Research increasingly points to the need for sustainable energy solutions as the global push for carbon neutrality gains momentum. A recent study has shed light on the transient stability of AC-DC hybrid power systems, highlighting potential challenges as countries aim to integrate Distributed Generation (DG) and High-Voltage Direct Current (HVDC) technologies.
With the International Renewable Energy Agency (IRENA) forecasting over 86% of all electricity generation based on renewable sources by 2050, the demand for effective and stable power systems becomes more pressing. This study investigates how DG and HVDC systems, which are pivotal for facilitating renewable energy integration, affect frequency stability—a key component for reliable energy delivery.
The research utilized the IEEE 30-bus test feeder to assess the transient stability within various configurations of power systems. The configurations included scenarios with no installations, DG-only, HVDC-only, and combined DG and HVDC systems. Notably, the study observed stark contrasts between the effects of DG and HVDC on frequency fluctuations. The analysis revealed DG installations led to approximately 10% reductions in frequency variation, whereas HVDC systems remarkably increased fluctuations by around 90%.
These findings are particularly important as power systems evolve and integrate more renewable energy resources. The research indicated another key metric—the Maximum Fault Clearing Delay Time (MFCDT)—which serves as the threshold for frequency stability during disturbances. Systems equipped solely with DG technology demonstrated the ability to operate with about 10% longer fault clearance times, enhancing resilience compared to HVDC, which required approximately 50% faster fault clearance.
To reach these conclusions, the study employed particle swarm optimization (PSO) algorithms to define optimal capacities and precise locations for DG installations. The results pointed out specific sites on the IEEE 30-bus test feeder where photovoltaic systems could be effectively integrated, showing customized capacities across different nodes.
The study systematically categorized 16 configurations and fault types to compare transient stability outcomes rigorously. These tests demonstrated how each system reacted under varied disturbances, yielding valuable insights for enhancing the stability of modern power grids.
While DG contributed positively to frequency stability, the integration of HVDC presented challenges. The study established cautious recommendations for the design and operation of HVDC systems, emphasizing their potential adverse effects on power system stability. The results advocate for improved control methodologies and careful placement of HVDC systems to balance the benefits of DC transmission with the inherent challenges posed to frequency stability.
Overall, this investigation is pivotal for equipping future power systems with the resilience necessary to support growing renewable energy integration. Policymakers and engineers must heed these findings to curb instability risks, paving the way for reliable and efficient energy systems.