Power Transformer Protection Devices: Types, Functions and Selection

Introduction

Power Transformer Protection Devices are electrical protection and monitoring equipment used to detect, isolate and manage faults and abnormal operating conditions in power transformers. A complete transformer protection system may include transformer differential protection relays, overcurrent and earth fault relays, Buchholz relays, temperature monitoring devices, pressure protection, oil level monitoring and other protection equipment.

The required protection devices depend on the transformer rating, voltage level, winding configuration, grounding method, fault level and the importance of the transformer within the power system. Main protection is typically used to detect internal transformer faults, while backup and mechanical protection functions help address external faults, overload, overheating, gas generation and other abnormal conditions.

This guide explains the main power transformer protection devices, their protection functions, typical applications, system configuration and selection factors. It is intended for EPC contractors, substation engineers, power utilities and procurement teams evaluating transformer protection equipment for new installations, upgrades and retrofit projects.

What Are Power Transformer Protection Devices?

Power transformer protection devices are a set of professional electrical equipment designed to monitor, detect, and isolate transformer faults in real time.

Power transformer protection devices are a combination of electromechanical, solid-state, or numerical relays, sensors, and mechanical devices that work together to detect abnormal conditions and faults in a power transformer and initiate appropriate action — typically tripping the circuit breaker to isolate the transformer or sending alarms for operator intervention.

These devices monitor parameters such as current, voltage, temperature, oil level, gas accumulation, and pressure. Modern protection systems integrate multiple protection functions into a single numerical relay (IED), providing faster operation, enhanced reliability, and advanced communication capabilities for substation automation.

What Does a Power Transformer Protection System Protect Against?

A comprehensive transformer protection system guards against:

• Internal Electrical Faults: Winding short circuits (inter-turn, phase-to-phase, phase-to-ground), core faults, and bushing failures.
• External System Faults: Downstream short circuits and earth faults that cause through-fault currents.
• Abnormal Operating Conditions: Overload, overheating, overexcitation (V/Hz), overvoltage, undervoltage, low oil level, and cooling system failure.
• Mechanical Issues: Internal arcing, pressure buildup, and oil decomposition.
• Incipient Faults: Early-stage insulation deterioration detected via gas accumulation or dissolved gas analysis.

Types of Power Transformer Protection Devices

Transformer Differential Protection Relay — 87T

The primary protection within a complete transformer protection system for large transformers compares currents entering and leaving the transformer. Under normal conditions, they are balanced (minus excitation current).

An internal fault creates an unbalance, and the relay trips instantly. Features include harmonic restraint (2nd harmonic for inrush, 5th harmonic for overexcitation) and percentage slope characteristics to ensure stability during through‑faults.

For detailed CT compensation, differential protection principles and setting calculations, see our Transformer Differential Protection Guide.

Overcurrent Protection Relay — 50/51

• 50 (Instantaneous Overcurrent): Fast clearing for severe phase faults.
• 51 (Time-Delay Overcurrent): Backup protection with inverse-time characteristics (IEC or IEEE curves) for coordination with downstream devices.

Essential for both primary and backup transformer protection.

Earth Fault Protection Relay — 50N/51N

• 50N (Instantaneous Earth Fault): Detects high-magnitude ground faults.
• 51N (Time-Delay Earth Fault): Sensitive detection of low-magnitude ground faults via residual current measurement.

Critical for detecting winding-to-ground faults, especially in grounded systems.

Restricted Earth Fault Protection — 64REF

A high‑sensitivity earth fault protection, one vital piece of transformer protection equipment, is specifically designed for the transformer winding zones. It compares neutral current with phase currents and provides fast clearing for earth faults within the protected zone. Often used in conjunction with 87T for enhanced ground fault sensitivity, especially in solidly grounded systems.

Overexcitation Protection — 24

Monitors the Volts/Hertz (V/Hz) ratio. When V/Hz exceeds design limits, the core saturates, causing excessive magnetizing current, heating, and vibration. Mandatory for generator step-up transformers and recommended for large power transformers where overexcitation risk exists.

