Power system protection

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Dead-tank circuit breaker

Power system protection is a set of techniques and power grid equipment used to limit the damage caused by an electrical fault and safeguard other components of the grid, like generators and transmission lines.[1] The term is also used for a branch of electrical power engineering that deals with the protection.[2] There is an overlap between the power system protection and power system operations, as the protection equipment can be used for operations.[3]

The protection devices are used to protect the power systems from faults by detecting the faults and taking action ("tripping"). P. M. Anderson distinguishes the reactionary devices, like protective relays, that "clear" a fault by isolating it from the rest of system and safeguard devices that address the source of the hazard (for example, an emergency core cooling system of a nuclear reactor). As a discipline, power system protection mostly deals with the reactionary devices.[4]

Protection devices

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Power system protection relies on few basic elements:[5]

  • a sensor performs a measurement (test) of a value (for example, of electric current in a transmission line);
  • a comparator checks the test result against a threshold that the result is not supposed to cross during normal operation (for example, the maximum acceptable current value when testing for the overcurrent condition). Ability to identify an abnormal condition is called sensitivity;[6]
  • a timing element (delay) that checks for the persistence of the condition (for example, if a fault had been cleared by another protection device with a smaller delay setting, this device should not take any action);
  • action element (typically circuit-opening).

Protective devices include,[7] under a common label of "switchgear":[8]

Connecting the protective devices to the grid usually involves additional hardware:

With the exception of the breaker, the components of the protective device are frequently deployed in a redundant fashion.[13]

Protective zones

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Overlapping protection zones: single-line diagram depicts generators at the top connected to voltage transformers, (vertical) transmission lines and (horizontal) busbars. The switch symbols are protective relays. Zone boundaries are indicated by colored dashed lines

The objective of a protection scheme is to keep the power system stable by isolating only the components that are under fault, whilst leaving as much of the network as possible in operation, thus minimizing the loss of load.[14] This property of the protection system is called selectivity.[6] To achieve selectivity, the power system is subdivided into protective zones, each containing a power system component that should be protected. Each zone has its own protection device(s) and provides sensitivity to faults within its boundaries. The boundaries of zones overlap to leave no part of grid without protection. The overlapping regions of sensitivity have a drawback of multiple relays possibly tripping when the fault is in the overlapped area.[15] For example, unless special arrangements are made, a short circuit above the relay A, but still within the blue zone on the diagram, might cause overcurrent conditions in relays A, C, and D and cause them to trip, with the two latter trips being redundant. This can be avoided by using specialized relays (distance or directional ones) or by coordinating the relay actions using a communication channel ("pilot").

Backup

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The power protection system needs to be resilient to its own malfunctions. Thus it includes backup protection devices. For example if the fault is in the top left red zone, but outside the blue zone, it is expected to be handled by the relay A. If the relay A malfunctions and cannot clear the fault, the backup relays C and D in the adjacent (blue) zone will trip. This can be arranged without coordination (for example, the delay setting of C and D can be higher so they do not act if A succeeds in clearing the fault)[16] or through coordination via a pilot.[citation needed] The term local backup is used when the backup relays are within the same zone as the "primary" one being duplicated.[17]

Testing conditions

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A digital ("numerical") multifunction protective relay for distribution networks. A single such device can replace many single-function electromechanical relays, and provides self-testing and communication functions.

The relays can be classified by their sensitivity to the location of a fault:

  • a nondirectional relay does not provide an information on which side of it the fault is located, this is the simplest form of the overcurrent relay. For example, in a radial system of electrical power distribution, the current always flow to the load spokes, so there is not need to sense its direction, as an overcurrent condition always indicates a short circuit on the load side;[18]
  • a directional relay compares the current phase with the reference and performs action only if the direction to the fault matches the selected one;[19]
  • a differential relay compares the values of electrical measurements on the input and output of a protected device. For example, in an electrical transformer, input and output voltage and current values are related through the transformer ratio, and large deviations from this constant indicate a fault;[20]
  • a distance relay determines the distance of the fault by calculating the line electrical impedance as seen by the relay based on observe current, voltage, and the the phase difference between them. The knowledge of distance can be used to prevent tripping when the fault is in the wrong zone;[19]
  • a pilot protection relay senses the conditions on the other end of the line through a communication channel (wire pilot, carrier pilot, microwave pilot, and fiber-optic pilot).[21]

In the 21st century a lot of testing for abnormal conditions is performed by multifunctional numerical relays that use computers for calculations. Individual measurements use cryptic identifiers from the ANSI device numbers list, like "50" for the "Instantaneous Overcurrent Relay" or "87L" for the "Segregated Line Current Differential".

