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Retrofit an old substation design

This approach assumes retrofitting and upgrading old substation secondary equipment such as intelligent electronic devices (IEDs), monitoring sensors, power apparatus, communication protocol and operating standards to improve the overall performance or reduce cost without disrupting the continuity of service.

Secondary equipment you should always consider when retrofitting existing HV substation
Secondary equipment you should always consider when retrofitting existing HV substation

For this purpose, a comprehensive survey of new technologies is done and the cost benefit analysis is addressed.

Two scenarios are discussed: upgrading and expanding (if possible) the old substation equipment using latest technologies. The emphasis is given to the use of wireless and optical fiber communication media when adding new equipment and using software integration of data when retrofitting existing design.


Retrofit for the substation secondary equipment

In following paragraphs, we introduce some retrofit options for the substation secondary equipment. The main functionalities of the secondary system of the substation are categorized into protection, monitoring, communication and backup& emergency control.

The retrofit design for substations may vary since the criteria for upgrades may be different. This section describes different strategies for retrofitting the secondary equipment at a large typical substation.

The retrofit strategy is split into four sections:

  1. Switchyard sensors
    1. Temperature sensors
    2. Pressure sensors
    3. Vibration sensors
    4. Oil and gas monitoring devices
    5. Current and Voltage sensors
  2. Intelligent Electronic Devices (IEDs)
    1. Metering and monitoring relay
    2. Control house safety function relay
    3. Transmission line protection relay
    4. Transformer protection
    5. Bus protection
    6. Fault recorder
  3. Use of fiber optic cables
  4. Wireless communication

1. Switchyard monitoring devices

The main functionality of the sensors is to measure signals from primary equipment in the substation yard such as transformers, circuit breakers, power lines, etc.

Such sensors are offered by most of the major companies such as Siemens, ABB, GE, SEL, GE and others. Original copper-wired analog sensors are replaced by optical fiber-based sensors for monitoring and metering.

As an example, the most prominent advantages of optical fiber current and voltage sensors are high accuracy, no saturation, reduced size and weight, safe and environmental friendly (avoid oil or SF6), higher performance, wide dynamic range, high bandwidth and low maintenance (Figure 1).

Switchyard monitoring devices
Figure 1 – Switchyard monitoring devices

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1.1 Temperature sensors

It may be a new functionality for some old substations which still lack this kind of technology. Original copper-wired analog apparatus may be replaced by optical apparatus with fiber-based sensors to measure temperature.

Such product, as SIEMENS SIRIUS 3RS1 and 3RS2 for temperature monitoring in solid, liquid or gas media are having compatibility to the original analog apparatus. At the same time, they can integrate many functions in one device.

SIRIUS 3RS1 and 3RS2 have temperature monitoring relays monitor heating, air conditioning and ventilation systems just as reliably as motors – and all this with up to 3 sensors simultaneously.

Thus, the high-end analysis equipment with digital displays can be used for a broad temperature range and with different types of sensors.

Sirius 3RS1 - Temperature monitoring relays can be used for measuring temperatures in solid, liquid and gas media
Figure 2 – Sirius 3RS1 – Temperature monitoring relays can be used for measuring temperatures in solid, liquid and gas media. The temperatures are acquired by means of sensors in the medium, evaluated by the device and monitored for overshoot, undershoot or location within a specified range (window function).

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1.2 Pressure sensors

Some substations still lack this kind of sensors, and existing sensors are mostly analog. They can be replaced by an optical one such as ABB’s S266 pressure sensor.

The S266 are used in combination with 266 compact transmitter class, allowing gauge, level or absolute pressure measurements. A wide range of remote seal types are available, which allows optimum design.

BB's model 266MST is a differential pressure transmitter with “multisensor technology”
Figure 3 – ABB’s model 266MST is a differential pressure transmitter with “multisensor technology” suitable for measuring liquid, gas or steam flow as well as level, pressure and density in applications with working pressure up to 41Mpa / 5945psi. The unique combination of several sensor systems in a single device allows simultaneous measurement of differential pressure and absolute pressure.