Overvoltage and Undervoltage Protection — 59/27

• 59 (Overvoltage): Protects insulation from sustained high voltages caused by load rejection, ferroresonance, or system faults.
• 27 (Undervoltage): Detects voltage sags; used for load shedding and bus transfer schemes.

Thermal Protection — 49

Monitors winding hot‑spot temperature using a thermal model based on load current, ambient temperature, and cooling mode as one of key transformer protection functions. It provides alarm and trip stages to prevent insulation aging and failure due to sustained overloads. Replaces traditional bimetal or wax‑type thermal devices with more accurate electronic modeling.

Buchholz Relay — 63

A mechanical relay installed in the oil pipe between the main tank and conservator. Detects:

• Slow gas accumulation (alarm): Minor arcing, insulation breakdown, or low oil.
• Sudden oil surge (trip): Severe internal fault with rapid pressure wave.

Mandatory for oil-immersed transformers with conservator tanks.

Pressure Relief Protection

A mechanical device that operates when internal tank pressure exceeds a set threshold due to sudden gas generation from an internal fault. Provides fast mechanical tripping independent of electrical relays. Essential for preventing tank rupture and oil fire.

Oil Level and Temperature Monitoring

• Oil Level Gauge: Monitors oil level in the conservator or main tank; provides low-level alarm.
• Winding Temperature Indicator (WTI) / Oil Temperature Indicator (OTI): RTD-based sensors (PT100) providing analog inputs to relays and SCADA systems for continuous monitoring and alarm/trip functions.

Power Transformer Protection Devices and Their Functions

Protection Device	ANSI Code	Main Function	Typical Fault / Condition
Transformer Differential Relay	87T	Main electrical protection	Internal faults
Overcurrent Relay	50/51	Backup protection	Short circuit / overload
Earth Fault Relay	50N/51N	Ground fault protection	Earth faults
Restricted Earth Fault	64REF	Sensitive winding earth fault protection	Internal earth faults
Overexcitation Relay	24	V/Hz protection	Core overheating
Overvoltage Relay	59	High-voltage protection	Overvoltage
Undervoltage Relay	27	Low-voltage protection	Undervoltage
Thermal Protection	49	Thermal monitoring	Overload / overheating
Buchholz Relay	63	Gas and oil-flow protection	Internal oil-filled transformer faults
Pressure Relief Device	—	Pressure protection	Internal pressure rise
Oil Level Monitor	—	Oil level monitoring	Oil leakage / low oil
Temperature Monitor	—	Temperature monitoring	Winding/oil overheating

Main Protection vs Backup Protection

Aspect	Main Protection	Backup Protection
Purpose	Primary line of defense for the protected zone.	Operates if main protection fails or is unable to clear.
Speed	Instantaneous or very fast (e.g., 87T trips in < 2 cycles).	Time-delayed to allow main and downstream protection to operate first.
Zone	Zone-specific (e.g., transformer zone).	Wider zone (e.g., covers transformer and connected system).
Typical Devices	87T, 64REF, Buchholz (63), pressure relief.	51 overcurrent, 51N earth fault.
Redundancy	No backup within its zone.	Provides redundancy for transformer and downstream protection.

Key Principle: Backup protection must coordinate with main protection and downstream devices to ensure selective fault clearing.

Transformer Protection Scheme

Protection schemes vary based on transformer size, voltage level, and criticality.

Medium Voltage Power Transformer (≤ 33 kV, < 10 MVA)

• Typical Protection: Overcurrent (51/50) + Earth Fault (51N) + Buchholz (63 for oil-filled) + Thermal (49) + Temperature Monitoring.
• Differential (87T): Usually optional; cost-benefit analysis typically favors overcurrent only.
• Application: Distribution substations, industrial plants, renewable generation step-up.

