vector group compensation are provided to eliminate the external interposing CTs.

The unique current differential protection includes conventional phase current differential elements and innovative DPFC differential elements, in effort to provide reliable and secure

make commissioning and maintenance easier.

The PCS-978 is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. Additionally, a RJ45 faceplate port is provided for testing and setting in order to

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is utilized to detect interrupted and unsymmetrical iNR Electricush currents. The harmonics method relies on the 2nd and 3rd harmonics in order to determine the iNR Electricush current. The self-adaptive blocking mode and phase-to-phase cross-blocking mode are both provided for iNR Electricush blocking.

Transformer restrained current differential protection (87PT) A high-setting stage and a low-setting stage are provided in effort to ensure the operating speed and sensitivity. The high-setting stage can be supervised by iNR Electricush blocking. Furthermore, the low-setting stage can be supervised by iNR Electricush blocking, CT saturation blocking, over excitation blocking and CT failure blocking.

Transformer UNR Electricestrained current differential protection (87UT) The uNR Electricestraint current differential protection instantaneously responds and clears serious internal faults without any restraining characteristics and blocking elements.

CT saturation blocking The 2nd and 3rd harmonics are both employed to detect both steady-state CT saturation and transient CT saturation. In addition, the time intervals between difference current and restraint current are utilized to distinguish internal faults and external faults.

Overexcitation blocking The 3rd and 5th harmonics are utilized in the V/Hz calculation to detect the overexcitation conditions and prevent mal-operation due to overexcitation.

CT failure blocking The percentage current differential protection can be blocked to prevent mal-operation due to CT circuit failure. Combined current and voltage detection are employed to accurately discriminate CT circuit failure conditions.

Amplitude compensation The current amplitudes can be internally corrected to compensate the amplitude difference due to mismatched CT ratios and transformer ratios.

Phase angle compensation The current phase angles can be internally corrected to compensate phase shifts due to Δ-Y connections. Y→Δ and Δ→Y compensation methods are provided to meet different protection requirements.

Restricted Earth Fault Protection (REF) Zero sequence differential protection is used as REF for each Y-connection winding to detect sensitive ground faults. Up to 3 REF protections are provided for different sides of the transformer. Furthermore, up to four 3-phase CTs and one neutral CT are integrated in each REF protection.

Transformer DPFC biased current differential protection (87DT) The Deviation of Power Frequency Component (DPFC) differential protection element is immune to load fluctuations and provides high sensitivity for turn-to-turn faults and high impedance faults. Reactor restraint current differential protection (87PR) The high-setting and low-setting stages are provided in order to ensure operating speed and sensitivity. The high-setting stage can be supervised by iNR Electricush blocking. Furthermore, the low-setting stage can be supervised by iNR Electricush blocking, CT saturation blocking and CT failure blocking. Reactor uNR Electricestrained current differential protection (87UR) Reactor uNR Electricestrained current differential protection is implemented in order to instantaneously clear potential internal faults without restraining characteristics and blocking elements.

Reactor DPFC biased current differential protection (87DR) DPFC biased current differential protection is immune to load fluctuations and is sensitive to slight internal faults within the reactor.

INR Electricush blocking Two methods are provided for iNR Electricush blocking: waveform distortion method and harmonic method. In the waveform distortion method, the symmetry principle

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Winding differential protection (87W/87N) Winding differential protection can be applied where winding CTs exist. In comparison to REF, it provides high sensitivity for both earth faults and phase-to-phase faults. Up to three winding differential protections are provided for the different sides of a transformer, and up to five 3-phase CTs can be integrated in each differential protection. It can also be used as T-zone current differential protection when the transformer is connected to a one-and-a-half breaker arrangement or ring breaker arrangement.

NR Electric Co., Ltd.

• •

Inter-turn fault protection for reactor (32G/21G) Reactor inter-turn faults may not be detected by current differential protection, thus dedicated inter-turn protection is provided in the relay. Inter-turn protection consists of zero-sequence power directional element, zero-sequence impedance element and a DPFC inter-turn fault detector element. It provides sensitivity for inter-turn faults while still maintaining security for external faults. Overexcitation protection (24) Overexcitation protection is based on the ratio of voltage to frequency (V/Hz). The overexcitation protection can be configured into any side of the transformer using PCSExplorer software. Underfrequency and overfrequency protection (81U/81O) Four-stage underfrequency protection and four-stage overfrequency protection are provided in each relay. The change-of-rate (df/dt) element is integrated for underfrequency protection. Zero-voltage and out-of-limit frequency are detected in order to block under-/overfrequency protection.

• •

70

Mechanical protection (MR) The relay provides eight high-power-pickup binary inputs for mechanical relays in order to realize mechanical tripping/alarm. Four of these inputs are provided with time delay. The high-power-pickup design reduces the risk of Electro-Magnetic Interference (EMI) to improve reliability. Generally, the mechanical relays include winding temperature relays, oil temperature relays and buchholz relays. Temperature protection (26) The relay provides six analog inputs (0-20mA/ 0-5V) for temperature transducers in effort to detect possible over temperature states.

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Two-stage phase-to-phase impedance protection (21P) Users have the option of selecting forward direction or backward direction by logic setting. The power swing blocking logic is integrated to improve reliability. Two-stage phase-to-ground impedance protection (21G) Users have the option of selecting forward direction or backward direction by logic setting. The power swing blocking logic is integrated to improve reliability. Power swing blocking (68) The unique power swing blocking logic is integrated to prevent the mal-operation of impendence protection due to power swings. Four-stage phase overcurrent protection (50P/51P/67P) Overcurrent protection is supervised by the voltage element, harmonic element and directional element. .Inverse-time curves take into account both IEC/IEEE curves and a self-definable curve. Four-stage neutral overcurrent protection for each side (50N/51N/67N) Overcurrent protection is supervised by the voltage element, harmonic element and directional element. Inverse-time curves take into account both IEC/IEEE curves and a self-definable curve. Two-stage negative sequence overcurrent protection (50Q/51Q) Inverse-time curves take into account both IEC/IEEE curves and a self-definable curve. Two-stage phase overvoltage protection (59P) Phase voltage and phase-to-phase voltage can be selected as calculation values. The ‘1-out-of-3’ and ‘3-out-of-3’ criterions are provided for flexible protection logic. Inversetime curves take into account both IEC/IEEE curves and a self-definable curve.

Two-stage ground overvoltage protection (59G) Inverse-time curves take into account both IEC/IEEE curves and a self-definable curve.

Four-stage undervoltage protection (27) Generally, undervoltage protection is employed for loadshedding in order to keep the system’s voltage in normal operation range. The positive-sequence voltage is used

as the calculation value. To differentiate between the lowvoltage due to short-circuit faults and the low-voltage due to the lack of reactive power, the voltage rate-of-change (du/dt) element, the negative sequence voltage element and the low positive sequence voltage elements are integrated . •

Thermal protection (49) A thermal model is adopted to continuously calculate the heat capacity of a transformer. Two stages are integrated for alarm and tripping. Up to three thermal protections are provided for the different sides of transformer. Breaker failure protection (50BF) Breaker failure protection for each breaker is supplied to initiate re-tripping and adjacent breaker tripping. Pole disagreement protection (62PD) External binary input and zero-sequence/negativesequence current are used to detect a pole disagreement state of the circuit breaker. Phase overcurrent alarm element (50PAlm) A dedicated overcurrent element is employed to detect the load current of the transformer. If an overload condition is detected, the relay can initiate the cooling system and block the tap changer. The phase overcurrent alarm element is not supervised by Fault Detector elements.

Ground overvoltage alarm element (59GAlm) The element is generally used in ungrounded systems to detect ground voltage and to issue potential alarm signals.

Voltage and current drift auto adjustment The relay continually and automatically traces the voltage and current drifts, then it adjusts the zero point to the normal value. Frequency tracking Frequency tracking is provided to accommodate the frequency shifts in the power system.

Monitoring and Measurement •

CT failure supervision

VT failure supervision

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 device logs

Disturbance recorder including 32 disturbance records with waveforms (The format is compatible with COMTRADE.)

Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

Communication •

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

Read more on the web www.nrelect.com

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NR Electric Co., Ltd.

Features •

A CT transient detection element is provided for REF in order to eliminate the influence of CT transient characteristic difference. The element is based on the ratio of zero-sequence current to positive-sequence current.

The waveform distortion and harmonics methods are both integrated in the current differential protection to improve reliability. Either method can be selected in order to cover applications in different types of transformers.

Self-adaptive blocking and phase-to-phase cross-blocking modes are both provided for iNR Electricush blocking. The self-adaptive mode enhances the dependability on internal faults and ensures security during iNR Electricush conditions.

To enhance the judgment accuracy of overexcitation condition, both the 5th and 3rd harmonics are employed for continuous overexcitation supervision.

Both Δ→Y and Y→Δ phase angle compensation are provided in the relay for selection. The Δ→Y method is preferred due to the iNR Electricush characteristic remaining in each corresponding phase, so as to realize phase-segregated iNR Electricush blocking. The unique DPFC protection principle, pioneered by NR Electric, employs superimposed increscent quantities as protection criteria. This principle provides high sensitivity for slight internal faults.

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with redundant scheme, the solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent mal-operation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Comprehensive flexibility is provided via modular hardware design scalable function library, programmable logics, configurable I/Os and definable LEDs. This allows users to create customized schemes for specific projects. Two fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/Red) are employed.

The relay is fully compatible with IEC 61850, including station bus communication and process bus communication. It provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS..

A powerful disturbance recording function is integrated in the relay for post-fault analysis. Up to 64 disturbance records can be stored in non-volatile memory. Each report includes 250-cycle to 500-cycle waveform records with 12-cycle pre-fault waveform.

PCS-974

Mechanical Protection

The PCS-974 mechanical protection provides sixteen highpower-pickup binary inputs dedicated to the mechanical relays in field, so as to realize the mechanical tripping/alarm with or without time delay. The high-power-pickup design reduces the risk of Electro-Magnetic Interference (EMI) in order to improve reliability. Generally, mechanical relays include winding temperature relays, oil temperature relays and buchholz relays. The relay can be used for transformer and generator protection. The PCS-974 is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is provided for testing and setting in effort to make commissioning and maintenance easier.

Functions Protection and Monitoring •

72

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Up to sixteen channels of mechanical protection (26: oil and winding temperature; 63: gas, pressure; 71: oil level; etc)

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 operating logs

Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

Communication •

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

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NR Electric Co., Ltd.

Features •

To eliminate the interference from switchyard field, highpower-pickup binary inputs are designed for dedicated mechanical inputs, in order to improve the protection reliability.

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Comprehensive flexibility is provided via the modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. This allows users to create customized schemes for specific projects. Two fixed LEDs and 18 definable 3-color LEDs (Green/ Yellow/Red) are provided.

The relay is designed based on NR Electric’s wellestablished and proven hardware platform with multiprocessor architecture. The multi-CPU technology supports parallel operation of CPU modules.

The relay is fully compatible with IEC 61850, it includes station bus communication and process bus communication. The relay provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

PCS-9671

Transformer Current Differential Protection The PCS-9671 is a numerical relay designed for the protection of two-winding or three-winding transformers with a maximum of three CT inputs. It also can be used to protect reactors or implemented as a stub current differential protection in a one-and-a-half breaker arrangement. The restraint current differential protection, uNR Electricestraint differential protection and restricted earth fault protection are provided . Comprehensive flexibility is provided via the modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. This allows users to create customized schemes for specific projects. Two fixed LEDs and 18 definable 3-color LEDs (Green/Yellow/Red) are provided. The relay is compatible with IEC 61850 station bus and process bus applications. It supports IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. The RJ-45 faceplate port is implemented in effort to make testing, setting, commissioning and maintenance easier.

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Functions Protection and Control •

Restraint current differential protection (87PT) A high-setting stage and a low-setting stage are provided to ensure the operating speed and sensitivity. The highsetting stage is supervised by iNR Electricush blocking and CT failure blocking. In addition, the low-setting stage is supervised by iNR Electricush blocking, CT saturation blocking, over excitation blocking and CT failure blocking.

UNR Electricestraint current differential protection (50/87UT) The uNR Electricestraint current differential protection instantaneously clears serious internal faults without any restraining characteristics and blocking elements.

Restricted earth fault protection(REF) Zero sequence differential protection is used as REF to detect sensitive ground faults. Up to 3 REF protections are provided for all sides of a transformer.

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Phase overcurrent protection(50/51P) Up to 3 overcurrent protection elements are provided. Inverse-time curves take into account both IEC/IEEE curves and a self-definable curve. CT circuit supervision. (CTS) CT circuit supervision consists of two elements: CT circuit abnormality without fault detector pickup and CT circuit failure with fault detector pickup. INR Electricush current blocking by 2nd and 3rd harmonic. Phase-segregated blocking, cross blocking and composited blocking are provided upon selection. Overexcitation blocking by 5th harmonic. Overexcitation is detected via the ratio of the 5th harmonic current and fundamental current.

NR Electric Co., Ltd.

Features •

The unique hardware design with two independent data acquisition paths can prevent the mal-operation due to hardware component failure. It significantly enhances the protection reliability.

Various methods of GPS time synchronization are supported in this relay, including SNTP, PPS (Pulse-PerSecond)and IRIG-B synchronization.

The device can communicate with SAS or RTU via different communication intermediates: Ethernet network, RS-485 serial ports. The communication protocol of this device is optional: IEC61850, IEC60870-5-103 or DNP3.0.

Complete event recording function is provided: 1024 supervision records, 1024 control operation records, 1024 user operation records and 1024 SOE records can be recorded.

CT saturation detection CT saturation is distinguished via combined 2nd and 3rdharmonics. •

Management •

1024 supervision alarm records, 1024 control operation records and 1024 user operation records

64 fault and disturbance records

1024 SOE records

Up to four 10Base-T/100Base-TX (RJ45) ports or two 100Base-FX ports with IEC 61850-8-1 MMS, IEC 60870-5103 over TCP/IP or DNP 3.0

Two RS-485 rear ports with IEC 60870-5-103

Up to Six 100Base-FX ports with IEC 61850-9-2 Sampling Value and GOOSE

One RS-485 rear port for clock synchronization

One RS-232 rear port for printer

One faceplate RJ-45 port for testing and setting

Clock synchronization via pulse, IRIG-B and SNTP

• • • •

76

Y→Δ transfer method is used to compensate phase angle of secondary current, and correction coefficients are adopted to complete amplitude compensation. Users may set the vector group in each side of the transformer. Furthermore,, 24 vector groups are available for two-winding transformer, and 288 vector groups are available for 3-winding transformer. Three slopes biased differential protection is adopted in order to avoid mal-operation caused by unbalance current during external faults. The 2nd, 3rd and 5th harmonic blocking functions for biased differential protection are available. The 2nd and 3rd harmonics are selectable to identify iNR Electricush current, and the 5th harmonic is used to detect possible overexcitation conditions. In addition, phase segregated blocking mode and crossing-blocking mode are provided for selection.

PCS-921 Circuit Breaker Protection The PCS-921 numerical relay provides protection for circuit breakers, which includes breaker failure protection, pole discrepancy protection, dead zone protection, phase/ neutral overcurrent protection, single and/or three-pole auto-reclosing and synchronism check functions.

PCS-9830 Point-on-Wave Controller of Breaker The PCS-9830 point-on-wave controller is a three-phase control device for circuit breakers it serves to open or close at specified phase angle on voltage waveform in order to minimize the impulse caused by switching on.

Function Index Function Breaker failure protection Dead zone protection Pole discrepancy protection

Functional Code

PCS-921

50BF

50D

62PD

Phase overcurrent protection

50/51P

Neutral overcurrent protection

50/51N

1/3 pole auto-reclosing

79

Synchronization check

25

√ √

Phase segregated tripping function

Self-adaptive compensation function

Realtime compensation function

Current zero-drift automatic calibration function

√ √

Frequency tracking

CT failure supervision

VT failure supervision

Fault recorder

GPS clock synchronization (IRIG-B, SNTP, PPS, PPM)

Configurable I/O and LED

Virtual binary input state change report generation and communication testing.

Programmable logic

Up to four Ethernet ports using IEC 61850, DNP 3.0 or IEC 60870-5-103 over TCP/IP

Binary output testing.

Up to two serial ports using IEC 60870-5-103

Manual triggering fault recording.

Optional sampling Value & GOOSE module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

Virtual tripping report generation and communication testing Virtual self-supervision report generation and communication testing.

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The CT transient detection element based on the ratio of residual current to positive current is adopted to eliminate the influence on REF due to the CT transient characteristic difference.

PCS-9830

Phase segregated closing function

Voltage and current drift auto adjustment

Auxiliary Testing Functions •

Powerful fault and disturbance recording functions are supported: 64 fault or disturbance waves, the duration of a wave recording is configurable.

Circuit Breaker Protection

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checking condition can be selected as live-bus to deadline, dead-bus to live-line or dead-bus to dead-line. •

PCS-921

Circuit Breaker Protection

Single and/or three-pole auto-reclosing (79) Up to 4 shots can be selected for single-/three- pole autoreclosing. Voltage and current drift auto adjustment The relay continuously and automatically traces voltage and current drifts and adjusts the zero point. Frequency tracking Frequency tracking is provided to accommodate the frequency shift in the power system.

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

One front RJ-45 port for testing and setting

One RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

Features •

A unique two-out-two logic is adopted in hardware design to improve security. Coordinating with the redundant scheme, this solution improves both security and dependability of protection system. The two independent data acquisition paths are provided to prevent maloperation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths.

Comprehensive flexibility is provided via the modular hardware design, scalable function library, programmable logics, configurable I/Os and definable LEDs. This allows users to create customized schemes for specific projects. Two fixed LEDs and 18 definable 3-color LEDs (Green/ Yellow/Red) are provided.

The relay is designed based on NR Electric’s wellestablished and proven hardware platform with multiprocessor architecture. The multi-CPU technology supports parallel operation of CPU modules.

The relay is fully compatible with IEC 61850, it includes station bus communication and process bus communication. The relay provides up to 6 Ethernet ports for process bus with IEC 61850-9-2 Sampling Value and IEC 61850-8-1 GOOSE, as well as up to 4 Ethernet ports for station bus with IEC 61850-8-1 MMS.

Monitoring and Measurement The PCS-921 numerical relay provides protection for circuit breakers, which includes breaker failure protection, pole discrepancy protection, dead zone protection, phase/ neutral overcurrent protection, single and/or three-pole auto-reclosing and synchronism check functions. The PCS- 921 relay employs the programmable logic, configurable I/Os and definable 3-color LEDs to provide flexibility for specific applications. Frequency tracking is used to minimize the sampling error caused by system frequency fluctuation. The PCS-921 relay adopts the advanced multi-processor platform, providing the interfaces to station bus and process bus respectively and supporting IEC 61850-8-1 MMS, GOOSE and IEC 61850-9-2 Sampling Value. In addition, the RJ-45 faceplate port serves for testing and setting in effort to make commissioning and maintenance easier.

VT circuit supervision (VTS)

CT circuit supervision (CTS)

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 operating logs

Disturbance recorder including 32disturbance records with waveforms (The format of disturbance recorder is compatible with COMTRADE.)

Clock synchronization using IRIG-B, SNTP, PPS (PulsePer-Second) and PPM (Pulse-Per-Minute)

Communication •

Up to four 10Base-T/100Base-TX copper Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/ IP

Up to two 100Base-FX optical Ethernet ports using IEC 61850, DNP3.0 or IEC 60870-5-103 over TCP/IP ( Sharing two copper Ethernet ports)

Two RS-485 serial ports using IEC 60870-5-103

One RS-485 serial port for clock synchronization

Optional Sampling value and GOOSE communication module with six optical Ethernet ports using IEC 61850-9-2 and IEC 61850-8-1 GOOSE

Functions Protection and Control •

78

Breaker failure protection (50BF) Re-tripping and adjacent breaker tripping will be executed if the internal/external tripping command is received and the overcurrent element does not drop off. To improve the sensitivity of generator/transformer protection, the phase overcurrent, neutral and negative-sequence overcurrent elements are provided. Pole discrepancy protection (62PD) Pole discrepancy is detected by breaker auxiliary contacts. Furthermore, asymmetrical current element is selected as an additional criteria. Dead zone protection (50DZ) The adjacent breakers are tripped if a fault between CT and breaker (dead zone) is detected via the initiating binary

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input from external protection, breaker auxiliary contacts and overcurrent element. •

Two stages of phase overcurrent protection (50/51P) The second harmonic element can be selected to block the overcurrent element to avoid mal-operation due to transformer iNR Electricush current.

Two stages of neutral overcurrent protection (50/51N) The second harmonic element can be selected to block the neutral overcurrent element.

Synchronism check (25) The criteria can be set as frequency difference, voltage difference, and phase angle difference. Hence, the

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Technical Data Item

PCS-9830

Point-on-Wave Controller of Breaker

Pole-segregated switching

Open, Close

Auxiliary Power Supply

80% ~ 120% of rated voltage Rated Voltage: 30Vdc/110Vdc/220Vdc; 110Vac ~ 220Vac

Rated Frequency

(50 Hz or 60Hz) ± 5%

Power Consumption Burden Open/Close Circuit Current

AC current

Temperature Transducer

The PCS-9830 point-on-wave controller is a three-phase control device for circuit breakers it serves to open or close at specified phase angle on voltage waveform in order to minimize the impulse caused by switching on. The controlled switching technology significantly eliminates harmful electrical transients upon planned switching, and thereby extending the breakers life

Features

time and improving the stability of the entire power system.

Functions •

Phase segregated closing function

Phase segregated tripping function

Self-adaptive compensation function

80

--

Self-adaptive compensation function based on current feedback

--

Self-adaptive compensation function based on position feedback

Complete self-adaptive compensation function and complete real-time status compensation function are provided. Measurement of current and voltage, as well as monitoring of operation status are realized. 32 operation records, 64 self-check records, and 64 binary quantity/status change records are provided. Software and hardware can be flexibly configured according to applications. Elaborate anti-interference assembly design with fully enclosed chassis provides strong resistance to vibration and Electro-Magnetic Interference (EMI).

Description

Pressure Transducer

Steady state: <10W Transient: <15W < 0.5 VA/Phase @ 1A <1.0 VA/Phase @ 5A Adaptive Rated: 1 A or 5 A Thermal withstand: 3In, Continuously 30In, 10 sec 100In, 1 sec 250In, half cycle Selective: 4~20mA 0~10Vdc 0~250Vdc Selective: 4~20mA 0~10Vdc 0~250Vdc

Adaptive Channels

6

Temperature Compensation

Step & range is configurable. Adaptive 6-point & 8-point curves

Adaptive mode

Yes

Compensation mode

Pressure compensation Temperature compensation Operating voltage compensation Operating frequency compensation

1/3 Pole

1-pole or 3-pole, selective

Binary Output

Relay paralleled with IGBT

Binary Output

Dry contact

Event & wave record

Yes

Realtime compensation functions --

Real-time compensation function based on control circuit voltage

--

Real-time compensation function based on mechanism’s ambient temperature

--

Compensation function based on resting time

Current zero-drift automatic calibration function

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Generator Protection

Function Index PCS-985T

PCS-985TS

PCS-985TW

PCS-985BT

PCS-985RS

PCS-985BG

PCS-985GW

PCS-985G

PCS-985AW

PCS-985B

Function Code

Function

Main protection for generator-transformer unit

PCS-985 Generator & Excitation Protection

UNR Electricestraint current differential protection Percentage restraint current differential protection

PCS-985 generator protection can be applied for any size turbo-dynamo, gas-turbine, hydro, pumped storage and nuclear power generator with different connection modes. It supports conventional CT/VT and ECT/EVT, and meets the requirements of power plant automation.

87P

Main protection for generator UNR Electricestraint current differential protection

87UG

Percentage restraint current differential protection

87PG

DPFC current differential protection

87DG

Split phase transverse differential protection

87SG

Incomplete differential protection

87IG

PCS-985T Main Transformer & Auxiliary Transformer Protection The PCS-985 transformer protection can be applied for any size transformer with various voltage levels and wiring modes, and meets the requirements of power plant automation. The full-integrated transformer protection integrates protection, control and monitoring functions to provide users with a comprehensive, reliable and cost-effective solution.

87U

Inter-turn fault protection Sensitive transverse differential protection

87S

Longitudinal zero-sequence overvoltage protection

59N

Directional DPFC negative-sequence power protection

7/67

Calculated longitudinal residual overvoltage protection for inter-turn fault

59N

Back-up protection for generator Phase-to-phase impedance protection

RCS-985U External Source for Stator Earth Fault Protection

Voltage controlled overcurrent protection

The RCS-985U adopts integrative design scheme of square-wave power source, resonant/ blocking impedor and voltage divider in a standard 6U box. The back-insertion design principle of square-wave power source module and resonant/blocking impedor module bring convenience for engineers in installation, disassembly and maintenance.

Fundamental zero-sequence overvoltage protection

21P

50P/51P

Stator ground fault protection 59G

27/59TN

Third harmonic voltage differential protection

87TN

100% stator earth-fault protection with 20Hz voltage injection

64G

Third harmonic voltage ratio protection

Rotor ground protection Rotor ground protection (ping-pang type)

PCS-985RE Rotor Earth Fault Protection with Voltage Injection

Rotor ground protection with voltage injection

The PCS-985RE is mainly designed for rotor earth fault by external voltage injection. Because of adopting self-adaptive active switching technology,

Stator overload protection

64R

49S

Rotor overload protection (negative sequence)

46

Loss of excitation protection

40

Out-of-step protection

78

27/59

Over excitation protection

24

Reverse power protection

32R

Low forward power protection Under/over frequency protection

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Miscellaneous protection for generator

Under/over voltage protection

82

64R

32F

81U/O

√ √

√ √

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NR Electric Co., Ltd.

87PT

Percentage restraint current differential protection

60

50LF

Back-up protection for auxiliary transformer HV side

√ Voltage controlled phase overcurrent protection

50P/51P

Back-up protection for auxiliary transformer LV side branch A

87UT

Percentage restraint current differential protection

87PT

Zero sequence overcurrent protection

50P/51P

50N/51N

Restricted earth-fault protection

REF

50P/51P

50N/51N

Back-up protection for auxiliary transformer LV side branch B

Back-up protection for main transformer (startup/standby transformer to PCS-985T) HV side REF

Voltage controlled phase overcurrent protection

50P/51P

Zero sequence overcurrent protection

Restricted earth-fault protection

Zero sequence overcurrent protection

50N/51N

Phase-to-phase impedance protection

21P

REF

Excitation transformer or exciter protection

50G/51G

Current differential protection for excitation transformer

87E

Directional zero-sequence overcurrent protection

67G

Current differential protection for exciter

87E

Inverse-time zero-sequence overcurrent protection

51G

Ground overcurrent protection

Phase overcurrent protection

50P/51P

Gap zero-sequence voltage protection

Thermal overload protection

49

Gap zero-sequence current protection

√ Mechanical protection

MR

over-excitation protection Pole discrepancy protection

62PD

Overload alarm for transformer

Initiating cooling for transformer

50BF

Blocking on-load tap change during overload

OLTC

Back-up protection for main transformer (startup/standby transformer to PCS-985T) MV side Restricted earth fault protection Voltage controlled phase overcurrent protection Zero sequence directional overcurrent protection Zero sequence overcurrent protection Ground overcurrent protection

Miscellaneous

24

Breaker flashover protection Breaker failure initiation

PCS-985T

UNR Electricestraint current differential protection

Voltage controlled phase overcurrent protection

PCS-985TS

Voltage controlled phase overcurrent protection

Restricted earth fault protection

PCS-985TW

50BF

PCS-985BT

PCS-985RS

87DT

PCS-985BG

Main protection for main transformer( startup/standby transformer to PCS-985T)

DPFC current differential protection

PCS-985GW

PCS-985G

PCS-985AW

SS

Main protection for auxiliary transformer UNR Electricestraint current differential protection

87UT

Function Code

Function

PCS-985B

PCS-985T

PCS-985TS

PCS-985TW

PCS-985BT

PCS-985RS

Voltage balance protection Low frequency overcurrent protection

PCS-985BG

Breaker failure protection

PCS-985GW

Startup/shutdown generator protection

PCS-985G

50/27

PCS-985AW

Inadvertent energizing protection

PCS-985B

Function Code

Function

REF 50P/51P

67G

50N/51N

50G/51G

CT circuit supervision

CTS

VT circuit supervision

VTS

GPS clock synchronization

Fault Recorder

IEC61850 MMS & GOOSE for station bus

IEC60870-5-103 protocol

MODBUS protocol

DNP 3.0 LAN

Back-up protection for main transformer (startup/standby transformer to PCS-985T) LV side or LV side branch

84

Voltage controlled phase overcurrent protection

50P/51P

Zero sequence overcurrent protection

50N/51N

Zero-sequence voltage alarm

59G

Restricted earth-fault protection

REF

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PCS-985

Generator & Excitation Protection

PCS-985 generator protection can be applied for any size turbodynamo, gas-turbine, hydro, pumped storage and nuclear power generator with different connection modes. It supports conventional CT/VT and ECT/EVT, and meets the requirements of power plant automation.

86

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PCS-985B provides complete electric quantity protection of a turbo-dynamo or nuclear power generator-transformer unit which usually comprises generator, main transformer, step-down transformer and exciter or excitation transformer. PCS-985AW can be applied for a large-scale hydro or pumped storage generator-transformer unit with different connection modes.

PCS-985GW provides complete electric quantity protection of a hydro-generator and excitation transformer.

PCS-985BG provides complete electric quantity protection of a gas turbine generator and exciter or excitation transformer.

PCS-985RS can be applied for small to medium scale generator and exciter or excitation transformer.

PCS-985G provides complete electric quantity protection of a turbo-dynamo or nuclear power generator and exciter or excitation transformer.

For medium to large generators, two sets of PCS-985 relays can be used to achieve duplicated protection configuration. Two PCS-985 relays use different CT groups, main and backup protection in one PCS-985 share one group of CTs.

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Functions Generator protection •

UNR Electricestraint current differential protection. (87UG) 87UG provides high speed clearing of stator phase-tophase faults, especially for serious fault.

Percentage restraint current differential protection. (87PG) 87PG is variable slope differential protection. Advanced “asynchronous method” CT saturation detection algorithms can prevent 87PG from mal operation caused by CT saturation during eternal fault. The fast detection of differential CT circuit-break can avoid malfunction due to the abnormal CT circuit.

Split phase transverse differential protection. (87SG) 87SG is mostly utilized for inter-turn faults of hydro generators.

Incomplete differential protection 1. (87IG) 87IG is mostly utilized for hydro generators, and it adopts currents of the terminal and one of the branches at neutral point to detect stator inter-turn fault and phase-to-phase fault.

DPFC differential protection. (87DG) 87DG reflects only deviation components of differential current and restraint current, it will not be affected by load current. It can detect slight fault within the generator.

component is able to exceed 100. Within the frequency tracking range the protection can only respond to the basic wave component.

Incomplete differential protection 2. (87IG) 87IG is mostly utilized for hydro generators, and it adopts currents of the terminal and one of the branches at neutral point to detect stator inter-turn fault and phase-to-phase fault.

88

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Inverse-time stator overload protection. (49S) Inverse-time stator overload protection consists of three parts: low-setting initiator, inverse-time part and upper-limit definite-time part.

Third harmonic overvoltage differential protection for stator earth fault. (87TN) 87TN is enabled automatically when the generator is connected with the system and if the load current exceeds 0.2Ie (generator rated current) it will only issue an alarm. It will protect 100% of the stator winding.

Definite-time negative-sequence overload protection. (46) Definite-time negative-sequence overload protection has two stages: one for alarm and the other for tripping.

Inverse-time negative-sequence overload protection. (46) Inverse-time negative-sequence overload protection consists of three parts: low-setting initiator, inverse-time part and upper-limit definite-time part.

Loss-of-excitation protection. (40) Loss-of-excitation protection represents abnormal operation of the generator due to excitation failure. It includes 3 criteria: undervoltage criterion, stator-side impedance criterion and rotor-side criterion. The voltage at the generator terminal and neutral point can be selected as undervoltage criterion. Static stability impedance circle and asynchronous impedance circle can be selected as statorside impedance criterion.

Out-of-step protection. (78) Out-of-step protection calculates impedance element by positive-sequence voltage and current, the operation characteristic of out-of-step protection comprises three parts: lens part, boundary part and reactance line part.

Overvoltage protection. (59) Two stages of overvoltage protection can be used for tripping or alarming.

Undervoltage protection. (27) Undervoltage protection reflects the reduction of three phase-to-phase voltages, and it is locked by the binary input of synchronous condenser operation.

Definite-time over-excitation protection. (24) Definite-time over-excitation protection consists of two stages: one is for alarm, the other is for tripping. Both of these time delays can be set independently.

Inverse-time over-excitation protection. (24) Inverse-time over-excitation protection realizes inversetime characteristic by linear processing on given inverse time operation characteristic, obtaining multiple of over excitation by calculation, and calculating corresponding operation time delay by sectional linear insertion. It reflects heat accumulation and radiation.

Phase-to-phase impedance protection. (21P) Two stages impedance protection is equipped at the generator terminal as phase-to-phase backup protection. Full impedance, directional impedance or shifted impedance characteristics can be selected for these two stages.

Voltage controlled overcurrent protection. (50P/51P) There are two stages with two separate time delays. Stage 1 is used to trip bus coupler breaker or other breakers, and stage 2 is to shut down the generator. Composite voltage element consists of phase-to-phase undervoltage element and negative overvoltage element.

Fundamental zero-sequence voltage protection for stator earth fault. (59G) 59G reacts to the magnitude of zero-sequence voltage from the generator neutral point. It adopts frequency tracking, digital filter and full cycle Fourier transformation, the filtration ratio of third harmonic component is able to exceed 100. Within the frequency tracking range the protection can only respond to the basic wave component. This protection consists of two stages: sensitive stage and insensitive stage (high setting stage).

High sensitive transverse differential protection. (87S) 87S adopts frequency tracking, digital filter and full cycle Fourier transformation, the filtration ratio of third harmonic component is able to exceed 100. It is installed on a connection between two neutral points of a generator, and mainly used for inter-turn faults of generator’s stator winding, open circuit fault of branches and short circuit fault between phases. Longitudinal zero-sequence overvoltage protection for inter-turn fault. (59N) 59N uses the zero-sequence voltage from the opendelta winding of dedicated VT at the generator terminal. It adopts frequency tracking, digital filter and full cycle Fourier transformation, the filtration ratio of third harmonic

Calculated longitudinal residual overvoltage protection for inter-turn fault. (59N) Dedicated VT is not needed for this protection. Calculated longitudinal zero-sequence voltage used by this protection is composed of zero-sequence voltages of generator terminal and neutral point.

Third harmonic overvoltage ratio protection for stator earth fault. (27/59TN) 27/59TN covers about 20~25% of earth fault of the stator winding near the neutral point of the generator.

• •

DPFC directional protection for inter-turn fault. (7/67) DPFC directional protection for inter-turn fault has default settings, and the sensitivity is about 3V of longitudinal zero-sequence voltage.

Zero-sequence overcurrent protection for stator earth fault. (51G) 51G detects the zero-sequence current from the neutral point of the generator, and operates when the current is over the setting. It is very sensitive for stator earth fault. •

100% stator earth-fault protection with voltage injection. (64S, with RCS-985U) Using the 100% stator earth-fault protection based on sub-harmonic injection, a 20Hz voltage from RCS-985U is injected to detect earth faults at any point across the winding. 64G provides a 100% stator earth-fault protection that is operation during generator start-up, running and stopped conditions. The solution includes: earthing resistance criterion, earthing current criterion and external voltage circuit monitoring. Rotor one-point earth-fault protection with ping-pong principle. (64R1) 64R1 adopts the switch-over sampling principle, and detects any insulation resistance between rotor winding and the axis. It includes two stages: sensitive stage and regular stage. Rotor two-point earth-fault protection with ping-pong principle. (64R2) If 64R1 is used for alarm only, when the earth resistance is less than the regular stage setting, it will automatically switch into 64R2 with a time delay. Rotor earth-fault protection with voltage injection.(64R) Based on the leading-out mode of the rotor windings, 64R has two injection styles: double-ends injection and singleend injection. The switching cycle of the injected power supply can be adjusted in accordance with the capacitor between rotor winding and ground. 64R can reflect the decline of insulation resistance between generator rotor and shaft by real-time calculating one-point earth resistance of rotor, with or without excitation voltage. Definite-time stator overload protection. (49S) Definite-time stator overload protection has two stages: one for alarm and the other for tripping.

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Reverse-power protection. (32R) Reverse power protection is provided to detect generator motoring in order to protect the prime mover from damage. Low forward power protection. (32F) Low forward power protection responds to low forward power flow. it can be released by the binary input for nonemergency shutoff or the binary input indicating that the valve of the steam turbine is in the closed position.

Differential protection. (87E) Differential protection consists of uNR Electricestraint differential protection and variable slop differential protection. It adopts 2nd, 3rd, 5th harmonic current detection and blocking method.

Sequential tripping reverse-power protection. (32R) Sequential tripping reverse-power protection is used when the steam valve of the turbine has been closed first before tripping.

Overload protection. (49) Overload protection consists of definite-time and inversetime excitation winding overload protection.

Underfrequency protection. (81U) Underfrequency protection will issue an alarm or trip if the accumulated time delay or once duration time delay exceeds its setting.

Main Transformer Protection

Inadvertent energization protection. (50/27) Considering security of the protection, both currents from the generator terminal and neutral point are used as criteria.

Startup/shutdown protection of differential current. (SS) Startup/shutdown protection of differential current is used for phase-to-phase fault of the generator.

Startup/shutdown protection of zero-sequence voltage. (SS) Zero-sequence overvoltage is utilized for stator earth fault of the generator during Startup/shutdown. Low-frequency overcurrent protection. (50LF) Low-freuquency overcurrent protection is used for phaseto-phase fault of the generator during Startup/shutdown. Breaker failure protection. (50BF) When there is an internal fault of the generator, the protection operates to trip but the breaker at the generator terminal fails, it needs to initiate breaker failure protection and trip adjacent breakers in time.

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Overcurrent protection. (50P/51P) Overcurrent protection includes two stages used as backup protection.

Overfrequency protection. (81O) Overfrequency protection will issue an alarm or trip when it operates.

Excitation Transformer/Exciter Protection

NR Electric Co., Ltd.

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UNR Electricestraint current differential protection for generator-transformer unit. (87U) UNR Electricestraint current differential protection is used to accelerate the trip speed for generator-transformer unit inner serious fault. It does not need any block element, but the setting should be greater than maximum iNR Electricush current. Percentage restraint current differential protection for generator-transformer unit. (87P) 87P can protect the generator, main transformer, auxiliary transformer, and exciter or excitation transformer. It is based on a variable slope percentage differential restraint characteristic with iNR Electricush and overexcitation inhibits. It includes two different iNR Electricush current detection principles: second harmonic restraint principle and waveform distortion discrimination principle. CT saturation detection element can prevent maloperation due to CT saturation during external fault. UNR Electricestraint current differential protection. (87UT) UNR Electricestraint current differential protection is used to accelerate the trip speed for transformer’s inner serious fault. It does not need any block element, but the setting should be greater than maximum iNR Electricush current. Percentage restraint current differential protection. (87PT) Percentage restraint current differential protection is based on a variable slope percentage differential restraint characteristic with iNR Electricush and overexcitation inhibits. It includes two different iNR Electricush current

detection principles: second harmonic restraint principle and waveform distortion discrimination principle. CT saturation detection element can prevent maloperation due to CT saturation during external fault.

Definite-time over-excitation protection. (24) Definite-time over-excitation protection consists of two stages one is for alarm the other is for tripping. Both of these time delays can be set independently.

DPFC differential protection. (87DT) 87DT reflects only deviation components of differential current and restraint current, it is not affected by the load current. It can detect slight fault within transformer.

Restricted earth-fault protection. (REF) REF extends protection coverage to the neutral point of wye-connected windings where fault currents may be below the pickup of the main transformer differential elements.

Inverse-time over-excitation protection. (24) Inverse-time over-excitation protection realizes inversetime characteristic by linear processing on given inverse time operation characteristic, obtaining multiple of over excitation by calculations, and calculates corresponding operation time delay by sectional linear insertion. It reflects heat accumulation and radiation.

Pole discrepancy protection at HV side. (62PD) Pole discrepancy protection at HV side adopts phase current, negative-sequence current, and zero-sequence current as criteria to detect the abnormal situation of Pole discrepancy.

Breaker flashover protection. Before the generator-transformer unit connecting with the system, when the difference of phase angle between bus voltage and generator voltage is around 1800, breaker flashover is possible. Breaker flashover protection is used in case of this situation, and one phase and two phase flashover are considered.

Zero-sequence voltage alarm at LV side. (59G) Zero-sequence voltage alarm at LV side can be provided for the main transformer as the supervision of earthing fault when GCB is not closed.

Overload alarm. (49)

Initiating cooling. (49)

Voltage controlled overcurrent protection at HV side. (50P/51P) 2 stages of voltage controlled overcurrent protection at HV side are used for phase-to-phase backup protection of the main transformer. Of which, voltage controlled element can be enabled or disabled by logic setting. Phase-to-phase impedance protection at HV side. (21P) Three kinds of impedance characteristics can be selected, i.e. full impedance, directional impedance and shifted impedance.

Ground overcurrent protection at HV side. (50G/51G) Ground overcurrent protection at HV side has two stages, with separate time delay of each stage.

Directional zero-sequence overcurrent protection at HV side. (67G) The directional element uses calculated zero-sequence current and calculated zero-sequence voltage. The direction points to the system side, definitely with the reach angle of 750.

Inverse-time zero-sequence overcurrent protection at HV side. (51G) Four IEC inverse-time operating characteristics are provided, and users can select according to their needs. Gap zero-sequence overvoltage/overcurrent protection at HV side. Gap zero-sequence protection at HV side is used for the transformer with neutral point grounded through a gap or small reactance.

Auxiliary Transformer •

UNR Electricestraint current differential protection. (87UT)

Percentage restraint current differential protection. (87PT)

Voltage controlled overcurrent protection at HV side. (50P/51P)

Voltage controlled overcurrent protection of branch 1 at LV side. (50P/51P)

Voltage controlled overcurrent protection of branch 2 at LV side. (50P/51P)

Zero-sequence overcurrent protection of branch 1 at LV side. (50N/51N)

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Zero-sequence overcurrent protection of branch 2 at LV side. (50N/51N)

Overload alarm. (49)

Initiating cooling. (49)

Miscellaneous •

Mechanical protection. (MR)

Fault detector. (FR)

Voltage and current drift auto adjustment.

VT circuit supervision. (VTS)

CT circuit supervision. (CTS)

CT saturation detection. (CTS)

INR Electricush current detection. (VTS)

Self diagnostic.

GPS clock synchronization.

Fault Recorder.

IEC61850 MMS & GOOSE for station bus

IEC60870-5-103 protocol

MODBUS protocol

DNP 3.0 LAN0

NR Electric Co., Ltd.

Variable slope percentage differential protection Variable slope percentage characteristic is adopted for current differential protection. If the pickup slope and maximum slope are reasonably set, high sensitivity can be gained during internal fault, while transient unbalance current can be avoided during external fault.

DPFC percentage differential protection DPFC percentage differential protection reflects only deviation components of differential current and restraint current, it is not affected by the load current. It can detect slight fault within the transformer and generator. Besides, it is insensitive to CT saturation since its restraint coefficient is set comparatively high.

High-sensitive transverse differential protection By adopting frequency tracking, digital filter and Fourier transformation, the filtration ratio of third harmonic component can exceed 100. All these countermeasures guarantee the reliability of protection in all conditions.

Percentage restraint inter-turn protection The device adopts new criteria of generator current percentage restraint technique to ensure the accurate operation during inter-turn fault occurs in stator winding and prevent mal-operation during external asymmetric fault occurs.