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1.3 Vibration sensors

A new optical technology such as Vibration Sensor Switch by Oncque Corporation, allows optical monitoring of vibration of circuit breakers and other primary equipment such as transformers switch disconnectors etc.

Two wireless sensors installed in oil-cooled transformer
Figure 4 – Two wireless sensors installed in oil-cooled transformer (photo credit: Asis Nasipuri, Hadi Alasti, Priya Puthran, Rob Cox, James M. Conrad, Luke Van der Zel, Bienvenido Rodriguez, Ralph McKosky, Joseph A. Graziano)

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1.4 Oil and gas monitoring devices

Besides the protection of the transformers, the monitoring of the operation of transformers is essential as well. Dissolved Gas Analysis (DGA) monitoring is one of the most valuable diagnostic tools available.

It is a procedure used to assess the condition of an oil-filled transformer from an analysis of the gases dissolved in the cooling/insulating medium. It is a well established technique that is cost effective, providing essential information from a relatively simple, non-destructive test based upon oil sampling.

The results reveal much about the health of the transformer including its present condition, any changes that are taking place, the degradation effects of overload, ageing, the incipient faults and the most likely cause of major failures.

Existing substations are mainly using off-line and at-line methods to evaluate the oil condition of the transformer.

Table 1 – DGA monitoring methods

Phase and its nameDefinitionAdvantagesDisadvantages
Off-lineManual sampling and Lab. AnalysisStrict analyzing process, accurate and reliableLong sampling interval
At-lineManual sampling and in situ analysisImmediate results analyzedEquipment for in situ analysis required
On-lineSampling continuously or discontinuously by side wayAutomatic sampling by side waySide way sampling required, temperature and pressure must fit the analyzer
In-lineSensor placed at the sampling pointLocated in situ real time analysisSensor needed to fit the measuring locale

With laboratory analysis only, no real-time results can be obtained so as to ensure the monitoring of transformers at all time. With the at-line analysis, it is manual labor tasks that lacks the flexibility and cannot always guarantee the accuracy.

Calisto 9 is a powerful tool for transformer condition assessment
Figure 5 – Calisto 9 is a powerful tool for transformer condition assessment

An example of such product is Morgan Schaffe DGA Calisto 9 which uses gas chromatography with proven reliable results. This is a physical method of separation in which the components to be separated are distributed between two phases, one of which is stationary (stationary phase) while the other moves in a definite direction (mobile phase).

On-line and In-line DGA sensors are two new methods for transformer monitoring. Most of current substations are lacking on-line DGA monitoring devices and it can be used as a good retrofit option.

Examples of this product is TMD Smart Monitor by Siemens.

Smart Monitor turns transformer monitoring data into actionable information by translating combustible dissolved gas
Figure 6 – Siemens’s TMDS™ Smart Monitor turns transformer monitoring data into actionable information by translating combustible dissolved gas, bushing capacitance deviation, moisture and other sensor measured data into diagnostic and prognostic messaging

For in-line DGA monitoring, products are now being developed and put into practice, like monitoring and assessing transformer and LTC health. Monitoring the dissolved gas levels in transformer oil samples is a useful, trusted maintenance tool for assuring optimal asset health.

Monitoring the dissolved gas levels in transformer oil samples is a useful, trusted maintenance tool for assuring optimal asset health.
Figure 7 – Monitoring the dissolved gas levels in transformer oil samples is a useful, trusted maintenance tool for assuring optimal asset health.

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1.5 Current and Voltage sensors

Current transformers (CTs), Potential Transformers (PTs) or Voltage Transformers (VTs), also called instrument transformers, are used to measure current and voltage signals.

A current transformer (CT) produces a reduced current at the secondary side proportional to the current in the primary circuit, which can be used to conveniently connect measuring and recording instruments. A current transformer also galvanically isolates the measuring instruments.

The current/voltage transformer is one of the most important interfacing sensors for measurement and relay protection subsystem.