High Voltage Power Transformer (66 kV – 220 kV, 10 – 100 MVA)

• Typical Protection: Differential (87T) + Overcurrent (51/50) + Earth Fault (51N) + Restricted Earth Fault (64REF) + Buchholz (63) + Thermal (49) + Overexcitation (24).
• Voltage Protection (27/59): Recommended.
• Application: Transmission substations, large industrial facilities.

Large Power Transformer (> 220 kV, > 100 MVA)

• Typical Protection: Dual differential relays (redundant) + Overcurrent (51) + Earth Fault (51N) + Restricted Earth Fault (64REF) + Buchholz (63) + Pressure Relief + Overexcitation (24) + Overvoltage (59) + Thermal (49) + Cooling Control.
• Redundancy: Two independent protection panels with separate CTs and DC supplies.
• Application: EHV transmission networks, generator step-up (GSU), bulk power substations.

Transformer Protection Devices by Fault Type

Fault / Condition	Primary Device	Backup Device
Inter-turn fault	87T	51
Phase-to-phase fault	87T / 50	51
Winding-to-earth fault	87T / 51N / 64REF	51N
Core fault	Buchholz (63) / DGA	—
Bushing fault	87T / 50	51
External phase fault	Downstream protection	51
External earth fault	Downstream earth relay	51N
Overload	49 (Thermal)	Cooling control
Overheating	49 / OTI/WTI	Cooling control
Overexcitation	24	59
Overvoltage	59	87T (stability check)
Undervoltage	27	Load shedding
Low oil level	Buchholz (63) alarm	—
Pressure buildup	Pressure relief	63 (surge)

For a detailed explanation of transformer fault types, see Transformer Fault Types: Causes, Symptoms and Protection Methods.

Digital Power Transformer Protection Devices

Numerical Protection Relay — Function Summary

Function	ANSI	Key Specifications	Procurement Checklist
Differential Protection	87T	Dual-slope restraint (15–30% / 50–80%); 2nd harmonic inrush blocking (15–20%); 5th harmonic overexcitation blocking (30–35%); supports 2 or 3 windings; auto phase-shift compensation.	[ ] 2 or 3 windings? [ ] CT class: 5P20/TPY
Overcurrent Protection	50/51	50: pickup 1.5–10 x In, instant trip. 51: IEC or IEEE inverse curves; pickup 0.5–2.5 x In; directional option.	[ ] IEC or IEEE curves? [ ] Directional required?
Earth Fault Protection	50N/51N	50N: pickup 0.1–5 x In, instant. 51N: residual from phase CTs or neutral CT; inverse curves; sensitivity 5–20%. Directional option.	[ ] Residual source: calculated or neutral CT? [ ] Directional required?
Under/Overvoltage	27/59	27: pickup 0.6–0.9 Vn; 59: pickup 1.05–1.3 Vn; definite or inverse time delay.	[ ] 1-phase or 3-phase input? [ ] Alarm, trip, or both?
Overexcitation (V/Hz)	24	Pickup 1.05–1.2 x rated; inverse-time characteristic. Mandatory for generator step-up transformers.	[ ] Required? (GSU → yes)
Thermal Overload	49	Thermal model using load current, ambient temp, cooling mode (OA/FA/FOA); alarm + trip stages.	[ ] Cooling classes confirmed?
Negative Sequence	46	Pickup 10–40%; inverse-time characteristic. Recommended for GSU and unbalanced systems.	[ ] Required for this application?

Event & Disturbance Recording

• Event Recording: Time-stamped sequence of relay pickups, trips, alarms (500–2000 events). Requires time sync (IRIG-B/NTP).
• Disturbance Recording: COMTRADE-format waveform capture (pre-fault 5–10 cycles, post-fault 10–20 cycles). Minimum 16–32 samples/cycle, 10–20 records storage.

Procurement Checklist:

• □ Event storage capacity ≥ 500 events.
• □ Disturbance recording: COMTRADE format, ≥ 16 samples/cycle, ≥ 10 records.