Features

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Detect CT Saturation by asynchronous method For external fault, waveform discrimination of phase current and differential current is adopted. Mal-operation will not occur if the CT correct transfer time from primary to secondary side is not less than 5ms. For internal fault, the device will operate quickly.

High-performance unified hardware and real-time calculations This relay adopts high performance CPUs and DSPs, internal high-speed bus, and intelligent I/O. Both hardware and software adopt modular design, and can be flexibly configured.

Stator earth-fault protection Through the real-time adjustment of coefficient of amplitude value and phase, the PCS-985 makes differential voltage between the generator terminal and neutral point in normal operation condition. When stator earth fault occurs, the criteria tend to operate reliably and sensitively.

Independent fault detector elements The unique hardware design with two independent data acquisition paths can prevent the mal-operation due to the hardware component failure. The tripping output is continuously supervised by the independent fault detector element executed in the separated CPU. It will significantly enhance the reliability.

Stator earth-fault protection with external voltage injection principle The protection adopts digital technology to calculate the earth fault resistance accurately. The protection is adaptive for various operation conditions, such as stillness, no-load, shutdown, startup and connected to the power grid.

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Rotor earth-fault protection with ping-pong principle DC current is input by a high-performance isolated amplifier. Via switching two different electronic switches, the PCS-985 solves four different ground-loop equations to compute rotor winding voltage, rotor ground resistance and earthing position on real time and display these information on LCD screen. Rotor earth-fault protection with external voltage injection principle The protection method is adaptive to various lead-out modes of rotor windings, and both single-end injection and double-ends injection can be selected. It can detect faults without excitation voltage, and the fault location can be measured if double-ends injection is selected.

VT circuit failure supervision Two groups of VT inputs are equipped at the generator terminal. If one group fails, the device will issue an alarm and switch over to the healthy one automatically. It does not need to block protection element relevant to voltage.

CT circuit failure supervision Reliable blocking function can prevent the device from undesired operation due to CT circuit failure or AC sampled circuit failure.

Powerful communication function 2 independent Ethernet interfaces and 2 independent RS485 communication interfaces are provided. Power industry communication standard IEC60870-5-103, Modbus protocol and new generation substation communication standard IEC61850 are supported.

Complete event recording function 64 fault operation sequences, 64 fault waveforms, results of 256 self-supervision reports, and 1024 binary signal change reports can be recorded.

Loss-of-excitation protection Loss-of-excitation protection optionally combines stator impedance criteria, reactive power criteria, rotor voltage criteria and busbar voltage criteria to meet various demands of different generator units.

Out-of-step protection Out-of-step protection adopts three-impedance elements (gains from positive-sequence current and positive sequence voltage of the generator) to distinguish out-ofstep from steady oscillation. In addition, the protection can accurately locate the position of oscillation center and record the oscillation slid numbers of external and internal oscillation respectively in real-time.

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PCS-985TS is adaptive to small main transformers, auxiliary transformers and startup/standby transformers in power plants. It can be used for the transformer with up to 4 branches at LV side.

PCS-985T is adaptive from medium to large startup/ standby transformers and auxiliary transformers in power plants. It can be used for the transformer with up to 8 branches at LV side.

PCS-985T

Main Transformer & Auxiliary Transformer Protection The PCS-985 transformer protection can be applied for any size transformer with various voltage levels and wiring modes, and meets the requirements of power plant automation. The full-integrated transformer protection integrates protection, control and monitoring functions to provide users with a comprehensive, reliable and cost-effective solution. The PCS985 is fully compatible with IEC-61850 communication. It supports conventional CT/VT and ECT/EVT, and meets the requirements of the power plant automation.

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For a large-scale transformer, two sets of PCS-985 can be used to achieve duplicated protection configuration. Two PCS-985 relays use different CT groups, and main and backup protection in one PCS-985 share one CT group. •

PCS-985BT is adaptive from medium to large main transformer and auxiliary transformer.

PCS-985TW is adaptive from medium to large main transformer in hydro power plant.

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Functions Protection and control •

UNR Electricestraint current differential protection. (87UT) UNR Electricestraint current differential protection is used to accelerate the trip speed for transformer’s inner serious fault. It does not need any block element, but the setting should be greater than the maximum iNR Electricush current. Percentage restraint current differential protection. (87PT) Percentage restraint current differential protection is based on a variable slope percentage differential restraint characteristic with iNR Electricush and overexcitation inhibits. It includes two different iNR Electricush current detection principles: second harmonic restraint principle and waveform distortion discrimination principle. CT saturation detection element can prevent maloperation due to CT saturation during external fault. DPFC differential protection for main transformer. (87DT) 87DT reflects only deviation components of differential current and restraint current, it is not affected by the load current. It can detect slight fault within transformer. Restricted earth fault protection. (REF) REF extends protection coverage to the neutral point of wye-connected windings where fault currents may be below the pickup of the main transformer differential elements.

High-voltage cable differential current protection. (87L) 87L can be used as main protection of High-voltage cable if it is not included in the differential protection range of startup/standby transformer.

High-voltage cable overcurrent protection. (50/51L) Two-stage overcurrent protections are used for the high-voltage cable between the bushing of startup/ standby transformer and high voltage breakers. One is instantaneous, and the other is time-delayed.

Ground overcurrent protection. (50G/51G) Ground overcurrent protection at HV side has two stages, with separate time delay of each stage.

Directional overcurrent protection. (67G) The directional element uses calculated zero-sequence current and calculated zero-sequence voltage. The direction points to the system side, definitely with the reach angle of 750.

• •

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Voltage controlled overcurrent protection. (50P/51P) 2 stages of voltage controlled overcurrent protection at HV side are used for phase-to-phase backup protection of the main transformer. Of which, voltage controlled element can be enabled or disabled by logic setting. Phase-to-phase impedance protection. (21P) Three kinds of impedance characteristics can be selected, i.e. full impedance, directional impedance and shifted impedance.

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Inverse-time residual overcurrent protection. (51G) Four IEC inverse-time operating characteristics are provided, and users can select according to their needs. Gap zero-sequence overvoltage/overcurrent protection. Gap zero-sequence protection at HV side is used for a transformer with neutral point grounded through a gap or small reactance. Definite-time over-excitation protection. (24) Definite-time over-excitation protection consists of two stages, one is for alarm, the other is for tripping. Both of these time delays can be set independently. Inverse-time over-excitation protection. (24) Inverse-time over-excitation protection realizes inversetime characteristic by linear processing on given inverse time operation characteristic, obtaining multiple of over excitation by calculation, and calculating corresponding operation time delay by sectional linear insertion. It reflects heat accumulation and radiation. Pole disagreement protection. (62PD) Pole discrepancy protection at HV side adopts phase current, negative-sequence current, and zero-sequence current as criteria to detect the abnormal situation of Pole discrepancy. Breaker flashover protection. Before the generator-transformer unit connects with the system, when the difference of phase angle between bus voltage and generator voltage is around 1800, breaker flashover is possible. Breaker flashover protection is used in case of this situation, and one phase and two phase flashover are considered.

Breaker failure initiation. (50BF)

Blocking on-load tap change during overload. (OLTC)

Residual voltage alarm at LV side. (59G)

Variable slope percentage differential protection Variable slope percentage characteristic is adopted for current differential protection. If the pickup slope and maximum slope are reasonably set, high sensitivity can be gained during internal fault, while transient unbalance current can be avoided during external fault.

DPFC percentage differential protection DPFC percentage differential protection reflects only deviation components of differential current and restraint current, it is not affected by a load current. It can detect slight fault within the transformer and generator. Besides, it is insensitive to CT saturation since its restraint coefficient is set comparatively high.

Detect CT Saturation by asynchronous method

Zero-sequence voltage alarm at LV side can be provided for the main transformer as the supervision of earthing fault. •

Overload protection. (49)

Cooling initiation function. (49)

Miscellaneous •

Mechanical protection. (MR)

Fault detector. (FR)

VT circuit failure supervision. (VTS)

CT circuit failure supervision. (CTS)

CT saturation detection.

INR Electricush current detection.

Voltage and current drift auto adjustment.

Self diagnostic.

GPS clock synchronization.

Fault Recorder.

IEC61850 MMS & GOOSE for station bus

IEC60870-5-103 protocol

MODBUS protocol

DNP 3.0 LAN

Features •

High-performance unified hardware and real time calculations This relay adopts high performance CPUs and DSPs, internal high-speed bus, and intelligent I/O. Both hardware and software adopt modular design, and can be flexibly configured. Independent fault detector elements The unique hardware design with two independent data acquisition paths can prevent the mal-operation due to the hardware component failure. The tripping output is continuously supervised by the independent fault detector element executed in the separated CPU. It will significantly enhance the reliability.

For external fault, waveform discrimination of phase current and differential current is adopted. Mal-operation will not occur if the CT correct transfer time from primary to secondary side is not less than 5ms. For internal fault, the device will operate quickly. •

VT circuit failure supervision Two groups of VT inputs are equipped at the generator terminal. If one group fails, the device will issue an alarm and switch over to the healthy one automatically. It does not need to block protection element relevant to voltage.

CT circuit failure supervision Reliable blocking function can prevent the device from undesired operation due to CT circuit failure or AC sampled circuit failure.

Powerful communication function 2 independent Ethernet interfaces and 2 independent RS485 communication interfaces are provided. Power industry communication standard IEC60870-5-103, Modbus protocol and new generation substation communication standard IEC61850 are supported.

Complete event recording function 64 faults and operation sequences, 64 fault waveforms, results of 256 self-supervision reports, and 1024 binary signal change reports can be recorded.

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Technical Data Mechanical Specifications

RCS-985U

External Source for Stator Earth Fault Protection

Enclosure dimensions (W×H×D)

482.2×266×285mm

Trepanning dimensions (W×H)

464.2mm×190.5mm,M6 screw

Mounting Way

Flush mounted

Weight per device

Approx. 15kg

Local control panel

2 LED indicators

Housing material

Aluminum

Housing color

Silver grey

Location of terminals

Rear panel of the device

Protection class (per IEC60529:1989)

Front side: IP51 Rear side, connection terminals: IP20 Other Sides: IP30

Ambient Temperature and Humidity Range

Usually 100% stator earth fault protection with RCS-985U voltage injection is used in large-sized generator with high

An external low-frequency alternating voltage source provided by RCS-985U injects into the generator stator windings by applying the voltage across the load resistor of the earthing transformer. So through voltage divider, the RCS-985 protection relay can get UG0. In addition, IG0 is measured via a miniature CT. Both quantities (UG0 and IG0) are fed to the protection relay. To prevent the secondary load resistance from becoming too small (it should be > 0.5Ω, where possible), a high secondary voltage should be selected for the earthing or neutral

resistance earthed of neutral point.

transformer. 500 V has proven to be a proper value.

The RCS-985U adopts integrative design scheme of squarewave power source, resonant/blocking impedor and voltage divider in a standard 6U box. The back-insertion design principle of square-wave power source module and resonant/blocking impedor module bring convenience for engineers in installation, disassembly and maintenance.

Standard Operating temperature Transport and storage temperature range Permissible humidity

IEC60255-6:1988 -25OC~ +55OC -40OC~ +70OC 5% ~ 95%, condensation not permissible

Voltage Input (Three-phase AC, Single-phase AC and DC) Rated voltage input Permitted AC deviation Rated DC voltage Permitted DC deviation

3×(100/110V) 50/60Hz 80~130 V 110V~220V 88~253 V

1×(100~230V) 50/60Hz 80~265 V

Square-Wave Voltage Output Amplitude Frequency Continuously withstand capability

25V approx. 20±0.1Hz 80VA

Alarming Relays Max system voltage Continuous carry Quiescent burden

250V(AC) 8A(AC) 240mW approx.

Withstand capability

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Continuous withstand voltage

55V (AC)

withstand voltage(≤30s)

550V (AC)

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Type Test Environmental Tests Dry heat test Dry cold test Damp heat test, cyclic

IEC60068-2-2:1974, Test Ad for 16 h at +55°C IEC60068-2-1:1990, Test Bd for 16 h at -25°C IEC60068-2-30:1980, Test Db for two (12+12 hours) cycles, 95%RH, low temperature +25°C, high temperature +55°C

PCS-985RE

Electrical Tests Dielectric tests Impulse voltage tests Insulation measurement

IEC60255-5:2000, test voltage: 2kV, 50Hz, 1min IEC60255-5:2000, test voltage: 5kV, unipolar impulses, waveform 1.2/50μs, source energy 0.5J IEC60255-5:2000, insulation resistance >100MΩ, 500Vdc

Rotor Earth Fault Protection with Voltage Injection

Electromagnetic Compatibility (EMC) 1MHz burst disturbance tests - Common mode - Differential mode Electrostatic discharge tests

IEC60255-22-1:1988(idt IEC61000-4-2:1995), Class III 2.5kV 1.0kV IEC60255-22-2 :1996 (idt IEC 61000-4-2) Class IV

- For contact discharge

8.0kV

- For air discharge

15.0kV

Radio frequency interference tests - Frequency sweep - Radiated amplitude-modulated Spot frequency

IEC60255-22-3:2000 (idt IEC 61000-4-3:1995 ) class III 10V/m(rms), f=80…1000MHz

The PCS-985RE is mainly designed for rotor earth fault by external voltage injection. Because of adopting self-adaptive active switching technology, The PCS-985RE can still supervise rotor insulation even if no excitation voltage is applied. It has high sensitivity and the same sensitivity to any one-point earth fault within the rotor winding. The automatic and manual control function to electric brush ensure rotor earth fault protection can be applied to the brushless exciter units.

- Radiated amplitude-modulated

10Vm(rms), f=80MHz/160MHz/450MHz/900MHz

- Radiated pulse-modulated Fast transient disturbance tests

10Vm(rms), f=900MHz IEC60255-22-4:2002 (idt IEC 61000-4-4)

- Power supply, I/O & Earth terminals

Class IV, 4kV, 2.5kHz, 5/50ns

- Communication terminals

Class IV, 2kV, 5.0kHz, 5/50ns IEC60255-22-5:2002 (idt IEC 61000-4-5:1995) , Class III

Surge immunity tests

1.2/50us,

Functions

- Power supply, AC inputs, I/O terminals

2kV, line to earth;

Protection Function

Conducted RF electromagnetic disturbance

1kV, line to line IEC60255-22-6, Class III

- Power supply, AC, I/O, Comm. terminal

10V(rms), 150kHz~80MHz

fault waveform. (The file format of disturbance recorder is compatible with international COMTRADE file.) •

Communication •

2 RS-485 communication rear ports conform to IEC 608705-103 protocol or Modbus protocol.

3 optional Ethernet ports conform to IEC 60870-5-103 protocol over TCP/IP or IEC61850.

One-point earth-fault protection of rotor.

Features

Two-point earth-fault protection of rotor.

Definite-time control of electric brush.

Support browsing and modifying setting group and protection settings remotely.

Manual control of electric brush.

Binary input supervision.

Support checking protection state and resetting signal remotely.

Frequency regulation of external injected voltage.

Fault location.

The calculation of earthing resistance has nothing to do with the earthing position, so no dead area.

External injected voltage supervision.

High accuracy of the calculation of earthing resistance, and not affected by the capacitance between rotor winding and earth.

The calculation of earthing resistance is excitation-voltage independent, so PCS-985RE can monitor the insulation of rotor without excitation voltage.

Flexible rotor winding connection, double injection or single injection type can be selected. The earthing position can be measured by the former injection type.

Miscellaneous Function •

Self diagnostic test.

DC power monitoring and alarming.

Event Recorder including 1024 binary input change reports, 1024 self-supervision reports and 64 control reports.

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GPS clock synchronization: PPS (pulse per second) or IRIG-B signal via RS-485.

Disturbance recorder including 64 fault reports, and 8 waveforms. The maximal record time is up to 15s for single

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Feeder Protection

Function Index

Function

PCS-9611 Directional Overcurrent Protection The PCS-9611 relay is a protection, control and monitoring unit for various applications (such as overhead line, underground cable and transformer etc.) on solidly ground, impedance grounded, Peterson coil grounded and ungrounded system.

The PCS-9613 relay is a current differential protection and overcurrent protection, control and monitoring unit with auto-reclosing function for distribution feeder lines in solidly grounded, impedance grounded, Peterson coil grounded and ungrounded system.

PCS-9611

87L

Phase overcurrent protection

50P/51P

67P

Directional phase overcurrent protection Zero sequence overcurrent protection

√ √

50G/51G

67G

Negative sequence overcurrent protection

51Q

Sensitive earth fault protection

51SG

Directional sensitive earth fault protection

67SG

Undervoltage/overvoltage protection

27/59

47

Zero sequence overvoltage protection

59G

Underfrequency protection

81U

Overfrequency protection

81O

Rate-of-change of frequency

81R

Breaker failure protection

50BF

Auto-reclosing with sync-check and dead line/bus check

79/25

Dead zone protection

50DZ

46

Broken conductor protection

46BC

√ √

√ √

Thermal overload element

49

PCS-9691E Overcurrent Protection

Undercurrent protection

37

REF

The PCS-9691E overcurrent relay is designed for fast and selective protection, control and monitoring of feeders, shunt capacitor banks, reactors or motors etc. in directly grounded, impedance grounded, Peterson coil grounded or ungrounded system.

Switch-onto-fault logic

SOTF

Cold load pickup logic

CLP

CT failure supervision

CTS

VT failure supervision

VTS

FR

SOE

Restricted Earth Fault Protection

Fault Recorder Sequence of events recoding

√ √

Mechanical Protection

Interlocking logic for distribution busbar protection

Remote and local tripping/closing of breaker

Interlocking logic of breaker control

Voltage and current drift auto adjustment

Frequency tracking

Line voltage failure supervision

Tripping circuit supervision

Synchro-check voltage failure supervision

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PCS-9691E

Directional zero sequence overcurrent protection

Negative sequence overcurrent protection

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P CS-9613

Current differential protection

Negative sequence overvoltage protection

PCS-9613 Feeder Differential Relay

Functional Code

GPS clock synchronization

Self diagnostic

Modbus protocol

IEC 60870-5-103 and RS-485 ports

IEC 61850 protocol for station bus

IEC 61850-9-2 and GOOSE for process bus

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PCS-9611

Directional Overcurrent Protection

The PCS-9611 relay is a protection, control and monitoring unit for various applications (such as overhead line, underground cable and transformer etc.) on solidly ground, impedance grounded, Peterson coil grounded and ungrounded system. The PCS-9611 features a high performance functional library, programmable logic, configurable I/O and integrated frequencytracking. The PCS-9611 is designed based on advanced multiprocessor platform, fully complying with IEC 61850 station bus & process bus, supporting IEC 61850-8-1 MMS, GOOSE and IEC 618509-2 Sampling Value.

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Four-stage sensitive earth fault protection. (67SG/51SG) The sensitive earth fault protection can be controlled by directional element. IDMT curves complied with IEC and ANSI are provided.

Two-stage undervoltage protection and two-stage over voltage protection. (27/59) The voltage input can select either phase voltage or phaseto- phase voltage. VT failure blocking is integrated in this protection.

Six-stage overcurrent protection. (67P, 50P/51P) Phase overcurrent protection can be controlled by voltage control element, directional element and harmonic blocking element. IDMT curves complied with IEC and ANSI standard are provided. Six-stage neutral/ground overcurrent protection. (67G, 50/51G) Up to two groups of neutral (ground) overcurrent protections are provided. It can be controlled by harmonic blocking element and directional element. IDMT curves complied with IEC and ANSI standard are provided.

Two-stage zero sequence overvoltage protection. (59G) Zero sequence voltage could be set as external voltage injection or internal calculated voltage.

Thermal overload element. (49) This relay provides a thermal overload model using the RMS value of current.

Undercurrent protection. (37) One-stage undercurrent protection is for monitoring a motor or a capacitor.

Switch-onto-fault (SOTF) logic. Switch-onto-fault logic is used to clear fault during manually closing or auto-reclosing.

Cold load pickup logic (CLP) The logic is used to inhibit the selected protective elements for an appointed duration, or to increase the settings of the selected protective elements.

Mechanical Protection Up to 4 channels for mechanical protection are provided. It receives the mechanical inputs from a transformer tank and issues the tripping or alarm outputs with or without time delay.

Four-stage under-frequency protection, four-stage overfrequency protection and four-stage rate-of-change of frequency (81)

The rate-of-change of frequency could be set as increasing or decreasing via the setting, as well the duration used for rate-of-change calculation is settable.

Interlocking logic for distribution busbar protection. The protection of distribution busbar can be realized via GOOSE communication.

Breaker failure protection. (50BF) The relay will initiate re-tripping and adjacent breaker tripping during breaker failure. Four logics based on the phase current and the circuit breaker state is selectable.

Remote and local tripping/closing of the breaker. The breaker tripping/closing can be implemented remotely or locally.

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4-shot three-pole auto-reclosing with sync-check and dead line/bus check. (79/25) Synchronism check and dead line/bus check are both provided for auto-reclosing.

Interlocking logic of the breaker control. The interlocking logic of the breaker, isolator and earth switch is integrated.

Voltage and current drift auto adjustment. The relay will continually and automatically trace the voltage and current drift and adjust the zero point to a normal value.

Frequency tracking. Frequency tracking is integrated to accommodate the frequency shift in power system.

Fault locator. The relay has an integral fault locator that uses information from the current and voltage inputs to provide a distance to fault location feature.

Functions Protection and Control

One-stage negative sequence overvoltage protection. (47) Negative sequence overvoltage protection could be used to detect the unbalance situation.

Dead zone protection. (50DZ) Dead zone protection can operate when a fault occurs between CT and circuit breaker.

Two-stage negative sequence overcurrent protection IDMT curves complied with IEC and ANSI are provided.

Broken conductor detection. (46BC) The ratio of negative-sequence current to positivesequence current (Ι2/Ι1) is used to detect the broken conductor.

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Monitoring and Metering •

Metering of current, voltage, active power, reactive power, power factor, energy, frequency, and harmonic.

Circuit breaker monitoring.

CT failure supervision.

VT failure supervision.

Line voltage failure supervision.

Tripping circuit supervision.

Self diagnostic.

Fault Recorder.

Total 1024 SOE, including tripping, alarm, binary input change and human operation reports.

Total 64 oscillograms. (Compatible with COMTRADE

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Overcurrent protection can be controlled by directional protection, harmonic blocking element and voltage control element.

The relay provides optional RTD input module and DC mA input module for temperature detection.

This device constantly measures and calculates a large amount of analog quantities, such as phase voltage, phase-to-phase voltage, neutral voltage, phase current, neutral current, active power, reactive power, power factor and frequency etc.

The connector type can be selected as plug in/out terminal connector or screw terminal connector. The unique plug in/out terminal connectors from the relay rear panel to the terminal blocks on the rack or cabinet makes the onsite commissioning and replacement much easier than the traditional screw terminals when you do the commissioning.

format)

Communications •

Up to four 10Base-T/100Base-TX (RJ45) ports or two 100Base-FX ports with IEC 61850-8-1 MMS and GOOSE for non-time-critical message, IEC 60870-5-103 over TCP/ IP or DNP 3.0

Two RS-485 rear ports with IEC 60870-5-103

Up to Six 100Base-FX ports with IEC 61850-9-2 Sampling Value and GOOSE for time-critical message

One RS-485 rear port for clock synchronization

One RS-232 rear port for printer

1 faceplate RJ45 port for testing and setting

Clock synchronization via pulse, IRIG-B and SNTP

Features •

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Modularized hardware design enables an easy upgrade or repairs. Various optional function modules can satisfy various situations according to the different requirements of users.

Various methods of GPS time synchronization are supported in this relay, including SNTP, pulse per second (PPS) and IRIG-B synchronization.

This device can communicate with a SAS or RTU via different communication intermediates: Ethernet network, RS-485 serial ports. The communication protocol of this device is optional: IEC61850, IEC60870-5-103 or DNP3.0.

This device can detect the tripping circuit of the circuit breaker and monitor the operation (close or trip) time of a circuit breaker by checking the auxiliary contacts of the circuit breaker.

Complete event recording function is provided: 64 latest protection operation reports, 1024 latest supervision records, 1024 latest control operation records, 1024 latest user operation records and 1024 latest records of time tagged sequence of event (SOE) can be recorded.

The relay is compatible with multiple protocols- IEC61850 and IEC 60870-5-103 for station bus, GOOSE and IEC61850-9-2 for process bus.

The setting group can be switched by binary inputs.

PCS-9613

Feeder Differential Relay The PCS-9613 relay is a current differential protection and overcurrent protection, control and monitoring unit with auto-reclosing function for distribution feeder lines in solidly grounded, impedance grounded, Peterson coil grounded and ungrounded system. This relay can fully support the IEC61850 communication protocol and GOOSE function, and can completely meet the demands of a modern digitalized substation.

Functions Protection and Control •

Current differential protection (87L) A dedicated FO channel module is adopted for data interchange in the relay. The fault detector contains three independent elements: the DPFC (Deviation of Power Frequency Component) phase-to-phase current fault detector, the phase overcurrent fault detector and the

This device can sample the analog values from the conventional CT/VT, or receive the sampled values from electronic CT/VT via merging unit.

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zero sequence overcurrent fault detector. Superior anti CT saturation measure is utilized to insure no maloperation caused by CT saturation during external fault.

Six-stage phase overcurrent protection (50P/51P/67P) All overcurrent element, directional element, voltage control element and harmonic blocking element settings are independent for each of the first four stages. Stages 1, 2, 5 and 6 only have definite time characteristic. Stages 3 and 4 overcurrent protections can be set as either definite time (DT) or inverse definite minimum time (IDMT).

Synchronism check (25)

Auto-reclosing (three-pole) (79)

Mechanical protection(MR)

Remote control and measurement.

Voltage and current drift auto adjustment. The relay will continually and automatically trace the voltage and current drift and adjust the zero point to a normal value.

Six-stage zero sequence overcurrent protection (50G/51G/67G) Definite time (DT) and inverse definite minimum time (IDMT) zero sequence overcurrent protection are provided. The first four stages can be controlled by directional element and harmonic blocking element respectively. Negative sequence overcurrent protection (46) Two stages of negative sequence overcurrent protection are provided with definite time characteristic. Stage 2 can be set with either definite time characteristic or inverse definite minimum time characteristic. Broken conductor protection (46BC) The ratio of negative-sequence current to positivesequence current (Ι2/Ι1) is used to detect the broken conductor. Breaker failure Protection (50BF) The circuit breaker failure protection is specially applied for re-tripping the circuit breaker, when the relay operates, but the fault current is still remaining. Thermal overload protection (49) Thermal overload protection adopts the thermal overload model based on IEC 60255-8 standard, and the largest phase current is used for the thermal model. Undervoltage/Overvoltage protection (27/59) Undervoltage/Overvoltage protection has two stages. It can support all kinds of VT connection: three phase voltages (Ua, Ub, Uc), three phase-to-phase voltages (Uab, Ubc, Uca), two phase-to-phase voltages (Uab, Ubc), any one of three phase voltages or any one of three phase-to-phase voltages.

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Switch-onto-fault (SOTF) logic. Switch-onto-fault logic is used to clear fault during manually closing or auto-reclosing.

Monitoring and Metering •

Tripping circuit supervision.

CT failure detection logic.

VT failure detection logic.

Synchro-check voltage failure supervision.

Self diagnostic.

Fault Recorder.

Total 1024 SOE, including tripping, alarm, binary input change and human operation reports.

Total 64 oscillograms. (Compatible with COMTRADE format)

Features •

Fully recognizing the technology to integrate six functions into one device: protection, measurement, control, remote signaling, merging unit function and remote module functions, to improve the reliability. Definite time and inverse time characteristics of overcurrent protection are both provided.

Overcurrent protection could be supervised by directional element and voltage elements.

Constantly measures a large amount of analog quantities, or receive the sampled values from the electronic transformers, such as phase voltage, phase-to-phase voltage, neutral voltage, phase current, neutral current, active power, reactive power, power factor and frequency.

Monitor and record the operating times of opening/ closing circuit breakers.

Various methods of GPS time synchronization are supported, including SNTP, pulse per second (PPS) and IRIG-B synchronization.

Equipped with Ethernet ports with the IEC 61850 protocol and RS-485 ports with IEC 60870-5-103 protocol.

Complete event recording function is provided: 64 latest protection operation reports, 1024 latest supervision records, 1024 latest control operation records, 1024 latest user operation records and 1024 latest records of time tagged sequence of event (SOE) can be recorded.

Can communicate with a SAS or RTU via different communication intermediates: Ethernet network, RS-485 serial ports. The communication protocol of this device is optional: IEC61850, IEC60870-5-103 or DNP3.0.

Communications •

Up to four 10Base-T/100Base-TX (RJ45) ports or two 100Base-FX ports with IEC 61850-8-1 MMS and GOOSE for non-time-critical message, IEC 60870-5-103 over TCP/ IP or DNP 3.0

Two RS-485 rear ports with IEC 60870-5-103

One RS-485 rear port for clock synchronization

One RS-232 rear port for printer

1 faceplate RJ45 port for testing and setting

Clock synchronization via pulse, IRIG-B and SNTP

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Metering and monitoring

PCS-9691E

Overcurrent Protection

Tripping/Closing circuit supervision

Circuit breaker status monitoring

Operation time supervision of breaker

256 SOE records, including tripping, alarm, change of binary inputs and self-check.

Eight (8) wave records, up to 4.5 seconds for each wave record, compatible with COMTRADE format.

Supervision of tripping time, CBF starting current, CB switching counter, CB travelling time and internal relay fault.

Control

The PCS-9691E overcurrent relay is designed for fast and selective protection, control and monitoring of feeders, shunt capacitor banks, reactors or motors etc. in directly grounded, impedance grounded, Peterson coil grounded or ungrounded system.

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Functions Protection

Features •

On the premise of 32 samples per cycle, all data measurement, calculation and logic discrimination could be done within one sampling period. The event recording and protection logic calculation are completed simultaneously.

Definite time and inverse time of phase overcurrent protection are both provided.

Definite time and inverse time of zero sequence overcurrent protection are both provided.

This relay constantly measures and calculates analog quantities for metering including phase current and zero sequence current.

10 configurable binary inputs

7 binary outputs for DC voltage (including 4 configurable contacts), 9 binary outputs for AC voltage (including 6 configurable contacts)

This relay is equipped with two EIA RS-485 standardized electrical interfaces for uplink communication.

This relay can communication with SAS or RTU, the communication protocol of this device is IEC60870-5-103, Modbus or DNP3.0.

Event recording function: 32 latest fault reports (up to 8 records in a report), 64 alarm records and 256 records of time tagged sequence of event can be recorded.

Perfect fault and disturbance recording function: 3 latest fault waves. the fault and disturbance file format is COMTRADE.

This device can store settings, history reports and fault waves in a 2Mbit FRAM, which means the information will not be lost even if the power supply is switched off.

Three-stage phase overcurrent protection. (50/51P)

8 LEDs, including 4 configurable LEDs

Three-stage neutral overcurrent protection. (50/51G)

Local/remote opening/closing logic of breaker

Three-stage negative sequence overcurrent protection. (51Q)

Faceplate buttons for local control of breaker

Directional ground time overcurrent protection. (67G)

Breaker failure protection. (51BF)

Thermal overload protection. (49)

Broken conductor protection. (46BC)

Undervoltage/overvoltage protection. (27/59)

Multi-slot three-pole auto-reclosing (Up to 3 slots). (79)

Ten (10) available curves complied with ANSI and IEC standard. (IDMT)

Thermal model overload curve.

Voltage transformer supervision. (VTS)

Current transformer supervision. (CTS)

Current drift auto-adjustment

Communication and HMI •

One RS-232 port for testing

Two RS-485 ports for communication with SCADA

IEC 60870-5-103 DNP 3.0 serial, and MODBUS protocol

RCS-PC assistant software for testing

Clock Synchronization

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Motor Protection

PCS-9641

PCS-9641 Motor Protection

Motor Protection

The PCS-9641 relay is a protection, control and monitoring unit for various kinds of motors on solidly grounded, impedance grounded, Peterson coil grounded and ungrounded system.

The PCS-9641 relay is a protection, control and monitoring unit for various kinds of motors on solidly grounded, impedance grounded, Peterson coil grounded and ungrounded system. The PCS-9641 features high performance functional library, programmable logic, configurable I/O and integrated frequencytracking.

Function Index

Functional Code

PCS-9641

Function

Current differential protection

87M

rate-of-change of frequency

81R

Phase overcurrent protection

50P/51P

Reverse power protection

32R

67P

Under power protection

37P

50G/51G

Power factor protection (Out-of-step protection)

55

67G

Restart inhibit for starts per time interval

66

Sensitive earth fault protection

51SG

Starting-time supervision

48

Directional sensitive earth fault protection

67SG

CT failure supervision.

CTS

Negative sequence overcurrent protection

46

VT failure supervision

VTS

Broken conductor detection

46BC

Fault Recorder

FR

Breaker failure protection

50BF

Remote and local tripping/closing of breaker

37

Voltage and current drift auto adjustment

27/59

Frequency tracking

Directional phase overcurrent protection Neutral/ground overcurrent protection Directional neutral/ground overcurrent protection

Undercurrent protection Undervoltage protection and Over voltage protection Zero sequence overvoltage protection Negative sequence overvoltage protection Thermal overload element

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Functional Code

PCS-9641

Function

59G

Circuit breaker monitoring.

47

Tripping circuit supervision

49

GPS clock synchronization

RTD temperature protection

49RTD

Modbus protocol

Under-frequency protection,

81U

IEC 60870-5-103 protocol

Over-frequency protection

81O

IEC61850 protocol

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This relay is designed based on advanced multiprocessor platform, fully complying with IEC 61850 station bus & process bus, supporting IEC 61850-8-1 MMS and GOOSE.

Functions Protection and control •

Current differential protection. (87M) The current differential protection is for fast clearing of stator phase faults. Advanced CT saturation detection algorithms are incorporated for increased security during heavy faults.

Overcurrent protection. (67P, 50P/51P) Phase overcurrent protection can be controlled by voltage control element, directional element and harmonic blocking element. IDMT curves complied with IEC and ANSI standard are provided.

Neutral/ground overcurrent protection. (67G, 50/51G) Up to two groups of neutral (ground) overcurrent protections are provided. It can be controlled by directional element. IDMT curves complied with IEC and ANSI standard are provided.

Sensitive earth fault protection. (67SG/51SG) The sensitive earth fault protection can be controlled by directional element. IDMT curves complied with IEC and ANSI is provided.

Negative sequence overcurrent protection. (46) The negative sequence overcurrent protection reflects the unbalance current when asymmetrical fault occurs.

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Broken conductor detection. (46BC) The ratio of negative-sequence current to positivesequence current (Ι2/Ι1) is used to detect the broken conductor.

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Undercurrent protection. (37) The undercurrent protection is for monitoring a motor. Undervoltage protection and Over voltage protection. (27/59) The voltage input can select either phase voltage or phase-to-phase voltage. VT failure blocking is integrated in this protection.

Zero sequence overvoltage protection. (59G) Zero sequence voltage could be set as external voltage injection or internal calculated voltage.

Negative sequence overvoltage protection. (47) Negative sequence overvoltage protection could be used to detect the unbalanced situation.

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Breaker failure protection. (50BF) The relay will initiate re-tripping and adjacent breaker tripping during breaker failure. Four logics based on the phase current and the circuit breaker state is selectable.

Thermal overload element. (49) This relay provides a thermal overload model using the RMS value of current. RTD temperature protection. (RTD) The relay RTD option provides 6 programmable RTD inputs that are used for monitoring the stator, bearing and the ambient temperatures, every RTD input can be used for tripping output or alarm output. Under-frequency protection, overfrequency protection and rate-of-change of frequency (81U/O/R) The rate-of-change of frequency could be set as increasing or decreasing via the setting, as well as the duration used for rate-of-change calculation is settable. Reverse power protection. (32R) The reverse power protection is useful to detect conditions where the motor can become a generator.. Under power protection. (37P) The under power protection feature provides for sensitive detection of a loss of load condition,

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Power factor protection (Out-of-step protection). (55) The power factor protection is used in synchronous motors applications to detect out-of-synchronism conditions. Restart inhibit for starts per time interval. (66) The restart inhibit function prevents restarting of a motor when the motor is too hot and does not have a sufficient amount of thermal capacity available. Not allowing a restart without being tripped offline. Starting-time supervision. (48) The motor startup-time supervision function protects against excessive starting time and locked rotor conditions of motors during startup.

Remote and local tripping/closing of breaker. The breaker tripping/closing can be implemented remotely or locally.

Voltage and current drift auto adjustment. The relay will continually and automatically trace the voltage and current drift and adjust the zero point to a normal value.

Frequency tracking. Frequency tracking is integrated to accommodate the frequency shift in the power system.

Monitoring and Metering •

Metering of current, voltage, active power, reactive power, power factor, energy, frequency,.

Circuit breaker monitoring.

CT failure supervision.

VT failure supervision.

Tripping circuit supervision.

Self diagnostic.

Fault Recorder: 64 fault and disturbance records, and 8 motor startup wave records.

Total 1024 SOE, including tripping, alarm, binary input change and human operation reports.

8 motor startup reports, 64 protection operation reports, 1024 supervision alarm records, 1024 control operation records, 1024 user operation records.

Communications •

Up to four 10Base-T/100Base-TX (RJ45) ports or two 100Base-FX ports with IEC 61850-8-1 MMS and GOOSE for non-time-critical message, IEC 60870-5-103 over TCP/ IP or DNP 3.0

Two RS-485 rear ports with IEC 60870-5-103, MODBUS

Up to Six 100Base-FX ports with IEC 61850-9-2 Sampling Value and GOOSE for time-critical message

One RS-485 rear port for clock synchronization

One RS-232 rear port for printer

1 faceplate RJ45 port for testing and setting

Clock synchronization via pulse, IRIG-B and SNTP

Features •

Modularized hardware design enables an easy upgrade and repairs. Various optional function modules can satisfy various situations according to the different requirements of users.

This device can sample the analog values from the conventional CT/VT, or receive the sampled values from electronic CT/VT via the merging unit.

Overcurrent protection can be controlled by directional protection, and voltage control element.

The relay provides optional RTD input module and DC mA input module for temperature detection.

This device has powerful GOOSE functions, and the connection and cooperation between some devices can be realized without using electrical cables, to facilitate such functions as simple bus differential protection, overload interlock shedding function and backup automatic transfer function etc.

This device has fully realized the technology to integrate six functions into one device: protection, measurement, control, remote signaling, merging unit function and remote module functions, to improve the reliability.

This device can communicate with a SAS or RTU via different communication intermediates: Ethernet network, RS-485 serial ports. The communication protocol of this device is optional: IEC61850, IEC60870-5-103, DNP3.0 or MODBUS.

This relay can detect the tripping circuit of the circuit breaker and monitor the operation (close or trip) time of a circuit breaker by checking the auxiliary contacts of the circuit breaker.

Powerful fault and disturbance recording function is supported: 8 latest motor startup wave records, 64 latest fault or disturbance waves, the duration of a wave recording is configurable.

Various methods of GPS time synchronization are supported in this relay, including SNTP, pulse per second (PPS) and IRIG-B synchronization.

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Transfer & Synchronization

Function Index Function

PCS-9651 Automatic Transfer Relay The PCS-9651 continuously monitors the power supply lines of load and provides automatic transfer logic from a main source to backup source.

PCS-9655 High Speed Transfer Device The PCS-9655 high speed transfer device is used in power plants to ensure the continuous and reliable power supply for busbars.

PCS-9659 Auto Synchronizer The PCS-9691E overcurrent relay is designed for fast and selective protection, control and monitoring of feeders, shunt capacitor banks, reactors or motors etc. in directly grounded, impedance grounded, Peterson coil grounded or ungrounded system.

Functional Code

PCS-9651

ATS

Tripping circuit supervision

TCS

VT circuit supervision

VTS

Current transformer supervision

CTS

Sequence of events recoding

SOE

Automatic synchronizing

25A

Semi-automatic synchronizing

25SA

Manual synchronizing

25M

Remote/local control function

Circuit breaker status monitoring

Multi-generator paralleling

Self diagnostic

Voltage and current drift auto adjustment

Fault record

Clock synchronization

Normal manual switching

Accident switching

Loss-of-busbar-voltage switching

Circuit breaker unexpected tripping switching

Undervoltage load shedding switching

Switch-onto fault protection

MODBUS protocol

IEC 60870-5-103 and RS-485 ports

IEC 61850 protocol for station bus

IEC 61850-9-2 and GOOSE for process bus

Reserve energy auto-switching scheme

ATS

CT failure supervision

CTS

VT failure supervision

VTS

√ √

Circuit breaker monitoring

GPS clock synchronization

Fault Recorder Sequence of events recoding Self diagnostic

FR

SOE

MODBUS protocol

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PCS-9659

Automatic transfer switch

Remote control and measurements

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PCS-9655

IEC60870-5-103 and RS-485 ports

IEC61850-8-1 MMS & GOOSE for station bus

IEC61850-9-2 SV & IEC61850-8-1 GOOSE for process bus

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PCS-9651

Automatic Transfer Relay

The PCS-9651 continuously monitors the power supply lines of load and provides automatic transfer logic from a main source to backup source. If a fault occurred in any of the power supply lines, the PCS-9651 can discriminate the abnormal state and switch over the load from the faulty line to the normal line, to guarantee the continuous power supply to the load. Up to four typical switching modes are provided for selection. Besides, the remote/local control function is integrated in the unit. This device can fully support the IEC61850 communication protocol and GOOSE function, and can completely meet the demands of a modern digitalized substation.

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Functions

Features

Automatic transfer switch (ATS)

Remote/local control function

The voltages inputs and external binary inputs connecting to breaker auxiliary contacts are used to detect the abnormal state.

Circuit breaker status monitoring

Tripping circuit supervision (TCS)

It provides the RJ-45 faceplate port for testing and setting allowing easier commissioning and maintenance.

VT circuit supervision (VTS)

Current transformer supervision (CTS)

Self diagnostic

The device could receive the analog values from conventional CT/VT.

Voltage and current drift auto adjustment

64 operation reports

1024 supervision alarm records

1024 control operation records

1024 user operating logs

The connector type can be selected as plug in/out terminal connector or screw terminal connector. The unique plug in/ out terminal connectors from the relay rear panel to the terminal blocks on the rack or cabinet makes the onsite commissioning and replacement much easier than the traditional screw terminals when you do the commissioning.

64 fault and disturbance records (FDR)

1024 latest SOE records

Up to four 10Base-T/100Base-TX (RJ45) ports or two 100Base-FX ports with IEC 61850-8-1 MMS and GOOSE for non-time-critical message, IEC 60870-5-103 over TCP/ IP or DNP 3.0

Various methods of GPS time synchronization are supported in this relay, including SNTP, pulse per second (PPS) and IRIG-B synchronization.

The PCS-9651 is fully complied with IEC 61850 and provides the independent interfaces for station bus and process bus respectively, supporting IEC 61850-8-1 MMS, GOOSE.

Two RS-485 rear ports with IEC 60870-5-103

Up to Six 100Base-FX ports with IEC 61850-9-2 Sampling Value and GOOSE for time-critical message

One RS-485 rear port for clock synchronization

One RS-232 rear port for printer

1 faceplate RJ45 port for testing and setting

Clock synchronization via pulse, IRIG-B and SNTP

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PCS-9655

High Speed Transfer Device

Functions

Features

Normal manual switching function

Accident switching function

Loss-of-busbar voltage switching function

This device can provide all kinds of switching functions: normal manual switching, accident switching, loss-ofbusbar voltage switching and circuit breaker maloperation switching.

Circuit breaker unexpected tripping switching function

Undervoltage load shedding switching function

Switch-onto fault protection

This device also provides useful auxiliary functions such as two stages of undervoltage load shedding protection and the SOTF overcurrent protection.

