760-P5-G5-S5-HI-A20-R GE Multilin 760 Feeder Protection Relay

• Brand
  GE
• Model
  760-P5-G5-S5-HI-A20-R
• Product Name
  Multilin 760 Feeder Protection Relay
• Place of Origin
  United States
• Customs HS Code
  85301000
• Power Supply
  85‑264 VAC / 88‑300 VDC
• Dimensions
  177.8 mm (height) × 139.7 mm (width) × 228.6 mm (depth)
• Weight
  2.72 kg
• Operating Temperature
  ‑40 °C to +60 °C
• Storage Temperature
  ‑40 °C to +85 °C
• Warranty
  12 month
• Product Status
  new and original

Input, Output, Supported Protocols and Compatible Software for GE 760-P5-G5-S5-HI-A20-R

1. Hardware Inputs

1.1 Analog Current Inputs

Equipped with 3-phase nominal 5A phase current inputs, 5A zero-sequence current input and 5A sensitive ground current input, supporting high-precision current sampling and overcurrent/ground fault protection detection for power feeders.

1.2 Analog Voltage Inputs

Includes 3-phase voltage inputs with 120V/240V nominal working voltage and one neutral voltage input with 120V nominal voltage, realizing line voltage monitoring, overvoltage and undervoltage protection functions.

1.3 Digital Status Inputs

Provides 8-channel dry-contact digital inputs with a nominal 24VDC working voltage, used for collecting external equipment status signals, switch position feedback and remote command signals.

1.4 Power Supply Input

Wide-range universal power supply input, supporting 88V–300V DC and 70V–265V AC power supply, with adaptive frequency range of 48Hz–62Hz, adapting to complex on-site power supply environments.

2. Hardware Outputs

2.1 Digital Relay Outputs

Configured with 6 Form-C relay outputs, with rated load of 5A @250V AC and 5A @30V DC. It is applicable for feeder trip output, alarm signal output and on-site equipment logic control.

2.2 Analog Outputs

Integrates 8 independent configurable 4–20mA analog output channels, which can convert real-time electrical parameters (current, voltage, power, frequency, etc.) into standard analog signals for connection with PLC, DCS and industrial display instruments.

2.3 Communication Output Interfaces

Comes with dual Ethernet ports and one RS-485 serial port, supporting multi-mode network communication and on-site bus communication to meet different industrial networking requirements.

3. Supported Communication Protocols

The relay is compatible with mainstream industrial communication protocols to realize data transmission, remote monitoring and inter-device linkage:

Modbus TCP/IP: Applied to Ethernet communication, supporting high-speed real-time data uploading, parameter remote reading and modification

Modbus RTU: Applied to RS-485 serial bus communication, suitable for traditional industrial field bus networking

IEC 61850: Optional professional power system protocol, supporting substation automation system integration, GOOSE message transmission and SV sampling value transmission

DNP3: Compatible with distributed network protocol for utility power system remote SCADA communication

IEEE 1588: Supports precision clock synchronization, ensuring unified time calibration for substation equipment data

4. Compatible Software

GE EnerVista Software Suite: Dedicated configuration and monitoring software for Multilin relays, supporting device parameter setting, logic programming, real-time data viewing, fault event recording query, waveform analysis and firmware upgrade

SCADA System Software: Compatible with mainstream industrial SCADA platforms including Siemens WinCC, Wonderware Intouch, GE Proficy, supporting upper computer remote monitoring and centralized control

Substation Automation System Software: Adaptable to IEC 61850-compliant substation management software for intelligent substation system integration

5. Compatible Operating Systems & Industrial Systems

PC Operating Systems: Windows 7, Windows 10, Windows 11, Windows Server 2016/2019 (fully compatible with EnerVista software operation)

Industrial Control Systems: DCS distributed control system, PLC industrial control system, substation automation system (SAS), power distribution monitoring system

Applicable Industrial Scenarios: Industrial factory power distribution, commercial building power supply system, municipal power grid, petroleum and chemical power system, mining power distribution system

Commissioning Steps for GE 760-P5-G5-S5-HI-A20-R Feeder Management Relay

Pre-commissioning Safety & Visual Inspection Disconnect all high-voltage and control power and implement lock-out tag-out safety procedures. Confirm secure mechanical mounting of the relay. Inspect all terminal wiring against schematic drawings, including CT, VT, digital inputs, relay outputs, power supply and communication cables. Measure insulation resistance for secondary circuits and eliminate short-circuit or open-circuit hazards within CT/VT loops. Ensure site ambient conditions comply with official equipment specifications.