Traditional current/voltage transformer, which is still widely used in power system, is based on magnetic circuits. This may create series of problems such as measured signal bandwidth limitation, magnetic saturation, etc.

However, recent trend goes in direction of developing combined fiber-optical current and electronic voltage transformer.


Combined fibre-optic-electronic current and voltage transformers are the newest technology. They combine all the advantages of two electronic transformers in one.

Their reduced size and weight compared to conventional electromagnetic transformers means that combined transformers can be installed even in small substations where there is limited space.

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2. Intelligent Electronic Devices (IEDs)

Recent multifunctional Intelligent Electronic Devices (IEDs) provide higher performance, reduction in operating cost, reduction in size, increase in efficiency and improvement in robustness in the existing substations.

As an example, protection relays are widely used in all kind of substations for different purposes from individual functions, such as differential protection, distance protection, overcurrent protection, metering, monitoring, etc, to several protection, monitoring, control and user interface functions included in one box.

Intelligent Electronic Devices (IEDs)
Figure 8 – Intelligent Electronic Devices (IEDs)

The main advantages of multifunctional IEDs are that they are fully IEC 61850 compatible, have compact size and offer various functions contained together in one design. This means reduction in size, increase in efficiency and improvement in robustness which is the main design goal.

New IEDs are complex and have variety of settings and functions. To be able to utilize them, protection engineer needs to very well understand their application features and performance properties.

The use of different digital simulators can help in the process of testing and evaluating the IEDs and making more informed decisions about the use of various features and selection of related settings.

Integrating multifunctional IEDs in one substation automation system can offer variety of benefits. To make sure the benefits are fully explored, engineer needs to think of new functions that can add the value to substation automation solutions.

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2.1 Metering and monitoring relay

ABB has a product, CM-ESS that can meter and monitor over or under voltage in single or multi-phase AC or DC system.

Multi-functional voltage metering and monitoring relay uses a multiplexer that has high speed synchronous communications, bit error correction, data management, and alarms with diagnostic at the same time.

CM-ESS.MS Voltage monitoring relay
Figure 9 – The CM-ESS.MS is a multifunctional voltage monitoring relay from the CM single-phase monitors range. This monitoring relay operates with a rated control supply voltage of 24 – 240 V AC / DC and has a 2 c/o (SPDT) output with contacts rated at 250 V / 4 A. It provides a RMS measuring principle for DC and AC voltages with 4 measuring ranges: 3-30 V, 6-60 V, 30-300 V and 60-600 V.

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2.2 Control house safety function relay

SIEMENS’ Multi-Functional Safety Relay (Sirius 3TK2845 multi-function device) combines multiple functions of individual safety relays in a single device.

Combination of individual safety function relays dealing with the room, appliance, labor and security monitoring is a unique control house safety monitoring multi-functional relay.

The arrangement of the functions in the diverse variants ensures that the most common applications can be realized with minimum engineering and cost expenditures.

Siemens Sirius 3TK2845 Multi-Function Device
Figure 10 – Siemens Sirius 3TK2845 Multi-Function Device. Where previously up to four individual devices had to be applied for a safety application, it can now be realized with a single multi-function device, because the devices combine multiple functions in a single enclosure.

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2.3 Transmission line protection relay

Combination of different protection and protection-related functions such as line protection, auto reclosing, fault location, circuit breaker monitoring can be combined in one product.

Examples of such products are Siemens 7SD600 relay which is a numerical current differential protection relay for distribution, as well as SIPROTEC 5 7SA522 for transmission, and GE F-60 for feeder protection.

Figure 11 – SIPROTEC 7SA522 Distance Protection Relay (SIPROTEC 7SA522 relay provides full-scheme distance protection and incorporates all functions usually required for the protection of a power line.)

SIPROTEC 7SA522 is designed to provide fast and selective fault clearance on transmission and sub-transmission cables and overhead lines with or without series capacitor compensation. The power system star point can be solid or resistance grounded (earthed), resonant-earthed via Peterson coil or isolated.

The SIPROTEC 7SA522 is suitable for single-pole and three-pole tripping applications with and without tele (pilot) protection schemes.