Voltage and current drift auto adjustment

Self supervision

Voltage transformer supervision

The PCS-9655 adopts automatic frequency tracking technology in the busbar voltage measurement to calculate the frequency and the phase of busbar voltage fast and accurately.

The PCS-9655 supports different GPS clock synchronization, including communication messages, pulse per second, and IRIG-B synchronization.

The PCS-9655 can communicate with SAS or RTU using IEC60870-5-103 or Modbus.

Fault and disturbance recording function: 64 latest fault reports and 64 fault waves are provided and the duration of a fault ware is up to 25s. The fault wave format is compatible to COMTRADE.

The PCS-9655 can record 1024 Self-check alarm, 1024 Operating alarm and 1024 binary input change during operation.

Management The PCS-9655 high speed transfer device is used in power plants to ensure the continuous and reliable power supply for busbars. In normal operation, the power supply of busbar is provided by the main power supply branch, and the standby power supply is ready for switching. If the circuit breaker CB3 is closed, the standby power supply is in hot standby state; if the circuit breaker CB3 is opened, the standby power supply is in cold standby state.

If the main power supply has fault, the PCS-9655 will trip circuit breaker “CB1”, and the voltage of busbar is lost. Due to the mechanical inertia of motor load of busbar, the composite feedback voltage of busbar is decaying gradually. In this procedure, if the standby power supply is put into service at an improper moment, the voltage difference between busbar residual voltage and standby power supply voltage will have a greater impact on other equipment in the power plant. Then the switching operation is failed, and the busbar voltage is absolutely lost.

Circuit breaker status monitoring

Circuit breaker control

64 Fault records and 64 Disturbance records

1024 SOE records, latest records of following elements state changing: operating abnormality alarm elements, self-check alarm elements, protection elements and binary input elements.

The PCS-9655 high speed transfer device can select the optimal moment for switching the standby power supply into service to ensure the safety and reliability of switching operation.

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Functions

PCS-9659

Auto Synchronizer

Automatic synchronizing (25A)

Semi-automatic synchronizing (25SA)

Manual synchronizing (25M)

Multi-generator paralleling solution: capability of 8 circuit breakers’ synchronization. To any of the circuit breakers, frequency and voltage regulation can be done separately.

Communications •

Up to four 10Base-T/100Base-TX (RJ45) ports or two 100Base-FX ports with IEC 61850-8-1 MMS for nontime-critical message, IEC 60870-5-103 over TCP/IP or MODBUS TCP.

Two RS-485 rear ports with IEC 60870-5-103 or MODBUS RTU.

One RS-485 rear port for clock synchronization

Blocking signal to other equipments

One RS-232 rear port for printer

Receive blocking signal from other equipments

1 faceplate RJ45 port for testing and setting

Clock synchronization via pulse, IRIG-B and SNTP

Monitoring

PCS-9659 is a digital synchronizer that determines the proper time to initiate closing of the circuit breaker to parallel a generator and bus, or to reclose a line. In order to fulfill different application requirements, it offers three synchronizing modes: automatic synchronizing, semi-automatic synchronizing and manual synchronizing. By monitoring frequency, voltage and phase angle, the PCS-9659 provides correction signals to the governor of prime mover and voltage regulator of generator for voltage matching and frequency matching.

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Automatic Synchronizing Mode: The closing command is issued via remote control center. PCS-9659 monitors slip frequency (frequency difference), slip speed, voltage difference and phase angle difference, issues control signal to adjust frequency and voltage of the generator for voltage matching and frequency matching and gives close command to the breaker at the appropriate moment. Semi-automatic Synchronizing Mode: The closing command is issued manually to initiate synchronism process, the other functions are provided automatically just the same as automatic synchronizing mode. Manual Synchronizing Mode: According to the indicator lights of voltage difference and frequency difference in the Synchronizing meter, and the value of voltage difference and frequency difference on the LCD screen, the operator controls the speed and voltage of the generator as well as the closure moment of the circuit breaker.

Low voltage alarm at system side

Low voltage alarm at the side to be connected

PT circuit failure alarm at system side

PT circuit failure alarm at the side to be connected

Synchronous mode error alarm

Over voltage alarm at the side to be connected

Synchronization failure alarm

Synchronization counts error alarm

Remote startup error alarm

Self diagnostic.

Fault Recorder.

Total 1024 SOE, including closing, alarm, binary input change and human operation reports.

64 closing records with oscillograms compatible with COMTRADE.

Features •

High performance hardware assures real time calculation of all relays in each sample interval. Modularized hardware design enables an easy upgrade or repairs.

PCS-9659 adopts double sampling and independent calculation

Frequency tracking technology is adopted. By the aid of that, real-time value of frequency, voltage and phase are calculated with high precision on every sampling point.

Precise capture of synchronization point insures the phase angle error of closing is less than or equal to 0.5°by the mode of difference frequency synchronization.

PCS-9659 can automatically memorize the operation time of closing circuit.

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Arc Protection

PCS-9656

PCS-9656 Arc Protection System

Arc Protection

The PCS-9656 Arc Protection provides a fast busbar protection in substations, power plants and industrial enterprises. In case of short circuit faults in switchgear, the arc faults in the protected area which is covered by arc sensors can be quickly cleared via arc protection, avoiding harm to personnel and assets. The arc protection uses arc sensors to detect the arc light caused by short circuit faults.

The PCS-9656 Arc Protection provides a fast busbar protection in substations, power plants and industrial enterprises. In case of short circuit faults in switchgear, the arc faults in the protected area which is covered by arc sensors can be quickly cleared via arc protection, avoiding harm to personnel and assets. The arc protection uses arc sensors to detect the arc light caused by short circuit faults. PCS-9656 Arc Protection can acquire the incoming line currents and arc flash signals via localized arc sensors to reliably discriminate the arc faults. Up to 12 current inputs can be integrated in one unit. It integrates the protection calculation, tripping output, event recording, and human-machine interaction etc. This device can be installed in a protection panel or local switchgear. PCS-9656SH-30-I Arc Sensor is locally installed in appropriate points on the case of the cubicles inside of the switchgear, to transmit arc signals to arc protection, which will perform optic-electric conversion. The optical signal transmission between sensors and arc protection can avoid electromagnetic interference and improve reliability during transmission.

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Typical Applications PCS-9656 Arc Protection employs the modular structure and supports up to 24 arc sensors in one unit. The modular structure makes the on-site replacement much easier. In case the applications require more than 24 sensors several units can be combined to realize the arc protection. . Up to 12 current inputs are provided in one unit for incoming lines. Flexible hardware configuration based on modular structure can be tailored according to specific site requirements. Single-unit or multi-unit arc protections are supported by PCS9656 relays. Single-unit protection can provide up to 24 arc sensors, as well multi-unit protection can provide over 24 sensors. Series connection of several units can be performed to realize the protection with 24+ arc sensors, implementing multi-unit arc protection. Up to 3 point-to-point optical ports are provided in one unit for series connections among the units. Typical applications are as follows: •

Single Busbar The single-unit or multi-unit of PCS-9656 can be chosen according to the number of bay units.

Single Busbar with Section, no more than 24 Sensors

Single Busbar with Section, Over 24 Sensors

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Features

Figure 1. PCS-9656 in single busbar application

Figure 2. PCS-9656 in single busbar with serction, no more that 24 sensors

The innovative technology of Deviation of Power Frequency Component (DPFC) is adopted in this relay. The current criteria based on DPFC technology utilize the change-of-current to realize the fast detection of faults.

The relay provides both single-criteria (arc) and dualcriteria (current and arc) to guarantee fast and reliable operation. When dual-criteria is enabled, the typical operation time (including output relay time) is less than 10ms.

The passive optic sensor, based on photometry cosine principle, realizes the analog optic signal transmission and has a strong immunity against interference.

The tripping outputs can be configured via tripping matrix to set different tripping zones. The relay can trip different zones sequentially in order to minimize the outage area.

Up to six breaker failure protections (50BF) are integrated in this relay. Two criteria can be selected for breaker failure protection: one is circuit breaker position; the other is both circuit breaker position and feeder currents.

Clock synchronization supports pulse-per-second, SNTP and IRIG-B.

Arc sensor continuously monitors ambient light intensity during normal service state. This device will continuously track ambient light, and automatically change operating threshold.

Continuous self-diagnostics is integrated in this relay, including hardware/software self-diagnostic, communication monitoring and arc sensor connection monitoring.

Up to four 100Mbps Ethernet ports or two RS-485 serial ports are provided for SCADA communication, complying with IEC 61850-8-1 MMS, IEC 60870-5-103 and DNP 3.0

Fault locator function is provided in this relay. Fault position and fault information can be displayed on the LCD screen.

Simulation outputs without current/voltage injection are provided to make on-site maintenance easier.

Tripping outputs adopt high-speed contacts using combined IGBT and output relay, the delay time of output contacts is less than 1ms. As well, the conventional output contacts can be supplied according to customer specifications.

Up to 64 trip reports, 1024 self-diagnostic reports,1024 logging reports and 1024 SOE are provided.

Up to 64 fault oscillograms compatible with COMTRADE format are provided, each oscillogram includes AC quantities, Binary Inputs/Outputs and arc intensity.

Figure 3. PCS-9656 in single busbar with serction, over 24 sensors

Functions Protections •

Arc Protection

Breaker Failure Protection for up to 6 breakers (50BF)

64 trip reports

1024 self-diagnostic reports

Monitoring

1024 logging reports

Arc intensity supervision

1024 SOE

CT failure supervision

64 fault records with oscillograms compatible with

Transfer/Receive module supervision

Self-Diagnostic

Phase current: Ia, Ib, Ic

Sequence current: positive/negative/zero sequence current (I1, I2, I0)

Phase angle: Ia^Ib, Ib^Ic, Ic^Ia

Power supply

110VDC/220VDC

Burden

<15W (Quiescent condition) <20W (Quiescent condition)

Recording •

Measurement

Technical Data

COMTRADE

Communication •

Up to four (4) Ethernet ports for automation (Optional)

Two (2) RS-485 serial ports for automation

One (1) faceplate RJ-45 port for commissioning

Complying with IEC 61850-8-1 MMS, IEC 60870-5-103

24 optical signal inputs; 6 data transmission ports

AC Inputs

Outputs

21 BI, 110VDC/220VDC 12 current inputs, 1A/5A optional, < 0.2VA/phase, @In Thermal withstand capability: 3In continuously 30In for 10s 100In for 1s 11 conventional output; 6 fast output; 1 normally closed device blocking signal contact; 1 normally open device alarm signal contact; Rated voltage: 250Vac/dc; making current: 5A

Operation time

<10ms (optical and electric dual criteria; including relay operation time)

Working temperature

-40°C ~ +70°C

Mechanical dimensions

247 x 177 x 234 (unit: mm) (W x H x D)

Relative humidity

5% ~ 95%, neither dewing nor icing inside equipment

Atmospheric pressure

70kPa ~ 106kPa

and DNP 3.0

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Digital Substation

PCS-221

PCS-221 Merging Unit Merging units are used to sample AC analog values and transmit the sampled values(SV) to protection devices, bay control units(BCU) or electric meters through optical communication channels based on the IEC61850-9-2 protocol or IEC60044-8 protocol.

Merging Unit

PCS-222 Circuit Breaker Controller The PCS-222 is an intelligent terminal used to control primary switching devices, whichinclude the circuit breaker and main transformer, in the digital substation at all voltage levels.

Merging units are used to sample AC analog values and transmit the sampled values(SV) to protection devices, bay control units(BCU) or electric meters through optical communication channels based on the IEC61850-9-2 protocol or IEC60044-8 protocol.

PCS-223 CB Online Monitoring Unit The PCS-223 circuit breaker(CB) online monitoring unit provides the online monitoring of circuit breaker and switches in the digital substations at all voltage levels.

PCS-9250-EGI/EAI Electronic CT/VT To keep pace with the increasing demands of transmission capacity and rising system voltage, NR Electric has pursued advanced research on electronic CTs and VTs to ensure maximum reliability and availability in the applications of metering and protection relays.

Functions •

IEC61850-9-2 sampled value transmission

IEC60044-8 sampled value transmission

GOOSE transmission/reception

GMRP function

Voltage and current synchronization

IEC60044-8 voltage sampled value reception from a busbar MU

Voltage transfer

Data synchronization

Features •

Ahigh performance multi-DSP hardware structure is adopted in this device.Therefore, the device can process real-time data with high speed and high precision.

Modularized hardware design allows for easy upgrade or maintanaice of the device by qualified service technicians.

Various function optional modules satisfy various scenarios according to the different requirements of each user.

The adoption of high precision 16 bits A/D converter ensureshigh precision measurement calculations. Two A/D converters are intergrated in a single AC sample channel, and the sampling rate is 80 samples per fundament wave cycle. The real-time data calculation can be completedwithin one sampling period.

Afriendly and convenient human machine interface (HMI) display is provided for the user to view the status of thedevice.

Various methods of GPS time synchronization are contained in this device.These includeIEEE1588, pulse per second (PPS) and IRIG-B synchronization.

This device can support several communication protocols, which are adopted in the modern digital substation. For example, IEC61850-9-2LE and IEC61850-8 (GOOSE).

Perfect event recording function: 128 latest binary bit change reports, and128 latest device self supervision

PCS-9250-OAI Optical CT The PCS-9250-OAI Fiber Optic CT (FOCT) is a passive optical current transducer; it uses light to accurately measure currents on high voltage systems. The sensor at the high voltage side of the passive optical CT is composed of insulating materials such as optical fiber, glass, etc.

reports.

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Data synchronization Input sampling signals, such as three-phase current and voltage, need to be synchronized if the merging unit is connected to several electronic CTs/VTs and electro-magnetic CTs/VTs. This can be solved either by GPS PPS, or by angle adjustment interpolation. The GPS PPS signal can gradually adjust the sampling interval of all intelligent sampling modules through the merging unit to realize synchronous sampling automatically. However, the synchronization accuracy of this method relies on the integrality and the accuracy of GPS PPS. Any loss of GPS PPS may directly influence the synchronization accuracy. The other way to synchronize the data sampling is using angle adjustment interpolation, which does not rely on the GPS signal, thus has higher reliability. In practice, the mentioned two methods can be used in combination to achieve better accuracy.

Model

Connection to protection & control devices Merging units and protection & control devices are usually connected through optical fibers based on IEC61850-9-2 or IEC60044-8 protocol. When using IEC60044-8 protocol, the merging unit only supports point-to-point communication with a speed of 2.5Mbit/s or 10Mbit/s.When the IEC618509- 2 protocol is adopted, it is compatible with both Ethernet communication and point-to-point communication. The pointto-point communication is usually applied to the protection and control devices, which have high requirements on real-time data sampling. The Ethernet network communication can be applied to bay control units and metering devices, which have less requirements on real-time data sampling. In point-to-point communication, it is much easier to use Manchester code than Ethernet technology. Thus, it is recommended to use IEC600448 protocol to realize the communication between merging units and bay level devices in practical applications.

Description

Functions and Features

PCS-221G

Merging unit for transmission line, main transformer application,

regular data sampling

PCS-221N

Merging unit for busbar application

regular data sampling

PCS-221C

Merging unit for transmission line, main transformer application

digital data sampling for GIS application

PCS-221D

Merging unit for busbar application

digital data sampling for GIS application

PCS-221E

Merging unit for transmission line, main transformer application

digital data sampling for AIS application

Analog Voltage Standard Phase rotation Nominal frequency (fn) Nominal range Rated phase-to-phase voltage (Un) linear to Thermal withstand capability

Binary Inputs Standard Rated voltage Rated current Pickup voltage Dropout voltage

IEC 60255-1:2009 110V 1.1mA 60.5V~77V 50% of pickup voltage

Maximum permissive voltage

300Vdc

Withstand Resolving time for logic input

2000VAC, 2800VDC(continuously) <1ms

Output mode Maximal working voltage Test voltage across open contact Continuous carry

Technical Data

Pickup time Drop-off time Electrical life

Power Supply

GOOSE BO accuracy

Rated Voltage Voltage Range Permissible AC ripple voltage

110Vdc or 220 Vac 80%Un~120%Un ≤15% of the nominal auxiliary voltage <20W <25W

Burden

Quiescent condition Operating condition

220V 2.2mA 121V~154V

Tripping contact, Signal contact, Goose BO Tripping contact 380Vac 250Vdc

Signal contact 380Vac 250Vdc

1000V RMS for 1 minute

1200V RMS for 1 minute

5A@380Vac 8A@380Vac 5A@250Vdc 8A@250Vdc 10A@3000ms 6A@3000ms 15A@500ms 20A@500ms 30A@200ms 30A@200ms 1.20A @ 48Vdc 0.65A @ 48Vdc 0.30A @ 110Vdc 0.50A @ 110Vdc 0.15A @ 220Vdc 0.25A @ 220Vdc <8ms (Typical 3ms) <10ms <5ms <10ms 10000 times 10000 times GOOSE delay in device (1.6~2.4ms) Direct connection: us Internet connection: 3ms (Device delay)+ 6~8ms (relay pickup time)

Enclosure dimensions (W°¡H°¡D)

482.6mm°¡177.0mm°¡291.0mm

Mounting Trepanning dimensions (W°¡H) Housing color Protection class: IEC 60255-1:2009

Flush mounted 450.0mm°¡179.0mm, M6 screw Silver grey

< 0.25VA/phase

IEC 60255-27:2005

Front side

IP40, up to IP51 (Flush mounted)

Phase rotation Nominal range Rated Current (In) Linear to

ABC fn±5Hz 1A 0.05In ~ 40In

Other sides

IP30

Rear side, connection terminals Pollution degree

IP20 2

Thermal withstand capability Burden

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Thermal withstand capability

4In

for 10s

30In

for 1s for half a cycle

200In 250In <0.15VA/phase

250V 2.5mA 121V~154V

Mechanical Specifications

Analog Current

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125V 1.25mA 60.5V~77V

Binary Outputs

Breaking capacity (L/R=40ms)

IEC 60255-11:2009

continuously 10s 1s

Burden

Short duration current

Standard

IEC 60255-6, IEC60288 ABC 50Hz, 60Hz fn±5Hz 100~130V 200V (Broken delta for residual voltage) 1~170V 1~233V 200V 220V 260V 380V 300V 420V < 0.20VA/phase @Un < 0.8VA/phase@Un

5A

< 0.25VA/phase

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Ambient Temperature and Humidity Range Standard Operating temperature Transport and storage temperature range

IEC 60255-1:2009 -40°C to +70°C Note: The operating temperature of LCD is -20°C ~ +70°C -40°C ~ +70°C

Permissible humidity

5% ~ 95%, condensation not permissible

Altitude

<3000m

Per IEC 60255-22-3:2007 class III Frequency sweep Radiated amplitude-modulated

Radio frequency interference tests

Radiated amplitude-modulated 10V/m (rms), f=80MHz/160MHz/450MHz/900MHz

Communication Port

Radiated pulse-modulated

- Sampled Value Transmission Channel Optical Ethernet

Optical Ethernet

10V/m (rms), f=80…1000MHz Spot frequency

Characteristic Connector typel Transmission standard Fibre type Transmission distance Wave length Protocol Transmission power Minimum receiving power Margin

Glass optical fiber LC 100Base-FX Multi mode <2km 1310nm IEC61850-9-2 or IEC60044-8 Min. -20.0dBm Min. -30.0dBm Min +3.0dB

- Time Synchronization Interface Medium Optical RS-485 (EIA)

Optical Ethernet

Fast transient disturbance tests

Surge immunity test

Conducted RF Electromagnetic Disturbance Power Frequency Magnetic Field Immunity

Parameters Port number Connector type Transmission distance Timing standard Port number Connector type Transmission distance Timing standard

1 ST < 2000m PPS, IRIG-B 1~2 LC < 2000m IEEE1588

Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity

Auxiliary power supply performance

10V/m (rms), f=900MHz Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV Per IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz Per IEC 61000-4-8:2001 class V, 100A/m for 1min, 1000A/m for 3s Per IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008 Voltage dips: Up to 300ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting

Type Test Electrical Tests Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

Electromagnetic Compatibility 1MHz burst disturbance test

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV

Electrostatic discharge test

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Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV

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PCS-222

Time between receiving a GOOSE message and corresponding at output relay is less than 7ms. This is normally not affacted by a GOOSE network storm.

This device adopts fully enclosed relays, which have high impedance and low power consumption, thus power consumption and heat dissipation are reduced. Improvingthe security of the device.

The device provides flexible communication modes. It is equiped with 15 independent GOOSE interfaces and 1 RS232 commissioning port. Furthermore, it supports the new generation substation communication standard IEC61850.

Supporting IRIG-B synchronization via fiber optical interface and IEEE1588 time synchronization and 256 latest local operation records.

A ambient temperature and humidity measuringfuncionis integrated.

Circuit Breaker Controller The PCS-222 is an intelligent terminal used to control primary switching devices, whichinclude the circuit breaker and main transformer, in the digital substation at all voltage levels. It supports realtime GOOSE communication, and can realize tripping and closing of circuit breakers and switches by matching protection and BCU. It can locally acquire binary signals of primary equipment such as breakers and switches at the same time. It can meet the requirement of GOOSE tripping by pointto-point mode. The device can be installed outdoors nearby the primary equipment or connected to the protection & control devices in the control room via optic GOOSE network. Special cabinets are designed for the Circuit Breaker Controllers to fulfill the requirements of dust-proof, humidity-proof, and radiation

This device provides 54 binary inputs. It can locally acquire binary quantities such as breaker position, switch position, and signals from thecircuit breaker mechanism and main transformer body. Then it can upload them to a corresponding protection device or BCU via GOOSE network.

Features •

Functions Tripping and closing of circuit breakers This device receives various GOOSE signals from protection devices, including tripping signals; both initial and non initial AR,and reclosing signals.Then the device drives corresponding output relays to convert GOOSE signals to output. •

Remote control outputs This device provides 33 binary outputs. In addition to tripping/closing and blocking the outputs from the circuit breaker, it also has remote control tripping, closing and blocking contacts for four disconnectors and four earth switches.There are 24 output contacts in total.

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Technical Data Power Supply Standard Voltage Range Permissible AC ripple voltage

IEC 60255-11:2008 88 to 300 Vdc or 88 to 264 Vac ≤15% of the nominal auxiliary voltage <35W <50W

Quiescent condition Operating condition

Burden

Binary Inputs

protection.

Remote signal inputs

All plug-in modules in this device can be smoothly upgraded to keep compatible with UAPC platform. Therefore, providing a solid protection for users' investment in equipment over a long period. The device adopts high-performance DSP, internal highspeed bus, and intelligent I/O. Both hardware and software adopt modular design, allowing flexible configuration, general module for both plug-in module and software modules, and easy expansionand maintenance. Therefore, the number and types of spare plug-in modules that auser needs to keep for replacement are largely reduced. This device can receive GOOSE signals, such as protection tripping/closing, manual closing/tripping of BCU, control of disconnecters and earth switches, and output of corresponding contacts. It can acquire and upload the position of breakers/ disconnecters/earth switches, breaker body signals, etc.

Standard Rated voltage Rated current Pickup voltage Dropout voltage Maximum permissive voltage Withstand Resolving time for logic input

IEC 60255-1:2009 24V 30V 1.2mA 1.5mA 13V~17V 17V~21V 55% of pickup voltage

48V 2.4mA 26V~34V

110V 1.1mA 60.5V~77V

125V 1.25mA 60.5V~77V

220V 2.2mA 121V~154V

250V 2.5mA 121V~154V

120% rated voltage 2000VAC, 2800VDC(continuously) 1ms

Binary Outputs Item Output mode Continuous carry

Tripping contact Potential free contact 8A@380V AC 8A@250V DC

Pickup time

<10ms

Drop-off time

<8ms 10A for 3000ms 20A for 500ms 0.7A @ 48Vdc , L/R=40ms 0.3A @ 110Vdc, L/R=40ms 0.2A @ 220Vdc, L/R=40ms 380V AC 250V DC 1200V RMS for 1minute

Short duration current Breaking capacity (L/R=40ms) Maximal working voltage Test voltage across open contact

Signal contact

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Mechanical Specifications Enclosure dimensions (W°¡H°¡D)

482.6mm°¡177.0mm°¡291.0mm

Mounting Trepanning dimensions (W°¡H) Housing color Protection class: IEC 60255-1:2009

Flush mounted 450.0mm°¡179.0mm, M6 screw Silver grey

Front side

IP40, up to IP51 (Flush mounted)

Other sides

IP30

Rear side, connection terminals Pollution degree

IP20 2

PCS-223

Ambient Temperature and Humidity Range Standard Operating temperature Transport and storage temperature range

IEC 60255-1:2009 -40°C to +70°C Note: The operating temperature of LCD is -20°C ~ +70°C -40°C ~ +70°C

Permissible humidity

5% ~ 95%, condensation not permissible

Altitude

<3000m

CB Online Monitoring Unit

Communication Port - For Process Level Characteristic Connector typel Fibre type Transmission distance Wave length Transmission power Minimum receiving power Margin

Glass optical fiber LC Multi mode <2km 1310nm Min. -20.0dBm Min. -30.0dBm Min +3.0dB

The PCS-223 circuit breaker(CB) online monitoring unit provides the online monitoring of circuit breaker and switches in the digital substations at all voltage levels. It can locally collect the operation signals of circuit breakers and switches and send the data to the substation automation system. The device supports

The PCS-223 provides real-time monitoring of the circuit breaker energy charging motor current. If an abnormal operation current is detected, the device will issue an alarm, and trip the motor operating circuit selectively.

IEC61850-9-1 MMS and GOOSE. •

Acquisition of motor current for isolator

This PCS-223 providesrealtime monitoring for themotor current of theisolator. If an abnormal operation current is detected, the device will issue an alarm, and trip the motor operating circuit selectively. Monitoring of circuit breaker operation characteristics

- For Synchronization Port Characteristic Connector typel Fibre type Wave length Minimum receiving power Margin

Glass optical fiber ST Multi mode 820nm Min. -25.0dBm Min +3.0dB

- For Debug Port Type Baud rate Safety level

Functions •

Acquisition and supervision of SF6 pressure

Acquisition and supervision of SF6 temperature This device acquires SF6 temperature via sensors and will issue an alarm if thetemperature exceeds the threshold.

Acquisition and supervision of SF6 moisture This device acquires SF6 moisture via sensors and will issue an alarm if moisture levels exceed the threshold.

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The device acquires the operation curve of circuit breaker via offset sensor to detect the potential problem of circuit breaker, and to issue an alarm.

This device acquires SF6 pressure via sensors and will issue an alarm if the pressureexceeds the threshold.

RS-232 9600bps Isolation to ELV level

Acquisition of circuit breaker energy charging

Mechanical service life of circuit breaker The device can count the numbers of circuit breaker operations.

Electrical service life of circuit breaker The PCS-223 can estimate the remaining electrical service life of circuit breaker through the monitoring of primary current.

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Features •

PCS-223A is a new generation intelligent online device that fully supports digital substation. This device adopts latest UAPC platform developed by NR Electric and supports GOOSE and MMS communication.

Flexible communication mode is provided with 2 independent optical Ethernet interfaces and 1 RS-232 debugging port. New generation substation communication standard IEC61850 is supported.

UAPC platform is designed for service life up to 10-15 years. Device cards can be smoothly upgraded as required and consistent with the platform, so as to provide long-term stable guarantee of user equipment investment.

Fiber optical IRIG-B code timing is supported and 1 fiber optical IRIG-B time code input interface is provided (also supporting PPS).

Latest local 256 operation reports can be recorded.

This device adopts integrated and fully enclosed chassis, so that resistance to interference reaches highest grade of various EMC standards.

This device has passed severe high temperature test, low temperature test, and EMC test, and can operate in severe outdoor environment.

The device adopts high performance DSP, high-speed internal bus, modular design of hardware and software, and flexible configuration. It features general purpose cards and software modules, easy expansion, easy maintenance, fewer types of spares, and easy replacement. The device adopts fully sealed, high impedance, low power consumption imported relays, to reduce device power consumption and heat generation, and improve device safety.

PCS-9250-EGI/EAI Electronic CT/VT

To keep pace with the increasing demands of transmission capacity and rising system voltage, NR Electric has pursued advanced research on electronic CTs and VTs to ensure maximum reliability and availability in the applications of metering and protection relays. ECTs/EVTs have the advantages of no magnetic saturation, none ferromagnetic resonance, large dynamic measuring scope, wide frequency band and compact structure. NR Electric’s electronic CTs/VTs are suitable for both gasinsulated switchgears and air-insulated switchgears. Furtheremore, they have been tested in the laboratory and been successfully put in-service in real substation applications worldwide.

Electronic CT/VT in GIS Application The electronic CT/VT for GIS can be applied to a 110kV (220kV, 330kV or 500kV) gas insulation switch (GIS) for measuring primary current and voltage. The output signal is sent to digitizing measuring devices, bay control units and protective relays. Electronic CT/VTs can be installed both indoor and outdoors. Electronic CT/VTs in GIS application are composed of the following three parts:

Figure 1. Electronic CT/VT in GIS Application

Main Body: The main body includes transformer tank, adapterflange, insulation salver, primary conductor, builtin current and voltage sensor. The space between primary conductor and the transformer tank is filled with SF6 insulating gas. Primary Sensor: The primary sensor is composed of two duplicated sensors, each of which include one low power CT (LPCT), one air core coil and one coaxial capacitor voltage divider. Remote end module: The electronic CT/VT for GIS is composed of two duplicated remote end modules. These are used to receive and process output signals for low power CTs, air core coils and the capacitor voltage divider. The output signals of remote end modules are transmitted to merging units through optical fibers. Primary sensors and remote end modules are all installed at the low voltage side with a duplicated configuration.

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Electronic CT/VTs in AIS Applications

Electronic CT/VT Groups in AIS Applications

Electronic CT/VTs in AIS applications can be applied to 110kV (220kV, 330kV or 500kV) substations for primary current and voltage measurement. The output signals are sent to digital measurement devices, bay control units and protective relays. Electronic CT/VTs can be installed both indoor and outdoors.

Electronic CT/VT groups are integrations of ECTs and EVTs used in AIS application. The device is composed of the following four parts:

Figure 2. ECT/EVT in AIS Application

Primary current sensors: Primary current sensors are placed at the HV side. They include one low power CT, two air core coils and one HV current draw-out coil.

Primary sensor: The primary sensor includes one current divider and one air core coil. The current divider is used to measure DC current and the air core coil is used to measure harmonic current. Remote modules: DC electronic CTs have three remote end modules, which can backup each other to guarantee high reliability. The remote module receives and processes output signals from the current divider and the air core coil. Remote modules produce serial digital optical signals as their output.

Dual remote electronic modules: Dual remote electronic modules are located at the high voltage side. They receive and process the output signals of low power CTs and the air core coil. Remote electronic modules produde series digital optic signals as their output.

Optic insulator: The optic insulator is composed of a solid suspended composite insulator with eight built-in multimode optical fibers. Of these, six are use to transmit laser and digital signals, and the other two serve as standby optic fibers.

Capacitor voltage divider: The capacitor voltage divider converts high voltage into low voltage signals and sends them to the remote modules for processing. It also can be used as a communication carrier device.

Merging unit: Merging units are placed in the control room to provide laser power supply and receive three-phase current and voltage signals. The output of merging units is sent to the protection and control devices using IEC60044-8 or IEC618509-1/2 protocols. Merging units are connected to remote modules

Merging unit: Merging units are placed in control rooms to provide laser power supply and receive three-phase current and voltage signals. The output of merging units is sent to the protection and control devices using IEC60044-8 or IEC618509-1/2 protocols.

Primary sensor: The primary sensor is composed of one low power CT, two air core coils and one HV current energy acquisition coil. It is installed at the high voltage side. Dual remote electronic modules: Each dual remote electronic module is located at the high voltage side. It receives and processes output signals for low power CT and air core coils. Remote electronic modules produde digital optic signals as their output.

DC Electronic CTs DC electronic CTs are intended for applications in HVDC converter stations. They measure DC current, harmonic current, and output digital signals for the protection and control devices in the converter station. The DC electronic CTs are composed of the following four parts:

Optic insulator: The optic insulator is composed of a solid prop composite insulator with eight built-in multimode optical fibers. Of these, four are used to transmit laser and digital signals, the other four serve as standby optic fibers. Merging unit: Merging units are placed in the control room to provide laser power supply and receive three-phase current and voltage signals. The output of merging unit is sent to the protection and control devices using IEC60044-8 or IEC618509-1/2 protocols.

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Medium and low voltage electronic CT/VTs are installed in 10kV-35kV switchgear cabinets or outdoors to measure primary current and voltage. The output signals are delivered to digital measurement devices, bay control units and protective relays. Medium and low voltage electronic CT/VTs are composed of low power CTs (LPCTs), transport modules, remote onsite acquisition units, etc.

via optic fibers.

Figure 4. Medium and Low Voltage Electric CT/VT

ECT in AIS Applications ECTs in AIS applications are composed of the following four parts:

Medium and Low Voltage Electronic CT/VTs

Technical Data Electronic CT/VT for GIS Application Max. operation voltage Um(kV) Withstand voltage (kV) Lightening impulse withstand voltage(kV) Switching impulse withstand voltage(kV) Rated primary voltage(kV) Rated primary current(A) Short time thermal current, 3S (kA), 3s Dynamic stability current(kA) Accurate limit coefficient Environment temperature Type Secondary output

Port Rating Accuracy

126 230 550

252 460 950/1050

110/ √3 300~3000 40 100 20, 25, 30, 40 -40°C ~ +50°C Digital Current Measurement 2D41H 0.2s

220/√3 300~3000 50 125

Current protection 01CFH 5TPE

363 510 1175 950 330/√3 300~3000 50 125

550 680 1550 1175 500/√3 300~3000 63 158

Voltage measurement 2D41H 0.2

2D41H 3P

Voltage protection

Figure 3. DC Electric CT/VT

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Electronic CT/VT for AIS Application Max. operation voltage Um(kV) Withstand voltage (kV) Lightening impulse withstand voltage(kV) Switching impulse withstand voltage(kV) Rated primary voltage(kV) Rated primary current(A) Short time thermal current, 3S (kA), 3s Dynamic stability current(kA) Accuratelimit coefficient Ambient temperature Type Secondary output

Port Rating Accuracy

126 230 55O

256 460

110/√3 300~3000 40 100 20,25,30,40 -40°C ~ +50°C Digital Current Measurement 2D41H 0.2s

220/√3 300~3000 50 125

Current protection 01CFH 5TPE

363 510 1175 950 330/√3 300~3000 50 125

550 680 1550 1175 500/√3 300~3000 63 158

Voltage measurement 2D41H 0.2

PCS-9250-OAI

Voltage protection

Optical CT

2D41H 3P

Electronic CT/VT for AIS Application Rated operation voltage Um(kV) Max. operation voltage (kV) Lightening impulse withstand voltage(kV) Switching impulse withstand voltage(kV) DC withstand voltage(kV) Rated primary current Ipr Rated Short time thermal current Ith Dynamic stability current Idyn Max. continuous overcurrent 8 hours overload current Radio interference voltage(RIV) Max. temperature Max. measured current Sample rate Data rate of output signal Protoco Transmission Medium

500kVDC 515kVDC 515kVDC ±1300kVcrest ±1425kVcres 1000~3000ADC 8kArms, 1s 20kAcrest 1.2Ipr 1.3Ip The RIV is less than 1000uV when the measured voltage is 635kVDC The max. temperature in the CT/VT is no larger than 65K at rated primary current 6Ipr 32kHz 10kHz TDM/IEC60044-8(optional) 62.5/125μm multimode fiber

The PCS-9250-OAI Fiber Optic CT (FOCT) is a passive optical current transducer; it uses light to accurately measure currents on high voltage systems. The sensor at the high voltage side of the passive optical CT is composed of insulating materials such as optical fiber, glass, etc. Each FOCT is designed based on Faraday’s magneto-optical effect and adopt special optical fibers as current sensing mediums. Connections between components rely on optical fiber communication, which has the advantages of strong antivibration capacity and long-term reliability and stability.

Oil insulation is replaced by a simplified insulation structure to eliminate flaming and explosion risks. The small volume and light weight of FOCTs can help save installation space.

NR Electric’s FOCT adopts the Sagnac interference technique to reduce the impact of ambient temperature, vibration, etc.

FOCTs are composed of three parts: --

Fiber optic transmission system: FOCT uses fiber optic transmission system to connect the HV side with the LV side. It delivers optic signals from the source to a primary current sensor. The fiber optic transmission systems transmit feedback signals to a modulator circuit.

--

Signal modulating device: The signal modulating device includes light source and optic components such as a detector and primary current signal processing system. The circuit processing system of the merging unit receives and processes three-phase current signals and output digital current signals; then transmits them to protective relays.

Electronic CT/VT for GIS Application Max. operation voltage Um(kV) Withstand voltage (kV) Lightening impulse withstand voltage(kV)

10 42 75

35 95 185/200

Switching impulse withstand voltage(kV)

-

35/√3

Rated primary voltage(kV)

10/

Rated primary current(A)

50~3000

50~3000

Short time thermal current, 4S (kA), 3s

31.5

31.5

Dynamic stability current(kA) Accurate limit coefficient Ambient temperature

80

Type

80 20.25 -15°C ~ +40°C Digital

Port

Current measurement

Current protection

Voltage measurement/ protection

Rating

4V/2D41H

225mV/01CFH

4V/6.5V/2D41H

Accuracy

0.2s

5P

0.2/3P

Secondary output

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Features

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Signals are transmitted via optic fibers at the HV side without any electrical circuits. High insulation properties of the optical fiber can guarantee complete electrical separation to prevent the risk of open circuit on the LV side.

No magnetic saturation and ferromagnetic resonance.

Wide dynamic measuring range and high measuring accuracy.

Significant benefits in a wide range of frequency responses. FOCTs can accurately measure high-order harmonic, transient current and DC current.

FOCTs have strong universality to adapt to various current transformers with different voltage levels and different current ratings.

The complete symmetrical reciprocal optical design can greatly reduce the risks of environmental impact in order to guarantee a higher reliability of optic circuits. The lightweight sensing ring can be widely applied to the traditional column-type CT, bushing-type CT and can also be integrated in GIS.

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Automation System

PCS-9700

PCS-221 Merging Unit

Automation System

Merging units are used to sample AC analog values and transmit the sampled values(SV) to protection devices, bay control units(BCU) or electric meters through optical communication channels based on the IEC61850-9-2 protocol or IEC60044-8 protocol.

PCS-222 Circuit Breaker Controller The PCS-222 is an intelligent terminal used to control primary switching devices, whichinclude the circuit breaker and main transformer, in the digital substation at all voltage levels.

PCS-223 CB Online Monitoring Unit The PCS-223 circuit breaker(CB) online monitoring unit provides the online monitoring of circuit breaker and switches in the digital substations at all voltage levels.

The PCS-9700 is a state-of-the-art automation solution for substations, power generators and a variety of industries. The PCS-9700 is equipped with diverce advanced technologies and patents. It can be incorporated into a variety of substations, from distribution level to the extra high voltage level. It integrates the applications of protection, control, Ethernet, IT and communication technologies based on international standards. Furthemore, PCS-9700 is fully compatible with the IEC-61850 standard. The system adopts the layered distributed architecture with a bay-oriented and object-oriented structure, which is more reliable, extensible and easy to maintain. The PCS-9700 helps customers realize the automation of local operations and collection, evaluation and forwarding of data. It provides remote control and monitoring of the power system operation status. It is suitable for the following applications: •

Transmission and distribution substations, power generation and a variety of industrial electrical systems

Utilities, power plants and industries

Newly constructed substations and retrofit substations

Gas and air isolated switchgears

Subway systems, light-rail systems, and electrified railway

PCS-9250-EGI/EAI Electronic CT/VT To keep pace with the increasing demands of transmission capacity and rising system voltage, NR Electric has pursued advanced research on electronic CTs and VTs to ensure maximum reliability and availability in the applications of metering and protection relays.

systems

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PCS-9250-OAI Optical CT

IEC-61850 Compatibility

The PCS-9250-OAI Fiber Optic CT (FOCT) is a passive optical current transducer; it uses light to accurately measure currents on high voltage systems. The sensor at the high voltage side of the passive optical CT is composed of insulating materials such as optical fiber, glass, etc.

NR Electric’s substation automation system is fully compatible with the IEC-61850 standard and has passed the IEC-61850 conformance test, obtaining the level A certification issued by KEMA. NR Electric has set up its own IEC-61850 level B test laboratory to confirm the standard compliance for all products.

The IEC-61850 standard provides an internationally recognized method targeted at increasing the interoperability between IEDs from different venders. The IEC-61850 standard has built-in capabilities for high-speed control and data sharing over the network, eliminating most dedicated control wiring. Interoperation between multi-vendor IEDs using the IEC-61850 standard is the future of communication technology. In the long run, such inteconectivity should save capital in long-term upgrade investment for customers. NR Electric protection relays, bay control units and substation automation systems are completely compatible with IEC-61850. We also provide solutions that allow the migration from the conventional substation automation system to the new standard. The PCS series protection and bay control units support the IEC-61850-9-2 standard and GOOSE message for the process bus. The sampled value, interlocking, real-time tripping/closing, interlocking and state information are transported via process bus. Compared to traditional substations, the process bus based optical fiber is used to replace cable connections between IEDs. This will significantly reduce the construction time and cost.

Process Bus Solution The process bus is one of the cornerstones in the development of the new digital substation. The process bus, with GOOSE and IEC 61850-9- 2 standard, is adopted in NR Electric’s digital substation solution. It realizes the transmission of sampled values, state information, tripping/closing commands and interlocking commands.

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NR Electric’s innovative digital substation solution aims at improving the modern substation operation modes by using a fiber optic network instead of conventional cable wiring, thereby reducing the workload and extending the substations operational period. NR Electric’s digital substation solutions include process level equipment such as electronic fiber CT/ VTs, merging units, circuit breaker controller and local control panels. It also includes PCS series protection and control devices like protective relays, disturbance recorders, automation systems, remote control systems and protection information systems. The merging unit is suitable for traditional CT/VTs and electronic CT/VTs. It distributes the digitalized data of current/voltage to various IEDs at the bay level via the process bus or point-topoint optical fibers. • Electronic CT/VTs digitalize the current/voltage signals and transmit them to various IEDs (protection units, control units, metering and disturbance recorders) via optical fibers.

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Communication with control center is independent of local HMI. The control command is transmitted directly from the control center. It supports IEC standard protocols and other standard protocols such as DNP3.0 and 1801. •

• Merging Units gather digitalized data of current/voltage and distribute it to various IEDs via the process bus. • Circuit Breaker Controllers collect state information from the breaker, and transmits it to various IEDs via the process bus, which receive the tripping/closing commands and implements them. • Local control panels realize the local installation of the protection and control devices

information in the process bus.

--

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

Real-time data acquisition and processing The system makes acquisition and processing of real-time data of the supervisory and control units, installed at the 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. The PCS-9705 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

Protection and fault information management. The system can acquire protection information, fault information, power system stability control and other automation equipments. Then it can display, analyze and process information locally. The information subsystem provides a powerful fault analysis tool. When faults occur, the information subsystem can transmit protection operation information and fault reports to the dispatching center quickly, helping dispatchers to get correct fault information, make rapid and correct fault analysis as well as decisions on fault clearance.

• Gigabit switches guarantee the real-time transmission of

Interfaces with third-party IEDs Protocol converters complied with IEC-61850 standards are provided for the integration of third-party IEDs. These can convert non-IEC-61850 protocols to IEC-61850 and realize the full automation of all IEDs in the substation.

SAS software package (HMI) The system provides a powerful and friendly human machine interface software package, which includes:

Functions

Time synchronization The system receives GPS standard time signals for clock synchronism. The absolute time is broadcasted through the network. The second or minute pulse signal is inputted to the equipment by RS-485 ports or potential free contact. IRIG-B signal (AC or DC) is also supported.

