For more than 100 years, electric power plants have mainly been large, utility-owned facilities, feeding distributed load based on unidirectional power flow. Over the past 20 years, smaller, independent power generation plants have been developed and distributed within electrical networks. The increasing number of Distributed Generation (DG) sites, and their increasing power ratings from kW to hundreds of MW, create new challenges for network planning and operation.

Distributed Generation Tee Infeeds to Existing Transmission Lines

Circuits near the coast may be candidates for tee infeeds to evacuate renewable energy from onshore and offshore wind generation. A tee infeed to a nearby transmission line can be a more cost effective solution to connect the generation to the grid than building a new substation. This economy enables more Distributed Generation connections to penetrate the network helping to meet green energy connection targets and reduce greenhouse gas emissions.

Multi-Ended Circuit Differential Lines

Previously transmission and distribution circuits would have two or three ends only. However, five or more ends are becoming common because large Distributed Generation sites such as onshore or offshore windfarms and solar farms are being connected to the grid. As the power networks evolve to transport power in ever more complex ring and meshed networks, line/cable differential protection becomes increasingly attractive, with its inherent ability to address grading/selectivity challenges and is scalable for multi-terminal circuits able to accommodate many connections of distributed generation along the line. GE Vernova’s Grid Solutions’ multi-ended current differential protection is now ready for any protection topology from two to six terminals, whether those multi-terminals exist now, or are provisioned for connection in the future.

Functional Block Diagram

• Powerful graphical Programmable Scheme Logic (PSL) customise relay logic
• Real-time monitoring of remote, local and differential per-phase currents
• Oscillography - 48 samples/cycle, up to 10.5 seconds record length
• Event Recorder - 1024 time tagged events, time tagged to a resolution of 1 ms

Programmable Scheme Logic

Powerful graphical logic allows the user to customise the protection and control functions. The logic includes 32 timers, gates (OR, AND, MAJORITY) and set/reset latch functions, with the ability to invert the inputs and outputs and provide feedback.

The system is optimised to ensure that the protection outputs are not delayed by PSL operation.  The programmable scheme logic is configured using the graphical S1 Agile software. The relay outputs may be configured as latching (lockout) or self-reset. All aspects of MiCOM P40 IED configuration are managed using the S1 Agile software.

Measurement and Recording Facilities

All events, fault and disturbance records are time tagged to a resolution of 1 ms. An optional IRIG-B port is available for accurate time synchronisation.

Power System Measurements

Instantaneous and time integrated voltage, current and power measurements are provided. These may be viewed in primary, or secondary values.

Fault Location

A fault location algorithm provides distance to fault in miles, kilometres, ohms or percentage of the line length. The proven algorithm employed tolerates pre-fault loading and fault arc resistance.

Event Records

Up to 1024 time-tagged event records can be stored. An optional modulated or demodulated IRIG-B port is available for accurate time synchronisation.

fault Records

The last 15 fault records are stored.

Disturbance Records

The oscillography has 16 analogue channels, 64 digital and 1 time channel, all at a resolution of 48 samples/cycle.

• Advanced IEC61850 Edition 2 implementation with complete settings via SCL files
• Embedded IEEE 1588 time synch protocol support eliminates dedicated IRIG-B wiring requirements for IEDs
• Redundant communications with zero downtime using optional PRP/HSR protocols
• Wide range of supported protocols Courier/K-Bus, IEC 60870-5-103, DNP 3.0 (EAI-485 or Ethernet) and IEC 61850

Protection Communications Interfacing

To ensure compatibility with standard communications equipment, the MiCOM P54x Agile multi-ended line differential series is designed to work with IEEE C37.94TM. A direct fibre optic connection to a MUX is possible if the MUX is IEEE C37.94TM compliant.

In direct fibre optic applications, 1300 nm and 1550 nm channel options are available. The transmitters are designed with a large "optical budget" to support up to 150 km.

Communications Supervision

Dependable communications are essential for high-performance differential protection. Each active longitudinal channel is independently monitored and reports error statistics in line with guidance from ITU-T G.821.

Multi-ended line differential works in a ring connection, which provide comms redundancy. In the event of degraded communications, the ring communications channels will continue to provide protection, thus providing duplicated links via diverse communications paths.