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2.4 Transformer protection

High-speed, three-phase, multiple winding transformer protection system, like GE Multilin SR745 which is a three-phase, multiple winding, transformer relay intended for the primary protection and management of small, medium and large power transformers includes a full featured set of protection, I/O, data logging, and communications capabilities.

GE Multilin SR745 - High-speed, three-phase, multiple winding transformer protection management relay
Figure 12 – GE Multilin SR745 – High-speed, three-phase, multiple winding transformer protection management relay

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2.5 Bus protection

Comprehensive and scalable bus and breaker failure protection for LV, HV or EHV Busbars, like GE B90, features integrated protection and breaker failure for reconfigurable LV, HV or EHV multi-section busbars with up to 24 feeders.

One can use one or more B90s together to build a sophisticated protection system that can be engineered to meet the specific application requirements. The B90 performs fast and secures low impedance bus protection with sub-cycle tripping time averaging 0.75 cycles.

The MultilinTM B90 bus differential system provides fast and secure low impedance bus protection for reconfigurable LV to EHV busbars.
Figure 13 – The MultilinTM B90 bus differential system provides fast and secure low impedance bus protection for reconfigurable LV to EHV busbars.

Use one B90 to protect up to 8 feeders and use three or more B90s together in a centralized phase-segregated architecture to protect up to 24 feeders. Many busbar applications, such as single, double, triple, breaker-and-a-half, with or without transfer bus, can be protected using the B90.

The B90 is ideally suited for applications where high impedance schemes are typically used.

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2.6 Fault recorder

Multi-functional fault recorder can integrate many functions associated with fault recording. Such products, like the GE REASON RPV-311, are a device for the acquisition, monitoring and recording of electrical quantities in applications demanding a high level of performance and flexibility.

The RPV311 is a multifunction processing unit and has an acquisition system with 16-bit A/D D converters that provide an acquisition rate of 256 points-per-cycle synchronized by the IRIG-B signal.

GE Fault recorder REASON RPV-311
Figure 14 – GE Fault recorder REASON RPV-311

It has a high processing capability, which allows the acquisition of up to 64 analog channels and 256 digital channels divided in up to 8 acquisition modules connected by fiber-optic links. Additionally, it is able to detect IEC 61850 GOOSE messages. It allows communication through the electrical Ethernet ports and optionally has a double internal converter for optical Ethernet interfaces.

Monitoring and configuration are performed through a web interface; also, it has a human-machine interface on the front panel for displaying information. It has a MODBUS and DNP3 interface for SCADA integration.

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3. Fiber optic cables

In a large substation, the cable length is around 200000 feet (17000 feet 12/C cable). The weight of copper wiring is pretty high, and sometimes creates interference problems.

In some old substations, they have been damaged substantially by rodents. The electrical substation environment has many environmental challenges to reliable and secure communications. These challenges involve high voltages, extreme temperatures, high-current faults, electromagnetic interfaces, and electrostatic discharges.

To overcome these challenges and to have a reliable, safe, secure and economical communications, the best option for upgrading the substations is to use fiber optic cables to interconnect all monitoring, control and protection parts.

Also, no external power is required for fiber optic transceivers which are designed to work in the harsh substation environment. The reliability, performance and weight of this wiring material can affect the entire performance of the substation.

The other advantages of this technology are higher speed, longer distance of transmitting information, greater immunity to electromagnetic interferences and lower cost. Both technical and cost considerations have to be taken into account in the decision to replace the damaged copper cables with fiber-optic cables.

Installation of fiber optic cables in HV substation
Figure 15 –  Installation of fiber optic cables in HV substation

Installation of fiber optic is pretty difficult and it requires expert human resources. Also, fiber is sensitive to twist. These shortcomings should be considered when evaluating the retrofit options. The fiber optic installation is shown in Figure 15.

From Figure 16, it may be seen that the primary equipment sensors are wired over copper cables to A/D converter block and the output digital signals are multiplexed together.