Features Optimized design scheme The PCS-9700 system consideres various functions of protection, local supervision, control, reactive power and voltage regulation, interlocking, selective ground fault protection (of an ineffectively grounded system), management of equipements, operation and information protection, fault recorder information, etc., Powerful and flexible communication facilities The station bus uses 100M Ethernet while the bay level uses dual 100M Ethernet for redundancy. A powerful communication platform is thus formed by merging these facilities together with network communication equipments, such as 100Mbps Ethernet Switches and gateways. The process bus uses redundant Gigabit or 100M Ethernet based on optical fibers. It will guarantee the real-time transmission of important information, such as tripping/ closing commands. The system uses IEC 60870-5-103 standard protocol for communication with protection relays and other IEDs. The RCS-9794A/B communication unit in the multiple CPU structure serves as protocol converter. It provides various standard ports so that the system can be connected with equipment made by other manufactures. Therefore, the user has the flexibility to select from various lines of products. •

Open HMI software in substation level The software of the system is developed based on Windows and UNIX operational systems. Either, SQL

server (compatible with Windows) or ORACLE (compatible with UNIX) is selected as the database management software. Based on softbus and network technology, the appropriate software package is intalled greatly enhancing the availability of the system. •

Direct data transmission to control center Functions of external communication and internal communication are independent to each other. Information can be acquired directly from the bay level and transmitted to dispatching centers. Communication bottlenecks are a problem in traditional RTU schemes. These can be solved so that reliability of information transmission can be greatly enhanced in the PCS-9700 system.

Object-oriented information structure The information structure is object-oriented. Each logic device in the database is associated with a physical device. Influence of single item change is limited to a related part on the corresponding logic device. Thus, it is easy to be extended. Attribution of information is selfdescribed. It supports on-line configuration and real-time check functions for the equipments.

Secure and reliable bay control unit The bay control unit is based on a 32 bits CPU and a DSP hardware platform. It adopts real-time multitasks operational system with powerful processing ability and is well suited for the requirements of data acquisition and processing at bay level.

Figure 1-1. Automation system structures for substation applications

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Figure 1-2. Automation system structures for substation applications Figure 2-2. ECS structures for power plants applications

System Architecture The system is comprised of three or four levels in hierarchical structure: Station Level, Network Level, Bay Level and optional Process Level. For Substations PCS-9700 HMI can be widely applied to substations. For power plants • Safety monitoring of electrical devices •

Complete telecontrol functions for power system dispatching, incorporating remote metering, remote

dispatching, remote control and remote signal transmition. •

Real-time monitoring of electrical parameters and other electrical devices if necessary

AGC and AVC functions

Power plant operation management and economic power distribution between each generator set.

For Solar Energy PCS-9700 HMI also can be widely applied to PV substations.

Figure 3. Automation system structures for solar energy applications

Figure 2-1. NCS structures for power plants applications

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• Station Level The station level is a distributed system comprised of a single computer host or several hosts. It provides supervisory, control and management functions for operators in the substation. The man-machine interface is friendly and easy to handle. The structure is flexible and capable of extention. Furthermore, the operation mode is reliable. By applying the component technology, “plug-and-play” can be realized for software functions. It can communicate with dispatching centers or other concentrated control stations using different standard protocols such as IEC-60870-5-101 and IEC- 60870-5-104.

• Network level The network level supports single or dual networks, based on distributed or ring structures. Balance flow control is used for duplicated network, so the reliability and the realtime performance can be ensured. This network level can communicate smoothly with equipment produced by other manufacturers using IEC standard communication protocols or private communication protocols. Optical links are used as a transmission medium with sever EMC immunity. Time synchronization is conveniently and correctly realized by a GPS system.

• Bay level The bay level consists of bay control units, various protection devices, disturbance recorders and other IEDs. All of NR Electric’s IEDs support IEC 61850-8-1 standards for station bus

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and redundant Ethernet ports. These equipments can operate with long-term stability in severe environments; for example, high temperatures, high humidity or high electro-magnetic disturbance.

• Process Level (Optional) The process level consists of process bus and intelligent devices including electronic CT/VTs, merging units, a circuit breaker controller and a local control panel. Merging units can be incorporated to traditional CT/VTs. Merging units receive the current/voltage via cables, then converts them into digital information and distributes them to various IEDs at the bay level. A gigabit switch is supplied so that the process bus can realize the real-time information transmission. The process bus can be configured in a redundant structure utilizing either Ethernet or optical fiber.

• Typical structure description --

The station level consists of a host, operator station and engineer station. Several computers or single computer configuration may be adopted.

--

Windows or UNIX can be used as the operational system.

--

The gateway can adopt RCS-9698G/H device, channel switching equipment and channel interface.

--

RCS-9785 can be used as the GPS receiver.

--

PCS and RCS series protection equipment can be connected with the station level directly via two 100M Ethernet ports or via two RS-485 ports through a protocol converter.

Ratings

150

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Electrostatic discharge Radiated, radio-frequency electromagnetic field Electrical fast transient/burst Surge Conducted disturbances, induced by radio-frequency fields Power frequency magnetic field Pulse magnetic field Damped oscillatory magnetic field Oscillatory waves Telesignal Telemetering

IEC 61000-4-2, class 4 IEC 61000-4-3, class 3 IEC 61000-4-4, class 4 IEC 61000-4-5, class 3 IEC 61000-4-6, class 3 IEC 61000-4-8, class 4 IEC 61000-4-9, class 5 IEC 61000-4-10, class 5 IEC 61000-4-12, class 2 Maximum capacity 80000 40000

Telecontrol Total number of stations can be comprised in system of a controlling station

20000 64

Accuracy Resolution of A/D conversion GPS clock synchronism

Voltage and current Active and reactive power Power frequency

14 bits ≤ 1 ms Total error of analog quantity measurement ≤ 0.2% ≤ 0.5% ≤ ±0.005 Hz

Refreshing cycle ≤ 3 sec ≤ 3 sec ≤ 1 sec ≤ 3 sec ≤ 2 sec ≤30s

Telemetering, from acquisition input to communication interface output Telesignal, from change of state input to communication interface output Telecontrol, from command creation to communication interface output Updating period of analog quantities on chart Updating period of change of state on chart Switch over time of standby hosts

Print Port Characteristic Optical fiber type Connector type Wave length Minimum transmission power Margin

Technical Data AC power supply DC power supply Secondary current of TA Secondary voltage of TV Pulse input: Digital input: Digital output:

Electromagnetic Compatibility

Glass optical fiber Multi-mode ST 820nm -25dBm Min. +3.0dB

Clock Synchronization Port 380 V/220 V, 50 Hz, 60 Hz 250V/220 V/125V/110 V 5 A/1 A 100 V/31/2, 110V/31/2 potential free contact, 40 ms min. potential free contact, DC 250V/220 V/125V/110 V potential free contact, 8 A

Type Transmission distance Maximal capacity Timing standard Safety level

RS-485 <500m 32 PPS, IRIG-B Isolation to ELV level

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Type Test Environmental Tests Dry cold test Dry heat test Damp heat test, cyclic

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Mechanical Tests Vibration Shock and bump

PCS-9700

Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

HMI Software

Electrical Tests Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

Electrical Tests 1MHz burst disturbance test

Electrostatic discharge test Radio frequency interference tests

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV Per IEC 60255-22-3:2007 class III

Frequency sweep --

Radiated amplitude-modulated

--

Spot frequency

--

Radiated amplitude-modulated

10Vm(rms), f=80MHz/160MHz/450MHz/900MHz

--

Radiated pulse-modulated

10Vm(rms), f=900MHz Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008

Fast transient disturbance tests

Surge immunity test

Conducted RF Electromagnetic Disturbance Power Frequency Magnetic Field Immunity Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity Auxiliary power supply performance

10V/m(rms), f=80…1000MHz

The PCS-9700 HMI (PCS-9700) is designed based on advanced distributed network technology, object-oriented database technology and cross-platform visualization technology. It is fully compatible with multiple International standards such as IEC60870-5-103 and IEC61850. The PCS-9700 is suitable for conventional substations, digital substations, and NCS systems in power plants. The system adopts distributed and expandable system framework to accommodate different structures. Applications and databases can be flexibly configured on each computer node without modification. The whole system is comprises by computers on which different operating systems are installed. The systems functions can be easily expanded according to

Functions •

Real-time data acquisition and processing

Control operation, synchronism checking and interlocking

Setup and maintenance of data bases

Reactive power and voltage automatic regulation

Configurable alarm processing

Sequence of events record and post-fault review

Configuration and displaying of graph and chart

user’s demands in order ensure system flexibility and scalability.

Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV Per IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz Per IEC 61000-4-8:2001 class V, 100A/m for 1min, 1000A/m for 3s Per IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008 Voltage dips: Up to 300ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting

Figure 1. Basic functions for PCS-9700 HMI Software

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Features The PCS-9700 HMI fully satisfies the customers’ requirements through using up-to-date technology. It has the advantages of high reliability, extensibility, easy maintenance, friend ly user interface and high system performance.Its features are listed below:

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List of events The system can provide various information, such as protection information, list of protection events, real-time and historical curves and real-time and historical reports. Besides, users can perform the following functions via the main interface, such as the reset of protection signals and configuration of protection setting, post-fault review and display of the results in picture form,,supervision of communication bit stream, etc.

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On-line calculation and reports preparation Based on the real-time data acquired, the system can make calculations on current, voltage, active and reactive power, power factor, statistics of maximum and minimum value per day, month and year of assigned quantities and duration of these values’ occurrence.

Operation management The system can give suggestions on typical failure, fault, accident or normal operation, and making of operational statistics.

Self-diagnosis and self-restoration Software and hardware can self-diagnose on-line. The range of self-diagnosis components include supervisory and control units, various kinds of stations, communication interface and other equipments, networks, channels, clock synchronism system and peripheral equipments.

Adopting unified commercial and realtime database. The equipment oriented database management system supports online equipment configuration and realtime verification functions.

Realizing network information by mutually exchanging, processing and verifying technologies based on softbus technology.

Module and object oriented technologies are used to build up the system.

The design adopts international standards such as C++, TCP/ IP, OLEDB, SQL,ActiveX, etc.

Switching over of redundant equipments without disturbance through network and node redundant configuration.

Supports various interfaces, such as: DDE and shared memory, supporting flexible network structure, connecting easily with other systems

Well-designed online self-diagnosing function to identify the failures of equipmentand network on time.

Self-restoration function helps the system restore the normal operation mode when the program losses control.

Supporting cross platform function.

he system can operate in UNIX, LINUX and Windows platforms and can be installed in computers with different OS.

Having a well-designed online self-diagnosing function, finding the failure of equipment and network system on time, then providing alarm information

Friendly HMI with online help function, which are easy to learn and use.

Having self-restoration function, the system can restore itself to the normal operation mode when the program losses control.

Figure 2. Advanced functions for PCS-9700 HMI

The system adopts distributed and expandable system framework to accommodate different structures. Applications and databases can be flexibly configured on each computer node without modification. The whole system is comprises by computers on which different operating systems are installed. The systems functions can be easily expanded according to user’s demands in order ensure system flexibility and scalability.

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PCS-9705

PCS-9700F

Bay Control Unit (BCU)

Power Forecast System

The power forecast system is used to predict the output power of renewable energy power station in an upcoming period. The system computes reliable forecast based on high accurate numerical weather prediction (NWP), with acquired site monitoring data, environment data and historical statistical data through the process of physical model and artificial neural network (ANN) model.

Features

NR Electric’s PCS-9700F power forecast system consists of two power forecast servers (main/standby), one weather data processor server, one WEB-based engineer workstation, one reverse isolation equipment, and one fire wall.

Advanced forecast algorithm: The physical model and ANN are used for power forecast to ensure forecast accuracy.

The power forecast system is isolated from the public internet via reverse isolation device.

The power forecast system is isolated from substation monitoring system via firewall.

Enviromental data such as ground radiation intensity, temperature, wind speed, etc;are required for solar power forecast. Therefore, the environmental monitor is provided,and is generally integrated into the solar power forecast supplier.

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Advanced and mature software platform: The power forecast system is based on NR Electric’s SOPHIC platform. The platform features such virtues as advanced architecture, mature and stable performance and has been applied to a series of national key projects.

PCS-9705 series bay control units (abbreviated as BCUs) are used for the control and monitoring of different types of bays inpower networks. PCS-9705 series BCUs are especiallysuitable for applications in control systemswith distributed control IEDs in all bays withhigh demands on reliability. The IED can beused up to the highest voltage levels.

PCS-9705 series BCUs are designed for the control, monitoring of circuit breakers, disconnectors, and earthing switches in any type of switchgear and different switchgear configurations. Additionally, PCS-9705 series BCUs enable the manual control of a tapchanger.

Functions Main functions of PCS-9705 are listed in the following table:

Main functions of PCS-9705 No.

Function

ANSI

1

Synchronism-check

25

2

Tap changer control and supervision

84

3

Monitoring (Binary inputs, AC/DC analog inputs)

/

4

Regulation(DC analog outputs)

/

5

Control(Binary outputs)

/

6

Interlocking

/

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Technical Data

Maximum configuration of PCS-9705 is listed in the following table:

Model

PCS-9705A

PCS-9705B

PCS-9705C

PCS-9705D

PCS-9705E

AC inputs

5VT/4CT

13VT

8VT/7CT

24VT

12VT/12CT

Binary Inputs

Up to 120

Up to 120

Up to 120

Up to 140

Up to 140

Binary Outputs

Up to 32pairs

Up to 32pairs

Up to 32pairs

Up to 25 pairs

Up to 25 pairs

Configurable Outputs

Up to 30

Up to 30

Up to 30

Up to 20

Up to 20

DC Inputs (4-20mA,0-5V, 0-250V)

Up to 16

Up to 16

Up to 16

Up to 16

Up to 16

DC Outputs (4-20mA)

Up to 4

Up to 4

Up to 4

0

0

Synchro-check

1 breaker

0

2 breaker

0

4breaker

Interlocking Logic

Yes

Yes

Yes

Yes

Yes

Support to ECVT (optional)

Yes

Yes

Yes

NO

NO

IEC61850 Process Bus (optional)

Yes

Yes

Yes

NO

NO

Power Supply Standard Rated voltage Operating range Permissible AC ripple voltage

IEC 60255-11:2008 110Vdc/125Vdc, 220Vdc/250Vdc 88~300Vdc ≤15% of the nominal auxiliary voltage

Analog Current Standard Phase rotation Nominal frequency (fn) Nominal range Accuracy Rated Current (In) Linear to Thermal withstand capability

IEC 60255-27:2005 ABC 50Hz, 60Hz 45~65Hz 0.2 class 1A 0.05In ~ 2In 2In 12In 30In 75In <0.2VA/phase @Ln

continuously for 10s for 1s for half a cycle

Burden

5A

< 0.25VA/phase @Ln

Analog Voltage Standard Phase rotation Nominal frequency (fn) Nominal range Rated phase-to-phase voltage (Un) linear to Thermalwithstand capability

IEC 60255-6, IEC60288 ABC 50Hz, 60Hz 45~65Hz 100~130V 1~130V 130V 200V 250V < 0.20VA/phase @Ln

continuously 10s 1s

Burden

Transducer Inputs

Features •

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PCS-9705 series BCUs adopt a fully-closed chassis with a complete panel, and completely separated spaces for electronic and electrical systems provided. PCS-9705 series BCUs adopt new UAPC hardware platform, 16 bits A/D converter, 320*240 graphic dot matrix LCD, and real time multi-task operating system for industrial purposes so as to realize high-capacity, highprecision, fast, real-time information processing. With highprecision A/D converters, synchronization sampling can be conducted for all the AC signals to ensure the accuracy of analog quantity measurements, which is up to the 15th harmonic component. Software and hardware clock synchronization are both adopted with 1ms timing accuracy to ensure the resolution of the Sequence Of Events (abbreviated as SOE).

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Large scale LCD provides graph and text HMI, which make the operation convenient.

Duplex Ethernet ports with 100M optical fiber or RJ45?are provided.

Back plug-in module structure is adopted. Electrical and electronic circuits are strictly separated, which enhances EMC immunity performance.

Low power consumption and wide ambient temperature range.

PCS-9705 series BCUs support IEC61850 and IEC608705-103 protocols.

Standard Input range Input resistance Accuracy

IEC 60255-1:2009 0-20mA 235Ω class 0.5

0-5V 4.4kΩ class 0.5

0-48V 54.2kΩ class 0.5

0-250V 248kΩ class 0.5

DC Analog Output Standard Output range Max load Dielectric tests Accuracy

IEC 60255-1:2009 0-20mA /4-20mA <500Ω 2000VAC class 0.5

0-10V <5mA 2000VAC class 0.5

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Binary Inputs Rated voltage Rated current drain Pickup voltage Dropoff voltage Maximum permissible voltage Withstand voltage Response time for logic input

Communication Port 24Vdc 48Vdc 1.2mA 2.4mA 13~17Vdc 26~34Vdc 50% of pickup voltage 100Vdc 2000Vac, 2800Vdc (continuously) ≤1ms

110Vdc 1.1mA 60.5~77Vdc

125Vdc 1.25mA 70~87.5Vdc

220Vdc 2.2mA 121~154Vdc

Continuous carry Pickup time Dropoff time Breaking capacity (L/R=40ms) Burden Maximal system voltage Test voltage across open contact Short duration current Durability

- Ethernet Port Connector type Transmission rate Transmission standard Transmission distance Protocol Safety level

300Vdc

Binary Outputs Contact type Output mode

250Vdc 2.5mA

Standard Front side Other sides Rear side, connection terminals

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100Base-FX <2km (1310nm)

300mW 380Vac 250Vdc

10,000 operations minimum

Glass optical fiber ST Multi mode <2km 1310nm Min. -20.0dBm Min. -30.0dBm Min. +3.0dB

For Process Level Characteristic Connector type Fiber type Transmission distance Wave length Transmission power Minimum receiving power Margin

1000V RMS for 1min 6A@3s 15A@0.5s 30A@0.2s

482.6mm×177.0mm×227.7mm (4U) Flush mounted 450.0mm×179.0mm, M6 screw Silver grey Approx. 8kg Aluminum alloy Rear panel of the device Plug-in modular type @ rear side, integrated frontplate Protection class IEC 60225-1:2009 IP40, up to IP51(With cover) IP30 IP20

For Station Level Characteristic Connector type Fiber type Transmission distance Wave length Transmission power Minimum receiving power Margin

<8ms (typical 3~5ms) <5ms 0.65A@48Vdc 0.30A@110Vdc 0.15A@220Vdc

Ambient Temperature and Humidity Range Standard Operating temperature Transport and storage temperature range Permissible humidity Pollution degree Altitude

ST (Multi mode)

- Optical Fiber Port Tripping/signaling contact Potential free contact 5A@380Vac 5A@250Vdc

Mechanical Specifications Enclosure dimensions (W×H×D) Mounting Way Trepanning dimensions (W×H) Chassis color Weight per device Chassis material Location of terminal Device structure

RJ-45 100Mbits/s 10Base-T/100Base-TX <100m IEC 60870-5-103:1997, DNP 3.0 or IEC 61850 Isolation to ELV level

Glass optical fiber LC Multi mode <2km 1310nm Min. -20.0dBm Min. -30.0dBm Min. +3.0dB

For Synchronization Port Characteristic Connector type Fiber type Wave length Minimum receiving power Margin

Glass optical fiber ST Multi mode 820nm Min. -25.0dBm Min. +3.0dB

- Clock Synchronization Port Type Transmission distance Maximal capacity Timing standard Safety level

RS-485 <500m 32 PPS, PPM, IRIG-B Isolation to ELV level

IEC 60255-1:2009 -25~55 (Readability of display may be impaired below -20°C) -40°C to +70°C 5%-95%, without condensation 2 <3000m

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RCS-9698G/H

Gateway

The RCS-9698G/H gateway is used to establish a communication links between a substation and the Load Dispatching Centers, or Grid Control Centers, in order to achieve data exchange. It is capable of communicating with several dispatching centers simultaneously via different telecommunication channels according to the applied protocol. Industrial hardware with embedded components is 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 complient with the 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 DualHOT running mode.

binary signals, transformer tap position, pulse counting of electricity quantity, communicationstates and so on. In addition, all the collected information can be sent to the dispatching center. •

Basic Communication Protocol •

Upward communications: IEC 60870-5-101, IEC 618505-104, MODBUS, CDT, DNP3.0, SCI1801, RP570 and further protocols upon request

Downward communications:IEC 60870-5-103 or IEC61850

It can cooperate with RCS-9794A/B to realize various

Settings management RCS-9698G/H can upload/download and modify settings of various protection relays and auxiliary IEDs. Setting management can be done by the Debugging Tool or accomplished by the dispatching center up.

Communicate with dispatching center via various protocols and interfaces Due its powerful communication function, RCS- 9698G/ H can send all collected information to the dispatching center via multiple standard communication interfaces (e.g. electrical/optical Ethernet port, electrical/optical serial port and so on).and RTU protocols (new protocols areprovided upon client’s request). Moreover, information sent to the dispatching center can be selected according to the

protocols.

Functions •

Collect Information from IEDs Depending on the applied protocol and database configuration, and also owing to its powerful communication interface, RCS-9698G/H can communicate with various IEDs in a substation, and automatically collect any wanted information from them, e.g. sequence of events (SOE),

Small-capacity memory storage With the incorporation of small-capacity industrial-grade NANDFLASH memory (128MBytes for single machine or 256MBytes for a dual machine system), a user can improve the collection of event information, such as: protection relays’ selfchecking information, trip event records, fault information, settings modification records and so on. This techonology also improves remote command from dispatching center, including selecting and executing of the binary outputs and setting modifications, remote regulation of transformer tap position, remote signaling reset events and so on. These events are stored, then automatically collected from various BCUs, protection relays and some other auxiliary IEDs.

Information marshalling and synthesizing An important aspect in multiple protocol application for RCS- 9698G/H (e.g. communicate with several dispatching centers) is the proper marshalling of the data that is to be transferred according to appropriate RTU protocols. With the help of the Configuration Tool, signal synthesization is implemented, such as General Alarm or General Failure. Signal transmitting Depending on the utilized RTU protocol, all the collected signals can be selectively sent to the dispatching center. Signal selection can be done during RCS-9698G/H database configuration by the Configuration Tool. Multiple Switchover Scheme for Dual-machine Configuration Whenever an error happens in the HOST MACHINE (e.g. CPU or power supply failure), the HOT STANDBY MACHINE is forced to serve as a primary host. With a dedicated seamless switchover technique, the equipment will guarantee that records are not lost during the switchover. There are up to four kinds of dual-machine switching schemes. Time Management The equipment’s Real Time Clock has small drift per day, therefore, in order to set a correct time for the time tagging of events the operator should set the time periodically or it should be synchronized by a master clock. The equipment can be configured to synchronize itselfwith the IED’s clock. Diagnostic The equipment can continuously self-supervise on its firmware. Once a hardware/software fault happens; its watchdog will make the CPU card restart.

Features •

Applicable to new substations or modernization of existing substations

Fit for installation in cubicles

Supporting dual machine system configuration with the merit of absoluteelectrical independence

Embedded multiple processor architecture, all processors are mutually independent and parallel running. Moreover, the equipment can equalize loads among each processor. This way, it exploits the merit of distributed multiprocessor system’s parallel processing ability.

Well-done network protocol stack effectively against virus, thus enforcing reliability

Configurable communication interfaces

Hardware time synchronization (IRIG-B standard and differential pulse per minute (PPM) and pulse per second (PPS))

Electrical (high speed optical-coupler isolated)/optical serial interfaces

Electrical/optical Ethernet interfaces (100Mbits/s)

LCD display with 25 LED indicators and dedicated keypad

Data marshalling and distribution

Continuous self-monitoring

Continuous supervision on connected device

Powerful and friendly configuration tool and debugging tool

Common functions (e.g. general alarm, general fault signal, communication monitoring, etc.)

necessities.

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Technical Data

Type Test

Power Supply

Environmental Tests

Rated Voltage (Un) Variation Ripple in the DC auxiliary voltage

110V/125Vdc, 220V/250Vdc, 48V DC (80% ~ 120%)Un Max 15% of the DC value. Per IEC 60255-11z

Voltage dips and voltage short interruptions

Per IEC 61000-4-11:2004, IEC 60255-11:2008 20ms for interruption without de-energizing, dips 60% of Un without reset up to 100ms

Burden Backup battery type

45W for single machine, 90W for dual machine configuration ML2032, 3V, 65mAh

Mechanical Specifications Enclosure dimensions Trepanning dimensions Mounting Way

482.6×177.0×291 (unit: mm) 450.0×179.0, M6 screw Flush mounted

Protection class

Front side: IP51 Rear side, connection terminals: IP20 Other Sides: IP30

Dry cold test Dry heat test Damp heat test, cyclic

Mechanical Tests Vibration Shock and bump

Standard Service temperature range Transport and storage temperature range Permissible humidity

Electrical Tests Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

IEC60255-6:1988 -25°C ~ +55°C -40°C ~ +70°C 5% ~ 95%, condensation not permissible

1MHz burst disturbance test

Electrostatic discharge test

Communication Interfaces Parameters Ethernet channel interfaces Port number Ethernet

RS-232/422/485 (EIA)

MODEM

RS-485 (EIA)

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Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

Electromagnetic Compatibility

Atmospheric Environment

Communication medium

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Connector type Transmission Rate Transmission standard Transmission distance Safety level Digital channel interfaces Port number Baud rate Transmission distance Maximal capacity Safety level Analog channel interfaces Port number Baud rate Center Frequency Offset Frequency Interfaces for clock synchronization Port number Transmission distance Maximal capacity Timing standard Safety level

Single machine: 4 ~ 16 Dual machine: 8 ~ 32 RJ-45 10M/100Mbps auto-negotiation 10Base-T/100Base-TX < 100m Isolation to ELV level Up to 12/24 (single machine/dual machine) 300, 600, 1200, 2400, 9600, 19200 or 38400 bps < 1000m@4800bps 32 Isolation to ELV level Up to 6/12(single machine/dual machine 300bps, 600bps, 1200bps, asynchronous 1080 ~ 3000Hz ±150 ~ ±500Hz 1 < 500m 32 PPS, IRIG-B Isolation to ELV level

Radio frequency interference tests Frequency sweep - Radiated amplitude-modulated Spot frequency - Radiated amplitude-modulated - Radiated pulse-modulated

Fast transient disturbance tests

Surge immunity test

Conducted RF Electromagnetic Disturbance

Power Frequency Magnetic Field Immunity Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity

Auxiliary power supply performance

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV Per IEC 60255-22-3:2007 class III 10V/m(rms), f=80…1000MHz 10Vm(rms), f=80MHz/160MHz/450MHz/900MHz 10Vm(rms), f=900MHz Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV Per IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz Per IEC 61000-4-8:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz Per IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008 Voltage dips: Up to 300ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting

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Features •

RCS-9698M/N Remote Terminal Unit

This device adopts multi-CPU structure, each CPU runs independently, yet synchronized with a CPU network. All the CPUs interchange data via the high-speed data bus on the motherboard. Each CPU operates independently; however, each CPU cooperate with each other.

This device supports friendly human-machine interface(abbreviated HMI), each CPU module and each COM module has corresponding “HEALTHY”and “ALARM”LED indicators. Each communication port has corresponding “ACTn” LED indicator (n=1,2,3 or 4).

RCS-9698M can be configured with up to 2 CPU modules, RCS-9698N can be configured with up to 4 CPU modules.

RCS-9698M has a LCD display and a 9-key keypad; RCS9698N has 2 LCD displays and two 9-key keypads. Due to theLCD display, the real-time dataadquisition, the operation status and theequipment parameters of RCS-9698M/N,the user can select appropriate parameter settings.

RCS-9698N supports dual machine system configuration with the merit of absolute electrical independence. Each machine has independent PWR module, CPU module, COM module and motherboard. These 2 machines have no electrical link except the outside communication link. The outside communication link adopts efficient electrical isolation.

The electrical independence improves the soveranity of each machine and ensures the redundant function of each machine to guarantee the operation’s safety and efficiency.

This device adopts embedded real-time OS and highly reliable network protocol stack.

The CPU of the RCS-9698M/N adoptsa high-speed and low-power network processor.It is specially designed for network communication and can deal with full load data flow easily. Each CPU module has a high-speed memory, thus ensuring the high-speed performance of the CPU.

RCS-9698M/N is a remote terminal unit (abbreviated RTU) designed for the highest standards of performance, safety and reliability to meet the requirements of a complex substation automation system (abbreviated SAS). It is an integral part of the SAS,it serves as a communication gateway that maps signals between protection and control IEDs in industrial or utility substations and higher-level systems such as Control Centers (abbreviated CC) or Distributed Control Systems (abbreviated DCS).

Storage and query of remote control records.

Realization and management of communication with CC and DCS.

Automatic clock synchronization and unified system timing can be realized via GPS. Able to receive and deal with IRIG-B signals, pulse per second (PPS) signals, timing messages and SNTP clock synchronization.

Monitoring the communication status of the IEDs.

RCS-9698M/N sends information for monitoring and control to a CC and DCS. Inversely, it receives process control commands from the CC and DCS.

Multi-scheme for dual monitoring and automatic switchover.

LCD display forview of real database, in order to set run schemes and parameters.

The RCS-9698M/N is based on a robust industrial hardware rather than on PC technology. The modular design enables it to be configured freely to fulfill the communication requirements of a particular application (physical interfaces, protocols,etc). The architecture is designed for parallel processing and multiprotocol operation. Standardized protocols, such as IEC608705-101/IEC60870-5-104, serve for linking systems from other

Self-diagnosis. This device can monitor its software and hardware during operation. Alarm signals will be issued if any software or hardware errors occur. At the same time, this device will lock itselfto avoid unwanted operation.

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Information synthesis and transmission According to the engineering requirements, RCS-9698M/N can synthesize several signals into a signal, and send this synthetic signal to the control center that is appointed by the user.

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This device can acquire PPS/IRIG-B clock synchronization signals from external devices via the GPSEXT module, and then transmit clock synchronization outputs. GPS module of this device can receive clock synchronization signals from the GPS antenna via the GPS antenna input socket. Then the built-in GPS receiver chip will decode the time codes, get an accurate current time, and transmit clock synchronization outputs.

Real-time OS guarantees the real-time reliable operation of RCS-9698M/N.

Supplying up to 12/24(single machine/dual machine) serial ports. These serial ports can be configured as RS-232/RS485/RS-422 and can adopt twisted-pair or fiber medium.

Each serial port can be configured with various serial port protocols. •

Functions

Supplying up to8/16(single machine/dual machine) 10M/100M self-adaptive industrial Ethernet port, each Ethernet port can be configured with various network protocols.

The serial ports with twisted-pair medium adopthigh-speed optical coupling isolation to significantly improve vibration resistance.

When errors occur in the host side of RCS-9698N, the host side locks itself, and thenthe standby side can run in host mode automatically.Furthermore, issue signals to ensure the stability and the reliability of the system.

suppliers, ensuring the openness of the system.

This device adopts industrial memory chips and large capacity non-volatile memory. Compared to the mechanical hard disks used in industrial computers, non-volatile memory provides a higher reliability, vibration resistance, and interference immunity to improve service life and reduce maintenance costs.

Each CPU module has an independent real-time clock, and receives uniform network clock synchronization. To ensure the accuracy of the clock, RCS-9698M/ N has uniform hardware synchronization interface. Furthermore, it can receive and deal with differential pulse per second (abbreviated PPS) signals and IRIG-B clock synchronization signals. The clock synchronization accuracy in all CPU modules yields consistency.

The highly reliable network protocol stack improves the real-time performance and flow of network data. At the same time, the network protocol stack prevents the intrusion of malicious elements into the network. •

This device adopts modular programming design; each module can operate on different CPU.The function configuration is flexible and convenient for engineering configuration and maintenance. Moreover, the equipment can equalize load amongst all the processors. In this way, it exploits the merit of distributed multiprocessor system‘s parallel processing ability.

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This device has completely a redundant dual-machine system. It has various dual-machine switching schemes. The real-time data of each machine is synchronized, realizing arapid and seamless switching under various schemes. Powerful and friendly configuration tools, the operation method is simple, flexible and convenient for engineering configuration and usage.

2 options available: 110Vdc/125Vdc, 220Vdc/250Vdc; 48Vdc

Supplying up to 4/8(single machine/dual machine) MODEM ports. Center Frequency and Offset Frequency can be set.

Operating Range Permissible AC ripple voltage

80%~120% of rated voltage ≤15% of the nominal auxiliary voltage

RCS-9698M/N supports IEC60870-5-101, IEC60870-5104, DNP 3.0 (serial and TCP/IP), MODBUS, RP570, CDT, or SC1801 protocols (new protocols supported or can be developed according to the requirements).

Burden

<45W for single machine, <90W for dual machine configuration

Real-time data, the operating status and some of the settings and parameters are displayed in the LCD display. The settings and parameters can be configured in LCD display.

Standard

IEC 60255-11:2008

Rated Voltage

2 options available: 110Vdc/125Vdc, 220Vdc/250Vdc; 48Vdc

Operating Range Permissible AC ripple voltage

80%~120% of rated voltage ≤15% of the nominal auxiliary voltage

Burden

<45W for single machine, <90W for dual machine configuration

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Enclosure dimensions (W×H×D) Mounting Way Trepanning dimensions (W×H) Chassis color Weight per device Chassis material Location of terminal Device structure

482.6mm×177.0mm×291.0mm Flush mounted 450.0mm×179.0mm, M6 screw Silver grey Approx. 5kg Aluminum alloy Rear panel of the device Plug-in modular type @ rear side, integrated frontplate Protection class IEC 60225-1:2009 IP40, up to IP51(With cover) IP30 IP20

Ambient Temperature and Humidity Range

Mechanical Specifications

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Mechanical Specifications

Standard Front side Other sides Rear side, connection terminals

Power Supply

Standard Front side Other sides Rear side, connection terminals

IEC 60255-11:2008

Rated Voltage

Technical Data

Enclosure dimensions (W×H×D) Mounting Way Trepanning dimensions (W×H) Chassis color Weight per device Chassis material Location of terminal Device structure

Standard

Hardware clock synchronization (IRIG-B or PPS).

Powerful and friendly debugging tools to achievethe local management functions (i.e.: real-time database viewing, remote commands query, history events query, etc.). The debugging tool can also be applied in RCS-9698M/ Nmaintainance (i.e.: operation on the memory disc, supervision of the messages of each communication port, supervision of the operation status of this device).

Power Supply

• •

Network protocol stack effectively prevents againts virus, thus enhancing reliability.

482.6mm×177.0mm×291.0mm Flush mounted 450.0mm×179.0mm, M6 screw Silver grey Approx. 5kg Aluminum alloy Rear panel of the device Plug-in modular type @ rear side, integrated frontplate Protection class IEC 60225-1:2009 IP40, up to IP51(With cover) IP30 IP20

Standard Operating temperature Transport and storage temperature range Permissible humidity Pollution degree Altitude

IEC60255-1:2009 -25°C ~ +60°C -40°C ~ +70°C 5% ~ 95%, without condensation 2 <3000m

Communication Protocols

Upward Communication (To control centers)

Downward Communication (To local SCADA) Downward Communication (To IEDs)

IEC 60870-5-101 IEC 60870-5-104 DNP 3.0 (serial and TCP/IP) MODBUS RP570 CDT SC1801 New programs can be developed for new protocols to meet the demands of the users. IEC 60870-5-103 IEC 61850 Supporting many protocols and new programs can be developed for new protocols to meet the demands of the users.

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Communication Port

Electromagnetic Compatibility

Communication medium

Ethernet

EIA-485 Port

EIA-232 Port

EIA-422 Port

MODEM Port

RS-485 (EIA)

Parameters Ethernet Port Connector type Transmission rate Transmission standard Transmission distance Protocol Safety level EIA-485 Port Baud rate Maximal capacity Transmission distance Safety level Twisted pair EIA-232 Port Baud rate Transmission distance Safety level Twisted pair EIA-422 Port Baud rate Transmission distance Safety level Twisted pair MODEM Port Baud rate Maximal capacity Center Frequency Offset Frequency Twisted pair Clock Synchronization Port Type Transmission distance Maximal capacity Timing standard Safety level

RJ-45 100Mbits/s 10Base-T/100Base-TX < 100m IEC 60870-5-103:1997, DNP 3.0 or IEC 61850 Isolation to ELV level 300, 600, 1200, 2400, 9600, 19200 or 38400 bps 32 <500m Isolation to ELV level Screened twisted pair cable 300,600,1200,2400,9600 <30m Isolation to ELV level Screened twisted pair cable 300,600,1200,2400,9600,19200 or 38400 bps <400m Isolation to ELV level Screened twisted pair cable 300bps, 600bps, 1200bps, asynchronous 32 1080 ~ 3000Hz ±150 ~ ±500Hz Screened twisted pair cable RS-485 < 500m 32 PPS, IRIG-B Isolation to ELV level

1MHz burst disturbance test

Electrostatic discharge test

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV IEC 60255-22-3:2007 class III Frequency sweep Radiated amplitude-modulated 10V/m(rms), f=80…1000MHz

Radio frequency interference tests Spot frequency Radiated amplitude-modulated 10Vm(rms), f=80MHz/160MHz/450MHz/900MHz 10Vm(rms), f=900MHz Fast transient disturbance tests

Surge immunity test

Conducted RF Electromagnetic Disturbance Power Frequency Magnetic Field Immunity Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity Auxiliary power supply performance - Voltage dips -Voltage short interruptions

Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz IEC 61000-4-8:2001 class V, 100A/m for 1min, 1000A/m for 3s IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008 Up to 500ms for dips to 40% of rated voltage without reset 100ms for interruption without rebooting

Type Test Environmental Tests Dry cold test Dry heat test Damp heat test, cyclic

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Mechanical Tests Vibration Shock and bump

Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

Electrical Tests Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

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IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

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Unified historical database -Embedded historical database, completely solves the problem of large data storage -Database capacity: >8GB --

PCS-9799

Station Manager

The PCS-9799 is a station manager designed for the highest standards of performance, safety and reliability in effort to meet the requirements of a complex substation automation system (SAS). It is an integral part of the SAS, and it is a communication gateway that maps signals between protection and control IEDs in industrial or utility substations and higherlevel systems (such as Control Centers (CC) or Distributed Control Systems (DCS)). Generally the PCS-9799 is applied in a variety of voltage level substation. Its high performance provides multiple functions, which are critical in a substation. It is used to acquire complete information from substation. Then it builds the general data platform and works as the terminal for data transmission. In addition, it also provides many advanced functions, such as: substation supervision, general gateway, protection information acquisition and transmission, on-line monitoring, electricity metering, PMU, etc. The PCS-9799 supports various protocols: IIEC60870-5-101, IEC60870-5-104, CDT, DNP, etc. The data can be transmitted across an analog channel, digital channel or net to the CC, DCS or other control centers. The PCS-9799 can also receive signals or commands from the remote centers. The information transmitted from the PCS-9799 applies the “Directly get and send” mode. This device can run independently with the HMI system although no interaction exists between these two.

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Features •

High performance hardware architecture -CPU: >1Ghz, RAM: > 1GB --

Capable for data management and communication of the SAS of mega substation or power plant

--

Capacity of device access: > 512 sets

--

Multiple MON module: at most 4 with 6 net port on each module

--

COM module: each module has 5 serial ports, RS485/RS-232 configurable

--

MODEM module: 3/6 analog channels, parameters configurable

--

IO Module: 9 adaptable binary inputs and 6 outputs

Advanced real-time database -Object-oriented design attitude --

Compatible for data model IEC61850 and IEC 103

--

Multiple models included: Primary/ secondary equipment model, association model between primary and secondary equipment, primary schematic diagram model

--

Provides full view model and data information for advanced applications

--

Unified data gathering and sending for advanced applications

Real-time data transmission platform -Furthest ensure the real-time data transmission to the RCC, which provide the real-time data for the advanced application in RCC --

Multiple data information: Historical event, operation report, wave file, etc.

Basic substation SCADA operation supported -Basic SCADA functions integrated(require computer for HMI) --

Real-time and historical alarm query

--

Measurement and operation supported

--

Powerful report recording function: device running report, operation report, SOE report

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Optimal report structure, high efficient query function

Multiple synchronization source supported: Net message, GPS, NTP net synchronization

--

Hardware synchronization: PPS, PPM, IRIG-B

Unified substation data sending platform -Realized the data model transformation between substation and RCC by using the SCD file --

Internal SOE transmission delay: <100ms

--

Redundant working mode -Automatically running-standby state switch --

Support most of mainstream protocols: IEC608705-101/104, IEC60870-5-102, IEC60870-5-103, IEC61850

Support channel-only switch mode which ensures the seamless switch between different channels with different protocols

Powerful configuration tool -Fully use of the SCD file --

Highly integrated functions

--

Total life cycle adoptable: project implementation, running and maintenance, analyze and diagnose

Powerful synchronization -Independent synchronization system for each MON board

Technical Data Mechanical Specifications Rated Voltage (Un) Variation Ripple in the DC auxiliary voltage Voltage dips and voltage short interruptions Burden

110Vdc/125Vdc, 220Vdc/250Vdc; (80% ~ 120%)Un Max 15% of the DC value. Per IEC 60255-11:1979 Per IEC 60255-11:1979 20ms for interruption without de-energizing, dips 60% of Un without reset up to 100ms Single device: <45W

Mechanical Specifications Chassis color Weight per device Chassis material Location of terminal Device structure Standard Front side Other sides Rear side, connection terminals

Silver grey Approx. 15kg Aluminum alloy Rear panel of the device Plug-in modular type @ rear side, integrated frontplate Protection class IEC 60225-1:2009 IP40 IP30 IP20

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Ambient Temperature and Humidity Range Standard Operating temperature Transport and storage temperature range Permissible humidity

IEC60255-1:2009 -25°C ~ +55°C -40°C ~ +70°C 5% ~ 95%, condensation not permissible

Communication Port Communication medium

RS-232/422/485 (EIA)

Parameters Port number Baud rate Transmission distance Maximal capacity Safety level Port number

EIA-485 Port

Connector type Transmission Rate Transmission standard Transmission distance Safety level Port number

MODEM

RS-485 (EIA)

Digital channel interfaces Up to 12/24 (single machine/dual machine) 300, 600, 1200, 2400, 9600, 19200 or 38400 bps < 1000m@4800bps 32 Isolation to ELV level Ethernet channel interfaces Single machine: 4 ~ 16 Dual machine: 8 ~ 32 RJ45 10M/100Mbps auto-negotiation 10Base-T/100Base-TX < 100m Isolation to ELV level Interfaces for clock synchronization Up to 6/12(single machine/dual machine)

Baud rate Center Frequency Offset Frequency Port number Transmission distance Maximal capacity Timing standard

300bps, 600bps,1200bps asynchronous 1080 ~ 3000Hz ±150 ~±500Hz EIA-422 Port 1 < 500m 32 PPS, IRIG-B

Safety level

Type Test Environmental Tests Dry cold test Dry heat test Damp heat test, cyclic

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Mechanical Tests Vibration Shock and bump

Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

Electrical Tests Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

Electromagnetic Compatibility 1MHz burst disturbance test

Electrostatic discharge test

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV IEC 60255-22-3:2007 class III Frequency sweep Radiated amplitude-modulated 10V/m(rms), f=80…1000MHz

Isolation to ELV level Radio frequency interference tests

Communication Protocols

Spot frequency Radiated amplitude-modulated 10Vm(rms), f=80MHz/160MHz/450MHz/900MHz 10Vm(rms), f=900MHz

IEC 60870-5-101 IEC 60870-5-104 DNP 3.0 (serial and TCP/IP) Upward Communication (To control centers)

Downward Communication (To local SCADA system manufactured by NR Electric)

MODBUS RP570 CDT SC1801 New programs can be developed for new protocols to meet the demands of the users.