Alternatively, back-up overcurrent elements can be switched into service, either as permanent parallel main protection, or temporary protection only during channel outages.

Communications with Remote Operators and Substation Automation

Rear Scada Communication

The wide range of communications options, including IEC 61850, provides interfacing with almost any type of substation automation system or SCADA system.

The following protocols are available:

• Courier/K-Bus
• IEC 60870-5-103
• DNP 3.0 (EAI-485 or Ethernet)
• IEC 61850 Edition 2

P54x devices can be enhanced with an optional redundant Ethernet board. The redundancy is managed by the market's fastest recovery time protocols: IEC 62439-3 PRP and HSR allowing bumpless redundancy and RSTP, offering multi-vendor interoperability. The redundant Ethernet board supports either modulated or demodulated IRIG-B and the SNTP protocol for time synchronisation. The redundant Ethernet board also has a watchdog relay contact to alarm in case of a failure.

Second Rear Courier Port

An additional second rear port can be ordered as an option, designed typically for dial-up modem access by protection engineers/operators when the main port is reserved for SCADA traffic. This port also offers the option of -103 communications when IEC 61850 is the chosen first port protocol.

Key benefits:

• Powerful, free of charge, PC toolsuite
• Optimum management of the installed base, structured as per the substation topology
• Intuitive and versatile interface with file management facilities
• Logical structure based on substation, voltage level and bay
• Version control and cross-checking facilities for IED settings
• Real-time measurement visualization – MiCOM S1 Agile extends to all MiCOM Agile IEDs - including P847 PMU and busbar schemes

Engineering Tool Suite

S1 Agile is the truly universal PC tool for MiCOM Agile relay, assemble all tools in a palette for simple entry, with intuitive navigation via fewer mouse-clicks. No-longer are separate tools required for redundant Ethernet configuration, phasor measurement unit commissioning, busbar scheme operational dashboards, programmable curve profiles or automatic disturbance record extraction – applications are embedded. MiCOM S1 Agile supports all existing MiCOM, K-Series and Modulex, including a utility for automatic conversion of setting files from previous generations of numerical relays like K-series and MiCOM P20 to the latest P40 Agile models.

To move to the future, with no loss of functionality, no loss of device support, and full compatibility with your installed base and system architecture – request a copy of S1 Agile with the contact form link below.

Protection & Control

The L90 is a high-end cost-effective line current differential protection relay intended for transmission lines and cables of different voltage levels, providing reliable and secure operation even under worst case power system conditions. The L90 provides high-speed phase-segregated fault clearance suitable for single and three-pole tripping applications. Part of the Universal Relay family, the L90 comes with a variety of versatile features, truly integrating protection, monitoring, metering, communication and control in one easy-to-use device. The Universal Relay family offers a high degree of modularity in its design and functionality, providing superior performance in protection and control, while meeting the toughest requirements of the marketplace.

Functional Block Diagram

ANSI® Device Numbers & Functions

Key Features

• Real-time monitoring of remote, local and differential per-phase currents
• Oscillography - 64 samples/cycle, up to 64 records
• Event Recorder - 1024 time tagged events, with 0.5ms scan of digital inputs
• Data Logger - Up to 16 channels with user selectable sampling rate
• P & M class synchrophasors of voltage, current and sequence components - 1 to 120 frames/sec
• Multi-ended fault location consistently providing 2% accuracy

Monitoring & Diagnostics

Advanced Automation

The L90 incorporates advanced automation features including powerful FlexLogic™ programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line relay. The L90 integrates seamlessly with other UR relays for complete system protection.

Complete IEC 61850 Process Bus solution providing resource optimization and minimizing total P & C life cycle costs

• Three independent 100Mbps Ethernet ports enable purpose specific LAN support that eliminates latency effect of heavy traffic protocols on mission critical communication services
• Embedded IEEE 1588 time-synch protocol support eliminates dedicated IRIG-B wiring requirements for IEDs
• Direct I/O secures high-speed exchange of binary data between URs
• Increase network availability by reducing failover time to zero through IEC62439-3 PRP, HSR or dual HSR support

Advanced Communications

The L90 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent and redundant Ethernet options provide the means to create fault tolerant communication architectures in an easy, cost-effective manner.