Communication Protocols

Protocol	Application	Interface
IEC 61850	New digital substations (GOOSE/SV)	Fiber optic
IEC 60870-5-103	European utilities, legacy plants	RS-485 / Fiber
Modbus RTU	Simple serial, PLC integration	RS-485
Modbus TCP	Universal Ethernet SCADA	RJ45 Ethernet

Procurement Checklist:

• □ Primary protocol specified.
• □ Secondary protocols for legacy integration (if needed).
• □ Port types and count confirmed.
• □ Time sync: IRIG-B, NTP, or PTP supported.

Substation Integration

Integration Level	Capability	Key Requirements
SCADA	Real-time data (current, voltage, power, status, alarms); remote setting changes; control commands (trip/close).	Protocol selection; cybersecurity (role-based access, password protection).
HMI	Local front-panel display or remote PC software; single-line diagram, event lists, waveform retrieval, setting modification.	Confirm local or remote HMI required.
Station Automation	Fast inter-tripping, interlocking, auto-transfer logic via GOOSE (IEC 61850); redundant topologies (PRP/HSR) optional.	Specify automation features (bus transfer, load shedding, interlocking).
Remote Monitoring	Web server access (HTTP/HTTPS); email/SMS alarm notification; IEC 62443 cybersecurity compliance.	Specify cybersecurity level and remote access method.

Summary — Digital Relay Selection Checklist

Category	Item	Confirmed?
87T	2 or 3 windings; CT class 5P20/TPY	☐
50/51	IEC/IEEE curves; directional?	☐
50N/51N	Residual source; directional?	☐
27/59	1-phase/3-phase; alarm/trip	☐
24	Required? (GSU: mandatory)	☐
49	Cooling classes confirmed	☐
46	Required?	☐
Event Recording	≥ 500 events; IRIG-B/NTP	☐
Disturbance Recording	COMTRADE; ≥ 16 samples/cycle	☐
Communication	Primary protocol; ports; time sync	☐
SCADA	Protocol; cybersecurity	☐
HMI	Local front panel / remote software	☐
Automation	GOOSE; interlocking; auto-transfer	☐
Remote Monitoring	Web access; email alarm; IEC 62443	☐

How to Select Power Transformer Protection Devices

Selection of power transformer protection devices requires a systematic approach covering transformer parameters, CT specifications, protection functions, communication, and project standards. The following checklist guides procurement and engineering teams through each decision point.

1. Transformer Rating

Parameter	What to Specify	Why It Matters
kVA / MVA	Rated capacity (e.g., 10 MVA, 50 MVA)	Determines if 87T is required (≥ 5 MVA → typically yes).
Continuous Load	Expected normal load current	Basis for CT ratio selection and thermal (49) relay settings.
Fault Level	Maximum symmetrical short-circuit current (kA) at transformer terminals	Determines overcurrent pickup settings, CT saturation requirements, and breaker interrupting capacity. Obtain from system study.

Procurement Checklist:

• □ Transformer MVA rating confirmed.
• □ Fault level (kA) provided by system study.
• □ %Z (impedance) from nameplate available for coordination study.

2. Voltage Level

Voltage Level	Typical Range	Protection Complexity
LV (Low Voltage)	≤ 1 kV	Simple: fuses or 51/51N only.
MV (Medium Voltage)	1 kV – 33 kV	Standard: 51/51N + 49 + Buchholz; 87T optional.
HV (High Voltage)	66 kV – 220 kV	Full: 87T + 51/51N + REF + 49 + 24 + Buchholz.
EHV (Extra High Voltage)	> 220 kV	Redundant protection, dual relays, advanced communication.

Procurement Checklist:

• □ HV and LV voltage levels confirmed.
• □ System grounding type (solid, resistance, isolated) specified — affects earth fault protection requirements.