Fast transient disturbance tests

Surge immunity test

IEC 60870-5-103 Conducted RF Electromagnetic Disturbance Power Frequency Magnetic Field Immunity Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity Auxiliary power supply performance - Voltage dips - Voltage short interruptions

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Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz IEC 61000-4-8:2001 class V, 100A/m for 1min, 1000A/m for 3s IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008 Up to 500ms for dips to 40% of rated voltage without reset 100ms for interruption without rebooting

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Information synthesis and transmission According to engineering requirements, the RCS-9794 can consolidateseveral signals into one signal, and send this synthetic signal to the user appointed control center.

Self-diagnosis When in operating mode, the RCS-9794 continiously

Embedded multiple processor architecture.All processors are mutually independent and run parallel to each other. Moreover, the equipment can equalizeworkloads among theprocessors. This way, it exploits the full benefitsof the distributed multiprocessor system’s parallel processing ability.

Configurable communication interfaces.

Hardware time synchronization (pulse per second (PPS))

Various communication protocols can be selected flexibly for individualcommunication ports,

Various communication interfaces can be flexible selected according to engineering requirements. Serial ports, copper Ethernet ports, fiber serial ports and fiber Ethernet ports can be selected.

Data marshalling and distribution

Suitable for installation in cubicles.

Continuous self-monitoring

Supporting a dual machine system configuration with the merit of absolute electrical independence.

Continuous supervision of connected devices

Dual Ethernet communication is used for upward communication with local HMI or RTUs at the station level to ensure the reliability of all upward communication.

Powerful and friendly configuration tools and debugging tools

Standard device functions (e.g. general alarm, general fault signal, communication monitoring, etc.)

checks for any hardware or software faults.

RCS-9794A/B Protocol Converter

The RCS-9794A/B protocol converter is an integral part of PCS9700 substation automation system. It is used to establish reliable and flexible communication links between IEDs and the workstation. As a powerful and multifunctional communication and data storage piece of equipment, the RCS-9794A/B builds a bridge between workstation and IEDs using a variety of communication protocols from diverse venders. With its modular configuration, it is flexible, allowing for the addition of new protocols. The device is fully compliant with IEC61850 communication protocol. RCS9794A can be used independently. In contrast, RCS-9794B adopts duplicated scheme with two RCS-9794A units to realize HOT-STANDBY or Dual- HOT running mode.

Functions •

Universal protocol converter The RCS-9794A/B is a highlyreliable, fully non-blocking intelligent protocol converter, which supports interworking between a wide range of protocols.

Linking protection equipments and other IEDs to substation automation system The RCS-9794 can send data from protective relays and other IEDs to SAS. It also can send the control commands from SAS to local bay units.

Basic Communication Protocol •

Upward: IEC 61850, IEC 60870-5-103

Downward: IEC 60870-5-101, IEC 60870-5-103, IEC 61850-5-104, MODBUS, CDT, DNP 3.0 (serial port).

NR Electric can customize new protocols for specific applications.

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Features •

Technical Data Power Supply

Linking protection equipments and other IEDs to remote terminal units The RCS-9794 can send data from protective relays and other IEDs to RTUs. It can also send the remote commands from the remote control center to local bay units.

Rated Voltage (Un) Variation Ripple in the DC auxiliary voltage

Inspection and communication status monitoring. The RCS-9794 can inspect and monitor the communication status of various equipments. If a connection or a disconnection occurs, the RCS-9794 will senda changeof-state message to a station-level device, such as a local HMI or RTU.

Mechanical Specifications

Clock synchronization and system time unification The RCS-9794 can receive Pulses Per Second (PPS) and timing signals from a GPS device. It also synchronizes its clock with the GPS device and sends timing messages to all linked equipment.

Voltage dips and voltage short interruptions Burden

110V, 125Vdc, 220V, 250Vdc (80% ~ 120%)Un Max 15% of the DC value. Per IEC 60255-11 Per IEC 61000-4-11:2004, IEC 60255-11:2008 20ms for interruption without de-energizing, dips 60% of Un without reset up to 100ms <40W

Enclosure dimensions (W×H×D) Trepanning dimensions Mounting Way

482.6×177.0×291(unit: mm) 450.0×179.0, M6 screw Flush mounted

Protection class

Front side: IP51 Rear side, connection terminals: IP20 Other Sides: IP30

Atmospheric Environment Standard Service temperature range Transport and storage temperature range

IEC60255-6:1988 -25°C ~ +55°C -40°C ~ +70°C

Permissible humidity

5% ~ 95%, condensation not permissible

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Communication Interfaces Communication medium

Electrical Tests Parameters Serial Interfaces

Copper

RS-232/422/485 Fiber

Copper

LonWorks Fiber

Copper Ethernet Ports)

Fiber Ethernet Ports

RS-485 (EIA)

Baud rate Transmission distance Safety level Baud rate Optical Fiber Type Connector type Wavelength Transmission distance Safety level Baud rate Safety level Connector type Optical Fiber Type Connector type Wavelength Transmission distance Safety level Ethernet Interfaces Connector type Transmission Rate Transmission standard Transmission distance Safety level Connector type Transmission Rate Transmission standard Optical Fiber Type Wavelength Transmission distance Safety level Interfaces for clock synchronization Port number Transmission distance Timing standard

300bits/s ~ 38400bits/s < 1000m@4800bps Isolation to ELV level 300bits/s ~ 38400bits/s Multi-mode ST 850nm ≤ 2000m Isolation to ELV level 9600bits/s Isolation to ELV level 9600bits/s Multi-mode ST 850nm ≤ 2000m Isolation to ELV level

1 < 500m PPS

Safety level

Isolation to ELV level

RJ-45 100Mbits/s 100BASE-TX < 100m Isolation to ELV level SC 100Mbits/s 100Base-FX Multi-mode 1300nm < 2000m Isolation to ELV level

Standard Dielectric tests

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min

Standard

IEC 60255-5:2000

Impulse voltage tests Overvoltage category Insulation resistance measurements

Test voltage 5kV III Isolation resistance >100MΩ@500VDC

Electromagnetic Compatibility 1MHz burst disturbance test

Electrostatic discharge test Radio frequency interference tests Frequency sweep - Radiated amplitude-modulatedSpot frequency - Radiated amplitude-modulated - Radiated pulse-modulated Fast transient disturbance tests

Surge immunity test

Conducted RF Electromagnetic Disturbance

Power Frequency Magnetic Field Immunity Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity

Auxiliary power supply performance

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV Per IEC 60255-22-3:2007 class III 10V/m(rms), f=80…1000MHz 10Vm(rms), f=80MHz/160MHz/450MHz/900MHz 10Vm(rms), f=900MHz Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV Per IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz Per IEC 61000-4-8:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz Per IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008 Voltage dips: Up to 300ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting

Type Test Environmental Tests Dry cold test Dry heat test Damp heat test, cyclic

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Mechanical Tests Vibration Shock and bump

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Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

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Flow Control

Multicast Management

Network storm protection: The upper rate limit to forward broadcasting/multicasting/ addressing-failure messages is configurable.

Supports VLAN multicast based on IEEE802.1Q

Supports static multicast management based on MAC address

Port rate Limiting: The message forwarding rate and burst rate of each port is configurable.

Supports GMRP dynamic multicast management

Note!GMRP is the abbreviation of “GARP Multicast Registration Protocol”.

Port mirror function: The user can designate a specific port to monitor the inflow/outflow data from the other ports.

Supports IGMP snooping dynamic multicast management.

Link aggregation: Supports link aggregation based on port, MAC address, etc.

Provides 3 port security states:

-None; -Static MAC address; -802.1X. Supports network security protocols based on SSL/SSH.

Supportsquantitative limitation on MAC address learning.

Supports Telnet functionsenable and disable.

Free of DoS(Denial-of-Service) attacks.

Supports security log and operation log.

PCS-9882

Ethernet Switch The PCS-9882 series switches can be used in substation automation system (SAS), networked control system (NCS) and distributed control systems (DCS). They can also be used in power plants, industrial control systems, etc. PCS-9882 series switches provide 1000Mbps Ethernet ports with higher data transmission rates to meetthe increasing requirements of the device communication.PCS-9882 series

Type PCS-9882AD PCS-9882BD PCS-9882ED PCS-9882PD PCS-9882QD

switches support up to twenty-four 10/100Mbps electrical Ethernetports and four 1000Mbps Ethernet ports.The fiber ports adopt SFP sockets, which support hot plugging. The following table shows the sub types of PCS-9882.The number and type of the fiber ports are different in each sub type in order to meet various requirements.

Communication Ports 1000Mbpsfiber ports 0~4 0~2 0 0~4 0~4

100Mbpsfiber ports 0~2 0~16 0~12 0~4 0~18

Maximum Power Supply 10/100Mbps electrical ports 22~24 0 12 24 0

2 2 2 2 2

QoS control: Supports message priority control based on IEEE 802.1pstandards; it also supports strict priority strategy and weighted priority strategy.

VLAN •

Support VLAN based on port

Support VLAN based on MAC address

SupportVLAN based on protocol

Support VLAN based on IEEE 802.1Q

Supports offline modification functions of the switch configuration file.

Support overlapped VLAN configuration

Supports switch configuration file upload and download.

Support VLAN tag insertion, modification or deletion

SupportsPC download functions of switch log and event file.

Support GARP VLAN registration protocol.

Note!

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Provide 10/100Mbps self-adaptiveelectrical Ethernet ports. The electrical Ethernet ports comply with 10BASET/100BASE-TX standardsThey are self-adaptive for crossover and straight-through network cable. MDI/MDIX automatic identification is supported. The 100Mbps fiber ports of this device adopt SFP socket. The SFP transceiver complies with IEEE802.3 100BASEFX fiber Ethernet standards andcan be plugged into the 100Mbps SFP socket of this device.

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The 1000Mbps fiber ports of this device adopt SFP socket. The SFP transceiver complies with IEEE802.3 1000BASESX 1000Mbps fiber Ethernet (1.25GBd) standardscan be plugged into the 1000Mbps SFP socket of this device.

Both the 100Mbps SFP socket and the 100Mbps SFP device socket support hot plugging.

The switching mode adopts non-blocking store and forward.

Support IEEE802.3x Flow Control.

Management Method •

Supports WEB Server, Telnet and CLI.

Supports simple network management protocol SNMPV1/ V2C/V3.

Ring Network

SupportsRMON Management

Support STP (802.1D) and RSTP (802.1w), fast switch to backup linksin case of communication link failure.

Provides an alarm signal output contact to indicate any abnormity of the device.

Supports“NR Electric-Ring” private ring network protocol with a fast ring network recovery speed.

Provides a block signal output contact to indicate device blocking.

Supports the dedicated ring network protocol, able to minimize network storms when cooperating with a common Ethernet switch (i.e.: the Ethernet switch unable to deal with network storm).

Supports IP conflict detection.

Supports MRP ring protocol.

Protocol”.

Ethernet Switch

File Management •

GARP is the abbreviation of “Generic Attribute Registration

Functions

Port Security

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Technical Data

Features All PCS-9882 series switches adopt a high-performance switch chip and excellent industrial design to keep line speed forwarding under full-duplex and full-rate operation of all the ports. The design and manufacturing of the device has fully considersvarious adverse conditions and interference factors in industrial applications to ensure reliable data transmission under tough environments. •

This device is suitable for application according to IEC61850 and indigital substation.

Patent protected advanced heat emission technologyincorporated to the device in order to ensure excellent heat emission performance. This device can perform in a range of temperatures, from-40°C~ +85°C. Furthermore, it does so stably and reliably.

Optimized RSTP protocol is adopted. The restoration time of the device is less than 1.2 ms per hop. A leading international landmark.

The processing capacity guarantees report handling at an average speed between 64-1518bytes without losing any packages.

• •

The device adopts the following advanced technologies: totally-enclosed chassis, partitioned grounding connection, anti-interference power supply, printed circuit board(abbreviated PCB) division by voltage level, cable shielding.Therefore, no package loss occur under strong electromagnetic interferences(abbreviated EMI).

VLAN, traffic prioritization, RSTP, port security, GMRP/ GVRP, IGMP applications are supported to meets the process level requirements in intelligent substations. Provides port security methods (based on static MAC address or based on 802.1X) to guarantee securityin linking of IEDs in substations. Network security protocol based on SSL/SSH is supported, so as to ensure safe access control. Static multicast management is supported. In this way, transparent and reliable flow control oflinkied IEDs to the device is ensured. This device is designed as an industrial management Ethernet switch with abundant functions (e.g.: port flow control, network storm limitation, port mirroring, SNMP, RMON, WEB, port trunking, SNTP clock synchronization).

Compact field parallel processing technology is incorporated into this device to ensure excellent performance.

Save and transfer processes occur in less that 2μs due to the 100 Mbps ports.

In case of short power supply interruptions, the device can still work up to 500ms.

Process time of save and transfer at 1000Mbps ports is less than 1μs.

Several 1000Mbps cascading fiber ports are provided to improve the cascading performance.

Supports IEC61850 protocol modeling, the user can monitor the device with the IEC61850 protocol.

Dual power supply technology based on load balance is supported. Both AC and DC power supplies can be applied to this device.

AC Power Supply Standard Rated voltage Operating range

IEC 61000-4-11:2004 110Vac/220Vac 88~264Vac

Burden (No load)

PCS-9882AD: <14W PCS-9882BD: <13W PCS-9882ED: <14W

Burden (Full load)

PCS-9882AD: <20W PCS-9882BD: <34W PCS-9882ED: <28W

DC Power Supply Standard

GB/T 17626.29-2006(idt IEC 61000-4-29:2000).

Rated voltage

3 options available: 110Vdc/125Vdc/220Vdc/250Vdc; 48Vdc; 24Vdc.

Operating range

88~300Vdc (Rated voltage is 110Vdc/125Vdc/220Vdc/250Vdc) ; 36~72Vdc (Rated voltage is 48Vdc). 16~36Vdc (Rated voltage is 24Vdc)

Permissible AC ripple voltage

≤15% of the nominal auxiliary voltage

Burden (No load)

PCS-9882AD: <10W PCS-9882BD: <9W PCS-9882ED: <10W

Burden (Full load)

PCS-9882AD: <16W PCS-9882BD: <30W PCS-9882ED: <24W

Mechanical Specifications Enclosure dimensions (W×H×D) Mounting Way Trepanning dimensions (W×H) Chassis color Weight per device Chassismaterial Location of terminal Device structure Standard Front side Other sides Rear side, connection terminals

482.6mm×44.4mm×266.0mm(1U) Flush mounted 450.0mm×44.45mm, M6 screw Silver grey Approx. 3.5kg Aluminumalloy Rear panel of the device Plug-in modular type @ rear side, integrated frontplate Protection class IEC 60225-1:2009 IP40, up to IP51(With cover) IP50 IP30

Ambient Temperature and Humidity

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Standard

IEC 60255-1:2009; IEEE1613:2007

Operating temperature Transport and storage temperature range Permissible humidity Pollution degree Altitude

-40°C to +85°C -40°C to +85°C 5%-95%, without condensation 2 <3000m

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Electromagnetic Compatibility

Communication Interfaces Communication Standards

IEEE 802.3, IEEE 802.3u, IEEE 802.3ab, IEEE802.3z, IEEE802.3x 100Mbits/s Ethernet Port

Connector type Transmission rate Transmission standard Transmission distance Safety level Characteristic Connector type Transmission standard Fiber type Transmission distance Characteristic Connector type Transmission standard Fiber type

Transmission distance

RJ-45 100Mbits/s 10Base-T/100Base-TX <100m Isolation to ELV level 100Mbits/s Optical Fiber Port Glass optical fiber LC 100Base-FX 50/125μm multimode fiber 62.5/125μm multimode fiber 9/125μm single mode fiber Multi mode: <2km Single mode: <40km 1000Mbits/s Optical Fiber Port Glass optical fiber LC 1000Base-SX 50/125μm multimode fiber 62.5/125μm multimode fiber 9/125μm single mode fiber Multi mode: <500m Single mode: <10km If procured by users themselves, the transmission distance is subject to the SFP transceiver module.

Damped oscillatory wave immunity test

Electrostatic discharge test

Radio frequency interference tests

Fast transient disturbance tests

Surge immunity test

Environmental Tests Dry cold test Dry heat test Damp heat test, cyclic

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Mechanical Tests Vibration

IEC60870-2-2:1996 Class Cm, IEEE1613:2007

Shock

IEC60870-2-2:1996 Class Cm

Radiated amplitude-modulated f=80~1000MHz, class III, AM 80%, 1kHz,10V/m (un-modulated) f=800~960MHz and 1400~2000MHz, class III, AM 80%, 1kHz,10V/m (un-modulated) IEC61000-4-4 Power supply, I/O, Earth: class IV, 4kV, 5kHz or 100kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHzor 100kHz, 5/50ns IEC61000-4-5 Power supply, AC input, I/O port: class IV,1.2/50μs Common mode: ±4kV Differential mode: ±2kV IEC61000-4-6

Conducted RF Electromagnetic Disturbance

Power Frequency Magnetic Field Immunity Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity

Type Test

IEC 61000-4-18 Common mode: class III ±2.5kV Differential mode: class III ±1.0kV IEC61000-4-2 For contact discharge: class IV, ±8kV For air discharge: class IV, ±15kV IEC61000-4-3

Power supply, AC, I/O, Comm. Terminal:Class III, 0.15~80MHz AM 80% 1kHz 10V (un-modulated) IEC61000-4-8 class V, 100A/m for 1min, 1000A/m for 3s IEC61000-4-9 class V, 6.4/16μs, 1000A/m for 3s IEC61000-4-10 class V, 100kHz & 1MHz–100A/m

Auxiliary AC power supply performance - Voltage dips

Per IEC 61000-4-11:2004, dips to 40% of rated voltage without reset up to 12 cycles, dips to 70% of rated voltage without reset up to 30 cycles, dips to 80% of rated voltage without reset up to 300 cycles.

- Voltage short interruptions

500ms for interruption without rebooting(only for 220Vac), 60ms for interruption without rebooting(only for 110Vac).

Auxiliary DC power supply performance - Voltage dips

Per IEC 61000-4-29:2000, Up to 100ms for dips to 40% of rated voltage without reset

- Voltage short interruptions

100ms for interruption without rebooting.

Electrical Tests

184

Dielectric tests

IEEE1613:2007, Ur <50V then 500 Vrms 51<Ur <250V then 2000 Vrms

Impulse voltage tests

IEC60255-5:2000, test voltage: 5kV IEEE1613:2007, 5kV

Overvoltage category Insulation resistance measurements

III IEC60255-5:2000, Isolation resistance >100MΩ@500VDC

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Technical Data Power Supply Rated Voltage (Un) Variation Ripple in the DC auxiliary voltage Burden

RCS-9785C/D

GPS Synchronization Clock

The RCS-9785C/D is a GPS Synchronized Unit with abuiltin GPS receiver module. It receives timing messages through a built-in GPS receiver module. Alternatively, it receives IRIG-B standardized timing code through one of the two input channels, decodes and converts the timing code, and then outputs such timing signals to the whole station. Output timing signals can be IRIG-B signals, pulse per second (PPS) signals, pulse per minute (PPM), pulse per minute (PPH) signals and timing messages. It also can provide Ethernet clock synchronization services (CSS) for bay units. The Ethernet CSS can work in the dual Ethernet mode (RJ45 over 100BASE-TX).Multi-business acquisition(simultaneous, access BCU, protection, PMU, meter, online monitoring device and among other advanced functions.

Features •

186

Highly accurate time signal output -The device is precise with a lag time of ±1μs for IRIG-B/ PPS/PPM/PPH time signals (excluding the propagation delay time on the cable). The pulse front edges of these time signals are less than 50ns. --

The inaccuracies of IRIG-B/PPS/PPM/PPH output signals for RS- 485 and TTL are ≤100ns.

--

The inaccuracies of IRIG-B/PPS/PPM/PPH output signals foroptic-coupled dry (potential-free) contacts are ≤3μs.

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Various output interfaces forthe time signals The RCS-9785C/D can provide electrical (including RS232/RS- 485, TTL, and AC modulation) or optical output timing signals. The timing signals supports IRIG-B, PPS, PPM, PPH, etc. Application for large system The device is equipped with enough ports for output. The RCS- 9785C/D can be used to multiply time synchronizing pulses to meet demand if required. High reliability The use of high-integration circuits and modular design technology in the RCS-9785C/D enhances the reliability of the device.

110V/125Vdc, 220V/250Vdc (80% ~ 120%)Un Max 15% of the DC value. Per IEC 60255-11:1979 <40W

Binary Outputs Item Output mode Max system voltage Test voltage across open contact

Signal contact Potential free contact 380Vac, 250Vdc 1200V RMS for 1min

Continuous carry

8A@380V AC 8A@250V DC

Breaking capacity at 250Vdc

0.7A@48VDC 0.3A@110VDC 0.2A@220VDC

Short duration current

10A@3s 20A@0.5s

Pickup time Drop-off time Bounce time

<10ms <8ms 1ms

Mechanical Specifications Enclosure dimension (W×H×D) Trepanning dimension (W×H) Mounting

482.6×177.0×291.0(unit: mm) 450.0×179.0, (unit: mm), M6 screw Flush mounted

Protection class(per IEC60529:2001)

Front side: IP51 Rear side, connection terminals: IP20 Other Sides: IP30

Atmospheric Environment Standard Service temperature range Transport and storage temperature range Permissible humidity

IEC60255-6:1988 -25°C ~ +55°C -40°C ~ +70°C 5% ~ 95%, condensation not permissible

Communication Interfaces Communication medium

Ethernet

RS-232

RS-485 (EIA)

Parameters Ports to Transmit Clock Synchronization Signals Connector type Transmission Rate Transmission standard Transmission distance Protocol Safety level Synchronization Standard Transmission distance Safety level Twisted pair Synchronization Standard Transmission distance Safety level Twisted pair

RJ45 100Mbps 10Base-T/100Base-TX < 100m SNTP Isolation to ELV level Serial Port Timing Messages(9.6kbit/s) or IRIG-B <30m Isolation to ELV level Screened twisted pair cable Serial Port Timing Messages(9.6kbit/s) or IRIG-B <500m Isolation to ELV level Screened twisted pair cable

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Radio frequency interference tests

Optical Fiber Port

TTL Port

RS-485 (EIA)

TTL Port

Optical Fiber Port

Characteristic Connector type Fiber type Transmission standard(for IEEE1588) Protocol Transmission distance Wave length Synchronization Standard Output voltage Output impedance Transmission distance Safety level Ports to Receive Clock Synchronization Signals Synchronization Standard Safety level Twisted pair Synchronization Standard Safety level Twisted pair Characteristic Connector type Fiber type Wave length Synchronization Standard

Glass optical fiber ST or SC 62.6/125 μm for multi-mode 100Base-FX IRIG Standard 200-04 or IEEE1588 <2km 820nm IRIG-B 0 - 5V 50Ω <100m Isolation to ELV level IRIG-B Isolation to ELV level Screened twisted pair cable IRIG-B Isolation to ELV level Screened twisted pair cable Glass optical fiber ST 62.6/125 μm for multi-mode 820nm IRIG-B

Per IEC 60255-22-3:2007 class III

Frequency sweep - Radiated amplitude-modulated

10V/m(rms), f=80…1000MHz

Spot frequency - Radiated amplitude-modulated

10Vm(rms), f=80MHz/160MHz/450MHz/900MHz

- Radiated pulse-modulated

10Vm(rms), f=900MHz Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us

Fast transient disturbance tests

Surge immunity test

Common mode: 4kV

Conducted RF Electromagnetic Disturbance

Differential mode: 2kV Per IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150

Power Frequency Magnetic Field Immunity

kHz~80MHz Per IEC 61000-4-8:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150

Pulse Magnetic Field Immunity Damped oscillatory magnetic field immunity

kHz~80MHz Per IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008

Auxiliary power supply performance

Voltage dips: Up to 300ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting

Type Test Environmental Tests Dry cold test Dry heat test Damp heat test, cyclic

Per IEC60068-2-1:2007 Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Mechanical Tests Vibration Shock and bump

Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

Electrical Tests Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

Electromagnetic Compatibility 1MHz burst disturbance test

Electrostatic discharge test

188

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Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV

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Technical Data Power Supply Rated Voltage (Un) Variation Ripple in the DC auxiliary voltage Burden

RCS-9785E

Clock Extension Unit

The RCS-9785E is a timing signal expansion unit without an internal GPS module. It receives IRIG-B standardized timing code from external GPS timing sources, decodes and converts timing codes, and then outputs expanded timing signals to the whole station. The expanded timing signals are IRIG-B signals, pulse per second (PPS) signals, pulse per minute (PPM), pulse

per hour (PPH) signals and timing messages.

Features •

Highly accurate time signaling output -The device is precise with a deviation of ±1μs for IRIG-B, PPS, PPM and PPH time signals (excluding the propagation delay time on the cable). The pulse front edges of these time signals are less than 50ns. --

The inaccuracies of IRIG-B/PPS/PPM/PPH output signals forRS- 485 and TTL are ≤100ns.

--

The inaccuracies of IRIG-B/PPS/PPM/PPH output signals foroptic-coupled dry (potential-free) contacts are ≤3μs.

Various output interfaces forthe time signals The RCS-9785E provides electrical (including RS-232/ RS-485, TTL, and AC modulation) or optical clock output timing signals. The timing signals support IRIG-B, PPS, PPM, PPH, etc. Application in large systems The RCS-9785E is equipped with enough ports for output. The time distribution can be separated for multiple devices wih a maximumdistance of 1km (when the optical ports areapplied). High reliability The use of high-integration circuits and modular design technology in the RCS-9785E enhances the reliability of

Binary Outputs Item Output mode Max system voltage Test voltage across open contact Continuous carry

Signal contact Potential free contact 380Vac, 250Vdc 1000V RMS for 1min 8.0A

Breaking capacity at 250Vdc

0.4A resistance 0.2A inductive(L/R=40ms)

Short duration current Pickup time Drop-off time Bounce time

50A for 200ms 5ms/10ms <8ms 1ms

Mechanical Specifications Enclosure dimension (W×H×D) Trepanning dimension (W×H) Mounting

482.6×177.0×291.0(unit: mm) 450.0×179.0, (unit: mm), M6 screw Flush mounted

Protection class(per IEC60529:2001)

Front side: IP51 Rear side, connection terminals: IP20 Other Sides: IP30

Atmospheric Environment Standard Service temperature range Transport and storage temperature range Permissible humidity

Communication medium

device.

Ethernet

RS-232

Optic-Coupled Dry Contact

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IEC60255-6:1988 -25°C ~ +55°C -40°C ~ +70°C 5% ~ 95%, condensation not permissible

Communication Interfaces

RS-485 (EIA)

190

110V/125Vdc, 220V/250Vdc (80% ~ 120%)Un Max 15% of the DC value. Per IEC 60255-11:1979 <40W

Parameters Ports to Transmit Clock Synchronization Signals Port number Connector type Transmission Rate Transmission standard Transmission distance Protocol Safety level Port number Transmission distance Safety level Port number Maximal capacity Transmission distance Safety level Port number Operating voltage Operating current Transmission distance Safety level

7 per module RJ45 100Mbps 10Base-T/100Base-TX < 100m SNTP Isolation to ELV level 7 per module <30m Isolation to ELV level 7 per module 32 <500m Isolation to ELV level 8 per module ≤ 300Vdc ≤ 60mA < 200m Isolation to ELV level

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Electrical Tests

TTL Port

RS-485 (EIA)

TTL Port

Port number Connector type Fiber type Wave length

8 per module ST 62.6/125 μm for multi-mode 820nm

Transmission mode

The optical fiber has light in it when the channel is idle. Or: The optical fiber has no light in it when the channel is idle

Transmission distance

< 2000m

Safety level Port number Output voltage Output impedance Transmission distance Safety level Ports to Receive Clock Synchronization Signals Port number Synchronization Standard Safety level Port number Synchronization Standard Safety level Port number Connector type Fiber type Wave length

Isolation to ELV level 8 per module 0 - 5V 50Ω <100m Isolation to ELV level

Optical Fiber Port Transmission mode Synchronization Standard Safety level

2 IRIG-B Isolation to ELV level 2 IRIG-B Isolation to ELV level 2 ST 62.6/125 μm for multi-mode 820nm The optical fiber has light in it when the channel is idle. Or: The optical fiber has no light in it when the channel is idle. IRIG-B Isolation to ELV level

Standard Dielectric tests Standard Impulse voltage tests Overvoltage category Insulation resistance measurements

Electromagnetic Compatibility 1MHz burst disturbance test

Electrostatic discharge test Radio frequency interference tests - Radiated amplitude-modulated - Radiated amplitude-modulated

10Vm(rms), f=80MHz/160MHz/450MHz/900MHz

- Radiated pulse-modulated

10Vm(rms), f=900MHz Per IEC 60255-22-4:2008 Power supply, I/O, Earth: class IV, 4kV, 2.5kHz, 5/50ns Communication terminals: class IV, 2kV, 5kHz, 5/50ns Per IEC 60255-22-5:2008 Power supply, AC input, I/O port: class IV, 1.2/50us

Fast transient disturbance tests

Surge immunity test

Dry heat test Damp heat test, cyclic

Per IEC60068-2-2:2007 Per IEC60068-2-30:2005

Common mode: 4kV

Conducted RF Electromagnetic Disturbance

Differential mode: 2kV Per IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150

Power Frequency Magnetic Field Immunity

kHz~80MHz Per IEC 61000-4-8:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150

Environmental Tests Per IEC60068-2-1:2007

10V/m(rms), f=80…1000MHz

Spot frequency

Damped oscillatory magnetic field immunity

Dry cold test

Per IEC 60255-22-1:2007 Common mode: class III 2.5kV Differential mode: class III 1.0kV Per IEC60255-22-2:2008 class IV For contact discharge: 8kV For air discharge: 15kV Per IEC 60255-22-3:2007 class III

Frequency sweep

Pulse Magnetic Field Immunity

Type Test

IEC 60255-27:2005 Test voltage 2kV, 50Hz, 1min IEC 60255-5:2000 Test voltage 5kV III Isolation resistance >100MΩ@500VDC

kHz~80MHz Per IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008

Auxiliary power supply performance

Voltage dips: Up to 300ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting

Mechanical Tests Vibration Shock and bump

192

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Per IEC 60255-21-1:1988 Class I Per IEC 60255-21-2:1988 Class I

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Technical Data Power Supply

MUX-2M/64

Communication Interface

Items Standard Auxiliary Voltage Operating Range

MUX-2M IEC60255-11: 2008 -48Vdc -32VDC~ -63VDC

MUX-64

Nominal Burden

< 10W

< 5W

-48Vdc, 110Vdc, 220Vdc 80% ~ 120%

Optical Fiber Interfaces Items Connector type Transmission medium Wavelength Transmission power Reception sensitivity Transmission distance

MUX-2M MUX-64 FC/PC 9/125μm single mode fiber cable 1310nm -10.0dBm ~ -16dBm ≤ -35.0dBm ≤ -32.0dBm < 10km

Electrical Interface The MUX-2M/64 communication interface is a communication interface between tele-protection devices and digital communication multiplexers. The tele-protection devices include PCS-902 line distance protection, PCS-931 line differential protection and power stability control devices.

The communication between MUX and protection relays is fulfilled by single mode optical fiber. MUX-2M is connected to the 2M bit/s interface of SDH multiplexer based on ITU-G.703 via a dedicated coaxial cable. MUX 64 is connected to the 64kbit/s co-directional interface of Pulse-Code Modulation (PCM) digital communication device based on ITU-G.703 via twistedwire.

Items Connector Type Transmission medium Communication speed Transmission distanc Safety level

MUX-2M BNC C o a xi a l ca b l e w i th 7 5 o h m characteristic impedance 2048kbit/s ± 50ppm < 50m Isolation to ELV level

MUX-64 DB9 Twisted pair cable 64kbit/s ± 100ppm < 20m

Mechanical Specifications Enclosure dimensions

482.60×44.40×273.00 (W×H×D, unit: mm)

Trepanning dimensions Mounting way Local HMI panel Panel language

450.00×44.50, M5 screw (W×H, unit: mm) Flush mounted 10 LED indicators Optional: English, Chinese

Housing material

Aluminum

Housing color Location of terminals

Silver grey Rear panel of the device

Protection class

IEC60225-1: 2009

Front side: IP40, up to IP51 Rear side, connection terminals: IP20 Other Sides: IP30

Ambient Temperature and Humidity Standard Operating temperature range Transport and storage temperature range Permissible humidity Altitude

IEC60225-1:2009 -40°C ~ +70°C -40°C ~ +70°C 5% ~ 95%, condensation not permissible <3000m

Type Tests Environmental Tests Dry cold test Dry heat test Damp heat test Cyclic temperature with humidity test

194

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IEC60068-2-1: 2007, 16h at -25°C IEC60068-2-2: 2007, 16h at +55°C IEC60068-2-78: 2001, 10 days, 93%RH, +55°C IEC60068-2-30: 2005, six (12+12hours) cycles, 95%RH, low temperature +25°C, high temperature +55°C

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Mechanical Tests Vibration test Shock test Bump test

IEC60255-21-1:1988, Class I IEC60255-21-2:1988, Class I IEC60255-21-2:1988, Class I

Seismic test

IEC60255-21-3:1988, Class I

Measurement

Electrical Tests Dielectric test Impulse voltage test Overvoltage category Insulation measurement Pollution degree

IEC60255-27: 2005, test voltage: 2kV, 50Hz, 1mi IEC60255-5: 2000, test voltage: 5kV, unipolar impulses, waveform 1.2/50μs, source energy 0.5J IEC60255-5: 2000, Class III IEC60255-5: 2000, insulation resistance >100MΩ @ 500Vdc IEC60225-1: 2009, Class II

Electromagnetic Compatibility 1MHz burst disturbance tests - Common mode - Differential mode Electrostatic discharge tests - For contact discharge - For air discharge Radio frequency interference tests - Frequency sweep - Radiated amplitude-modulated - Spot frequency - Radiated amplitude-modulated - Radiated pulse-modulated Fast transient disturbance tests - Power supply, I/O & Earth terminals - Communication terminals Surge immunity tests - Power supply, AC inputs, I/O terminals Conducted RF electromagnetic disturbance - Power supply, AC, I/O, Comm. terminals Power frequency field immunity Conducted emission limits Radiated emission limits Auxiliary power supply performance - Voltage dips - Voltage short interruptions Power frequency magnetic field immunity Pulse magnetic field immunity Damped oscillatory magnetic field immunity Ring wave immunity - Power supply, I/O terminals

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IIEC60255-22-1: 2007, Class III 2.5kV 1.0kV IEC60255-22-2: 2008, Class IV 8.0kV 15.0kV

PCS-996 Phasor Measurement Unit The PCS-996 Phasor Measurement Unit (PMU) is mainly applied for the measuring synchronized phasor, and the recording dynamic process of the power system. It improves the dynamic stability monitoring and analysis abilities, Phasor Measurement Units (PMUs) are installed in the corresponding substations and power plants.

IEC60255-22-3: 2007, Class III 10V/m(RMS), f=80…1000MHz 10Vm(RMS), f=80/160/450/900MHz 10Vm(RMS), f=900MHz IEC60255-22-4: 2008, Class IV 4kV, 2.5kHz, 5/50ns 2kV, 5.0kHz, 5/50ns IEC60255-22-5: 2008, Class IV 1.2/50us, 4kV, line-to-ground 2kV, line-to-line IEC60255-22-6: 2001, Class III 10V(RMS), 150kHz~80MHz IEC60255-22-7: 2003, Class A 10s 300V, line-to-ground 150V, line-to-line IEC60255-25: 2000, Class A IEC60255-25: 2000, Class A IEC60255-11: 2008 Up to 500ms for dips to 40% of rated voltage without reset 100ms for interruption without rebooting IEC61000-4-8: 2001, Class V 100A/m for 1min 1000A/m for 3s IEC61000-4-9: 2001, Class V 6.4/16us, 1000A/m for 3s IEC61000-4-10: 2001, Class V 100kHz & 1MHz – 100A/m IEC61000-4-12: 2006, Class III 1MHz 2kV, line-to-ground 1kV, line-to-line

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NR Electric provides the following models for PMUs and PDCs: • PCS-996A The phasor measurement unit is used to measure the synchronized phasor in the substation. It collects and records the phasor and binary inputs of the bus, line, main transformer and so on.

PCS-996

Phasor Measurement Unit In order to improve the dynamic stability monitoring and analysis abilities, Phasor Measurement Units (PMUs) are installed in the corresponding substations and power plants. Furthermore, the use of a wide area measurement system (WAMS) serves to view the system’s state from the dispatching center. The PCS-996 Phasor Measurement Unit (PMU) is mainly applied for the measuring synchronized phasor, and the recording dynamic process of the power system. The PCS996 consists of Phasor Measurement Units (PMU) and phasor data concentrators (PDC). The core phasor measurement unit characteristics include the synchronized phasor measurement, based on standard clock signals and timekeeping capacity without the standard clock signal. In addition, the system is designed to achieve high-speed communication capacities between the localized PMUs and the central WAMS. The standard communication protocol is IEEE C37.118. A PDC is used to collect data from several PMUs, and then the PDC sends the data to the WAMS control center. In addition, the auxiliary function of the local storage of the phasor data can be equipped with PDCs. WAMS consists of PCS-996 series PMUs and PDCs, a clock synchronization system, high-speed communication network equipment and the analysis systems of the master substation. Furthermore, WAMS can realize dynamic process monitoring and analysis of the regional electric network and the cross-regional electric network. Distributed architecture is adopted for the application of PCS996. Therefore, PCS-996 can be easily implemented for system measuring and recording in wide area substations or power plants. The PCS-996 Phasor Measurement Unit (PMU) relies on GPS time signals in order to provide extremely accurate timestamping for the power system’s information. The measured vector quantities are sent to the control center in effort to provide a basis for monitoring, protecting and controlling power networks.

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PMU in Substation/Power Plant

PMUs are installed in substations and power plants as a part of the Wide Area Measurement System (WAMS). PMUs improve the system’s economic operation and enhance power stability and protection against any severe disturbances. PMUs installed in different locations are synchronized by a GPS clock. If the GPS source is lost, an internal high-precision clock source is used as a fallback. Phasor Data Concentrators (PDCs) receive and store the synchronized phasor data from PMUs throughoptical fibers, and send the collected information to the WAMS in real-time. One phasor data concentrator can communicate with more than eight WAMS stations. The PCS-996 is hosted on the advanced UAPC multiprocessor platform, fully complying with IEEE Std C37.118-2005, IEC 60870-5-103 and IEC 61850 standards in order to ensure open communication and enable easy integration into any system.

PCS-996B The phasor measurement unit is utilized in the measuring of the synchronized phasor of the power plant. It collects and records the phasor and binary inputs of the generator, including internal voltage potential, power angle, the terminal voltage, current and so on. In addition, it collects and records 4-20mA signals, which can be excitation voltage, current, rotating speed, frequency modulation and so on. PCS-996B can measure two generators and two AC bays. PCS-996G The phasor data concentrator receives and stores the synchronized phasor data from PCS-996A and PCS-996B through direct connections via optical fibers. Meanwhile, it can communicate with the WAMS station or the monitoring system and send synchronized phasor data to them in realtime. The PCS-996G provides at least four independent network ports and can communicate with more than eight WAMS stations. Through the extension of communication plug-ins, it can accomplish further communication with more WAMS stations.

Fault Recording Function --

Event records including 1024 IO events, 1024 alarm events and 1024 device logs.

--

Disturbance recording (also called triggered recording) function: 1024 fault reports, and 1024 disturbance waveforms, and file format of waveform is compatible with COMTRADE file.

Functions for PCS-996 PDC •

Data concentration function: The PCS-996 PDC receives real-time phasor data from several PMUs. Then the PDC sends this accumulated data to the WAMS.

Dynamic recording function: store and backup phasor data locally.

Communications •

Two RJ-45 Ethernet port and two fiber Ethernet ports, which support IEC60870-5-103, or IEC61850 protocol. These two RJ-45 Ethernet ports can also be used for FTP service.

One RS-485 serial port is used for clock synchronization.

One front RS-232 serial port is used to test and configure the device.

Functions for PCS-996 PMU

Features

The robust hardware platform adopted for PMU and PDC is the same one as in NR Electric’s protection and control system, which has been well proven in field.

PCS-996 PDC can be connected to at least 1-8 PMUs and at least four control centers. Furthermore, a 128G storage disk can be integrated to the PDC.

The high-precision IRIG-B code is adopted for GPS clock synchronization through optical fiber or RS-485 ports.

The PCS-996 supports the communication standards of

Phasor calculation function -Calculate amplitudes and phase angles of phasor, such as Ua, Ub, Uc, U1, Ia, Ib, Ic, I1, Eq, etc. --

Calculate measurement values, such as P, Q, f, df/dt etc.

--

Supervise binary signals, such as disconnector status, protection operation signal, PSS operation signal, etc.

Real-time communication function: send phasor data to PDC or WAMS control center through IEEE C37.118 protocol.

IEEE C37.118 and IEC60870-5-103.

Triggered recording function: electric quantities or binary inputs can trigger the recording function with COMTRADE standard.

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Recording

Integration to WAMS The PCS-996 fully supports communications to the Wide Area Measurement System (WAMS) based on international protocols (IEEE Std C37.118-2005, IEC 60870-5-103 and IEC 61850). The measured phasors are transmitted from PCS-996 to WAMS via a communication network and assembled for advanced supervision and analysis. This allows direct phasor comparison from various locations in the power system.

PCS-9013 DFR Management System The Disturbance Fault Recording Management System (DFRMS) is designed to manage various Disturbance & Fault Recorders(DFRs) across the entire power system. It provides real-time monitoring and waveform analysis based on the information collected from each DFR.

PCS-996R Disturbance Fault Recorder

Figure1. Typically Architecture for Integration in WAMS

The PCS-996R disturbance & fault recorder (DFR) is a multifunctional data acquisition system designed to address the data recording requirements of substations. It captures the curves of monitored quantities and aligns the values of different supervised objects to build disturbance records.

PCS-996S Disturbance Fault Recorder

Integration to PSCS The measured phasors can be transmitted from PCS- 996 to the Power Stability Control System (PSCS) for stability control. In case of an imbalance between power generation and load or severe power oscillations due to system disturbances, PSCS can take fast and reliable emergency actions, such as: generator shut-down, load-shedding, etc. These actions are taken in effort to ensure the systemâ&#x20AC;&#x2122;s stability and in defending the power system against blackouts.

The PCS-996S disturbance & fault recorders are designed for the monitoring and recording of electrical quantities in digital substations. Digital signals are collected by merging units and transmitted to the PCS-996S for data comparison and information storage.

PCS-986 Disturbance Fault Recorder The PCS-986 disturbance & fault recorders are designed to record electrical parameters of generator-transformer units and operation processes in the protection& control devices of power plants.

Figure 2. Typically Architecture for Integration in PSCS

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PCS-9013

PCS-996R

DFR Management System The Disturbance Fault Recording Management System (DFRMS) is designed to manage various Disturbance & Fault Recorders(DFRs) across the entire power system. It provides real-time monitoring and waveform analysis based on the information collected from each DFR. Operators in local substations are capable of modifying settings, viewing alarm information and analyzing waveforms. Brief information is available for retrieving on request. Short message (SMS) and Email reminding functions are integrated into this management system. The DFR Management System can be configured at the customers’ request in a centralized or decentralized architecture. It can operate in regional and wide area networks under IEC 61850 protocol, FTP and IEC 60870-5-103 based on LAN. Up to 1500 sets of DFRs can be integrated and managed with this system.

Waveform analysis: it provides waveform analysis using dedicated analysis tools;

WEB inquiry: operators can inquire DR parameters and waveform files through the Internet. All information can be downloaded to a local PC for further analysis.