The L90 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems.

Use the L90 with integrated IEC 61850 to lower costs associated with line differential protection, control and automation. GE Vernova’s leadership in IEC 61850 comes from thousands of installed devices and follows on years of development experience with UCA 2.0.

The L90’s IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing Universal Relay applications, including protection functions, FlexLogic, metering and communications. 
Learn more

The L90 can also connect to GE Vernova MU320 or third-party merging units using standard IEC 61869 or IEC 61850-9-2LE communication protocols.

CyberSentry enables UR devices to deliver full cyber security features that help customers to comply with NERC CIP and NITIR 7628 cyber security requirements through supporting the following core features:

Secure FW upgrade

UR FW files v7.9 and up now include a hash code that allows for authentication prior to being used for upgrading UR devices.

Password Complexity

Supporting up to 20 alpha- numeric or special characters, UR passwords exceed NERC CIP requirements for password complexity. Individual passwords per role are available.

AAA Server Support (Radius)

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC)

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM)

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This enables UR devices integration with established SEM (Security Event Management) systems.

EnerVista™ Software

The EnerVista™ suite is an industry-leading set of software programs that simplifies every aspect of using the L90 relay. The EnerVista™ suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the L90 into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation. 
Learn More

Key Benefits

Protection & Control

The T60 transformer protection system is a comprehensive three-phase transformer relay designed to protect medium and large power transformers. The T60 provides automatic or user-definable magnitude reference winding selections for CT ratio matching, and performs automatic phase shift compensation for all types of transformer winding connections. The T60 algorithm allows the user to enable removal of the zero-sequence current even for delta-connected transformer windings, facilitating transformers with a variety of grounding configurations. As part of the Universal Relay (UR) Family, the T60 provides superior protection and control.

Functional Block Diagram

ANSI Device Numbers & Functions

Key Features

• Metering - current, voltage, power, energy, frequency, temperature, transformer monitoring
• P & M class synchrophasors of voltage, current and sequence components – 1 to 120 frames/sec
• Oscillography – analog and digital parameters at 64 samples/cycle
• Event Recorder - 1024 time tagged events with 0.5ms scan of digital inputs
• Data Logger - 16 channels with sampling rate up to 1 sample / cycle
• Setting for security audit trails for tracking changes to T60 configurations

Monitoring & Diagnostic

The T60 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle. For power quality applcations, harmonic measurements (up to the 25th) for voltage and current are available. T60 can monitor, calculate and log hottest-spot temperature, aging factor and loss-of-life data over a long period. This data, combined with economic analysis, allows criteria to be developed regarding the best time at which to replace a power transformer due to load growth, i.e. to minimize the cost without significantly increasing the risk.

Advanced Automation

The T60 incorporates advanced automation features including powerful FlexLogic™ programmable logic, communication, and SCADA capabilities that far surpass what is found in the average transformer relay. The T60 integrates seamlessly with other UR relays for complete system protection.

Key Features

Complete IEC 61850 Process Bus solution providing resource optimization and minimizing total P & C life cycle costs

• Three independent 100Mbps Ethernet ports enable purpose specific LAN support that eliminates latency effect of heavy traffic protocols on mission critical communication services
• Embedded IEEE 1588 time-synch protocol support eliminates dedicated IRIG-B wiring requirements for IEDs
• Direct I/O secures high-speed exchange of binary data between URs
• Increase network availability by reducing failover time to zero through IEC62439-3 PRP, HSR or dual HSR support

Advanced Communications

The T60 provides advanced communications technologies for remote data and engineering access, making it the most advanced and flexible transformer protection relay to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent and redundant Ethernet options provide the means to create fault tolerant communication architectures in an easy, cost-effective manner. 
The T60 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems.

Interoperability with Embedded IEC 61850

Use the T60 with integrated IEC 61850 to lower costs associated with power transformer, control and automation. GE Vernova’s leadership in IEC 61850 comes from thousands of installed devices and follows on years of development experience with UCA 2.0.

The T60’s IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing Universal Relay applications, including protection functions, FlexLogic, metering and communications. Learn more

The T60 can also connect to GE Vernova MU320 or third-party merging units using standard IEC 61869 or IEC 61850-9-2LE communication protocols.