Historically, the power industry went through multiple generations of sensors and comparators, retaining the terminology and some of the devices:

  • Electromechanical relays are the simplest devices used for protection since the early days of electrical power industry. For example, an induction disk overcurrent relay is an overcurrent relay that uses an induction disk as a sensor and timing element;[22]

Types of protection

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High-voltage transmission network

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Protection of the transmission and distribution system serves two functions: protection of the plant and protection of the public (including employees). At a basic level, protection disconnects equipment that experiences an overload or a short to earth. Some items in substations such as transformers might require additional protection based on temperature or gas pressure, among others.

Generator sets

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In a power plant, the protective relays are intended to prevent damage to alternators or to the transformers in case of abnormal conditions of operation, due to internal failures, as well as insulating failures or regulation malfunctions. Such failures are unusual, so the protective relays have to operate very rarely. If a protective relay fails to detect a fault, the resulting damage to the alternator or to the transformer might require costly equipment repairs or replacement, as well as income loss from the inability to produce and sell energy.

Overload and back-up for distance (overcurrent)

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Overload protection requires a current transformer which simply measures the current in a circuit and compares it to the predetermined value. There are two types of overload protection: instantaneous overcurrent (IOC) and time overcurrent (TOC). Instantaneous overcurrent requires that the current exceeds a predetermined level for the circuit breaker to operate. Time overcurrent protection operates based on a current vs time curve. Based on this curve, if the measured current exceeds a given level for the preset amount of time, the circuit breaker or fuse will operate. The function of both types is explained in "Non-Directional Overcurrent Protection" on YouTube.

Earth fault/ground fault

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Earth fault protection also requires current transformers and senses an imbalance in a three-phase circuit. Normally the three phase currents are in balance, i.e. roughly equal in magnitude. If one or two phases become connected to earth via a low impedance path, their magnitudes will increase dramatically, as will current imbalance. If this imbalance exceeds a pre-determined value, a circuit breaker should operate. Restricted earth fault protection is a type of earth fault protection which looks for earth fault between two sets of current transformers[23] (hence restricted to that zone).

Distance (impedance relay)

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Distance protection detects both voltage and current. A fault on a circuit will generally create a sag in the voltage level. If the ratio of voltage to current measured at the relay terminals, which equates to an impedance, lands within a predetermined level the circuit breaker will operate. This is useful for reasonably long lines, lines longer than 10 miles, because their operating characteristics are based on the line characteristics. This means that when a fault appears on the line the impedance setting in the relay is compared to the apparent impedance of the line from the relay terminals to the fault. If the relay setting is determined to be below the apparent impedance it is determined that the fault is within the zone of protection. When the transmission line length is too short, less than 10 miles, distance protection becomes more difficult to coordinate. In these instances the best choice of protection is current differential protection.[citation needed]

Back-up

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The objective of protection is to remove only the affected portion of plant and nothing else. A circuit breaker or protection relay may fail to operate. In important systems, a failure of primary protection will usually result in the operation of back-up protection. Remote back-up protection will generally remove both the affected and unaffected items of plant to clear the fault. Local back-up protection will remove the affected items of the plant to clear the fault.

Low-voltage networks

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The low-voltage network generally relies upon fuses or low-voltage circuit breakers to remove both overload and earth faults.

Cybersecurity

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The bulk system which is a large interconnected electrical system including transmission and control system is experiencing new cybersecurity threats every day. (“Electric Grid Cybersecurity,” 2019). Most of these attacks are aiming the control systems in the grids. These control systems are connected to the internet and makes it easier for hackers to attack them. These attacks can cause damage to equipment and limit the utility professionals ability to control the system.

Coordination

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Protective device coordination is the process of determining the "best fit" timing of current interruption when abnormal electrical conditions occur. The goal is to minimize an outage to the greatest extent possible. Historically, protective device coordination was done on translucent log–log paper. Modern methods normally include detailed computer based analysis and reporting.