Local station human-machine interface(LHMI) •

• • •

The DFRMS is composed of a master station humanmachine interface(MHMI) and a local station human-machine interface(LHMI). Functions of MHMI and LHMI mainly include:

Master station human-machine interface (MHMI) •

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Parameters configuration: all parameters of DR in the whole system can be configured and uploaded to devices;

Document management: operators can search and call waveform files according to waveform list;

State monitoring: it can monitor network status and check measured data to learn the operating conditions of DR;

Setting management: DFR-MS can modify settings of any DR within the scope of control;

Remote control: it supports remote control, remote time synchronization and remote reset.

Alarm processing: it provides real-time monitoring of received events and fault reports, and sends postprocessing to DR via emails and short messages;

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Parameters configuration: all parameters of DR in local substations can be configured and uploaded to devices; Alarming: it checks the fault report, events and waveforms received from DRs Analysis function: DFR-MS can call waveform files and perform analysis using dedicated analysis tool; Remote control: the management system supports remote control, remote time synchronization and remote reset.

Disturbance Fault Recorder The PCS-996R disturbance & fault recorder (DFR) is a multifunctional data acquisition system designed to address the data recording requirements of substations. It captures the curves of monitored quantities and aligns the values of different supervised objects to build disturbance records. The PCS-996R helps users simplify disturbance analysis by combining the discrete records in different protective relays.

Authority configuration and verification functions are provided. When logging on the management interface, users can choose to browse the DR status in a region. Users with WEB authority are entitled to accept or reject short messages or emails. The default view path for MHMI model is: Region → station → device → unit, the default view path for LHMI model is: Device → unit → subordinate station. Switch over between these two models is available. Disturbance recorders are usually configured and tested on site at the local substation. The configuration information is collected at master stations and stored synchronously in the database.

Recording Functions •

The disturbance & fault recording system architecture can be centralized or distributed based upon customers’ requests. DFRs can also be applied to a substation independently with a local computer and HMI software. The protocol for the communication network can be IEC 61850, FTP and IEC 608705-103 based on LAN. GOOSE function is integrated to receive information from the process bus.

Standard format

Features

Functions

Initiating recording by AC voltage --

Phase voltage over upper limit

--

Phase voltage under lower limit

--

Sudden increase/decrease of phase voltage over limit

--

Negative sequence voltage over upper limit

--

Zero sequence voltage over upper limit

--

Sudden change of zero-sequence over limit

--

Frequency over upper limit

--

Frequency under lower limit

--

Absolute value of df/dt over limit

Initiating recording based on AC current out-of-limit

PCS-996R DFRs are equipped with 48 analog channels and 60 binary channels in one unit. Furthermore, it can be synchronized

--

Phase current over upper limit

--

Sudden change of phase current over limit

via an external time source.

--

Negative sequence over upper limit

--

Zero sequence over upper limit

--

Sudden change of zero sequence over limit

--

Power swing

Recording •

Triggered recording @ 9600Hz, for short-term transient process.

Continuous recording @1200Hz, for mid-term dynamic process

Slow recording @1 ~ 50Hz , for long-term power quality monitoring

Extract recording @ 9600Hz, isolate fault channels automatically for information efficiency.

Initiating recording based on binary input

Continuous recording (24hours of uninterrupted recording)

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NR Electric Co., Ltd.

PCS-996S

Disturbance Fault Recorder Figure 1. Typical application of the PCS-996R in a wide-area DFR system

The PCS-996S disturbance & fault recorders are designed for the monitoring and recording of electrical quantities in digital substations. Digital signals are collected by merging units and transmitted to the PCS-996S for data comparison and information storage. GOOSE and Sampled Value modules are integrated for communication with intelligent control devices and merging units based on IEC 61850-9-2 protocols.

Auxiliary Function •

Self diagnostic test

Loss of DC power supply alarm

Hardware circuit online detection

Support IRIG-B time synchronization

Features •

The robust hardware platform adopted for DFR is the same as NR Electric’s protection and control system, which has been well proven in field.

This device adopts a fully-closed chassis with a well designed structure, providing separate spaces for low and high voltage systems. The traditionally integrated circuit board mode is abandoned. Furthermore, anti-interference measures are integrated into the software, thus enhancing anti-interference capabilities.

This device makes use of an advanced hardware platform, which includes 16 bits parallel A/D converter, 320*240 graphic dot matrix LCD, and real-time multi-task operating system. The advanced hardware platform can achieve the high-capacity, high-precision, high-speed, and real-time data processing. The high-precision parallel A/D converter can sample all the AC signals simultaneously in order to ensure the accuracy of these measurements.

Communications •

1 RJ45 Ethernet port complies with IEC60870-5-103 and IEC61850 protocol

1 RS-485 serial port used for GPS time synchronization

1 RS-232 serial port used to test and configure device

1 Ethernet interface used for FTP service for continuous recording and real-time waveform display

Two fiber Ethernet ports which support IEC60870-5-103 and IEC61850 protocol (available for PCS-996R)

Functions Recording Functions •

Initiating recording by AC voltage --

Phase voltage over upper limit

--

Phase voltage under lower limit

--

Sudden increase/decrease of phase voltage over limit

--

Negative sequence voltage over upper limit

Figure 2. Typical application of the PCS-996R in a smart substation

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--

Zero sequence voltage over upper limit

--

Sudden change of zero-sequence over limit

--

Frequency over upper limit

--

Frequency under lower limit

--

Absolute value of df/dt over limit

Initiating recording based on AC current out-of-limit --

Phase current over upper limit

--

Sudden change of phase current over limit

--

Negative sequence over upper limit

--

Zero sequence over upper limit

--

Sudden change of zero sequence over limit

--

Power swing

Initiating recording based on binary input

Continuous recording (24hours uninterrupted recording)

Auxiliary Function •

Self diagnostic test

Loss of DC power supply alarm

Hardware circuit online detection

Support IRIG-B time synchronization

Communications •

1 RJ45 Ethernet port complies with IEC60870-5-103 andIEC61850 protocol

1 RS-485 serial port used for GPS time synchronization

1 RS-232 serial port used to test and configure device

1 Ethernet interface used for FTP service of continuous recording and real-time waveform display

NR Electric Co., Ltd.

Features •

The robust hardware platform adopted for DFR is the same as NR Electric’s protection and control system, which has been well proven in field.

This device adopts a fully-closed chassis with a well designed structure, providing separate spaces for low and high voltage systems. The traditionally integrated circuit board mode is abandoned. Furthermore, anti-interference measures are integrated into the software, thus enhancing anti-interference capabilities.

This device makes use of an advanced hardware platform, which includes 16 bits parallel A/D converter, 320*240 graphic dot matrix LCD, and real-time multi-task operating system. The advanced hardware platform can achieve the high-capacity, high-precision, high-speed, and real-time data processing. The high-precision parallel A/D converter can sample all the AC signals simultaneously in order to ensure the accuracy of these measurements.

PCS-986

Disturbance Fault Recorder The PCS-986 disturbance & fault recorders are designed to record electrical parameters of generator-transformer units and operation processes in the protection& control devices of power plants. The device adopts unit architecture so that hardware and

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Initiating recording based on frequency out-of-limit and sudden changes

Initiating recording based on third harmonic out-oflimit

Initiating recording based on over-excitation out-oflimit

Initiating recording based on reverse power out-oflimit

Initiating recording based on low-frequency overcurrent or zero-sequence voltage for startup/ shutdown

Initiating recording based on differential current of the main transformer, step-down transformer, generator or excitation transformer

Initiating recording based on binary input

software can be flexibly assembled and upgraded in the future.

Functions Recording Functions •

Initiating recording based on AC voltage --

Phase voltage sudden change

--

Positive-sequence voltage sudden change

--

Zero-sequence voltage sudden change

Initiating recording based on AC current --

Phases voltage sudden change

--

Positive-sequence voltage sudden change

--

Zero-sequence voltage sudden change

Initiating recording based on AC voltage out-of-limit

Initiating recording based on system oscillation

Initiating recording based on AC current out-of-limit

Initiating recording manually

Initiating recording based on positive-sequence and negative-sequence component out-of-limit

Initiating recording remotely

Continuous recording (24hours of uninterrupted recording)

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Initiating recording based on DC sudden change or DC component out-of-limit

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Auxiliary Function •

Self diagnostic test

Loss of DC power supply alarm

Hardware circuit online detection

Support IRIG-B time synchronization

NR Electric Co., Ltd.

Features •

The robust hardware platform adopted for DFR is the same as NR Electric’s protection and control system, which has been well proven in field.

This device adopts a fully-closed chassis with a well designed structure, providing separate spaces for low and high voltage systems. The traditionally integrated circuit board mode is abandoned. Furthermore, anti-interference measures are integrated into the software, thus enhancing anti-interference capabilities.

Communications •

1 RJ45 Ethernet port which complies with IEC60870-5-103 andIEC61850 protocol

1 RS-485 serial port used for GPS time synchronization

1 RS-232 serial port used to test and configure device

1 Ethernet interface used for FTP service of continuous recording and real-time waveform display

This device makes use of an advanced hardware platform, which includes 16 bits parallel A/D converter, 320*240 graphic dot matrix LCD, and real-time multi-task operating system. The advanced hardware platform can achieve the high-capacity, high-precision, high-speed, and real-time data processing. The high-precision parallel A/D converter can sample all the AC signals simultaneously in order to ensure the accuracy of these measurements.

Stability Control System

PCS-990 Power Stability Control System The Power Stability Control System (PSCS) is used to effectively prevent and reduce the possibility of system oscillations. It can quickly restore the system’s balance by load shedding or generator shut down based on the preset control tactics.

PCS-993 Out-of-Step Controller When the out-of-step condition is detected, the PCS-993 controller can take corresponding actions to maintain a balance between load and generation. These measures include tripping associated circuit breakers, shutting down some generators, shedding appropriate loads and triggering other related synchronizers.

PCS-994 Frequency & Voltage Controller PCS-994 is a frequency-voltage controller, which performs control functions for underfrequency, under-voltage, over-frequency and over-voltage. It can be used to perform load shedding in case of under-frequency or under-voltage conditions. It can also execute hydro-generator self-starting in a under-frequency scenario.

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PCS-990

Power Stability Control System

Blackouts may seriously impact to daily life of modern society from the economic sector to the daily routine. Furthermore, power stability is particularly critical in important institutions, such as hospitals, underground mines, gas stations, sewage treatment plants, etc. NR Electric provides well-proven power stability control solutions to improve the power system’s stability and significantly reduce blackouts. The Power Stability Control System (PSCS) provides a systemlevel solution for the whole power grid. Different from other System Protection Schemes (SPS), the PSCS is based on instability prediction instead of instability measurement. Before the installation, the tactic table is designed according to predetermined and simulated stability studies and strategy analysis. After installation, PSCS acquires all the necessary real-time data from the substations or power plants and seeks the appropriate remedy actions in the tactic table to pull the power system back to a stable state BEFORE the system goes into an unstable state. In contrast, conventional SPSs only detect the system’s parameters and take actions AFTER the system enters an unstable state. The Power Stability Control System (PSCS) is used to effectively prevent and reduce the possibility of system oscillations. Imbalance between loads and generations can result in system frequency and voltage changes and could potentially lead to system collapse. Power stability control can quickly restore the system’s balance by load shedding or generator shut down based on the preset control tactics. Therefore, bring voltage and frequency back to an acceptable value, so as to minimize the affected area and avoid cascading instability.

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Figure 1. The typical structure of power stability control system

A Power Stability Control System (PSCS) is composed of several master stations, multiple sub-stations and execution stations. Communication between the master station and the sub-stations is implemented via optical fibers.

Architecture Figure 1 shows a power stability control system composed of master station, various sub-stations and execution stations. Up to 300 stations can be connected to a power stability control system. Each station has one Central Unit (CU) and several Bay Units (BUs), the combination of these units is known as the stability controller.

Calculate local-scale control tactic tables

Transmit data to Sub-Station

Acquire data and execute tripping or close commands

The selection of master station, sub-stations and execution stations is determined according to system’s actual operating conditions. The master station may either be a key power plant or an important transmission substation. Other transmission substations are selected as sub- stations, and other power plants are selected as execution stations.

Master Station Functions •

Calculate region-scale control tactic tables

Transmit data to Execution Stations & Master Stations

Acquire data and drive control outputs

Sub-Master Station Functions •

Calculate region-scale control tactic tables

Transmit data to Execution Stations & Master Stations

Acquire data and drive control outputs

Execution Station Functions

Stability Controller PCS-992 Stability Controllers are installed in transmission substations and power plants to collect system operation data, power flow conditions, event records and data records from master and sub- stations through communication channels, then send control tactic tables and setting values to other transmission stations. The communication channel is either fiber microwave or optic cable interface with 2M(64K) Ethernet using IEC 60870-5-103 or IEC 61850 protocol.

Functions Stability Controller •

Detect the operation conditions of outgoing lines, transformers and generators.

Transmit status information from one station to another.

Automatically identify the on-line operating mode of the grid.

Discriminate the fault types of outgoing lines, transformers or busbars.

Calculate the best control strategy using stability analysis according to power flow and fault type.

Determine measurements that should be taken, e.g. generators shutdown, load shedding, separating, modulating of DC power, quickly reducing output of generators, etc.

Real-time control measures will be taken in case of incidents related to frequency or voltage stability, overload, etc.; which are independent of the current network operating mode.

Select the units to be shutdown in a reasonable manner according to pre-defined specific requirements.

Control commands, control values, etc.; are transmitted to other stations to be performed via a communication network.

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PCS-993

Figure 2. PCS-992 Stability Controller

Out-of-Step Controller Control commands received from the master station or other stations will be performed after local discriminations and confirmations are made.

Receive discrimination results from local sub-stations.

Implement stability control tactics.

Remote monitoring and remote modification of settings.

Bay Units at Sub-Master Station

GPS clock synchronization.

Acquire and calculate data.

Self-checking, abnormality alarm, automatic display, printing, etc.

Discriminate line transformer and generator operating status.

Central Unit at Master Station •

Communicate with central units in other master stations.

Receive discrimination results from local central units.

Discriminate system operation mode.

Establish power transfer limits.

Implement stability control tactics.

Discriminate faulty line transformer, generator, busbar and fault types.

Execute commands received from local bay unit.

Implement stability control tactics.

Perform control functions that are not related to the system’s operating modes such as transformers or lines overload discrimination.

Central Unit at Execution Station Bay Units at Master Station

Communicate with central unit in sub- station.

Acquire and calculate data.

Receive discrimination results from local bay units.

Discriminate line transformer and generator operating status.

Implement stability control tactics.

Discriminate faulty line transformer, generator, busbar and fault types.

Execute commands received from local bay unit.

Implement stability control tactics.

Perform control functions that are not related to system operation modes such as transformers or lines overload discrimination.

Central Unit at Sub-Station •

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Communicate with central units in master station and execution station.

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Bay Units at Execution Station •

Acquire and calculate data.

Discriminate line transformer and generator operating status.

Discriminate faulty line transformer, generator, busbar and fault types.

Execute commands received from local bay unit.

Implement stability control tactics.

Perform control functions that are not related to the system’s operating modes such as transformers or lines overload discrimination.

Power systems are required to remain stable after experiencing any disturbance, which may be caused by a fault, loss of a generator, or loss of a transmission line. Some disturbances may cause out-of-step between the interconnected systems, which may lead to blackouts and equipment damages if no remedial measures are taken to prevent this. In order to avoid these results, the PCS-993 out-of-step controller presents an effective way to prevent system collapse caused by out-of-step.

Functions Protection & Control •

When the out-of-step condition is detected, the PCS-993 controller will take corresponding actions to maintain a balance between load and generation. These measures include tripping associated circuit breakers to separate the power system into two or more smaller islands at the pre-selected points, shutting down some generators, shedding appropriate loads and triggering other related synchronizers preparing for the system synchronism after the system separation.

Out-of-step discrimination Based on measurement impedance, R-X plane is divided into six sequential zones. The PCS-993 controller provides two tripping modes for different oscillation cycles; which are the fast tripping mode and the slow tripping mode. The fast tripping mode can operate in the first cycle of out-ofstep for oscillation cycles of 200ms and above. The fast tripping mode operates in the second cycle of out-of-step for oscillation cycles of 100ms~200ms. The slow tripping mode operates with the same criteria as fast tripping mode but after 2~15 cycles out-of-step subject to the setting. Therefore, it only serves as a backup operation.

The PCS-993 controller adopts the advanced multi-processor platform, supporting IEC 61850-8-1 MMS. In addition, it incorporates the RJ-45 faceplate port for testing and setting in

Protection zone restriction According to dedicated zone measurement elements, the operating zone is individually determined.

Out-of-step Protection (78)

order to make commissioning and maintenance easier.

--

Separation

--

Shutdown

--

Trigger synchronism

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Monitoring and Measurement •

VT circuit supervision (VTS)

CT circuit supervision (CTS)

Self diagnostic

Event recorder including 1024 change-of-binary-input events, 1024 supervision events and 1024 operating logs

Disturbance recorder including 32disturbance records with waveforms (The format of disturbance recorder is compatible with COMTRADE.)

Communication •

Up to 4 10Base-T/100Base-TX copper Ethernet ports using IEC 61850 protocol, DNP3.0 protocol or IEC 608705-103 protocol over TCP/IP Up to 2 100Base-FX optical Ethernet ports using IEC 61850 protocol, DNP3.0 protocol or IEC 60870-5-103 protocol over TCP/IP ( Sharing with 2 copper Ethernet ports)

2 RS-485 serial ports using IEC 60870-5-103 protocol

1 RS-485 serial port for clock synchronization

NR Electric Co., Ltd.

Features •

Measured impedance characteristic with perspicuous physical conception employed for out-of-step condition detection.

Data measurement, protection calculation, logic discrimination, event recording and protection logic calculation are processed within one sampling period.

Out-of-step discrimination for parallel lines is integrated for diverse parallel-line applications.

Fast tripping mode and slow tripping mode are provided for different oscillation cycles.

The patented adaptive floating threshold is immune to system unbalance and disturbance.

Unique two-out-two logic is adopted in hardware design to improve security, coordinating with a redundant protection scheme, which improves dependability. The two independent data acquisition paths are provided to prevent mal-operation caused by component failure. One works as a fault detector and the other is designed for protection logic. Both data acquisition paths supervise tripping outputs.

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

1 front RJ-45 port for testing and setting

1 RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

The relay is designed based on NR Electric’s wellestablished and proven hardware platform with multiprocessor architecture. The multi-CPU technology supports parallel operation.

PCS-994

Frequency & Voltage Controller PCS-994 is a frequency-voltage controller, which performs control functions for under-frequency, under-voltage, overfrequency and over-voltage. It can be used to perform load shedding in case of under-frequency or under-voltage conditions. It can also execute hydro-generator self-starting in a under-frequency scenario. Furthermore, it can conduct generator shut-down in case of over-frequency and systemseparating in case of over-frequency or over-voltage conditions. The controller performs calculations and analysis based on the system’s voltage. Under-frequency load shedding and under-voltage load shedding provide 8 stages respectively, over-frequency provides 5 stages, and over-voltage provides 3 stages. The output of each stage can be configured via the output matrix. This relay has a total of 30 groups of outputs; each group can be configured for load shedding or generator shut-down independently.

Accelerated under-frequency load shedding function In the case of serious lack of generation, this relay will accelerate load shedding according to df/dt, so that stage 2 and/or 3 can be accelerated to operate after stage 1 to promptly stop frequency decrease as soon as possible.

Over-frequency protection function In case of frequency increase due to rising active power in the power system, this relay will automatically shut down some generators according to the frequency increase value, so that the system’s frequency can be restored to normal levels. Over-frequency generator shut down function provides 5 stages.

Under-voltage load shedding function In case of voltage decrease due to lack of reactive power in the power system, this relay will automatically shed some loads according to the voltage decrease value, so that system’s voltage is restored to normal levels. Undervoltage load shedding function provides 8 stages including 5 basic stages and 3 special stages.

Accelerated under-voltage load shedding function In case of accelerated decrease in system voltage, this relay has the capacity to accelerate load shedding according to dU/dt, so as to stop the system voltage decrease as early as possible. Thus, avoid voltage collapse, and restore voltage to optimal operating range.

Over-voltage protection function In case of a voltage increase due to rising reactive power in the power system, this relay will automatically divide the system, so that system voltage can be restored to normal levels. The over-voltage protection function provides 3 stages.

The PCS-994controller adopts the advanced multi-processor platform, supporting IEC 61850-8-1 MMS. In addition, RJ-45 faceplate port for testing and setting to make commissioning and maintenance easier.

Functions Protection & Control •

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Under-frequency load shedding function It serves in case of frequency decrease due to lack of active power in a power system. This relay will automatically shed some loads according to the frequency decrease value, so that the generation and loads regain equilibrium. The under-frequency load shedding function provides 8 stages, which include 5 basic stages and 3 special stages.

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df/dt and du/dt blocking functions They are used to prevent possible undesired operations due to short circuit, load feedback, or abnormal frequency or voltage. Additional, blocking functions against VT circuit failure are also provided.

NR Electric Co., Ltd.

Five basic stages and three special stages are provided for under-frequency load shedding and under-voltage load shedding respectively. The 30 groups of tripping output can be flexibly set to corresponding stages via software.

Five basic stages are provided for over-frequency generator cutting. The 30 groups of tripping output of this relay can be flexibly set to corresponding stages via software.

Monitoring and Measurement •

VT circuit supervision (VTS)

Self diagnostic

Event recorder including1024 change-of-binary-input events, 1024 supervision events and 1024 operating logs

Disturbance recorder including 32disturbance records with waveforms (The format of disturbance recorder is compatible with COMTRADE.)

Communication •

Up to 4 10Base-T/100Base-TX copper Ethernet ports using IEC 61850 protocol, DNP3.0 protocol or IEC 608705-103 protocol over TCP/IP

Up to 2 100Base-FX optical Ethernet ports using IEC 61850 protocol, DNP3.0 protocol or IEC 60870-5-103 protocol over TCP/IP ( Sharing with 2 copper Ethernet ports)

2 RS-485 serial ports using IEC 60870-5-103 protocol

1 RS-485 serial port for clock synchronization

Five independent stages of rate-of-change of frequency protection, each stage can be used for load shedding or generator shut-down independently.

Three basic stages are provided for over-voltage system separating. The 30 groups of tripping output of this relay can be flexibly set to corresponding stages via software.

The power swing blocking function, based on the analysis of df/dt and du/dt, can prevent mal-operation caused by short-circuit fault or abnormal conditions of voltage and frequency.

A patented adaptive floating threshold method is adopted, which is insensitive to system unbalance and disturbance. The measuring element can achieve both high levels of security and speed simultaneously.

User Interface •

HMI interface with large-size LCD and 9-button keypad on the front panel

1 front RJ-45 port for testing and setting

1 RS-232 or RS-485 rear port for printer

Language selection – English + selected language

Assistant software - PCS-Explorer

Features •

The PCS-994 can accelerate load shedding to prevent power system collapse when the system’s voltage or the frequency decreases sharply. Thus, restoring voltage back to optimal operating rang.

Since the decrease of three-phase voltages due to insufficient reactive power is basically symmetric, and no large sudden variation occur, the under-voltage element of this relay makes judgments based on positive-sequence voltage. If a negative-sequence voltage exceeds 0.15Un or a positive-sequence voltage changes suddenly, the undervoltage load shedding function is blocked. Therefore, the relay will not execute system separation during faults.

Unique two-out-two logic is adopted in the hardware design to improve security, while the redundant scheme improves dependability. The two independent data acquisition paths are provided to prevent mal-operation caused by component failure. One works as a fault detector and the other is designed for protection logic. Tripping outputs are supervised by both data acquisition paths. The relay is designed based on NR Electric’s well established and proven hardware platform with multiprocessor architecture. The multi-CPU technology supports parallel operation.

Energy Management

PCS-9000 Energy Management System The PCS-9000 Energy Management System (EMS) is a highly specialized, real-time, computer based supervisory control system designed to assist electric utility grid system operators in monitoring, controlling, managing and optimizing the transmission grid and/or the performance of power generation reliably and efficiently.

PCS-9000 Distribution Management System The PCS-9000 Distribution Management System is designed to serve for distribution control centers around the world. It provides integrated functions and advanced applications for the control, management, analysis and optimization of day-to-day operations.

PCS-9720 Management Unit NR Electric’s PCS-9720 distribution sub-station management unit can provide a complete automation solutions for switching stations, ring main units, distribution stations, pole-type switches and transformers.

PCS-9721A Distribution Terminal Unit (DTU)for Switchyard

PCS-9721B Distribution Terminal Unit (DTU)for Ring Main Unit The PCS-9721B Distribution Terminal Unit (DTU) can provide real-time SCADA control and monitoring, fault detection, distribution automation and communication management for 10KV main ring unit.

PCS-9721C Feeder Terminal Unit (FTU) The PCS-9721C FTU is designed to provide monitoring and control of circuit breakers for 10KV distribution overhead lines. It offers real-time SCADA monitoring, fault detection, DA and communication management functions. It can be deployed directly on the outdoor tower.

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NR Electric Co., Ltd.

Structure

Functions

PCS-9000

Energy Management System

The PCS-9000 Energy Management System (EMS) is a highly specialized, real-time, computer based supervisory control system designed to assist electric utility grid system operators in monitoring, controlling, managing and optimizing the transmission grid and/or the performance of power generation reliably and efficiently. With hundreds of licenses deployed in China and all over the world, the PCS-9000 EMS is the stateof-the-art solution for optimal grid analysis and operation in regards to security, quality and economy. It adopts an advanced network management, object-oriented database and visualized cross-platform technology. Furthermore, it provides abundant practical applications to manage the expanding energy system and reduce the operating and maintenance costs, while meeting the present and future's ever-changing business requirements.

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The PCS-9000 system is based on the latest IEC61970 standard, providing a unified application platform for large scale energy management of power enterprises. The applications of the PCS-9000 system includes SCADA, Automatic Generation Control (AGC), Power Advanced Software (PAS), Dispatching Training System (DTS), Wide Area Measurement System(WAMS), Operation Management System (OMS) and WEB. It can also be easily integrated with other systems which comply with IEC61970 standard. This is in favor of protecting the existing investments and reducing internal information and

Unified Application Supporting Platform (ASP) The PCS-9000 unified Application Supporting Platform (ASP) provides powerful and universal services for applications such as distributed real-time database management, coordinated man-machine interactive interface, transmission of network information, interprocess communication, system management, alarm services, etc. It is computer manufacturer independent and can execute across hybrid hardware platform architecture. All applications based on the PCS-9000 ASP are modular designed for easy installation, operation, maintenance and expansion. Electric power applications based on ASP The PCS-9000 Energy Management System provides full series power system applications to improve power system management levels. Its modular functions can be easily customized to meet the demands of control centers. In addition, the PCS-9000 EMS is expandable to accommodate the anticipated EMS growth.

Supervisory Control and Data Acquisition (SCADA) SCADA is a specific application framed on a unified support platform and the most basic application of the EMS system. It is mainly used to implement the highperformance acquisition and supervisory control function of real-time data. SCADA application makes use of the system's software supporting platform to provide services implementing the following functions: -Data Processing The data processing module is used for data acquisition, database updating and generation of corresponding alarm and events. In normal operation, SCADA acquires system data from front-end applications and communication services. During post disturbance review (PDR), SCADA receives data from the PDR playback manager. -Reserved Capacity Supervision Reserved capacity supervision is used to manage the risk of fortuitous faults in power grids, such as the loss of the largest unit or the largest exchange power. Definitions of class, subclass, levels and corresponding areas are provided in the grid model for the components.

function redundancy.

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Figure 2. PCS-9000 EMS Module

-Control and Regulation SCADA control and regulation functions refer to the remote control of breaker status, changing of transformer tape position, switchover of capacitors and regulation of generator outputs. Specific program logic is integrated to avoid mal-operations during control and regulation so as to ensure operation reliability. -Sequence of Event (SOE) When a fault occurs in the power grid, PCS-9000 SCADA acquires general fault signals, CB closing/opening/ tripping signals, protection operation signals, etc. After SOE records are received, the PCS-9000 organizes these events in sequence, displays them on the LCD display, prints and stores as historical data in the database. -Data Calculation and Statistics Assessment Considering system real-time performance and its implementation, the PCS-9000 provides data calculation functions in each application, including standard and customized calculations. -Trend Curves Trend records store data changes over determined periods of time. The sampling period can be defined as seconds, minutes or hours. The smallest sampling cycle is 1 second. Trend records can display in curves. Users can select any data on the single line diagram to display its trend curve. Users can also select multi-data to display in the same window to make comparisons. -Post Disturbance Review (PDR) The post disturbance review function records the power system's operating conditions before and after a disturbance to facilitate analysis, study and reconstruction of system disturbance by dispatchers.

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-Event and Record An event is usually caused by status changes of the power grid abnormal conditions of the SCADA/EMS system. Grid events and EMS system events can be separately recorded, stored and printed. -Blocking and Unblocking The blocking function is used to prohibit particular data processing, data acquisition, alarm processing and report printout. Blocking and unblocking functions are provided simultaneously with authority control. -Labeling The labeling function enables users to define label graphs, label names and label usages. Effective label duration can be set in software. The label can be configured or removed from an equipment object on the display. Before a control operation is executed, the system would check object labels automatically. -Topological Coloring The topological coloring module identifies the system's real-time wiring configuration and colors up equipments in different statuses according to the network connection and the status of circuit breakers/switches. The module can figure out the number of topological islands and, the equipment composition of topological islands. Then the equipment is activated or not according to the real-time status of circuit breakers. -Shift Handover and Takeover Management The multi-dispatcher shift handover and takeover management mechanism is established for the PCS-9000 energy management system. Shift handover and takeover contents are recorded and stored in detail.

-Clock Synchronization The PCS-9000 SCADA/EMS system provides hoststandby GPS clock port to ensure clock synchronization of all equipments in the system.

minutes. The spare generation capacity value required in a determined area can be inputted and modified via the interface, and an alarm will be sent out when spare generation capacities are insufficient.

-Database Modeling Database modeling provides a visual and convenient Graph-Model-Database Integration modeling tool, to generate single line diagrams, power grid model and database simultaneously.

-Generation Scheduling The generation scheduling function is used to arrange generator basic power planning, output reduction planning and fuel consumption planning.

-Manual Data Input Manual data input includes database table attributes that can be manually imputed. Validity checks can be applied to all manually input data. The input interface includes graphs, related interface tools, curve tools, etc. -Automatic Generation Control (AGC) Automatic Generation Control (AGC) is an advanced modern power grid control built for Energy Management System and generator unit coordination control system to implement closed-loop control. The system modifies the energy generating plan and auxiliary service plan in response to the power market. The AGC adjusts system frequency and inter-tie exchange- power by controlling the active power of generators to ensure a steady and economical operation of the power grid. -Load Frequency Control Load frequency control function is implemented by the data processing module, basic power tracking module, power distribution regulating module and power plant controller module. -Economic Dispatch The economic dispatch function allocates power demands among available on-line thermal and hydro generators based on the system's actual operation conditions to minimize generation costs. -LFC Performance Monitor LFC performance monitoring is activated during each AGC execution period to evaluate AGC control behavior. It calculates and counts area performance indicators and unit performance indicators.Furthermore, it calculates qualification ratio of frequency, exchange- power and ACE at different threshold values and under different conditions. -Reserve Monitoring During reserved monitoring period, spare generation capacities are calculated, and the response speeds are supervised. Usually, this process is completed in 2

-Transaction Scheduling The transaction scheduling function is used to arrange various transaction contracts and to obtain regional network exchange- power plans. The type of Interchange Transaction Scheduling is defined off-line into the database. Several transaction types can be defined between two identical transaction areas. The exchange plan is manually inputted by dispatcher or provided by transaction planning software. -Unit Test and Sampling The unit test and sampling function is used to perform unit commissioning for AGC units. It sends pre-defined control signals to test unit response and supports automatic load increase test and automatic load reduction test. The program automatically records test start time, test end time, test unit output,unit load increase,reduction rate, etc. -Super Short-term Load Forecast The super-short term load forecast function operates every 5 minutes. It serves to forecast loads for the next hour using the linear extrapolation method. It periodically obtains online system load data from SCADA according to the preconfigured definition and stores the data for inquiry, analysis and assessment. Error analysis is performed anytime during load forecast. All forecast results and error results are displayed in curve and tabulation. -Unit Commitment Unit commitment determines the startup/shutdown schedule of generators so as to minimize total operating cost within a specified period. Unit commitment considers the system's constraints such as system loads, reserve, unit capacity and minimum startup/shutdown time. -Hydro Scheduling & Hydro-Thermal Coordination Hydro Scheduling determines the schedule of hydro generator units. This is done in effort to achieve maximum hydro generation efficiency and to ensure consistency with river flow schedules and constraints.

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Hydro-Thermal Coordination is used to determine the schedule of thermal resources, hydro plants and pumped storage plants. Coordination is implemented in order to minimize the total cost. Hydro-thermal coordination can make the hydro thermal power plant schedule to satisfy the constraints of both electricity and water as long as system load, water flow, thermal power cost characteristic and unit commitment conditions meet the requirements. •

Power Application Software (PAS) The PCS-9000 Power Application Software (PAS) is a power grid modeling analysis tool designed to enhance system safety and economical operation. It analyzes the power system operating status, helps dispatchers understand the system's operational status and provides the basis for making analysis strategies. The PCS-9000 PAS provides functions which includeing Network Modeling ,Network Topology, State Estimation, Dispatcher Load Flow, Short-term Load Forecast, Steady State security Analysis, Short circuit Calculation, Dynamic Stability Assessment , Optimal Power Flow,Automatic Volt/ Var Control, etc. -Network Modeling The Network Modeling is fully compliant with IEC 61970 CIM standard. The established network models are shared by all network analysis applications and the dispatcher training simulator system, and are capable of data exchange with third party systems via a CIS data exchange interface. During network database maintenance, all application software can run normally without affected by the maintenance procedure. -Network Topology The Network Topology function identifies system wiring configuration according to interconnection relations of electric elements in thepower grid and circuit breakers statuses. Furthermore, it,creates a network busbar model for the analysis application software. It can determine the number of topological islands, the composition of topological islands and their operating condition, and indicate the state of these items with different colors. - State Estimation State Estimation is used to check the tele-signaling and tele-metering status of each plant/station to facilitate the maintenance of the measuring system. It uses state estimation results to count heavy loads over-limit time, provide real-time supervisory control of the power grid and issue over-limit time alarms. The results can also be used for further grid analysis.

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breaker rated capacity. The protection action settings can be determined, allowing an operator to adopt optimal protection scheme rationality, etc. Short circuit calculation is the foundation of protection settings.

In state estimation, the grid can be divided into 2 parts: observable part and unobservable part. Observable part refers to the measured values of sufficient redundancy in grid. In contrast, unobservable parts or external parts, are those which do not provide collectible data for grid analysis. Pseudo measurements can be applied to convert the unobservable parts to observable for calculation.

-Optimal Power Flow Optimal power flow serves to optimize the static network state. This is achieved through regulating control variables while all economic and secure constraints are satisfied. Ultimately, leading to a safer and more economic network operation mode.

-Dispatcher Load Flow Dispatcher Load Flow (DLF) is a network analysis software which calculates the operation status of whole network according to the given grid structure and operating conditions, These includethe voltage of each bus and the power distribution in the network. In addition, it provides statistics onpower generation output, total loads,power loss, etc. Furthermore, DLF analyzes the reasonableness of the operating mode according to calculation results. -Short Term Load Forecast Short Term Load Forecast (SLF) is used to forecast the hourly,half-hourly or quarter-hourly future load in one day or one week based on the historical loads and weather data. SLF can forecast full system loads or regional loads. The results are displayed via full graphic user interface. It can also work in tandem with other application such as the Dispatcher Load Flow. -Steady State Security Analysis The Security Analysis software studies the effects of fault or combined fault of the preset power elements on the safe static operation of grid. It monitors the power lines, transformer, generator, loads, bus, circuit breaker, etc. The main functions of the Steady State Security Analysis are to facilitate fault type selection according to dispatcher requirements, quickly determine the harm of various faults on the power system, provide an accurate system operating mode post-fault, and display various fault consequences in an accurate manner. The security analysis will issue alarms in case of line overload, limit-exceeding voltage, generator limit-exceeding power and other faults. Therefore, the system can timely indicate serious faults to a dispatcher. -Short Circuit Calculation Short Circuit Calculation is used to simulate and study power system behavior under various fault conditions. It can simulate single phase, 2-phase and 3-phase faults. Short circuit fault, broken line fault, single and complicated faults can also be simulated. By means of short circuit calculation, each branch current and bus voltage can be determined to check equipment fault withstand capabilities and protection settings. For example, the calculated fault current can be used for the calculation of circuit

Dynamic Load Flow and Dynamic Frequency Calculation Algorithms are used in the simulation.The electromechanical transient process is not considered in such simulation. The automation equipment can be triggered according to power network static status.

-Automatic Volt/VAR Control (AVVC) The PCS-9000 AVVC function offers centralized decision and multi-level coordination to achieve automatic optimal volt/var control. The system is composed of one AVVC master station system installed in the control center, several coordination control sub-systems installed in regional power plants and substations, associated communication systems and data transmission networks. •

-Control Center Simulation Subsystem Control center simulation subsystem is consistent with the actual control center. Several online dispatching automation functions are provided, including supervisory control system and online application software. •

Dispatcher Training Simulator (DTS) A Dispatcher Training Simulator (DTS) is used for dispatcher training examination, anti-fault exercises and operational analysis. DTS can simulate a power system’s normal status, emergency status, fault status and restoration process. Therefore,DTS enables trainees to study normal operation modes, fault handling and system restoration in an identical dispatching environment similar to an actual control center. -Trainer Subsystem Trainer subsystem consists of 3 parts: preparations for training, control and supervision during training and posttraining treatment. It is used to complete preparation of training data, monitor and control training process, display or print training reports and dynamic curves, etc. -Power System Simulation Subsystem The power system simulation method includes steady state simulation and dynamic simulation. Steady state simulation considers the changes in generator and load, power change in load flow and system frequency after disturbances in the system. It also can simulate the operations of protection and automation devices when a fault occurs to realize real-time simulation of a power system.

Wide Area Measurement System (WAMS) The Wide Area Measurement System (WAMS) is used to monitor grid operation status, analyze system characteristics, and accurately capture power system dynamic characteristics under several scenarios. For example, fault disturbances, under frequency power swings and test conditions. It is an effective tool to check the power system stability calculation model. The real-time monitoring of power system dynamic characteristics greatly facilitates power system stability analysis, pre-warning, dispatching, fault analysis, parameter identification and online stability decisionmaking. WAMS can realize synchronous measurement and rapid transmission, and thus it is suitable for large scale rapid control. It is one of the best measures for regional power exchange control, fault area restrain extension and enhancing main network operation safety.

Operation Management System (OMS) The operation management system provides integrated and unified operation analysis and management for power grid. The management relies on the process operation platform using various supporting technologies such as processing management tool, workflow engine and processing templates. This allows for a unified operation management of dispatching centers and provides technical support for dispatching automation operation decisions.

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Features •

Unified platform development The PCS-9000 EMS provides the user an autonomously developed software integration platform: complying with the latest international standards, adopting the latest computer technologies, and realizing object-oriented realtime database modeling. The PCS-9000 is equipped with a unified data display, unified system management platform and unified WEB application.

Modular design All functions of the PCS-9000 adopt modular design. Users can freely select required application modules to build their own application system. It is ensured that when a new application module is added, other operating functions will not be affected. In order to add a new application module or new node, users just need to use the unified application configuration tool to configure the corresponding applications. After the new application is deployed, it will automatically synchronize data with the application duty node. Thus online addition of application or node is realized easily.

Innovative EMS system developed based on IEC61970 standard From the unified application supporting platform to all power system applications, the management system fully complies with IEC61970 standard. Hybrid Platform System The use of cross-platform visualization technology and operating system independent middleware provides the system with better portability, more easy expansibility and lower cost maintenance. The PCS-9000 system can be deployed on multiple hardware platforms conveniently. Flexible Distributed Data Acquisition Technology The PCS-9000 adopts flexible and expandable design. The independent acquisition application can be established according to data characteristics and scale.

Advanced Distributed Real-time Database Synchronization Technology The core technology of support platform is an autonomously developed object-oriented real-time database. Using our autonomously developed real-time database management system, new applications can be easily expanded and data synchronization in different nodes can be ensured reliably. Offline Maintenance and Online Seamless Loading Technology The PCS-9000 system provides application offline maintenance and disturbance-free online loading functions. After an application at the maintenance node is modified, strict verification and testing must be carried out before the loading and operation of the application. This reduces the pressure on maintenance personnel, and ensures system operation security and continuous operation. Easy Expandability and Progressive Upgrading The PCS-9000 system frame is easily expandable due to its distributed modularization structure which utilizes ESB (Enterprise Service Bus) based on SOA.

PCS-9000

Distribution Management System Keeping the path of Smart Grid moving forward, NR Electric has developed innovative solutions for electric distribution networks based on state-of-the-art software and hardware technologies. The PCS-9000 Distribution Management System, designed to serve for distribution control centers around the world, provides integrated functions and advanced applications for the control, management, analysis and optimization of day-to-day operations. As a complete solutions provider, NR Electric can undertake distribution network automation planning, system design, software/hardware installation and commissioning, project management, engineering, maintenance and after-sale services. NR Electric provides customizable services and professional technical support for global customers. NR Electric’s product family of distribution automation includes the following:

Control Center

PCS-9000 Distribution Management System The PCS-9000 is a state-of-the-art Distribution Management System (DMS) which is fully compatible with IEC 61970 and IEC 61968 standards. Furthermore, it provides a unifying environment and the required functions to enhance the management efficiency of distribution networks. NR Electric’s PCS-9000 achieves full scale automation of dispatching by blending powerful operations and services with a real-time management system. In addition, practical application analysis features facilitate secure, efficient and effective dayto-day operations and enhance flexibility and profitability. The PCS-9000 uses SCADA data as the base data and implements Geographic Information System (GIS) as the display platform. Furthermore, it operates on subsystems such as: SCADA/ DA, NAO (Network Analysis and Optimization), GIS and OMS (Outage Management System) and so on.

PCS-9000 Distribution Management System (DMS)

Sub-Station PCS-9720 A/B Management Unit (PCS-9720A is a single unit. PCS-9720B is a duplicated unit.)

Distribution Terminals PCS-9721A: Distribution terminal Unit (DTU) for switchyard PCS-9721B: Distribution terminal Unit (DTU) for Ring Main Unit (RMU)

The PCS-9000 precisely manages the whole distribution network and enhances economic benefits by integrating real-time data acquisition, distribution automation and job management. It emphasizes on job distribution management and related system data interactions. The self-developed, customizable and flexible working-flow management platform substantially improves managerial efficiency, and ensures that the system’s functions are tightly correlated with the internal working flows of the electric provider.

PCS-9721C: Feeder terminal Unit (FTU)

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Fig 1. Typical System Structure Diagram

The self-developed, customizable and flexible working-flow management platform substantially improves managerial efficiency, and ensures that the system’s functions are tightly correlated with the internal working flows of the electric provider.

Functions SCADA The SCADA subsystem is the foundation of the DMS. Its main objective ismonitoring real-time data and controlling distribution equipment such as: feeders, circuit breakers, ring main units, switching stations and distribution transformers. It accomplishes these tasks by analyzing basic real-time data and static data for the entire distribution system. It contains the following functions: • Data acquisition

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Data processing

Control and regulation

Emergent event and alarm

Real-time data calculation and statistics assessment

Schematic Network and Stations Diagrams

Network topology

Historical data

Device management

Shift takeover management

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Clock synchronization

Authority management

System monitoring management

Outage Management System (OMS)

Dispatcher Training Simulator (DTS)

The Outage Management System is designed to be computerized and achieve paperless operational management. OMS is based on operational worksheets and is driven by the workflow engine. It is in favor of reducing the work intensity, improving the work efficiency and quality. OMS is used for a series of day-to-day work tasks. For example, outage maintenance, dispatch plan, log management, etc.

