Abstract
The operation and the development of power system networks introduce new types of stability problems. The effect of the power generation and consumption on the frequency of the power system can be described as a demand/generation imbalance resulting from a sudden increase/decrease in the demand and/or generation. This paper investigates the impact of a loss of generation on the transient behaviour of the power grid frequency. A simplified power system model is proposed to examine the impact of change of the main generation system parameters (system inertia, governor droop setting, load damping constant, and the high-pressure steam turbine power fraction), on the primary frequency response in responding to the disturbance of a 1.32 GW generation loss on the UK power grid. Various rates of primary frequency responses are simulated via adjusting system parameters of the synchronous generators to enable the controlled generators providing a fast-reliable primary frequency response within 10 s after a loss of generation. It is concluded that a generation system inertia and a governor droop setting are the most dominant parameters that effect the system frequency response after a loss of generation. Therefore, for different levels of generation loss, the recovery rate will be dependent on the changes of the governor droop setting values. The proposed model offers a fundamental basis for a further investigation to be carried on how a power system will react during a secondary frequency response.
Highlights
The operation and the development of power system networks introduce new types of stability problems [1,2,3]
The impact of change of the main generation system parameters, systems inertia Heq, governor droop setting Req, load damping constant D, and the high-pressure steam turbine power fraction (T1/T2), are adapted to simulate the primary frequency response of the simplified power system model in order to examine and analyse how each of these parameter individually affects primary frequency system response in responding to the disturbance of a 1.32 GW generation loss on the UK power grid which occurs after 5 s from starting the simulation process
The system inertia has no overall impact on the final steady state value of frequency, where all the response curves stabilise at 49.9 Hz
Summary
The operation and the development of power system networks introduce new types of stability problems [1,2,3]. Qazi and Flynn [4] investigated and analysed the implications of large-scale decentralised DSR resource seasonal variations on system operation and system recovery post a loss of large infeed/load They addressed how the DSR controller hardware characteristics influence the provision and effectiveness of reserve delivery. Albayati et al [23] investigated the impact of responding to the secondary static demand side response events, on the supply power profile and energy efficiency of the widely distributed aggregated commercial refrigeration systems. A simplified power grid model that tests and simulates the effect of model parameters on the frequency response will be developed to examine the effect of four operational parameters of the generation systems (system inertia, governor droop setting, load damping constant, and the high-pressure steam turbine power fraction) in controlling and stabilising the systems frequency post responding to the primary frequency response. One potential approach would be to regulate the generator speed which can control the power system frequency by incorporating a governor that controls the turbine speed via the turbine gate of the generator, essentially highlighting the effect of the operational parameters of the generation systems in controlling and stabilising the systems frequency post responding to the primary frequency response
Sign-in/Register to view highlights & summary Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a callDisclaimer: All third-party content on this website/platform is and will remain the property of their respective owners and is provided on "as is" basis without any warranties, express or implied. Use of third-party content does not indicate any affiliation, sponsorship with or endorsement by them. Any references to third-party content is to identify the corresponding services and shall be considered fair use under The CopyrightLaw.