3. Winding Configuration

Configuration	Relay Impact	Key Requirement
Two-Winding	Standard differential with 2 CT inputs.	87T with 2 restraint inputs.
Three-Winding	Differential requires 3 CT inputs (one per winding).	87T with 3 restraint inputs (e.g., SEL-487E, P643).
Auto-Transformer	Zero-sequence current flows through neutral.	Requires 87TN (zero-sequence differential) in addition to standard 87T.

Procurement Checklist:

• □ Winding count confirmed (2 or 3).
• □ If auto-transformer, specify 87TN requirement.

4. CT Parameters

Parameter	Specification	Decision Guide
CT Ratio	Primary current based on transformer full-load current; secondary current selected to match relay input.	Choose ratio so HV and LV secondary currents are close (compensation factor < 15%).
Secondary Rating	1A (IEC standard, preferred for long cable runs) or 5A (ANSI standard).	Must match breaker CTs. Use 1A for cable runs > 100m to reduce burden.
Accuracy Class	For 87T: 5P20 or TPY (anti-saturation). For 50/51: 10P10 minimum.	TPY required if knee point voltage check indicates saturation risk.
Burden (VA)	CT rated VA > relay input + cable burden.	Calculate cable burden based on length and conductor size.
Saturation (Vk)	Knee point voltage must exceed max fault secondary voltage.	If Vk insufficient → specify TPY class CTs.

Procurement Checklist:

• □ CT ratio calculated and checked for HV/LV secondary current match.
• □ Secondary rating (1A or 5A) confirmed with breaker CTs.
• □ Accuracy class specified (5P20/TPY for 87T).
• □ CT burden verified against relay input + cable burden.
• □ Knee point voltage calculation performed.

5. Protection Functions

Check each function against project requirements:

Function	ANSI	When Required	Procurement Decision
Differential	87T	Transformer ≥ 5 MVA, or critical application.	☐ Required ☐ Not Required
Overcurrent	50/51	Always required (primary/backup protection).	☐ Required
Earth Fault	50N/51N	Always required (grounded or resistance-grounded systems).	☐ Required
Restricted Earth Fault	REF (64)	For enhanced ground fault sensitivity in solidly grounded systems.	☐ Required ☐ Not Required
Overexcitation	24	Generator step-up transformers (mandatory); large power transformers (recommended).	☐ Required ☐ Not Required
Thermal Overload	49	Strongly recommended for all transformers.	☐ Required ☐ Not Required
Over/Undervoltage	59/27	Required for voltage protection and load shedding/auto-transfer schemes.	☐ Required ☐ Not Required

Procurement Checklist:

• □ All required functions marked.
• □ For REF, confirm CT configuration (neutral CT + phase CTs required).
• □ For 24, confirm if transformer is generator step-up.

6. Communication

Protocol	Application	Decision
IEC 61850	New digital substations (GOOSE/SV for fast interlocking and process bus).	☐ Required for new substations
Modbus TCP/RTU	Universal SCADA and PLC integration; cost-effective.	☐ Typically required for all projects
IEC 60870-5-103	European utilities and legacy power plants.	☐ Required for legacy integration

Procurement Checklist:

• □ Primary protocol confirmed (e.g., IEC 61850 + Modbus TCP dual stack).
• □ Number and type of communication ports specified (Ethernet, RS-485, fiber).
• □ Time synchronization (IRIG-B, NTP, PTP) confirmed.

7. Project Standards

Compliance requirements vary by project location and application:

Standard	Typical Application	Decision
IEC (e.g., IEC 60255, IEC 61850, IEC 60076)	International projects, Europe, Asia, Middle East, Africa.	☐ IEC compliance required
IEEE (e.g., IEEE C37.2, IEEE C57, IEEE C37.112)	North American projects (USA, Canada, Latin America).	☐ IEEE compliance required
Utility Specifications	Specific utility requirements (e.g., National Grid, PG&E, EDF, TNB).	☐ Utility spec required — obtain document.
EPC Specifications	Contractor-specific technical requirements for turnkey projects.	☐ EPC spec provided — cross-check against this checklist.