The Dispatcher Training Simulator is used for dispatcher training examinations, anti-fault exercises and operational analysis. It can simulate diverse power system hypothetical situations such as normal status, fault status, fault identification and restoration processes. DTS enables trainees to study and handle normal operation functions, fault handling and system restoration in an identical dispatching environment to the actual control center. The training simulator operation does not interference real-time SCADA operations. It contains the following: • Simulated distribution power system

OMS is designed to connect to real-time system closely. It can help assist dispatchers in verifying various tasks, such as the management of equipment inspection, power dispatching and job management. The OMS contains the following functions:

Distribution operator training

Anti-fault exercises

Network Analysis and Optimization provides distribution power application software, which is based on distribution network topology. Complex software analysis and optimization functions designed for distribution networks provide unified grid modeling of the distribution network complying with IEC61970 CIM model and IEC61968 standard. The NAO consists of the following functions: • Network modeling

Workflow management

Outage and restoration training

Worksheets customization management

Operations analysis and validation

Operation rule customization management

Worksheets authority and operation configuration management

Operation Worksheets and Worksheets management

Trouble call interaction and management

Network topological analysis

Outage maintenance request management

Fault Location, Isolation and System Restoration (FLISR)

Outage plan management

State Estimation

Outage analysis and indices

Load Flow Calculation

Power supply assurance request management

Short Circuit Calculation

Emergency management

Volt-VAR Control(VVC)

Crew and resource management

Optimal Feeder Reconfiguration

Interactive services between OMS and SCADA

Load Forecasting (LF)

Shift management

Load Management

Dispatch log management

Tracing and Dynamic Line Coloring

Automatic Switching Plan Generation

Network Analysis and Optimization(NAO)

Enterprise Service Bus (ESB) The PCS-9000 Enterprise Service Bus(ESB) was developed to integrate multiple operating systems into one platform. The PCS-9000 ESB is event-driven and is supported by XML (eXtensive Makeup Language) message engine. The PCS9000 ESB provides complex software architecture and provide unifying coding for the enterprise message system. It supports information exchange and service sharing among PCS-9000 DMS and other systems users. It supports: •

Synchronous messaging service

Asynchronous messaging service

Point-to-point messaging service

Publisher/subscriber messaging service;

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Features •

Complies with IEC 61970 and IEC 61968 standards

The GIS display platform is combined with the online realtime system data. Based on the unified data and graphic platform, the GIS and the SCADA graphic systems are integrated in order to provide a real-time display mode identical to the operation mode.

It adopts open architecture and an integrated application platform to meet the expandable requirements of distribution functions. •

Hardware independent All operations and job management can be executed with the assistance of GIS mapping, which makes operations very convenient and visualization. By combining device management functions with the collection of real-time system data, a user can remotely monitor and manage the individual components of the power network. The equipment management mode is flexible and can be customized according to users’ requirements.

The application of hardware independent technology and middleware technology provides a convenient combination of different computer platforms on which to build a distribution management system. •

Enterprise Service Bus (ESB) The PCS-9000 DMS adopts standard Enterprise Service Bus(ESB) to integrate DMS, CIS, GIS, AMR, etc.

Graph-Model-Database Integration modeling Technology Graph-Model-Database Integration modeling Technology and the unified management system can quickly generate an array of graphs for the power grid, equipment properties and network topology models for SCADA, NAO and DTS applications.

Intellectualized Feeder Automation (FA)

The FA technology enables fast and versatile real-time topology calculations based on the internal relations between devices. It fulfills this task by automatically searching the current network topology and the system’s real-time information. The system can automatically identify any fault by analyzing the network’s topology and calculating the optimum operational solution as to perform a quick fault location, isolation and system restoration. Seamless integration design with the GIS display platform

job management The operational worksheets are oriented towards improving day-to-day work efficiency. The worksheets are driven by work flow. These increase efficiency by creating a paperless and automatic management system. Users can customize the workflow and the operational worksheets via software tools preprogrammed into the management functions. The management of day-to-day operations can be automated up to 90%. This significantly improves work efficiency. Utilizing operational worksheets we can achieve a largely automatic distribution and dispatching operation, management and service.

NR Electric promotes a complete automation solution for distribution management system. It provides not only PCS-9000 software system but also PCS-9720A/B substation management units and PCS-9721 series terminal units for switching stations, ring main units, distribution stations, pole-type switches and transformers. All Units give sufficient consideration to severe operation environment impact, and have advantages of high reliability, stability, good electromagnetic capability, low power consumption, wide working temperature range, shock-proof, water-proof, anti-lightning and easy maintenance. The PCS-9720A/B distribution sub-station management unit is usually installed in substations for distribution automation and information transmission between terminals. It collects data from DTU & FTU and transmits them to the main station via analog/ digital channels or Ethernet network based on the IEC60870-5101, IEC60870-5-104 or DNP 3.0. Simultaneously, it receives remote commands and delivers them to other intelligent equipment.

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Management Unit

Operational worksheets and work flow aimed at day-to-day

Features

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PCS-9720

The CPU of PCS-9720A/B adopts the INTEL high-speed low-consumption network processor, which can process the full-load data flow in the 100Mb/s Ethernet connections easily. Additionally, the 128Mbytes cache on each CPU board can help to fully utilize the high-speed performance of the CPU.

The PCS-9720A/B management unit adopts complete electric-isolated duplicated-unit configuration which ensures each unit has independent power supply, modules and rear panels. The two units have no electrical connection except for the external communication links where effective electrical isolation is adopted. The complete electrical isolation greatly improves the independence of a single unit. Thereby, ensuring real redundancy of duplicate unit and its safe operation.

The complete redundant duplicate unit design enables the device switch-over, manual/automatic channels switch and real-time data synchronization of duplicate units very smooth, fast and seamless.

Benefitted from embedded real-time operation system and reliable network protocol stack, PCS-9720A/B is capable of ensuring the reliability of real-time operational systems. The network protocol stack dramatically improves real-time full capacity flow of network data and efficiently prevents any malign networks from accessing. Thereby ensuring the safe and reliable operation of the device.

The large capacity hard disk with a memory of 8Gb ensures unlimited information storage of event information and control commands.

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PCS-9721A

Distribution Terminal Unit (DTU) for Switchyard

NR Electric’s solutions for switching stations, ring main units, distribution stations, pole-type switches and transformers are to provide PCS-9721 series products include PCS-9721A/B/ C. It is designed to accomplish SCADA real-time monitoring, distribution automation, power quality management and switchin and retransmission functions of intelligent equipment. They give sufficient consideration to severe operation environment impact, and has the advantages of high reliability, stability, good electromagnetic capability, low power consumption, wide working temperature range, shock-proof, water-proof, antilightning and easy maintenance. To improve the accuracy of fault discrimination and enhance the efficiency of fault isolation, terminal units are equipped with an optical fiber Ethernet ring communication network, which provides it with high communication speed and transverse communication capabilities between devices. The distribution network terminal units can easily form an Ethernet ring network using optical fibers without any optical transceiver, leading to simplified maintenance work and enhanced communication reliability. The PCS-9721A Distribution Terminal Unit (DTU) can provide real-time SCADA control and monitoring, fault detection, distribution automation and communication management for 10KV switchyard or switching room.

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PCS-9721B Distribution Terminal Unit (DTU) for Ring Main Unit

Features •

The PCS-9721A can provide distribution automation (DA) functions to up to 6 lines and several PCS-9721As can be connected via Ethernet for expansion.

The PCS-9721A has powerful communication management functions which collect data from low voltage protection devices, electric meters, and integrated testers. The communication protocol is expandable and configurable.

The PCS-9721A can provide DC measurements to accommodate the application of the switching station with the transformer.

The PCS-9721A has fault detection and discrimination functions to protect against faults of over current and zero sequence over current.

The primary communication is implemented by optical fiber network, and the serial port and GPRS can be used as a backup. When optical fiber network is adopted, the capability of the transverse communication between units is provided to improve accuracy of fault discrimination and

The PCS-9721B Distribution Terminal Unit (DTU) can provide real-time SCADA control and monitoring, fault detection, distribution automation and communication management for 10KV main ring unit.

Features •

The PCS-9721B has advantages of large capacity and modularized components. It can provide monitoring for up to 6 lines.

The PCS-9721B has powerful communication management functions which collect data from low voltage protection devices, electric meters, and integrated testers. The communication protocol is expandable and configurable.

The PCS-9721B has fault detection and discrimination functions to prevent against faults of over current and zero sequence over current.

The optical fiber network is adopted as the primary communication mode, with the serial port and GPRS as backup. When an optical fiber network is adopted, the capability of the transverse communication between units is provided to improve the correctness of fault discrimination and efficiency of fault isolation.

efficiency of fault isolation.

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The PCS-9721C FTU is designed to provide monitoring and control of circuit breakers for 10KV distribution overhead lines. It offers real-time SCADA monitoring, fault detection, DA and communication management functions. It can be deployed directly on the outdoor tower.

PCS-9721C Feeder Terminal Unit (FTU)

PCS-9721C has fault detection and discrimination functions to protect against over current and zero sequence over current.

Features

The primary communication is implemented by optical fiber network, and the serial port and GPRS are used as backup. When an optical fiber network is chosen, the capability of the transverse communication between units is provided to improve accuracy of fault discrimination and

efficiency of fault isolation.

The powerful communication management function can help in information transmission and switching over to other separate intellectual devices, such as Transformer Terminal Units (TTU) and electric meters. The communication protocol is expandable and configurable.

POWER ELECTRONICS Chapter 5

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APPLICATIONS

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PCS-9580

Static Var Compensator (SVC)

Renewable Energy Generation

Benefits

Weak energy generation systems such as small hydro-power plants or wind power plants often experience power oscillation problems. By installing a SVC system at the interconnection point, these systems can effectively stabilize system voltage to an acceptable level. Therefore, preventing harmful impacts caused by faults in the power grid.

Increase power factor.

Reduce voltage distortion caused by harmonics.

Stabilize voltage and reduce voltage fluctuation and flicker

Balance three-phase load and improve negative sequence.

Enhance operation safety of impact-loading equipment and its adjacent electrical equipment.

Benefits •

Improve power factor

Filtering harmonic current

Reduce power fluctuation and voltage flicker

Provide local reactive power support, stabilize system voltage and reduce transmission line losses

Industrial Consumers NR Electric’s PCS-9580 Static Var Compensator (SVC) system is a shunt reactive power compensation system with integrated control and protection system. It is based on the high-power thyristor semiconductor technology used to improve power system transmission and distribution performance. The stability and economy of power grid operations can be affected by active and reactive power disturbances caused by switching of large loads or other common system faults. The resulted overcurrent and over-voltage may damage the related electrical apparatuses. The PCS-9580 static Var compensator system can adjust the reactive power in the power grid to achieve a reasonable power flow distribution.

Additionally, a SVC system installed on the AC side of the DC converter station can provide sufficient reactive power. In addition, the SVC system features fast response and easy

Compared with traditional reactive power compensation methods, the PCS-9580 SVC system has extensively gained a significant application. This is primarily due to its superior performance in supplying dynamic reactive power with fast response time and with low-cost maintenance.

Applications A complete SVC system can be used to generate/absorb time-changing inductive and capacitive reactive power in a fast response time. So far, the SVC system has been used successfully in electric power systems and industrial fields.

Power transmission For long-distance AC transmissions, transmission capacity is limited by the influence of voltage rise in the middle of transmission lines. Therefore, to reduce the voltage rise and maximally enlarge the transferred power, SVCs are normally installed at a midpoint or several points in the middle of the transmission lines.

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maintenance.

Benefits •

Regulate and stabilize system bus voltage.

Increase static stability and transient stability of the power system.

Increase line transmission capacity.

Restrain power oscillation and sub-synchronous

Electric power rectifiers, when applied to electrolysis power supply and mill machines, require large amounts of reactive power. The use of AC arc furnace usually yields heavy harmonics and large negative sequence currents. Large amounts of reactive power variation result in the voltage fluctuation and flicker, which also reduces the operation’s efficiency. The SVC system can supply sufficient reactive power, and also eliminate the harmonics to prevent against voltage fluctuation in the equipment.

Configuration The PCS-9580 static Var compensation system consists of a static var compensator and a control and protection system, which is used to protect capacitors and reactors in the valves. The static Var compensator is composed of a thyristor controlled reactor (TCR), thyristor switched capacitor (TSC), thyristor switched reactor (TSR), and a Mechanical Switched Capacitor (MSC). It supplies reactive power to the grid. It may also absorb surplus reactive power from grid. Under normal operating conditions, the system receives the reactive power from a group of capacitors. Then the surplus reactive power can be absorbed by an air-core shunt reactor.

resonance. Restrain transient overvoltage.

Distribution system The PCS-9580 SVC can be connected to the terminal substation of the power distribution system to reduce reactive power consumptions, improve power factor, reduce distribution system losses and decrease damages caused by frequent switching on/off the capacitor banks.

Benefits •

Reduce reactive power exchange and improve system stability

Improve power factor and power quality

Decrease system losses of distribution system

Operate in combination of stepped-switchover capacitor bank to reduce the damage caused by frequent switching of the capacitor bank

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The current in the air-core reactor is controlled by a thyristor valve. The valve controls the fundamental current by changing the firing angle. These control features ensure that the voltage can be limited to an acceptable range.

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Capacitor/filtering banks can supply sufficient capacitive reactive power to a given power grid and filter harmful harmonics. Banks are composed of multiple capacitors and other auxiliary components such as a filtering reactor and filtering resistors.

Step down transformer The SVC valve is always connected to the bus in the power substation, and a step-down transformer is required in case of abnormally high voltage levels in the incoming

Professional system design --

Control and protection system SVC control system is composed of an operator workstation, LAN and printers. It realizes SVC remote control, monitoring and event alarm functions from the control room.

Thyristor valve Thyristor valves are the main control hardware in the SVC system. The valve is composed of several series/parallel connected thyristors and the auxiliary components. Each thyristor is controlled through optical fibers and is cooled down by the water cooling method.

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SVC control and protection equipment covers the master controller, distributed field bus, distributed I/O, etc.

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Microcomputer protection measurement and control equipment, including reactor and capacitor protection, and filter bank protection.

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Interface to primary equipment and measuring equipment. This equipment includes valve trigger control unit (VCU), a water cooling control interface, current and voltage measurement interface, breaker/ switch interface, etc. The VCU communicates with the SVC controller as well as with the valves. Furthermore, the water cooling control interface controls the water cooling equipment.

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Interface to other control systems, such as substation monitoring system, include the communication management device (protocol converter). This device is installed to transmit SVC alarm information, protection information, and important status information and operation parameters to the substation monitoring system or remote dispatch system. The communication management device receives control and status information from the substation monitoring system and remote dispatch system. The communication management device also recieves time clock comparison signal using the

NR Electric takes into account RTDS, analog simulation environment and PSCAD in the design processes to study system stability, active and reactive power distribution and power quality as to optimize SVC system design.

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Optimized filter groups can filter large amount of harmful harmonics, providing fundamental frequency reactive power and minimizing dynamic active power losses.

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The customized SVC system can analyze system power quality to check injected harmonic current and filter resonance.

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The optimal regulation modes will be selected based on the installation place to gain the most effective voltage/reactive power regulation.

Water cooling system A water cooling system is necessary for thyristor valves, which have high operating voltage. The cooling system uses deionized pure water as the internal cooling medium and air for external cooling.

Linear (air-core) reactor Air-core reactors are stable and have good linear performance. An air-core reactor can be used to absorb or adjust the reactive power. Usually the air-core reactor is linked in series with the thyristor valve using delta connection, and then connected to the power grid.

Medium voltage switchgear A medium voltage switchgear can be installed indoor or outdoor. It includes isolating switches, grounding switches and circuit breakers.

Functions and Features

In practice, the capacitor/filtering banks are divided into several sub banks and can be connected/disconnection to the system by breakers or other thyristor valves.

line.

Capacitor/filtering banks

integrates forward overvoltage protection components, and thyristor management units are used instead of thyristor control units. •

A thyristor can be damaged by a large size forward voltage if there is no current flowing thought the thyristor. Thus it is essential to force the thyristor to switch on before the voltage across the thyristor reaches the break-over voltage threshold. The break over diode (BOD) is usually used to protect thyristors from being damaged by forward overvoltage. However, a series connected BOD can cause a large deviation in the break-over voltage threshold. To solve this problem, NR Electric invented the unique circuit integrated thyristor protection valves. It reduces the break-over voltage deviation to a minimum value, so that the break-over voltage can be fixed manually in order to accomodate different types of thyristor.

Thyristor valve NR Electric’s TCR valve has many advantages like compacted structures and light weight. Therefore ,occupying less area, and making valve installation and maintenance work much easier. The valve assembly is completed in factory before shipping to ease on-site installation. Only the electrical connection to reactor, the hydraulic connection to water cooling system and the optic connection to control devices are conducted on site.

Electric-optical triggering system

The electrical triggering system is comprised of two parts: the Valve Control Unit(VCU) in the control room and the Thyristor Control Unit(TCU) in the valve. The Control Pulse (CP) is converted to an optic Firing Pulse (FP) by VCU. This optic FP is then converted to an electric FP to trigger the thyristor. The conversion between optic to electric FP is conducted by TCU. If the thyristor is not forward biased or damaged, the control system will issue an alarm or stop operating according to the signal sent from TCU. The optic triggering system uses light to trigger thyristor. It

Thyristor breaker-over voltage protection

Water cooling system NR Electric’s SVC system uses the industrial-class hermetic water cooling system with de-ionized water for heat dissipation. This patented cooling radiator features low thermal resistance and low water resistance. Due to their high reliability, NR Electric’s water cooling systems are currently utilized in several industrial sectors such as aviation, power generation and HVDC transmission. Well-proven protection and control system The protection and control of the Static Var Compensator system uses the same reliable software and hardware platform as the HVDC control and protection system. The highly integrated software platform uses graphic programming and test tools to realize diverse control functions. The universal hardware platform is equipped with multi-functional modular PCB to achieve data acquisition, control and monitoring functions.

substation main GPS .

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PCS-9583

Static Synchronous Compensator

The static synchronous compensator (STATCOM) is currently the most advanced technology in reactive power compensation. It is based on a voltage-source converter and can act as a source. The STATCOM can automatically output inductive or capacitive power, and follow the demand on load side or in the power system network. NR Electric’s STATCOM adopts a cascading scheme of multilevel topology. This topology consists of several H-bridge power

units with monopole multiplier modulation to achieve threelevel output on the AC side. Each phase uses the carrier phase modulation method to obtain better voltage output waveform with more levels. The use of industrial grade components significantly improves the entire system’s reliability. The multilevel output voltage has low harmonics, which can effectively reduce the voltage distortion at the interconnection point and decrease the harmonic current flowing into the outside grid.

NR Electric's H-bridge cascading STATCOM is composed of power units, reactors, starting units and control units. Control units regulate the control of normal operations, running mode switching and data exchange with the substation automation system. The advantages are shown as follow: •

Faster response time

High voltage flicker reduction

Wide operating range

Various compensation functions

Lower harmonic

Small site space

The H-bridge cascading STATCOM provides direct dynamic reactive power compensation for HV busbar. The compensation is composed by a series cascading connections of full-controlled converter bridges.

Advanced OWS --

Support IEC 60870-5-103, IEC 61850 and other international standards

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Support the entire substation monitoring solution.

Advanced control and protection platform --

Advanced IC technology and network communication technology

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Smoothly upgraded upon each module

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Visual programming and on-line debugging

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Hierarchical and distributed control and protection system

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IEC 61850(GOOSE,SV), IEEE1588 and other standards

Integrated wave recording function --

Transient and steady state waves

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IEEE Comtrade format

DC voltage balancing techniques --

Chain balance algorithm integrated with phase balance algorithm

Professional test environment --

Real time digital simulation lab

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High voltage test lab

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High power test lab

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Analogue simulation test lab

NR Electric's STATCOM has been widely used in the utilities field and other industries. NR Electric technology has also been well proven in these applications, whose performance and features are listed as follow: •

Professionally designed power module

Redundant design

Hierarchical protection function --

The operation time in element-level shall not exceed ten microseconds.

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The operation time in device-level ranges from 100 to 1000 microseconds

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The limit protection time in system-level is from 5 to 2000ms.

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The control unit is used as the backup protection.

Figure 1. Cascading scheme of STATCOM

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PCS-9570

Series Compensation The PCS-9570 series products are designed based on years of experience in the protection and control solutions for HVAC relay protection. The AC digital sampling, based on electronic transformer measurement, effectively solves the interference problem on site. The protection and control model based on IEC61850 standards can implement sequence control of the substation series compensators to automatically switch-in or switch-over capacitor banks with series compensators, so as to optimize the power flows and improve transmission capacity in digital substations.The series products are mainly applicable in the AC transmission lines of 66kV~1000kV.

The spark gap is the main component for series compensation. It serves as the key component used to protect the capacitor and MOV against overvoltage stress. NR Electric’s spark gap is initiated by a trigger circuit. Forced-triggered gaps typically spark over only during internal faults. The maximum time delay from the point at which the MOV high-current or high-energy bypass threshold is exceeded until Spark Gap conduction shall not exceed 1ms. Series Compensation typical system configuration is shown below. The NR Electric protection devices and trigger gap control provide a redundant design. The series compensation switching control device integrates a conventional circuit breaker monitoring and control function into one device. The protocol converter and the remote device are configured, based on the system’s needs. The remote device implements distant sequence control of series compensation, allowing for a

Features •

Professional design for safe and reliable primary system The protection and control system were designed to fascilitate the coordination among the capacitor bank, MOV, spark gap, damping circuit, and electronic transformers.

Advanced UAPC platform The UAPC platform developed by NR Electric features reliable performance, rapid processing and modular interface/card plug-ins. It has been widely used in HVDC transmission systems.

Duplicated protection configuration This configuration was created to ensure the reliability of the protection system.

Easy-to-use series compensation debugging device The conventional relay testers, are also Suitable for on-site for series compensation check.

maintenance-free station.

The series compensator (SC) plays an important role in the intelligent network due to its effect on transmission lines, especially with long distances. It can increase the power capacity of the transmission network and optimize power flow dispatching, reduce power losses and make full use of power supply at the minimum generation cost. NR Electric’s PCS-9570 series compensators offer complete SC solutions. The PCS-9570 consists of capacitor, metal oxide arrester, damping circuit, spark gap, bypass switch, series compensator platform and electronic transducers, SC protection & control system, etc.

Figure 1. Protection and control system panel configuration

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PCS-9590 DC De-Icer

Heavy ice coating can damage transmission lines and towers, ultimately leading to a power supply outage in partial or the entire grid network. To guarantee the safe operation of the power system in severe weather, NR Electric provides consumers with the PCS-9590 fixed DC de-icer and the PCS9591 relocatable DC de-icer for the protection of transmission lines. The DC output voltage is adjustable. Different DC shortcircuit currents can be supplied according to the conductor’s diameter and length. In addition, the de-icer device can also be used as SVC to quickly compensate reactive power, stabilize system voltage and improve power quality.

PCS-9590 Fixed DC De-Icer

Relocatable DC De-Icer

The fixed DC de-icer can be used for long transmission lines with high voltage level. The power supply of PCS-9590 is normally fed by a LV AC bus. The PCS-9590 fixed DC de-icer includes:

The relocatable DC de-icer device can be utilized in shortdistance lines with low voltage levels. The PCS-9591 relocatable

Two standard containers: one is used to install valve banks and water cooling system, the other is equipped with phase switching disconnector and control panels.

Converter transformer: to offer voltage transformation and commutation reactance

12 pulsation conversion valve banks: to convert AC current to DC current.

Water cooling system: including indoor forced water cooling and outdoor forced air cooling.

Phase switching disconnector: to select the target AC line and realize balanced de-icer of AC lines.

Control and protection system: to provide supervision and

DC de-icer includes: •

One standard container: to install all equipments.

6-pulse conversion valve: To convert AC current to DC current.

Cooling system: including indoor forced water cooling and outdoor forced air cooling.

Phase switching disconnector: to select the target AC line and realize balanced de-icer of AC lines.

Control and protection system: to provide supervision and protection functions for the whole DC de-icer device.

protection of whole DC de-icer device.

Figure 3. Relocatable DC De-Icer Topology

Figure 2. Fixed DC De-Icer Topology

Features

Figure 1. Melting configuration with DC De-Icer

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The use of thyristor rectifiers can reduce the impact on the power system during ice melting and ease the switch-over operations.

The DC de-icer device supports large current and large angle continuous stable operation. It is applicable to transmission lines with different conductor diameters and lengths.

The PCS-9590/9591 DC de-icer can adopt container type installation and valve hall installation, effectively reducing land occupation, shortening the site construction time frame and easing the equipment transportation.

The device adopts reliable and compact structure with a water cooling or air cooling system and compact valve banks.

The PCS-9590/9591 is equipped with 6 phase switching disconnectors enabling the automatic switchover among various ice melting modes and realizing the balanced ice melting for AC lines.

NR Electric also provides the high performance control and protection system for DC de-icing.

Primary system of DC ice melting device requires only very small number of operations to realize SVC function.

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- Dynamic Var control In case of voltage drop in the grid, the control system can provide automatic reactive power compensation to maintain a stable grid voltage based on the voltage dip and duration. - Island detection The system can rapidly detect the appearance of island conditions and handle it according to the preset configuration.

PCS-9563

- Low voltage ride through (LVRT) operation The PCS-9563 inverter can maintain grid-interconnection operation and realize LVRT in case of low voltage fault in the grid.

Photovoltaic Interconnection system is not required. The inverter automatically detects the DC/AC system data in standby mode and automatically shifts to ‘Run’ mode for grid interconnection when running conditions are fulfilled. It tracks the PV array maximum peak power (MPPT) in real-time and maintains the maximum power output during running.

The PV grid-interconnection system converts solar power to electric power and transmits it to the grid. It consists of solar array modules, a PV convergent cubicle, PV grid-connection inverter, and grid-connection system. NR Electric introduces PV grid-interconnection technology and provides an integrated solution for inverters, substation monitoring and power prediction, PV power stations centralized monitoring and control. The grid-connection inverter is the key equipment of the PV grid-tie system. PCS-9563 series PV grid-interconnection system consists of an advanced IGBT controlled inverter, protection & control equipments, I/O switchgear, etc. The system power capacity portion is designed in modularized structure featuring easy extension, convenient installation and maintenance, optimal layout, and less land occupation. The system control portion is based on the professional control and protection platform featuring abundant hardware resources, complete software functions, and flexible configuration of control/operation parameters.In effort to maximally meet the extension demand of the system’s flexibility and extensibility.

Function •

Operating modes The PCS-9563 has three operating modes—Standby, Run and Stop; two self-check statuses—Normal and Fault; several running control modes—PQ control, Voltage Frequency control and Low voltage ride through (LVRT), etc.; and several auto control logics—Auto run, Auto stop, Fault emergency stop, etc.

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Auto start/stop The PCS-9563 PV grid-interconnection inverter is designed with automatic grid connection; therefore, manual control

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Auto fault processing During grid-interconnection operation, the inverter detects the self-operation conditions and the status of PV array and AC grid in real-time. When a fault or abnormal condition is detected in the PV power generating system, the inverter will stop running, send out alarm signals and enter fault emergency stop mode. Then, detailed fault information is displayed on the LCD screen of the control devices. The inverter will continuously detect the system’s status in fault mode and automatically restore running mode after the system fault is cleared for 5 minutes.

diverse performance margins to ensure the reliable system operation and working life. The inverter adopts modular design to ease installation and maintenance. These modules include a IGBT module and other major equipments. The large capacity IGBT modules are used to reduce parallel connections and increase equipment reliability. The optical triggering method has strong antiinterference capabilities and a patented heat dissipation scheme is employed to achieve high reliability and efficiency. •

High-performance and reliable control devices The control & protection devices feature excellent performance, high reliability and mature hardware/software technologies. The core controller is equipped with the most advanced floating algorithm, which has the advantages of high main frequency, large memory capacity, and high computation and control accuracy. The control system fully supports protocols such as IEC61850 and IEC60870-5103, etc. The equipment uses integrated front panels and an enclosed rack that serves to protect against dust and ensure the safe and reliable operation during the service life of the PV power station.

High power quality The grid-connection power quality controlled by PCS-9563 is far higher than that defined in the relevant codes and standards. In the certified test by CGC-SOLAR, both the total harmonic distortion of voltage (Uthd) and current (Ithd) are smaller than 2%, the voltage on connected network is even smaller than 1% at rated power.

Complete and reliable protection functions PCS-9563 system has inherent protection for IGBT modules by detecting abnormal dv/dt and di/dt across IGBT and blocking the triggering pulse instantly. As a result, it can ensure a safe and reliable operation or rapid and safe shutdown in severe environments.

- Power quality (PQ) control The system is designed with grid-interconnection power optimization to ensure power quality.

Features •

Product testing and certification The PCS-9563 inverter has passed the LVRT field test by SGEPRI and Qinghai Electric Power Research Institute in the Qinghai PV Power Station.

High reliability and long-life system design The primary and secondary components of the inverter are designed and manufactured with high quality and long operation life. The component selection, power unit design, and heat dissipation designs are conceived to perform optimally at high altitudes and extremely adverse conditions. In addition, these designs take into account

Running functions - SCADA The SCADA function acquires and processes the real-time system operating data of the PV system. The collected information includes battery DC voltage measurements, inverter running data, etc. Then SCADA sends out an alarm and updates the automation system database. - Soft grid-connection control The control system can accurately regulate the inverter output voltage in real-time. This is accomplished by relying on the detected grid voltage and eliminating dynamic/static error to realize impulse-free connection. - Maximum Peak Power Tracking (MPPT) control The system can search the maximum peak power based on the collected battery physical data and control the realtime tracking of the inverter. Ultimately, achieving maximum power utilization.

Technical Data Input Data (500kW) Maximum DC Voltage Maximum DC Current Maximum Power Starting Voltage MPPT Voltage Range

1000 V 1200 A 550 kW 550 V 500~820 V

Output Data (500kV, 50Hz) Rated Voltage Rated Current Permitted Voltage Range Maximum Efficiency Total Harmonic Distortion Power Factor

315 V 916A 284~347 V 98.5% < 3% -0.9~0.9

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System Configuration •

PCS-9561

Cabinet Arrangement The PCS-9561 doubly fed converter system is especially designed for doubly fed wind power turbines. It consists of a grid interconnection/control cabinet (1200mm*800mm*2200mm, protection class is IP54), and power module cabinet (1200mm*800mm*2200mm, protection class is IP23).

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The filtering system contains grid side LCL filter and generator side du/dt filter. The grid side LCL filter can effectively filter high frequency harmonics flow from converter to grid. The du/dt filter works with the choking reactor on the generator to suppress voltage peaks and fast transient voltage, which appear on rotor, thus effectively delaying motor insulation aging.

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The temperature control system monitors temperature and humidity of key parts inside the cabinet. It controls the cabinet internal temperature and humidity within an acceptable range through heating, aircooling, heat dissipation, and dehumidifying.

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The pre-charging system is used to raise the DC voltage of DC capacitor to certain amplitude prior to the startup of the converter. Thereby, reducing the current impulse during converter startup to the maximum extent.

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The low voltage system adopts active crowbar circuit. In case of operation fault, line fault, or rotor high voltage, the low voltage system can protect the power semiconductor devices at motor side in order to achieve low voltage ride through. Thus the converter system can supply current to the grid even in the case of grid fault.

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The power distribution system provides uninterrupted power supply for each active device of the converter.

Wind Energy Converter System Due to the rapid development of computer science and control technologies, wind power technologies have also advanced at an equivalent rate. Wind power generation control methods have evolved from simplex constant pitch stall control to full blade variable pitch and variable speed control. At present, the doubly fed converter system with variable speed and constant frequency control is widely used in the wind power generation market.

Operating principle Figure 1 shows the schematic structure of a doubly fed converter. The rotor is excited by two back-to-back connected VSC converters with PWM. This arrangement is referred to as generator side converter and grid side converter respectively. The doubly PWM converters supply excitation current to rotor winding in order to realize the maximum capture of wind energy and the adjustment of stator reactor power output. When the

turbine operates at a sub-synchronous speed, power is fed into the rotor and the grid side converter runs as a rectifier while the rotor side converter runs as an inverter, providing the excitation current to the turbine. When the turbine operates at supersynchronous speed, stator and rotor can both feed energy to the grid. If the turbine operates in synchronous status, the generator runs as a synchronous motor and the converter system provides DC excitation to the rotor. The grid side converter and the generator side converter are controlled by two control units. The grid side control unit is used to maintain DC busbar voltage stability and ensure high quality input current waveform and unit power factor. The generator side control unit is used to controls the rotor current torque and the excitation components of a doubly fed motor to adjust its active power and reactive power output, and tracks active power order and reactive power order. So that the doubly fed motor can run on the optimum power curve of wind turbine to realize the maximum capture of wind power.

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The grid interconnection/control system is divided into two isolated cabinets, which are the control cabinet and the grid interconnection cabinet. The control cabinet is composed of controller, UPS, low voltage circuit breakers, protection devices and wiring terminals, etc. The grid interconnection cabinet incorporates a distribution transformer, main circuit breaker, grid interconnection contactor, grid side contactor, main fuse, and pre-charging resistor, etc. The power module cabinet is the main part for accomplishing current conversion. In addition, there are three power units at both grid and generator sides. Each integrate IGBT, drive board, radiator, DC capacitor, absorption capacity, temperature measuring resistor, etc. The power module cabinet also includes laminated busbar, grid side reactor, bridge arm side reactor, generator side reactor, grid side and generator side filtering resistor and capacitor, large and small fans, heater, etc.

Primary part The primary part of the converter system consists of power modules, integrated power units, heat dissipation accessories, filtering component, etc. The integrated power units include IGBT and its drive. The secondary part includes the protection unit, temperature control system, pre-charging system, low voltage ride through system, etc. --

The power module consists of three groups of grid side power units and 3 groups of generator side power units connected by a laminated DC busbar. Each group of power units integrates high power switches, air-cooling radiator and gate driving units with protection and monitoring circuits, etc. The laminated structure can maximally reduce the stray inductance in DC busbar so as to significantly restraint the voltage peak occurred during turn-off of IGBT.

Control unit The control unit is the brain of the doubly fed converter system; it significantly influences the convertor ’s performance. The control unit mainly performs the following functions: --

Ensure that the converter system torque, or the active output is able to follow orders from the generator to realize the maximum capture of wind power

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Control the power factor by system power factor order (or reactive power order) tracking issued by wind turbine control function;

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Realize “zero” impulse grid interconnection control;

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Control high voltage and low voltage ride through of converter system;

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Restrain the injecting current harmonics to grid via harmonics control strategy;

Figure 1. Schematic structure of a doubly fed converter

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Limit the low frequency rotor current harmonics via SVPWM dead zone compensation strategy;

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Monitor system operating conditions and provide various protection functions such as overcurrent protection, DC overvoltage protection, excess temperature protection, external abnormal voltage protection, over temperature protection, motor overspeed protection, etc.;

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Control the temperature and the humidity of cabinets;

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Communicate with the main controller of the wind power turbine;

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Provide friendly HMI to monitor converter system operating conditions, accurately record operating conditions, and to provide maintenance and fault analysis interface.

NR Electric Co., Ltd.

Photo-electric encoder, which adopts software reset mode, can improve the accuracy and reliability of motor rotation speed acquisition;

High voltage and low voltage ride through control strategies are used to guarantee the converter fault ride through capability;

Harmonics suppression control strategy and dead zone compensation strategy are adopted to effectively ensure the quality of power delivered from converter to grid;

Compatible with various industrial fieldbus communication interfaces, such as CANopen and Profibus;

Identical IGBT converter bridge modules are connected in parallel, and installation and removal of each power module is made convenient;

Elaborately designed filtering system and a harmonics restraint control strategy ensure the superior quality of power delivered to the grid;

This product can withstand high/low temperatures and high humidity. Inside the cabinets temperature, humidity, heating and dehumidifying sensors measure the internal environment. All circuit boards are equipped with anticorrosion coating and all cabinets have very high protection class.

Features •

Fast response capabilities and high control precision;

Complete fault recording function conformed to IEEE COMTRADE format;

Highly reliable and flexible integrated protection system;

Grid interconnection control strategy based on selfadaptive positioning of rotor that can realize “zero” impulse grid synchronization;

PCS-9400

Generator Excitation System

The range of rated currents is 100A to 7000A and the range of voltages is 100V to 700V. The PCS-9400 system is available for various excitation types, including: • Stationary excitation system •

One-generator and one-excitation system

One-generator and two-excitation system

Brush-less excitation system

DC exciter excitation system

PCS-9400 system consists of the following equipment: • Numerical excitation regulator •

Thyristor rectifier

Diode valve rectifier

De-excitation equipment

Auxiliary cabinet

According to the different requirements of each excitation type, all equipment can be flexibly selected to combine to compatible excitation system. • Numerical excitation regulator. It consists of dual-channel configuration or three-channel configuration. Each channel is an independent regulation unit based on advanced hardware platform, which is based on multi-processor system including DSP, ARM and CPU. The system provides all essential functions, such as PID regulation+ PSS strategy, many closed-loop and open-loop control laws, difference regulation, many limiters and protections, i.e. under-excitation limiter, over-

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excitation limiter, false strong excitation limiter, peak current limiter, V/F limiter, overvoltage protection on noload, TV signal failure protection etc. And self-diagnose function, fault-tolerance control element, oscilloscope and event recording function are all equipped with. The HMI with a LCD and a 9-button keypad is friendly to users. And it is also easy to communicate with PC at higher level. Ethernet interface, 2 CAN bus interfaces (Used for internal communication) and RS-232/RS-485 serial ports are supplied for communication.

The PCS-9400 generator excitation system can improve generator performance and reduce maintenance costs. It provides complete control functions, including power system stabilizer, optimum control, adaptive control and other functions. The PCS-9400 can be customized with a wide range of options to accomodate various specifications from customers.

Thyristor rectifier A lot of levels of current output are supplied to match the requirements of users, i.e. 250A, 800A, 1200A, 1800A and 2400A. Parallel-connected multi-cabinet operational mode is adopted. The coefficient of equalizing current is larger than 0.9. Aluminum Radiator or Heat Pipe Radiator can be selected alternatively.

Diode rectifier A lot of levels of current output are supplied to match the requirements of users, i.e. 1800A, 2400A and 3000A. Parallel-connected multi-cabinet operational mode is adopted. The coefficient of equalizing current is larger than 0.9. Aluminum Radiator or Heat Pipe Radiator can be selected alternatively.

De-excitation cabinet Linear or nonlinear resistor and magnetic blow-out switch are supplied in de-excitation equipment. And overvoltage protection is also equipped with.

Auxiliary cabinet Special devices for complicated requirements and logic circuits are equipped with the cabinet.

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Features •

The AVR uses high-performance CPU as the core hardware, and adopts high precise multi-point AC sampling technology, and all the control, regulation, protection function are realized by the module designed software. Rectifier cabinet has high capacity. Cooling Rectifier cabinet is with outstanding cooling effect.

A lot of elements and protections are supplied for complete control function of excitation system.

Parallel-connected dual-cabinet operational mode without switchover process has more reliability.

Trending and recording data are provided. The user can record the data one second before fault. The system measures AC current and voltage of generator, active power, reactive power and power factor, etc.

The voltage response time will not exceed 0.08 s in voltage increasing(force excitation) and will not exceed 0.15s in voltage decreasing(rapid de-excitation and ceiling voltage reducing to zero) •

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The excitation is capable of supplying continuously 1.1 times the field Voltage and field current needed for the rated power output of generator.

The excitation system is capable of continuously supplying ceiling voltage 1.8 times the generator rated field voltage for 15 seconds.

Allowable time for excitation system operation at 1.8 times nominal excitation current is longer than 10s without damage.

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--

AC: -15%~+15%of rated value.

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DC: -20%~+20% of rated value.

Frequency deviation: -5~+22.5Hz. based on the rated frequency

The excitation system is able to control generator voltage change less than 0.25% when generator frequency changes for 1%.

Excitation system parameters such as gains, time constants feedback signals and reference signals, etc. are adjustable ranges and proposed settings are recommended by the supplier. Equipment are properly shielded and willl not be effected by electromagnetic interference. Ratings, tests and characteristics are in accordance with the latest approved standards of IEEC and IEC.

The excitation control can be arranged for both local and remote operations. Unless otherwise specified, all accessories required for control system interface can be provided by supplier whether or not such items are specifically mentioned in contract documents.

All control operations, detailed alarms and operating conditions are possible and activated by an operator panel mounted in front door of the AVR (Automatic Voltage Regulator) cubicle.

Excitation System Functions The excitation system meets the following technical requirements: • The excitation system can supply continuously excitation current required by the generator under all operating conditions.

The excitation system can ensure continuous normal operation of the generator, when voltage and frequency of the station service power varies in the following rangers:

The user can configure and troubleshoot PCS-9400 via the communication network.

The excitation system is a high initial response system.

FLEXIBLE DC Chapter 6

TRANSMISSION

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PCS-9550

LCC-HVDC Control and Protection System The design criterion for the control system is to reach 100% availability for the transmission system. The NR Electric's HVDC control and protection system is equipped with parallel redundancy at all levels. All system parts that are involved in the power transfer of the HVDC link are made redundant.

LCC-HVDC Control and Protection

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Synchronization and time calibration for all subsystems within the station

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Parameter adjustment for DC control system

computers, distributed field buses and distributed I/O. The redundant system configuration is adopted for each pole to achieve the following functions:

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History data documentation

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Generate control pulse for converter valves

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Emergent stopping of AC and DC systems

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Management of converter station documents and programs

Maintain the synchronization between control pulse and commutation voltage

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Keep interval equal between control pulses

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Fundamental training functions

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Deblock/block converter valve with smooth and stable startup/shutdown

AC/DC Station Control System AC/DC station control system consists of main computers and distributed I/O. The DC station control is assembled with the pole control system. The main functions of this system are:

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Regulate triggering angle of converter valves within the designed range to satisfy the ordered amount of power/current.

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Adjust converter transformer tap changers according to the operation status of the AC and DC system

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Sequence control of the equipment in AC and DC switchyard

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Implement sequence control of HVDC system

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Execute trip commands initiated by protections

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Connect and disconnect filters upon the orders from pole control system

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Interlock

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Collect and manage the alarm signals of main/ auxiliary equipment

DC Control System The DC control system implements the control of bipolar, pole and converter unit. It consists of main control

DC protection system DC protection system ensures the safe operation of the whole HVDC system. It includes DC protection (PPR), DC filter protection (DFP), converter transformer protection (CTP) and AC filter protection (AFP). The HVDC control and protection system supports connection to electronic measuring devices, which receive digital measurement signals via optical fiber.

A complete PCS-9550 HVDC control and protection system can be divided into the following sub-systems: A conventional HVDC control and protection system is a key part in guaranteeing the overall performance of the HVDC thyristor-based transmission system. It contributes to safe and steady system operation, provides flexible operating modes and accurate control effects, helps to clear fault and assists in system recovery during system disturbances. A well-designed control and protection system can maximally exert the advantages of conventional HVDC transmission technology in the following aspects: •

Long distance bulk power transmission

Underground or underwater cable transmission

Asynchronous interconnection of an AC system

The PCS-9550 control and protection system is designed based on very powerful and flexible building blocks built with a stateof-art UAPC platform and connected by high performance fiber optic communication links. It brings the biggest convenience to new and retrofit HVDC transmission projects.

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Interface with remote control center (e.g. state dispatching center, provincial dispatching center and remote central control). This sub-system consists of tele-control workstations and Remote Terminal Units (RTUs) for point-to-point communication with remote control centers.