Power-on and Self-test Supply qualified control power within range 88-300 V DC / 70-265 V AC. Observe LED status indicators and front-panel LCD screen. Allow the unit to finish power-on self-diagnosis; document firmware revision, serial number and hardware configuration details. Clear the factory-default "Relay Not Ready" warning message.

Establish Communication Connection Connect a personal computer to the relay through front-panel RS232, rear-mounted RS-485 or Ethernet port. Open EnerVista 750/760 Setup software and create a new site with target device added. Configure matching communication parameters: baud rate, slave address, IP address, subnet mask and gateway. Confirm stable, error-free online connection between PC and protection relay.

Basic System Configuration Program device name, substation tag, system date-time and time-synchronization mode (SNTP / IEEE1588). Enter CT primary-secondary ratio, VT ratio and correct phase-wiring scheme. Assign functions for digital input channels, allocate Form-C relay outputs, and define scaling parameters for 4-20 mA analog outputs. Activate required communication protocols including Modbus TCP, Modbus RTU, DNP3 and optional IEC 61850 features. Store a local backup copy of project settings on PC prior to downloading to hardware.

Protection & Control Parameter Download Configure feeder protection setpoints: overcurrent, ground fault, negative-sequence overcurrent, over-voltage / under-voltage, breaker failure, cold-load pickup, plus associated threshold values and time delays. Set breaker control logic, auto-reclosing parameters, interlock logic and alarm assignments. Download full setpoint database to relay, then perform read-back verification to guarantee data integrity. Switch relay operational status from “Not Ready” to “Ready for Service” via front keypad or software interface.

Static I/O Functional Test (Secondary Injection Test Recommended) Digital Input Test: Inject 24 V DC external signal to each dry-contact input terminal; validate corresponding status feedback both on local LCD and EnerVista software. Relay Output Test: Manually trigger each configured output logic; verify Form-C contact operation and continuity of trip-alarm wiring loops. Analog Output Test: Force simulated internal measured variables; use multimeter to test every 4-20 mA channel and verify scaling accuracy.

Secondary Injection Protection Performance Test Connect protective relay test set to CT and VT secondary terminals. Apply sequential simulated fault conditions: phase overcurrent, ground fault, voltage deviation and other abnormal scenarios. Validate pickup thresholds, operating time, trip-alarm response, LED indication, event logs and COMTRADE fault waveform capture. Confirm all protection elements behave consistently with programmed settings and record complete test data.

Communication Interoperability Verification Validate data transmission towards upper-level SCADA or DCS platforms. Verify normal acquisition of real-time metering values, binary status points, alarm notifications and sequence-of-event fault records. Verify remote parameter access permissions (read-only or modification) aligned with on-site security regulations.

Post-test Confirmation & On-site Preparation Erase temporary test-triggered fault records, event history and latched alarm flags. Re-retrieve full setpoints for final cross-check. Archive final commissioning configuration files and fault waveform data for project documentation. Retighten all wiring terminals; remove temporary jumpers and test cabling used during secondary testing. Restore all site safety arrangements; the relay is now prepared for primary equipment energization.

On-line Monitoring after Primary Energization Once feeder primary circuit is energized, continuously observe real-time current, voltage and power readings on relay local display as well as remote supervisory system. Confirm measured magnitude, phase sequence and polarity are physically reasonable without unexpected alarms or inadvertent element pickup. Complete all commissioning acceptance paperwork.

DS200PTBAG1BBA
DS200TDAH1BHD
DS200TCRAG1ACC
DS200DTRAG1AAA
DS200DTBBG1ABB
DS200SDCCG4AFD
DS200TCDAG1BDB
IS220PTURH1B
C60G01HCHF8FH6PM8FP6PU6PWXX
DS200TCQCG1BHF