Protection coordination is also handled through dividing the power system into protective zones. If a fault were to occur in a given zone, necessary actions will be executed to isolate that zone from the entire system. Zone definitions account for generators, buses, transformers, transmission and distribution lines, and motors. Additionally, zones possess the following features: zones overlap, overlap regions denote circuit breakers, and all circuit breakers in a given zone with a fault will open in order to isolate the fault. Overlapped regions are created by two sets of instrument transformers and relays for each circuit breaker. They are designed for redundancy to eliminate unprotected areas; however, overlapped regions are devised to remain as small as possible such that when a fault occurs in an overlap region and the two zones which encompass the fault are isolated, the sector of the power system which is lost from service is still small despite two zones being isolated.[24]

Disturbance-monitoring equipment

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Disturbance-monitoring equipment (DME) monitors and records system data pertaining to a fault. DME accomplish three main purposes:

  • model validation,
  • disturbance investigation, and
  • assessment of system protection performance.[25]

DME devices include:[26]

  • Sequence of event recorders, which record equipment response to the event
  • Fault recorders, which record actual waveform data of the system primary voltages and currents
  • Dynamic disturbance recorders (DDRs), which record incidents that portray power system behavior during dynamic events such as low frequency (0.1 Hz – 3 Hz) oscillations and abnormal frequency or voltage excursions

Performance measures

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Protection engineers define dependability as the tendency of the protection system to operate correctly for in-zone faults. They define security as the tendency not to operate for out-of-zone faults. Both dependability and security are reliability issues. Fault tree analysis is one tool with which a protection engineer can compare the relative reliability of proposed protection schemes. Quantifying protection reliability is important for making the best decisions on improving a protection system, managing dependability versus security tradeoffs, and getting the best results for the least money. A quantitative understanding is essential in the competitive utility industry.[27][28]

  • Reliability: Devices must function consistently when fault conditions occur, regardless of possibly being idle for months or years. Without this reliability, systems may cause costly damages.
  • Selectivity: Devices must avoid unwarranted, false trips.
  • Speed: Devices must function quickly to reduce equipment damage and fault duration, with only very precise intentional time delays.
  • Sensitivity: Devices must detect even the smallest value of faults and respond.
  • Economy: Devices must provide maximum protection at minimum cost.
  • Simplicity: Devices must minimize protection circuitry and equipment.

Reliability: Dependability vs Security

There are two aspects of reliable operation of protection systems: dependability and security.[29] Dependability is the ability of the protection system to operate when called upon to remove a faulted element from the power system. Security is the ability of the protection system to restrain itself from operating during an external fault. Choosing the appropriate balance between security and dependability in designing the protection system requires engineering judgement and varies on a case-by-case basis.

See also

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Notes

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  1. ^ Bansal 2019.
  2. ^ "Knowledge and References: Power-system protection". Taylor & Francis. Retrieved 2025-06-14.
  3. ^ Khan 2013, p. 5.
  4. ^ Anderson 1998, pp. 4–6.
  5. ^ Mason 1956, p. 7.
  6. ^ a b Anderson 1998, p. 9.
  7. ^ Mason 1956, p. 43.
  8. ^ Mason 1956, p. 1250.
  9. ^ Mason 1956, p. 44.
  10. ^ Mason 1956, p. 23.
  11. ^ Mason 1956, p. 1175.
  12. ^ Mason 1956, p. 35.
  13. ^ Mason 1956, p. 1105.
  14. ^ Anderson 1998, p. 8.
  15. ^ Mason 1956, p. 5.
  16. ^ Mason 1956, pp. 9–10.
  17. ^ Mason 1956, p. 10.
  18. ^ Mason 1956, p. 56.
  19. ^ a b Mason 1956, p. 57.
  20. ^ Mason 1956, pp. 57–58.
  21. ^ Mason 1956, p. 58.
  22. ^ Mason 1956, p. 98.
  23. ^ "Restricted Earth Fault Protection". myElectrical.com. Retrieved 2 July 2013.
  24. ^ Glover J. D., Sarma M. S., Overbye T. J. (2010) Power System and Analysis 5th Edition. Cengage Learning. Pg 548-549.
  25. ^ "System Protection Manual" (PDF). New York Independent System Operator. Retrieved 2011-12-31.
  26. ^ "Glossary of Terms Used in Reliability Standards" (PDF). North American Electric Reliability Corporation. Retrieved 2011-12-31.
  27. ^ Kumm, John J.; Weber, Mark S.; Schweitzer, E. O.; Hou, Daqing (March 1995). Philosophies for Testing Protective Relays (PDF). NETA International Electrical Testing Association Technical Conference.
  28. ^ Kumm, John J.; Schweitzer, Edmund O.; Hou, Daqing (May 1995). Assessing the Effectiveness of Self-Tests and Other Monitoring Means in Protective Relays (PDF). 1995 Pennsylvania Electric Association Relay Committee Spring Meeting.
  29. ^ NERC Reliability Fundamentals of System Protection, December 2010, Sec 3 - 4.1.2.3, https://www.nerc.com/comm/PC/System%20Protection%20and%20Control%20Subcommittee%20SPCS%20DL/Protection%20System%20Reliability%20Fundamentals_Approved_20101208.pdf

References

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Sources

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