Abstract
In this chapter, the concepts regarding frequency, as a basic parameter of power systems are described. Initially, the physical phenomenon, based on that, this parameter is affected and how it can be controlled are explained. A short historical view on frequency is then followed. It is then discussed how the players in a power system may be affected by frequency. A more detailed description of the affecting parameters on power system frequency related to the generating units (primary frequency participation, droop, dead band, practical powers, operating point, activity range, frequency ramp rate, time constants, and inertia) and loads (frequency and voltage dependency), is then given. The final sections are devoted to various frequency control strategies especially from UCTE and ENTSO-E (both for Europe) and NERC (North America) perspectives, as the most famous governing entities for two large-scale interconnected power systems.
This is a preview of subscription content, log in via an institution to check access.
Access this chapter
Tax calculation will be finalised at checkout
Purchases are for personal use only
Notes
- 1.
See Sect. 2.5.2.
- 2.
Due to reasons such as efficiency and also increase of material usage in production process of motors, generators and transmission equipment.
- 3.
Proportional to magnetic flux.
- 4.
IEC 34-1 standard.
- 5.
Under Frequency Load Shedding (UFLS).
- 6.
Any frequency increase normally leads to increase in power of the motors. This is beneficial for the power system as it can result in controlling the frequency (see Sect. 2.5.2).
- 7.
The methodologies for allocation and distribution may be economic, technical, etc.
- 8.
Although the actual slope is negative, R is usually presented as a positive value.
- 9.
Independent of frequency.
- 10.
Current value for North America, while 36 MHz was earlier used.
- 11.
For instance, a gas turbine generation power is more sensitive to the ambient conditions.
- 12.
While a single continuous acceptable range is normally defined for a thermal unit, there may be some acceptable ranges and forbidden zones for a hydro unit.
- 13.
For a 160 MW gas turbine, typical normal and fast values are 11 and 30 MW/min, respectively.
- 14.
Inertial constant (H) is usually modelled in generator.
- 15.
In this figure, it is assumed that DB = 0 Hz.
- 16.
See also [43].
- 17.
“K” is sometimes called self-regulation coefficient of the load or load damping, as once frequency is reduced, the load would also be reduced, thereby, helping to regulate the frequency.
- 18.
Union for the Coordination of the Transmission of Electricity (UCTE).
- 19.
European Network of Transmission System Operators for Electricity (ENTSO-E).
- 20.
The abbreviation is the same as the frequency ramp rate, which may be misleading.
- 21.
Great Britain.
- 22.
Ireland.
- 23.
North American Electric Reliability Corporation (NERC).
- 24.
Electric Power Research Institute (EPRI).
- 25.
See the references.
- 26.
Area Control Error (ACE).
Author information
Authors and Affiliations
Corresponding author
Rights and permissions
Copyright information
© 2019 The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd.
About this chapter
Cite this chapter
Seifi, H., Delkhosh, H. (2019). Fundamentals of Frequency Control. In: Model Validation for Power System Frequency Analysis. SpringerBriefs in Energy. Springer, Singapore. https://doi.org/10.1007/978-981-13-2980-7_2
Download citation
DOI: https://doi.org/10.1007/978-981-13-2980-7_2
Published:
Publisher Name: Springer, Singapore
Print ISBN: 978-981-13-2979-1
Online ISBN: 978-981-13-2980-7
eBook Packages: EnergyEnergy (R0)