Cyber Security - CyberSentry™ UR (FW v7.4xx)

CyberSentry enables UR devices to deliver full cyber security features that help customers to comply with NERC CIP and NITIR 7628 cyber security requirements through supporting the following core features:

Secure FW upgrade

UR FW files v7.9 and up now include a hash code that allows for authentication prior to being used for upgrading UR devices.

Password Complexity

Supporting up to 20 alpha- numeric or special characters, UR passwords exceed NERC CIP requirements for password complexity. Individual passwords per role are available.

AAA Server Support (Radius)

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC)

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication. 

Event Recorder (Syslog for SEM)

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This enables UR devices integration with established SEM (Security Event Management) systems.

EnerVista™ Software

The EnerVista™ suite is an industry-leading set of software programs that simplifies every aspect of using the T60 relay. The EnerVista™ suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the T60 into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation. Learn More

• Power quality alarming/event capture for utility or industrial event investigation/reconciliation, ensuring uptime and predictive maintenance for critical power quality sensitive assets
• Accurate Class 0.2S energy measurement (demand, time of use) and for utility or industrial Applications
• High sampling data capture and control in applications such as utility generation or renewables
• Specialized utility/industrial power quality reporting for standards such as Class A IEC 61000-430 Ed.3, IEC 61000-4-15 flicker, IEC 61000-4-7 harmonics and EN50160

The iSTAT M365 utilizes QDSP setup software to allow for easy initial meter setup, configuration and data visualization.

The iSTAT M365 support multiple types of time synchronization to ensure accuracy and synchronization of various measurements and events to meet standards.

GE Vernova Reason RT43x GNSS clocks are recommended to provide accurate time synchronization.

• Unmodulated (DC 5V level shift) and modulated (1 kHz) serial coded format with support for 1pps, day of year, current year and straight seconds of day as described in standard IRIG-200-04. GE Vernova Reason RT43x GNSS clocks recommended for time synchronization
• Supported serial time code formats are IRIG-B007 and IRIG-B127 Interface for modulated IRIG-B is designed as BNC-F terminal with 600 Ohm input impedance
• Interface for unmodulated IRIG-B is designed as pluggable terminal

• Synchronization via Ethernet requires access to a NTP server

Note: NTP can usually maintain time to within tens of milliseconds over the public Internet, but the accuracy depends on infrastructure properties - asymmetry in outgoing and incoming communication delay affects systematic bias. It is recommended that dedicated network rather than public network is used for Synchronization purposes.

The iSTAT M365 supports various communications connections and protocols for easy integration. It is equipped with standard communication port COM1 (Ethernet & USB) and an auxiliary communication port COM2 (RS232/RS485).

Energy Aggregator provides standardized and customizable reports that are automatically generated and distributed to decision makers and management, enabling constant awareness.

• Standardized and customizable reports provide insight on high-value aspects of energy consumption to make effective decisions
• Automated report generation and distribution ensures accurate, consistent reporting and constant awareness with low resource effort
• Easily baseline, determine and pinpoint opportunities for savings and energy improvements
• Example reports include:
  • Usage Summaries
  • Location-based Temperature Impact on Usage/Demand
  • Monthly/Yearly Meter Comparisons
  • Peak Day/Week Profile
  • Average Hourly/Daily Usage

Energy Aggregator generates standardized and customizable bills with support for rate structures and charges. Generated bills can be sent and distributed automatically to users as per a defined interval reducing resource efforts and costs involved with engaging other billing service providers.

• Standardized and customizable billing provides fair billing based on energy consumption
• Automated bill generation and distribution ensures accurate, consistent reporting and ownership with low resource effort and eliminates need to engaging billing service providers
• Support for rates structures such as fixed, tiered or TOU rates (fixed, seasonal) as well as additional charges, taxes
• Ability to bill completely for energy as well as other commodities such as Water, Air, Gas, and Steam

Energy Aggregator is designed with functionality to make both initial setup and ongoing maintenance of the system easy for users.

• Automated discovery of meters eliminates setup errors and reduces configuration challenges
• Reduces initial commissioning efforts and ongoing operating and maintenance costs with automated setup, report email functionality and application updates
• Easy to use reporting setup for customized report formats or export to other systems