Procurement Checklist:

• □ Governing standard identified (IEC or IEEE).
• □ Utility or EPC specification document obtained and reviewed.
• □ Relay must comply with utility approval list (if applicable).

Summary — Complete Procurement Checklist

Category	Parameter	Your Specification	Confirmed
Transformer Rating	MVA	_____ MVA	☐
	Fault level	_____ kA	☐
	%Z	_____ %	☐
Voltage	LV voltage	_____ kV	☐
	HV voltage	_____ kV	☐
Winding	Type	☐ 2-wind ☐ 3-wind ☐ Auto	☐
CT	Secondary rating	☐ 1A ☐ 5A	☐
	Accuracy class	☐ 5P20 ☐ TPY ☐ 10P10	☐
	Ratio	_____ / _____	☐
Protection	87T	☐ Required ☐ Not Required	☐
	REF	☐ Required ☐ Not Required	☐
	24	☐ Required ☐ Not Required	☐
	49	☐ Required ☐ Not Required	☐
	27/59	☐ Required ☐ Not Required	☐
Communication	Primary protocol	☐ IEC 61850 ☐ Modbus ☐ IEC 103	☐
Standards	Governing standard	☐ IEC ☐ IEEE	☐
	Utility/EPC spec	Document No.: __________	☐

Power Transformer Protection Devices for EPC Projects

For EPC contractors, transformer protection delivery goes beyond hardware — it requires complete documentation, engineering support, and testing services. The following checklist defines what suppliers must provide at each project phase.

Technical Documentation

Document	Format	Purpose
Datasheet	PDF + Excel	Complete relay specs for engineering integration.
Protection Function List	PDF	ANSI codes, setting ranges, default values.
Wiring Diagram	CAD (DWG/DXF) + PDF	External connections: CT/VT, I/O, power, comms.
Terminal Diagram	CAD + PDF	Physical terminal arrangement for panel design.
Communication Protocol & Point List	PDF + ICD/CID (IEC 61850)	Supported protocols and data mapping.
Setting Guide	PDF	Step-by-step configuration and logic diagrams.
User Manual	PDF	Operation, installation, maintenance.

Checklist: ☐ All documents requested in RFQ ☐ CAD formats specified ☐ ICD file included for IEC 61850 projects.

Project Engineering Support

Task	Supplier Responsibility
SLD Review	Confirm CT/VT locations, protection zones, relay placement.
Relay Selection	Recommend model based on MVA, voltage, windings, protection functions.
Protection Configuration	Provide setting templates; assist with coordination calculations.
CT/VT Compatibility	Verify ratios, accuracy class (5P20/TPY), burden, knee point voltage.
Communication Integration	Provide point list/ICD file; assist with SCADA/station bus integration.
Panel Design	Supply dimensions, cutout drawings, terminal schedules.

Checklist: ☐ Setting calculation support included ☐ CT/VT compatibility check ☐ ICD file provided ☐ Panel drawings delivered.

Factory Acceptance Testing (FAT)

Test	What Is Verified
Visual/Mechanical Inspection	Correct assembly, wiring, labeling.
Secondary Injection	Each protection function (87T, 51/51N, REF, 24, 49, 27/59) operates per settings.
I/O Test	All binary inputs/outputs correctly wired and functional.
Communication Test	Protocols (IEC 61850, Modbus, DNP3) working; data mapping correct.
Power Supply Test	Operation under nominal, undervoltage, overvoltage DC conditions.

Checklist: ☐ FAT scope defined ☐ Procedure approved ☐ FAT witnessed (if required) ☐ Signed FAT report delivered.

Site Acceptance Testing & Commissioning Support

Test	What Is Verified
Visual Inspection	Correct site installation per approved drawings.
Secondary Injection (Site)	Settings loaded correctly; functions verified with site wiring.
I/O & Trip Circuit Test	Binary I/O functional; breaker trips correctly from each function.
Communication Test (Site)	SCADA/HMI/station automation integration verified.
Primary Injection	CT ratio, polarity, and relay measurement accuracy under actual current flow.
Commissioning Support	On-site engineer assists with final settings and troubleshooting.