Operator Control System The operator control system is so called SCADA system. It consists of station LAN, operator workstations (OWS), engineer workstations (EWS), SER terminals, system servers, station clock, etc. The operator control system is used as the man-machine interface during HVDC operation and has the following functions: --

Receiving and executing operation orders from operators or dispatch center

--

Monitoring and processing failure information or abnormal operation status

--

Event sequence record and event alarm within the whole station

Figure 1. LCC HVDC control and protection structure

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Hierarchical and Distributed Structure

NR Electric Co., Ltd.

Features •

Full digitalization - all complex control and protection functions are realized by software precisely

Open-ended - based on well-proved and common industrial standards

High reliability

High integration level

Easy to cooperate with converters in various techniques

Communications between distributed cells are based on standard Fieldbus or Ethernet via fiber cables. This arrangement features excellent real-time properties, strong interference immunity and good stability and reliability.

Visual programming and debugging tools with cross platform capability

High-performance distributed system with the fastest interrupt response time of 25us;

The whole HVDC control and protection system is built in hierarchical structure, which is divided into station level and equipment level. Station level equipments include SCADA system equipments. Equipment level equipments include control and protection units, I/O interface and distributed field bus. The station level and equipment level are connected via redundant a SCADA LAN network. While the control and protection units and their I/O interfaces are connected through optical Fieldbus.

Efficient heat dissipation - system without rolling fans

High-accuracy measuring system with synchronous sampling technology;

The HVDC control and protection system is designed in a distributed structure with object-oriented principles. Each cell is responsible for monitoring and controlling equipment in one physical or logical area. The design of each cell aims at independence to achieve minimum information exchange between different cells, and to eliminate the influence of a faulty cell on the normal operation of others.

Redundancy The design of HVDC control and protection system aims at 100% availability and the whole system is built in redundant structure. The reliable and complete duplicate design ensures that the normal operation of the HVDC system can be immune to any single failure. For the redundant control system, one system is active and the other is on hot standby. System self-supervision and automatic switch-over functions are used to ensure that the relatively healthy system is active. Operators may also manually select the system’s operating state.

Optical – media-based Fieldbus of high interference immunity, less use of cables;

Systematic electromagnetic shielding design, high interference immunity;

All parts in the system are in redundant design, including I/ O devices;

Self-supervision function and fast switch-over in 2ms;

Flexible configuration of protection, easy to realize duplicate, redundant or two-out-of-three configuration.

Compatible with IEC 61970 standard and fully supports IEC 61970 CIM graphic-model-database integration technology; supporting many standard communication protocols and the connection to equipments using different communication protocols (IEC-61850, IEC-60870-5-101, IEC-60870-5-102, IEC-60870-5-103, IEC-60870-5-104, IEC-60870-6 (TASE 2)).

Abundant events with characteristic easy to distinguish. Dynamic link can directly indicate the variable in visual program tool and fault tracing;

Independent harmonic supervision system;

Independent 2M tele-communication channel for protection system;

Tele-control system can be chosen between UNIX or embedded unit system

PCS-9520

VSC-HVDC Control and Protection System The control and protection solution is the brain of the entire TM

VSC-HVDC system. The HVDC SuperCon control system employs tough UAPC platform designed by NR Electric, to implement hierarchical structure, redundant design, robust control functions and comprehensive protection scheme. It monitors, controls and protects all equipment in the VSC-HVDC transmission system and converter station. Control and protection system is designed by applying embedded CPU, DSP with current advantageous reliability, functionality and processing power, and high-capacity FPGA, by taking the fiber channel acquired with industry-standard high-speed Ethernet and IEC-standard analog data as the data transmission link, and by using internally high-reliability, realtime, high-efficient data exchange interface. All board cards are based on standardized, modular design, so as to flexibly build a variety of devices necessary to the system. Each VSC-HVDC project has two independent control and protection systems for redundancy to ensure high reliability. Multiple transient fault recording (TFR) functions are for fault tracing in the control and protection system. The recording settings are flexible to accommodate the consumer ’s requirements. Therefore, it provides complete a picture of the dynamic performance of the converter. VSC-HVDC control and protection system consists of operator monitoring equipments and distributed control and protection equipments, with the former connected with control and protection equipments via high-speed Ethernet while the latter mutually communicated and coordinated by means of highspeed on-site bus.

Operator Monitoring Equipment Operator control system is the operation and monitoring interface of the operators for VSC-HVDC consisting of the workstation, server and remote communication equipment, so as to achieve multiple monitoring of station, remote scheduling and centralized control center. Station operator monitoring: Providing converter station operators with an interface of monitoring and control. The operators control layer equipment, completing operations monitoring, control, fault or abnormal condition handling, control and protection, as well as parameter adjustment. Remote control center monitoring: Sending operating parameters of the AC-DC system and control and protection system of the converter station to the remote control center through the communication channel, and sending control and protection parameters and operating instructions of the monitoring and control center to the control and protection system of the converter station. Centralized control center monitoring: Establishing the centralized control center with remote communication or station LAN network extension and implementing monitoring and control functions in the same as the station monitoring and control;

Distributed Control and Protection Equipment Distributed control and protection equipment achieves control and protection functions of the AC-DC system, including the control and protection of the host and IO.

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DC control and protection host adopts the overall design, including system-level, converter-station-level and converterlevel control protection which are integrated in a single host. This design has the such advantages as effectively reducing interfaces and decreasing fault rates and improving the system availability, thus ensuring the microsecond-level control, improving the system transient performance and fault ridethrough capability, guaranteeing accurate multi-terminal coordinated control and reliable takeover of the standby station in case of a fault.

Support FACTS equipment to use digital communications to achieve coordinated control.

High-performance decentralized, distributed system based on embedded hardware technology

Core control and protection function, running in nonoperating system environment, as well as good stability

Master control and protection unit uses dedicated HTM high-speed data bus, ensuring the powerful processing capability

In addition, the control layer equipment is comprised of the exchange station control system (including station power control and auxiliary system interface), coupling transformer protection equipment, etc.

Full system redundancy design, dual power supply configuration

Systematic design of electromagnetic shielding, strong anti-interference ability

Consisting of measuring and monitoring equipment, I/O unit is the interface of the protection layer, AC-DC primary system, converter station auxiliary system, station power equipment and valve cooling control and protection equipment. Adopting decentralized distribution design, it communicates the upper high-speed communication host through high-speed on-site bus.

Fiber media field bus, high anti-interference ability, a small number of cables used

Unix / Linux + Windows hybrid platform system controlled by operator, with dual advantages of both security and ease of operation

Each software of all devices’ supports the remote maintenance of the workstation

Its main features are: • Support electronic measuring equipment and optical measuring equipment.

Friendly man-machine operation interface

Rich and accurate alarm events

Complete, accurate internal wave-recording function

Full-truth training systems

Full-featured backup on-site control system

Support external coordination control system(s) to use digital communications to achieve AC and DC coordinated control.

PCS-8100

VSC-HVDC IGBT Valve The PCS-8100 converter valve is comprised of sub-modules, converter valve tower and valve control units. It is one of the

--

Based on the power module frequency optimized control technology, it reduces switching losses and improves the efficiency of the transmission system.

--

The power module circuits, based on centralized layout and covering design by partition, compact structure, additional shielding design in terms of functional partitions, and high anti-interference ability, improve the reliability of the converter valve operation.

--

Based on the building block concept and compact structure, the power module circuit is characterized by easy maintenance and repair.

--

The power module over-voltage protection strategy, based on hardware circuit protection and realtime sampling software circuit protection combining hardware protection speed-ability and software protection flexibility, effectively solves the problem of over-voltage of series modules, achieving reliable overvoltage protection.

--

Hardware detection technology and driving grading current protection technology helps achieve excellent fault ride-through capability.

--

Based on patented technology, the radiator takes advantage of the IGBT current capability.

--

The reliably designed water cooling system ensures the safe operation of the converter valve.

TM

core equipment of HVDC SuperCon which is used to achieve mutual conversion between DC and AC. NR Electric HVDC TM

SuperCon system is based on a multi-level voltage sourced converter technology. Its innovative design offers technical and economic advantages. The capacitor and IGBT-based switching devices are key components of a sub-module. Each valve phase bridge is composed of several sub-modules and a series of connected reactors. By setting the quantity of submodules, the converter’s output voltage and power levels are flexible to control. Thus, it is easy to extend the output levels with low harmonic distortion and low switching frequency, so as to reduce operational losses and improve system efficiency. NR Electric PCS-8100 converter valve features low running loss, high margin of safety, easy operation and maintenance. •

Modularized, layered and staged, compact vertical structure --

--

Based on the on-site situations, it flexibly selects layout style, such as “-” and “[]”, characterized by flexible manner and free combination, meeting the requirements of different voltage levels and capacities.

--

Design of the integrated converter valve based on overall transport, testing and installation

Optimally-designed and well-controlled sub-modules --

Figure 1. Configuration of VSC-HVDC Control & Protection System

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The converter valve, based on the modular and standardized design concept with high scalability, can save site installation, commissioning efforts and accelerate on-site engineering.

Based on the independently developed digital driving, perfectly match the power equipment and loss reducing components to achieve high efficiency converter valve.

High integration and high performance valve control unit --

Multi-channel high-speed parallel bus and delay-free extension technology helps achieve high integration

--

High-precision balancing algorithm helps achieve excellent voltage balanced control

--

The optimized circulation control strategy effectively suppresses the system current circulation.

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PCS-9250

DC Yard Electronic Transformer

The diverter uses Manganin as a material, which has a lower temperature factor.

The structure of the sensor provides great performance in heat dissipation.

The air-core coil is used here for harmonic current measurement, and the wide-frequency band can be obtained with good dynamic performance.

The remote module uses redundant configuration with high reliability.

Sixteen A/D signals are adopted in the remote module with high precision.

Laser power supply is used for remote modules with multifunction self-checking.

DC Electronic VT The PCS-9250-EAVD DC electronic VT is used to measure and transmit DC voltage signals to control and protection devices in the converter station. It's well-proven in 800kV and 500kV HVDC converter stations.

NR Electric provides DC electronic CT, electronic VT and DC filter electronic CT for both line commutation converter (LCC) and voltage source converter (VSC-based) HVDC transmission projects. The DC electronic transformers have the advantages of small size, light weight, and no ferromagnetic resonance

The PCS-9250 EAVD consists of DC divider, resistor box, remote module and merging unit. The sampling data is sent to the merging unit in the control room via optical fiber.

problems.

DC Electronic CT PCS-9250-EACD DC Electronic CT is used in HVDC converter stations to measure the DC current and send the signals to the control and protection devices. The DC electronic current transformer is composed of diverter, air-core coil, remote module, composite insulator with embedded optical fiber, and merging unit. The digital outputs of the DC electronic CT are transmitted by optical fibers to the merging unit on the low voltage side.

Figure 1. 500kV DC ECT

There are several main components listed below for DC ECT products:

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Primary Sensor It includes one current diverter and one air-core coil in all. The current diverter is used for measuring the direct current, and the air-core coil is utilized for harmonic current measurement.

Remote Module DC Electronic CT usually has three remote modules. Each one in these modules is designed as a spare of each other. The remote module collects the outputs of both the diverter and air-core coil to send them in series mode to the merging unit in the control room.

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DC Divider The precise resistor voltage divider is used to measure DC voltage. The use of shunt capacitor can achieve equalized voltage distribution and ensure its frequency characteristics.

Composite Insulator with Embedded Optical Fiber This insulator adopts the composite material as insulation support, while eight multimode optical fibers are embedded inside as signal transmission media. Merging Unit The merging unit is placed in the control room, which it takes as power supply, with laser mode for remote module in high voltage side, and also receives the signals from the remote module. Currently, the TDM bus protocol is used here and the IEC60044-8 protocol is also incorporated.

Features •

The insulator uses a composite type with silicon rubber. The insulator has many advantages, for example, it is easy to manufacture, while maintaining high reliability in operation, and it is light weight.

Resistor Box The resistor box is a low voltage divider, which can convert the measured voltage to multiple channel signals sent to the remote module.

Remote Module The remote module locally collects and transmits signals via optical cables. The remote-end module has two independent analog sampling circuits to perform duplicated sampling, real-time comparison and verification, and selfcheck functions;

Merging Unit The merging unit is operating based on IEC60044-8 or TDM bus. It has good compatibility and system integration capability;

Features •

The DC electronic VT adopts HV resistor in high precision with metallic film as a voltage divider resistor. The measurement accuracy can reach Class 0.2;

The HV side and LV side of the capacitance divider are designed with the same time constant, and thus the transformer has good frequency characteristics and transient characteristics as well as rapid response;

The remote-end in the high voltage side is powered by laser supply. The laser power can be adjusted in real-time according to the operating situation of the remote-end module;

The remote module is extensible, and can be flexibly combined with merging units to meet various application demands of the DC control & protection system;

The DC electronic VT is equipped with complete selfmonitoring functions to perform operation monitoring and maintenance.

DC Filter Electronic CT The PCS-9250-EAC DC filter electronic CT uses the low power CTs (LPCT) to convert primary current to digital signals. PCS9250 EAC can be used for current measurement in the high voltage side, low voltage side and imbalance branch for DC filter. The filter electronic CT is composed of LPCTs, remoteend modules, merging units, and composite insulators with embedded optical fibers. The output signals of LPCT are processed by the remote module and transmitted via optical fibers. The filter electronic CT has the same features as the PCS-9250-EACD does.

Figure 2 Filter imbalance ECT in support type

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Software

PCS-Explorer

PCS-Explorer Assistant Software The PCS-Explorer is a software tool designed for the debugging and commissioning of PCS series devices. It configures the inputs, outputs and parameters of PCS series devices in visual and graphic display to facilitate project configuration.

Assistant Software

PCS-PC Assistant Software The PCS-PC assistant software is designed to offer setting for NR Electric’s PCS series products. It provides various functions for device configuration and commissioning, including device setup, configuration & setting, programmable logic development, test & commission, sampled value monitoring and fault analysis.

IEC-61850 SCL Configuration Tool The SCL configuration tool is developed for the engineering implementation of IEC61850. It is the visual configuration tool used to set SCL files, including creating, editing and viewing SCL files that conform to IEC61850-6 regulations.

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The PCS-Explorer is a software tool designed for the debugging and commissioning of PCS series devices. It configures the inputs, outputs and parameters of PCS series devices in visual and graphic display to facilitate project configuration. The software integrates offline visible programming configuration, device drive file generation, construction files comparison and

Off-line configuration Device hardware configurations can be configured through PCS-Explorer. Users can edit and change device settings either on the LCD display window or via this software in order to meet the site requirements

merging, online debugging and download functions.

Visualized device configuration PCS-Explorer provides visualized device configuration functions to simplify configuration processes. Users are capable of enabling and disabling device protection functions and programming the required logic functions.

On-line debugging and download PCS-Explorer offers download and on-line debugging functions to check device state. The pre-configured files can be compressed into driver package and downloaded to PCS series devices.

Functions •

Manage configuration for all devices in substation The PCS-Explorer can manage the configuration of PCS series devices and the operations of project files in PCSExplorer.

Create device settings based on template driver PCS-Explorer provides users with standard templates of PCS series devices to simplify device configuration to streamline new device deployment. Ultimately, simplifying project installation and maintenance.

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IEC-61850

PCS-PC

SCL Configuration Tool

Assistant Software

The PCS-PC assistant software is designed to offer setting for NR Electric’s PCS series products. It provides various functions for device configuration and commissioning, including device setup, configuration & setting, programmable logic development, test & commission, sampled value monitoring and fault analysis. It scans and retrieves disturbance information for automatic report file generation. Waveform analysis is integrated for postfault diagnostic. With an intuitive matrix structure, the software offers easy-to-use configuration capabilities for I/O mapping and signal mapping.

PCS-PC can manage several devices in one substation. Under offline mode, the software provides I/O configuration, programmable logic and setting management functions. Under on-line mode, the software communicates with devices through an Ethernet port and downloads settings and configuration data to devices. Operators can modify settings and view the real-time state of devices via PCS-PC.

The SCL configuration tool is developed for the engineering implementation of IEC61850. It is the visual configuration tool used to set SCL files, including creating, editing and viewing SCL files that conform to IEC61850-6 regulations. Users can construct the substation configuration, structures and models via this tool, and quickly design and manage substation settings. The SCL configuration tool provides the following functions:

Import the IED into the ICD that conforms to IEC61850-6.

Associate different intelligent electronic devices and logical nodes (LN) to substation details, and complete the configuration of the substation system according to IEC61850-6.

Edit and maintain the functions and date elements in IED.

Create the substation configuration description (SCD) file in accordance with IEC61850-6 regulations.

Define the substation communication configuration.

Check the data templates and solve the conflicts.

Build a single line diagram for the primary system of the substation.

Verify standard SCL Schema.

Provide grammar and semantic check.

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Manage the version of SCD files.

Construct different substation structures and create the complete system specification description (SSD).

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Accessories

MD1501

MD1501 Series Auxiliary Relays

Series Auxiliary Relays

MD1501 series auxiliary relays are mainly used with main protection and control devices. Each relay type is designed with a specific function. Each relay is independent from others with high configurability and extensibility.

MD1701 Series Test Blocks MD1701 series products, including test blocks, test plugs and accessories cooperate with protection relays to provide online monitoring/testing for power system protection schemes.

MD1501 series auxiliary relays are mainly used with main protection and control devices. Each relay type is designed with a specific function. Each relay is independent from others with high configurability and extensibility. Relay types are continuously developed in order to meet the requirements of various applications.

Features •

Various types of relays with dedicated functions are available and can be flexibly combined to meet the requirements of various applications.

Completely-sealed, high-resistance and low-power consumption relays are adopted. Therefore, power consumption and heat dissipation are greatly reduced and moisture proof is improved.

The relay modules can be accommodated in a rack and installed on a panel.

The high burden relay for tripping or closing a circuit breaker has strong interference withstanding capabilities.

More spare relays can be provided and flexibly applied.

Functions MD1501 series auxiliary relays provide the following functions: •

Trip circuit supervision

Lockout function

Tripping relay function

Repeat relay function (voltage operated or current operated)

AC voltage switching function

Type MD1501 series auxiliary relays can be classified as the following types according to their function. Type MD1501-551 MD1501-552 MD1501-556 MD1501-561 MD1501-571 MD1501-572

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Applications Trip circuit supervision with current operated auxiliary relay Phase segregated trip circuit supervision Current operated auxiliary relay (3 elements) Bi-stable switching relay Electrical reset auxiliary element with internal operating coil supervision (high burden) Self reset auxiliary relay with electrical reset LED indicator (high burden)

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Technical Data Power Supply (Voltage Operated Element) Rated Voltage

110Vdc, 125Vdc, 220Vdc, 250Vdc

Variation Ripple in the DC auxiliary voltage

(80%~120%)Un Max 15% of the DC value. IEC 60255-11:1979 Quiescent condition Operating condition

Burden

< 6W < 120W

MD1701

Mechanical Specifications Enclosure dimensions (W×H×D) Trepanning dimensions (W×H) Ripple in the DC auxiliary voltage Weight per relay Housing material Housing color Location of terminal Enclosure Protection IEC60529:1989 Front side Other sides Rear side, connection terminals

35.5×173.8×198 (unit: mm) 36.4×154(unit: mm), M3 screw Mounting Approx. 1kg Aluminum, steel Silver grey Back side IP40 IP40 IP20

Ambient Temperature and Humidity Range Standard Operating temperature Transport and storage temperature range Relative humidity

IEC 60255-6:1988 -25°C~+55°C -40°C~+70°C 5%~95%, without condensation

Series Test Blocks

MD1701 series products, including test blocks, test plugs and accessories cooperate with protection relays to provide online monitoring/testing for power system protection schemes. With the application of MD1701 series test blocks, operation security can be ensured. Moreover, monitoring, isolation and secondary injection testing can be simplified and quickly performed.

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MD1701-02 MD1701-02 is a special test block designed for use in busbar protection schemes. Terminal 13 and 14 of the MD1701-02 can be used for CT connections.

CJ28T CJ28T is a multi-finger test plug.

YJ2T YJ2T is a single-finger test plug.

CJ4T CJ4T is a four-terminal CT shorting link.

CJ2T CJ2T is a two-terminal CT shorting link.

Available models of MD1701 series products are listed below: •

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MD1701-01 MD1701-01 is a standard test block. Terminal 13 and 14 of the MD1701-01 can be used to connect the main DC auxiliary supply to the protection scheme or relay through this circuit.

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Appendix 1

Technical Data

Relay Technical Data

Electrical Specifications Maximum working current for all contact circuits(continuously) Maximum working current for all contact circuits(for 1s) Maximum working voltage Contact resistance

20A 400A 320V ≤4mΩ

Mechanical Specifications

Mechanical Specifications Interconnecting cable Screw Durability Standard with cover fitted (without cover) and CJ28T Flame Retardation

Ambient Temperature and Humidity Range

1.5 mm2 ~ 2.5 mm2 M4 screw Torque: 1.2 N·m ~ 1.8 N·m Increment percentage of contact resistance ≤ 50% (After 500 operations) Protection class IEC 60225-1:2009 IP50 IP20 UL94V-0

Standard

IEC 60225-1: 2009

Operating temperature

-40°C to +70°C ( LCD normal working condition:-20°C+70°C)

Transport and storage temperature range

-40°C to +70°C

Permissible humidity

5%-95%, without condensation

Altitude

<3000m Front panel: IP40

Ingress protection degree

Case: IP20(with heat-dissipation holes), IP50(without heat-dissipation holes)

Ambient Temperature and Humidity Range Standard Operating temperature Ripple in the DC auxiliary voltage Weight per relay

Rear panel: IP30 IEC 60255-1:2009 -25°C to +55°C Mounting Approx. 1kg

Power Supply (PCS-900)

Ambient Temperature and Humidity Range Standard Operating temperature Transport and storage temperature range Permissible humidity

Electrical Specifications

IEC 60255-6:1988 -25°C~+55°C -25°C to +70°C 5%-95%, without condensation

Standard

IEC 60255-11:2008

Rated Voltage

24V/30Vdc

48V/60Vdc

110V/125V/220V/250Vdc

Variation

18V-36Vdc

36V-72Vdc

88V-300Vdc or 88V-265Vac

Permissible AC ripple voltage

≤15% of the nominal auxiliary voltage

Power Supply (PCS-9000)

Type Tests Mechanical Tests Vibration

IEC 60255-21-1:1988 Class I

Shock and bump

IEC 60255-21-2:1988 Class I

Standard

IEC 60255-11:2008

Rated Voltage

24V/30/48Vdc

110V/125V/220V/250Vdc

Variation

19V-60Vdc

88V-300Vdc or 88V-265Vac

Permissible AC ripple voltage

≤15% of the nominal auxiliary voltage

Electrical Tests Standard

IEC 60255-27:2005 Dielectric tests

Analog Input Ratings

AC Current (1A or 5A, Protection Coil, PCS-900)

Between terminal 13 and terminal 14 of MD1701

Test voltage 1kV, 50Hz, 1min

Between any two terminals of MD1701 Between earth and any terminal of MD1701

Test voltage 2kV, 50Hz, 1min Test voltage 5kV, 50Hz, 1min

Nominal frequency

50±5Hz, 60±5Hz

Standard

IEC 60255-5:2000

Rated Current (In)

1A

Insulation resistance measurements

Isolation resistance >100MΩ@500VDC Linear to

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5A

0.05In~40In 0.05In-30In (PCS-996)

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AC Voltage (PCS-9000)

Thermal withstand -continuously

4In

-for 10s

30In

-for 1s

100In

-for half a cycle

250In

Burden

< 0.15VA/phase @In

< 0.25VA/phase @In

AC Current (Adaptive 1A/5A, Protection Coil, PCS-900) Nominal frequency

50±5Hz, 60±5Hz

Rated Current (In)

1A/5A

Linear to

0.05In~40In (Adjustable according to the software)

Nominal frequency

50±5Hz, 60±5Hz

Rated Voltage (Un)

100V~130V (phase-to-phase)

Linear to

1~130V (phase)

Thermal withstand -continuously

130V (phase)

225V (phase-to-phase)

-10s

200V (phase)

346V (phase-to-phase)

-1s

250V (phase)

433V (phase-to-phase)

Burden at rated

< 0.10VA/phase @Un

Thermal withstand -continuously

4In

-for 10s

30In

-for 1s

100In

-for half a cycle

250In

Burden

< 0.15VA/phase @In (1A)

Binary Input

24/30/48Vdc Binary Input < 0.25VA/phase @In (5A)

AC Current (1A or 5A, Protection Coil, PCS-9000) Nominal frequency

50±5Hz, 60±5Hz

Rated Current (In)

1A or 5A

Linear to

0.05In~40In

0.05In~30In

Thermal withstand -continuously

2In

3In

-for 10s

20In

30In

-for 1s

50In

100In

-for half a cycle

125In

250In

Burden

< 0.15VA/phase @In (1A)

< 0.25VA/phase @In (5A)

AC Current (1A or 5A, Metering Coil) Nominal frequency

50±5Hz, 60±5Hz

Rated Current (In)

1A

Linear to

0.05In~2In

5A

Thermal withstand -continuously

2In

-for 10s

12In

-for 1s

30In

-for half a cycle

75In

Burden

< 0.2VA/phase @In (1A)

Standard

IEC 60255-1:2009

Rated Voltage

24Vdc

30Vdc

48Vdc

Rated current drain

1.2mA

1.5mA

2.4mA

On value

16.8~28.8Vdc

21~36Vdc

33.6~57.6Vdc

<15Vdc

<24Vdc

Off value

<12Vdc

Maximum permissible voltage

100Vdc

Withstand voltage

2000Vac, 2800Vdc (continuously)

Resolving time for logic input

<=1ms

110/125/220/250Vdc Binary Input Standard

IEC 60255-1:2009

Rated Voltage

110Vdc

125Vdc

220Vdc

250Vdc

Rated current drain

1.1mA

1.25mA

2.2mA

2.5mA

On value

77~132Vdc

87.5~150Vdc

154~264Vdc

175~300Vdc

Off value

<55Vdc

<62.5Vdc

<110Vdc

<125Vdc

Maximum permissible voltage

300Vdc

Withstand voltage

2000Vac, 2800Vdc (continuously)

Resolving time for logic input

<=1ms

< 0.4VA/phase @In (5A)

AC Voltage (PCS-900) Nominal frequency

50±5Hz, 60±5Hz

Rated Voltage (Un)

100V~130V (phase-to-phase)

200V (phase)

Linear to

1~170V (phase)

1-233V (phase)

Thermal withstand -continuously

270

200V (phase)

346V (phase-to-phase)

220 (phase)

-10s

260V (phase)

450V (phase-to-phase)

380 (phase)

-1s

300V (phase)

519V (phase-to-phase)

420 (phase)

Burden at rated

< 0.20VA/phase @Un

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< 0.80VA/phase @Un

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Communication Port

Binary Output

Tripping relay Output Type

Maximal system voltage Test voltage across open contact Continuous carry

Short duration current

EIA-485 Port Parallel-Connection contact

Single Contact

Baud rate

4.8kbit/s, 9.6kbit/s, 19.2kbit/s, 38.4kbit/s, 57.6kbit/s, 115.2kbit/s

380Vac

380Vac

Protocol

IEC 60870-5-103:1997

250Vdc

250Vdc

1000V RMS for 1min

1000V RMS for 1min

Maximal capacity

32

8A@380Vac

5A@380Vac

Transmission distance

<500m

8A@250Vdc 10A@3s

5A@250Vdc

Safety level

Isolation to ELV level

Twisted pair

Screened twisted pair cable

15A@1s 20A@0.5s 30A@0.2s 0.65A@48Vdc

Breaking capacity (L/R=40ms)

6A@3s 15A@0.5s 30A@0.2s

0.25A@110Vdc

0.65A@48Vdc

0.2A@125Vdc

0.30A@110Vdc

0.15A@220Vdc

0.15A@220Vdc

<8ms (typical 3ms)

100Base-FX <2km (1310nm)

<8ms (typical 3ms)

Protocol

IEC 60870-5-103:1997, DNP 3.0 or IEC 61850

Safety level

Isolation to ELV level

Durability

10,000 operations minimum

10,000 operations minimum

Short duration current

Characteristic

Glass optical fiber

Connector type

ST, SC

Fibre type

Multi mode (50/125μm, 62.5/125μm)

8A@125Vdc

Transmission distance

<2km

8A@250Vdc 10A@3s

Wave length

1310nm

Transmission power

Min. -20.0dBm

Minimum receiving power

Min. -30.0dBm

Margin

Min +3.0dB

250Vdc 1200V RMS for 1min

15A@1s 20A@0.5s 30A@0.2s 1.20A@48Vdc 1.50A@110Vdc

Breaking capacity (L/R=40ms)

0.30A@125Vdc 0.25A@220Vdc 0.20A@250Vdc

- For Process Level Characteristic

Glass optical fiber

Connector type

LC

ST

<10ms

Fibre type

Multi mode (50/125μm, 62.5/125μm)

Multi mode (50/125μm, 62.5/125μm)

Drop off time

<10ms (excluding software time delay)

Transmission distance

<2km

<2km

Durability

10,000 operations minimum

Pickup time

Rapid signal relay (Dedicated contact for PCS-902 pilot signal initiation) Maximal system voltage Test voltage across open contact Continuous carry

Breaking capacity (L/R=40ms)

272

Optical Fibre Port - For Station Level

380Vac

8A@380Vac Continuous carry

100Mbits/s 10Base-T/100Base-TX

<5ms

Test voltage across open contact

Transmission rate

ST, SC (Multi mode)

<100m

<5ms

Maximal system voltage

RJ-45

Transmission standard

Drop off time

Signal relay

Connector type

Transmission distance

0.12A@250Vdc Pickup time

Ethernet Port

380Vac

Wave length

1310nm

820nm

Transmission power

Min. -20.0dBm

Min.-20.0dBm

Minimum receiving power

Min. -30.0dBm

Min.-30.0dBm

Margin

Min +3.0dB

Min +3.0 dB

250Vdc 1000V RMS for 1min 5A@380Vac 5A@250Vdc 1.0A@48Vdc 0.9A@110Vdc

- For Pilot Channel Characteristic

Glass optical fiber

Connector type

FC

ST

Fiber type

Single mode (9/125μm)

Multi mode (50/125μm, 62.5/125μm)

0.4A@220Vdc

Wave length

1310nm

1550nm

850nm

Pickup time

<1ms

Transmission distance

Max.40km

Max.100km

Max.2km

Drop off time

<5ms

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Insulation Tests Transmission power

Min. -16.0dBm

Min. -8.0dBm

Min. -20.0dBm

Standard

IEC 60255-27:2005 Isolation resistance >100MΩ@500VDC

Minimum receiving power

Min. -36.0dBm

Min.-36.0dBm

Min.-30.0dBm

Insulation resistance measurements

Margin

Min. +3.0dBm

Min. +3.0dBm

Min. +3.0dBm

Dielectric tests Standard

- For Synchronization Port Characteristic

Impulse voltage tests

Glass optical fiber

Connector type

ST

Overvoltage category

Fiber type

Multi mode (50/125μm, 62.5/125μm)

Pollution grade

Wave length

820nm

Minimum receiving power

Min. -25.0dBm

Margin

Min. +3.0dBm

2.8kV, dc, 1min 2.0kV, ac, 1min IEC 60255-5:2000 Test voltage 5kV ( rated insulation voltage: >63V) Test voltage 1kV ( rated insulation voltage: <63V) IEC 60255-5 III IEC 60255-1:2009

Electromagnetic Compatibility IEC 60255-22-1:2007 1MHz burst disturbance test

Common mode: class III 2.5kV Differential mode: class III 1.0kV

Print Port

IEC60255-22-2:2008 class IV

Type

RS-232

Baud Rate

4.8kbit/s, 9.6kbit/s, 19.2kbit/s, 38.4kbit/s, 57.6kbit/s, 115.2kbit/s

Printer type

EPSON® 300K printer

Safety level

Isolation to ELV level

Electrostatic discharge test

For air discharge: 15kV IEC 60255-22-3:2007 class III Frequency sweep

Clock Synchronization Port

Radiated amplitude-modulated

Mode

Pulse per second (PPS)

Pulse per minute (PPM)

Input

RS-485, TTL, Dry contact

Dry contact

≤1ms

≤1ms

Accuracy

For contact discharge: 8kV

IRIG-B RS-485, TTL, Multimode fiber ≤1ms

SNTP

Radio frequency interference tests

LAN

10V/m (rms), f=80~1000MHz Spot frequency Radiated amplitude-modulated 10V/m (rms), f=80MHz/160MHz/450MHz/900MHz

≤2ms

Radiated pulse-modulated 10V/m (rms), f=900MHz Per IEC 60255-22-5:2008

Type Tests

Surge immunity test

Environmental Tests

Power supply, AC input, I/O port: class IV, 1.2/50us Common mode: 4kV Differential mode: 2kV

Dry cold test

IEC60068-2-1:2007

Dry heat test

IEC60068-2-2:2007

Damp heat test, cyclic

Per IEC60068-2-30:2005

Damp heat test, constant

Per IEC60068-2-78:2001

Mechanical Tests

Conducted RF Electromagnetic Disturbance

Power Frequency Magnetic Field Immunity

Pulse Magnetic Field Immunity

Vibration

IEC 60255-21-1:1988 Class I

Shock and bump

IEC 60255-21-2:1988 Class I

earthquake

IEC 60255-21-3:1993

Damped oscillatory magnetic field immunity

IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class III, 10Vrms, 150 kHz~80MHz IEC 61000-4-8:2001 class V, 100A/m for 1min, 1000A/m for 3s IEC 61000-4-9:2001 class V, 6.4/16μs, 1000A/m for 3s IEC 61000-4-10:2001 class V, 100kHz & 1MHz–100A/m IEC60255-11: 2008

Auxiliary power supply performance

Voltage dips: Up to 200ms for dips to 40% of rated voltage without reset Voltage short interruptions: 100ms for interruption without rebooting (PCS-900) 100ms for interruption without rebooting (PCS-9000)

274

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Appendix 2 Device Diemension Diagram

Figure 1. PCS Series Standard 4U Device Figure 3. PCS-9600 Series Standard 1/2 4U Device

Figure 4. PCS-9000 Series Standard 1U Device

Figure 2. PCS Series Standard 8U Device

Figure 5. RCS-900 Series Standard 4U Device

276

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Appendix 3 Panel Design Outdoor Cabinet and Outdoor Terminal Box Ingress protection degree: ≥IP55 Material: Stainless steel NR Electric supplies a wide range of cabinets in different sizes and colors, with various steel plate thicknesses and dooropening types. In addition to conventional cabinets, NR Electric also provides outdoor cabinets for IEDs; they feature a welldesigned top structure to ensure effective drainage of rainwater. The outdoor cabinets are also equipped with a heater, cooling system and other auxiliary facilities in order to effectively control the cabinet’s internal temperature. Depending on the installation site and function, cabinets are mainly divided into three categories: indoor cabinets, outdoor cabinets and outdoor terminal boxes.

Indoor Cabinet

Contamination level: III

External dimensions: 2,260 (2360) (height) × 800 (width) × 600 (depth) (mm) ( lintel measuring 60 mm),. Customizable upon customer request.

Maximum wind speed: 35 m/s (maximum average over a 30year return wind speed at a high of 10 m for a time frame of 10 min)

• •

Seismic Intensity Protection: 8 degrees Seismic capability: Horizontal component: 0.5 gravity; Perpendicular component: 0.25 gravity.

Structure: Steel cabinet with embedded door. Structural configuration: Cold-rolled bent steel plates welded together, with a plate thickness of 1.5 mm Ingress protection degree: ≥IP30, see Figure 1

Basic dimensions of the outdoor cabinet: Frame size 1375 mm (height) × 900 mm (width) × 700 mm (depth), with effective usage dimensions of 1200 mm × 800 mm × 600 mm. Increasing progressively according to actual engineering requirements by 200 mm to a maximum size of 1975 mm × 1300 mm × 900 mm, with an effective usage dimension of 1800 mm × 1200 mm × 800 mm,. See Figure 3. Dimensions of the outdoor terminal box: 1,548 mm (height) × 610 mm (width) × 620 mm (depth) (recommended dimensions), adjustable according to actual engineering requirements.

≥IP54, see Figure 2

Figure 3. Outdoor Cabinet (Unit: mm) Figure 1. Indoor Cabinet with IP degree≥IP30

Figure 2. Indoor Cabinet with IP degree≥IP54 (Unit: mm)

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Figure 4. Photovoltaic Cabinet (Unit: mm)

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Appendix 4 Relay Connection Terminals

NR Electric provides screw terminals and weld terminals to satisfy different project needs. The terminals feature cost-saving installation, easy operation and maintenance, high mechanical and electric properties, and strong resistance to environmental conditions. The terminals have many advantages: •

The insulation adopts enhanced flame retarding material with distortion temperature of 250°C for applications in strong corrosive environments.

The clips use highly elastic copper with gold plated surfaces, which improve anti-corrosion capabilities.

The conducting strip adopts advanced wire spring jack and crown spring jack technologies to increase electric contact reliability. The jacks have strong current load capacities and can withstand high current impulses.

The conducting strips have excellent welding abilities and comply with RoHS instruction requirements.

Easy plugging and unplugging of connectors, which are free of stagnation.

DL Series Screw Terminals for AC Inputs DL series terminals are suitable for AC current/voltage inputs, and can be used for PCS-900 series protection and PCS-9700 series bay control units.

Features

Figure 5. STATCOM Cabinet (Unit: mm)

280

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Compatible with wire sizes ranging from 26 AWG (0.14 mm²) to 12 AWG (4.0 mm²)

Rated voltage 600V

Rated current 20A

Operating temperature from -40°C to -125°C

• • •

Small contact resistance

Anti-shock capability

Automatic short connection of external CT circuit after unplugging the connector

Automatic identifying and matching between plugs and sockets

Press-fit connection for cold pressed connector or hard wire

Optional protective casing

DL screw terminal with protective casing

DL screw terminal with wire

DL series terminals provide CT automatic short circuit function and can effectively avoid risks due to open circuit in CT secondary circuits.

JX Series Screw Terminals for AC Inputs JX series terminals are used for AC current/voltage inputs, and are applicable to RCS-9600 series protection, PCS-9600 series protection, PCS-9720 series distribution automation units, etc. The 0.14 mm²-4.0 mm² or AWG 26-12 cables can be connected with a rated operating voltage of 600V and rated operating current of 20A. The operating temperature ranges between -40°C-125°C, and contact resistance between conductors is less than 1mΩ. The effect on AC quantity measuring precision is small and its application in electric power systems can be realized.

Features •

Traditional screw type press-fit wiring structural form

Press-fit connection can be used for cold pressed connector or hard wire

Easy operational use as screwed connection has very low requirements on auxiliary tools.

Contact resistance between conductors less than 1mΩ.

Protective casing is optional to improve its safe protection

Traditional screw type press-fit plug structure

Low contact resistance ensures measurement precision for AC current/voltage input.

JX screw terminals

JX screw terminal with wire

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XH Series Weld Terminals for DC Inputs

XH Series Screw Terminals for DC Inputs

XH series wield terminals support plug-and-play assembling mode so that the user can replace the modules without removing any of the connected wires. Therefore, increasing operational performance and greatly reducing site maintenance time. XH series terminals adopt a reliable welding technique, which features reliable connection, small connection resistance, and a life-long maintenance-free property. In addition, the provisions of the protective casing provide better and more reliable safety performance when compared with other connectors.

XH series screw terminals provide two types of structures: traditional screw press-fit wiring and balance wheel clamping wiring. XH series screw terminals are used for binary input/ output, power supply, DC quantities input/output, etc. These terminals are applicable for RCS-900 8U/12U rack protection, RCS-9600 series protection, among others.

XH series terminals can be used for binary input/output, power supply, DC quantities input/output, etc. These terminals are applicable to RCS-900 series protection, RCS-9600 series protection, RCS-9700 series bay control unit, etc. The 0.14-2.5 mm² or AWG 26-14 cables can be connected to the XH series terminals, rated operating voltage is 600V, rated operating current is 5A, applicable operating temperature range is -40°C-125°C, and contact resistance between conductors is less than 2mΩ. Application in electric power system can be satisfied.

The 0.14-2.5 mm² or AWG 26-14 cables can be connected with a rated operating voltage of 600V, rated operating current of 5A, with an applicable operating temperature range of -40°C-125°C, and contact resistance between conductors is less than 3mΩ. Application in electric power system can be satisfied. XH series screw type terminals adopting balance wheel clamping wiring mode and have the advantages of large hole position density, strong wiring capacity, front operation, safe protection performance, etc.

Features •

Plugging/unplugging type terminals allow for card replacements without removing/re-connecting wires

Structural form with protective casing provides a high level of safety

Wire spring jack structure allows for gentle plugging/ unplugging, small contact resistance, shock resistance, and vibration. Therefore ensuring reliable performance

Wires are connected by soldering, which provides stable, reliable, small resistance, and life-long maintenance-free connections

Repeated wiring at single welded end can be realized by de-soldering and re-soldering to facilitate modification and correction of soldering

XH weld terminals

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Internal view of XH weld terminals

XH screw terminals with screw press-fit wiring

XH screw terminals with balance wheel clamping wiring

XH screw terminal with wire

Features •

2 structural forms: traditional screw press-fit wiring and balance wheel clamping wiring.

Wire spring jack structure allows for gentle plugging/ unplugging, small contact resistance, resistance to shock and vibration, and reliable performance.

Press-fit connection can be used for cold pressed connector or hard wire.

Balance wheel clamping wiring is a derivative form of screw type wiring and it is more convenient and faster than the older screw press-fit wiring systems.

Balance wheel clamping features large hole position density, strong wiring capacity, front operation, and safe protection performance.

Low requirements on auxiliary tools.


2014 Product Catalog

NR Electric Co., Ltd. (Headquarters)

NR Electric Power Automation Factory

NR Electric Power Electronics Co., Ltd.

69 Suyuan Avenue, Nanjing 211102, China

99 Shengtai Road, Nanjing 211106, China

328 Wuyi Road, Changzhou 213025, China

Tel: +86 25 8717 8888

Tel: +86 25 87178911

Tel: +86 519 88408179

Fax: +86 25 8717 8999

Fax:+86 25 52100511

Fax: +86 519 88408576

NR Electric International Co., Ltd.

PT NR Electric Jakarta

NR Energy Solutions India Pvt. Ltd.

Unit C, 7/F, Ford Glory Plaza, 37-39 Wing Hong Street, Cheung Sha Wan Kowloon, Hong Kong

Unit I, 2nd Floor, Tower Menara Prima, Jl Lingkar Mega Kuningan Blok 6.2, Indonesia

Tel: + 852 23703773

Tel: +62 2157948606

807, Platinum Techno Park, Plot 17-18, Secotr-30A, Vashi, Navi Mumbai-400703, Maharashtra, India

Fax: + 852 27439555

Fax: +62 2157948608

Email: international@nrelect.com

Email: indonesia@nrelect.com

NR Electric USA LLC

NR Electric Nigeria Co., Ltd.

11 Orchard Road, Suite 104, Lake Forest, CA 92630

A5, Salatu royal estate, Aminu kano crecent, Wuse II. Abuja, Nigeria

Tel: +1 949 305 7789

Tel: + 234 806 1299663

Fax: +1 949 305 7763

Email: nigeria@nrelect.com

E-mail: NRsales@nrelect.com NRservices@nrelect.com Website: www.nrelect.com (EN) www.nari-relays.com

Email: usa@nrelect.com

Tel: + 91 22 66731755 Fax: +91 22 67942779 Email: india@nrelect.com

Relés Digitais de Proteção & Controle  

A STD revende no Brasil e oferece esta solução em seus Painéis os Relés Digitais de Proteção & Controle da NR Electric.

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