Hence, each primary equipment and associated sensors use only one fiber-optic cable to transmit measurements to the control house. This saves considerable amount of wiring as the distance of primary apparatus to control house is around 1000 feet.

Multiplexing fiber optics together
Figure 16 – Multiplexing fiber optics together

In summary the fiber-optic design reduces the wiring need to less than half, and the cost of the fiber-optic is less than copper wires for the same use and application.

The additional hardware requirements for the use of fiber-optic cable are about a few thousand dollars. By comparison the prices, considerable amount of money will be saved, and it can be easily concluded that the replacing the old wiring with fiber optic cable is economical.

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4. Wireless communication

Wireless communication is another option for data transfer from substation switchyard to control house which does not require wire installation in the switchyard.

This solution is easy to install and provides compact low cost solution. Data transfer speed is not critical because data are not used in real-time control applications.

Considering recordings size and number of units in the switchyard data rate of 115 or 256 kbps should enable relatively fast data transfer. Using suggested data rate data transfer from one unit will last few seconds, which meets requirements even for relatively fast applications such as alarm processor.

There are several technologies, which can be used for this purpose:

  • Frequency Hopping Spread Spectrum (FHSS),
  • ZigBee,
  • WI MAX,
  • wireless LAN
  • etc.

Some of them are more suitable for harsh environment and short distances. Figure 17 illustrates the simple concept of wireless communication between switchyard and control house.

Wireless communication
Figure 17 – Wireless communication

In addition, several configurations could be used for this network: Multipoint and Mesh configuration, Figure 18 shows a few most suitable options for circuit breaker monitoring communication.

Because of high level of Electromagnetic Interference (EMI) in substations, output power of transmitters should be higher than power required for normal outdoor application. Transmitter’s Equivalent Isotropically Radiated Power (EIRP) in multipoint network configuration should be around 60mW (18dBm) for 2.4GHz frequency range.

In some countries maximum allowed power is limited to 10dBm or 12dBm so gain antennas and repeaters could be used to enable longer distance communication.

Mesh network configuration requires larger number of low power transmitter, which makes it very reliable because of multiple transfer paths through the network.

Mesh network transmitters are relatively cheap and easy to use which makes them good solution especially for circuit breaker monitoring purposes.

Network should also have error detection and error handling mechanism. Encryption should be considered as an options but it should not overburden microprocessor of the field unit. Sometimes encryption algorithms are even implemented in wireless transceivers so that could be easily used.

Multipoint and Mesh network configuration
Figure 18 – Multipoint and Mesh network configuration

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Benefits of retrofit design

The benefits of retrofit of the existing substations can be summarized as follows:

  1. Cost reductions in operation, maintenance and service
  2. Prolonged equipment service life
  3. Higher productivity and availability of assets.
  4. Improving reliability, entire performance and efficiency
  5. Improved maintainability
  6. Lower installation time
  7. Enhanced communications
  8. Better utilization of data
  9. New functionality
  10. Increased cost efficiency, performance and availability of the system

The prominent advantages of replacing the original copper-wired analog sensors by optical fiber-based sensors for monitoring and metering can be listed as follows:

  1. High accuracy
  2. Higher performance
  3. No saturation
  4. Low maintenance
  5. Reduced size and weight, switchgear integration and potential substation size reduction
  6. Safety, no risk of explosion
  7. Environmental friendly (avoid oil or SF6)
  8. Wide dynamic range and high bandwidth
Using fiber-optics in the proposed retrofit strategy minimizes the wiring requirement due to the multiplexing of multiple signals on one fiber-optic cable. This can save considerable amount of wiring.

Wireless communication between substation switchyard and control house is easy to install and provides compact low cost solution.

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Reference // The 21st Century Substation Design by Power Systems Engineering Research Center

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author-pic

Edvard Csanyi

Electrical engineer, programmer and founder of EEP. Highly specialized for design of LV/MV switchgears and LV high power busbar trunking (<6300A) in power substations, commercial buildings and industry fascilities. Professional in AutoCAD programming. Present on

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