Checklist: ☐ SAT scope included ☐ Primary injection equipment/procedure defined ☐ On-site engineer assigned ☐ SAT report signed before energization.

EPC Scope of Supply — Quick Summary

Phase	Key Deliverables	Included?
Documentation	Datasheet, wiring/terminal diagrams, point list/ICD, setting guide, manual	☐
Engineering	SLD review, relay selection, protection config, CT/VT check, comms integration, panel drawings	☐
FAT	Visual, secondary injection, I/O, comms, power supply tests + report	☐
SAT & Commissioning	Site secondary injection, I/O/trip, comms, primary injection + on-site engineer + SAT report	☐

Why Choose Our Power Transformer Protection Devices?

We supply transformer protection devices and relay solutions for EPC contractors, utilities, substations and industrial power projects. Our products are sourced from qualified OEM manufacturing partners and can be selected according to transformer ratings, protection requirements, communication interfaces and project specifications.

Our Power Transformer Protection Devices

1. Transformer Differential Protection Relay

Core: 87T — Primary protection for internal transformer faults.

Key Features: Dual-slope restraint; 2nd/5th harmonic blocking; supports 2 or 3 windings; auto phase-shift compensation; CT saturation detection.

Application: Large transformers, GSU, critical substations (≥ 5 MVA).

Comms: IEC 61850, Modbus, DNP3.

➡ View Product →Transformer Differential Protection Relay

2. Numerical Transformer Protection Relay

Core: 87T + 50/51 + 50N/51N + 24 + 49 + 27/59 — All-in-one digital IED.

Key Features: Full protection suite; event & disturbance recording (COMTRADE); multi-protocol communication.

Application: HV/EHV transformers, industrial substations.

Comms: IEC 61850, Modbus TCP/RTU, IEC 103, DNP3.

➡ View Product →Numerical Transformer Protection Relay

3. Transformer Backup Protection Relay

Core: 50/51 + 50N/51N — Phase and earth fault backup.

Key Features: Instantaneous + inverse-time overcurrent; residual earth fault; directional option; compact and cost-effective.

Application: Backup for power transformers; distribution transformers without 87T.

Comms: Modbus RTU/TCP; IEC 61850 optional.

➡ View Product →Transformer Backup Protection Relay

4. Three-Winding Transformer Protection Relay

Core: Three-winding 87T — Differential with 3 independent restraint inputs.

Key Features: Dedicated 3-winding algorithm; independent ratio/phase compensation per winding; supports tertiary connections.

Application: Three-winding power transformers, auto-transformers with tertiary.

Comms: IEC 61850, Modbus, DNP3.

➡ View Product →Three-Winding Transformer Protection Relay

5. Transformer Protection & Control Panel

Core: Relay + CT/VT interface + breaker control + SCADA/IEC 61850 — Complete panel solution.

Key Features: Full protection relay; test blocks for CT/VT; trip/close controls; SCADA integration; dual DC supply option.

Application: New substations, EPC turnkey projects, retrofits.

Mounting: 19″ rack, switchgear flush-mount, or standalone cubicle.

➡ View Product →Transformer Protection & Control Panel

Quick Selection Guide

Product	Core Functions	Best For
Differential Relay	87T	≥ 5 MVA transformers
Numerical Relay	Full suite (87T + 50/51 + 51N + 24 + 49 + 27/59)	All-in-one protection
Backup Relay	50/51 + 50N/51N	Distribution / backup applications
Three-Winding Relay	3-winding 87T	Three-winding & auto-transformers
Protection Panel	Relay + CT/VT + control + SCADA	EPC projects, substations

For datasheets, application notes, or quotations, contact our engineering team.

Power Transformer Protection Devices — FAQ

What are power transformer protection devices?

Power transformer protection devices are instruments and relays — both electrical and mechanical — that monitor transformer parameters (current, voltage, temperature, oil level, gas, pressure) and initiate alarms or trip commands to isolate the transformer during faults or abnormal conditions, preventing catastrophic damage.

What are the main protection devices used for power transformers?

Main devices: Differential relay (87T), overcurrent relays (50/51), earth fault relays (50N/51N), restricted earth fault relay (64REF), overexcitation relay (24), thermal relay (49), over/undervoltage relays (59/27), Buchholz relay (63), pressure relief device, and oil/winding temperature monitors.

What is the main protection for a power transformer?

Differential protection (87T) is the primary main protection for transformers ≥ 5 MVA. For smaller distribution transformers, overcurrent protection (51) plus fuses often serves as the main protection.

Is a transformer differential relay the main protection device?

Yes — for medium to large power transformers, 87T differential relay is the primary/main protection for internal winding faults (phase-to-phase, inter-turn, and winding-to-earth). However, it does not cover all fault types (e.g., incipient gas faults, thermal overload), so additional devices are required for complete protection.

What protection is used as backup for a power transformer?

Overcurrent relays (51/51N) provide backup protection. They operate with time delay to allow primary and downstream protection to clear faults first. If the main protection fails, the backup relay trips the transformer.

What is the function of a Buchholz relay?

A Buchholz relay (63) is a mechanical device installed in the oil pipe between the main tank and conservator. It alarms on slow gas accumulation (incipient faults, low oil) and trips on sudden oil surge (severe internal arcing). It is mandatory for oil-immersed transformers with conservator tanks.

What protection devices are required for a high-voltage power transformer?

For HV transformers (66–220 kV), typical requirements: 87T differential, 50/51 overcurrent, 50N/51N earth fault, 64REF restricted earth fault, 24 overexcitation, 49 thermal overload, 63 Buchholz, pressure relief, and 27/59 voltage protection. Redundant relays are often specified for critical units.

How do I select power transformer protection devices?

Follow this 7-step checklist:

1. Transformer Rating — MVA, fault level, %Z.
2. Voltage Level — LV/MV/HV/EHV determines protection complexity.
3. Winding Configuration — 2-winding, 3-winding, or auto-transformer.
4. CT Parameters — ratio, 1A/5A, accuracy class (5P20/TPY), burden, saturation.
5. Protection Functions — define required ANSI codes (87T, 50/51, etc.).
6. Communication — IEC 61850, Modbus, DNP3, IEC 103.
7. Project Standards — IEC, IEEE, utility, or EPC specifications.

Can one numerical relay integrate multiple transformer protection functions?

Yes. Modern numerical relays (e.g., SEL-487E, Siemens 7UT85, MiCOM P643) integrate 87T, 50/51, 50N/51N, 24, 49, 27/59, event/disturbance recording, and multiple communication protocols into a single IED, reducing panel space, wiring, and cost.

What communication protocols are used by digital transformer protection devices?

Common protocols: IEC 61850 (new digital substations, GOOSE/SV), Modbus TCP/RTU (universal SCADA/PLC integration), DNP3 (North American projects), and IEC 60870-5-103 (European legacy/power plants). Most relays support multiple protocols simultaneously.

What is the difference between transformer protection devices and transformer protection relays?

Protection devices is a broader term that includes electrical relays (87T, 51), mechanical devices (Buchholz, pressure relief), and sensors (temperature, oil level). Protection relays specifically refer to electrical IEDs that measure currents/voltages and make trip decisions.

How are transformer protection devices tested and commissioned?

Testing follows two stages:

SAT (Site Acceptance Test): Visual inspection, secondary injection (site), I/O and trip circuit test, communication test (site), primary injection test (CT ratio/polarity) — conducted after installation, with on-site commissioning engineer support. A signed SAT report is required before transformer energization.

FAT (Factory Acceptance Test): Visual inspection, secondary injection (verify each function), I/O test, communication test, power supply test — conducted at supplier’s facility.