• Energy Research

Abstract Gradual technical advancement and rapidly decreasing costs have led to widespread deployment of solar photovoltaic (PV) systems. In Australia, distributed PV systems make up the vast majority of installed PV capacity. In remote communities, distributed PV systems offer a supplementary solution to existing diesel-based electricity generation. However, remote electricity networks, being different from urban networks primarily due to their limited generation capacity and spinning reserve are likely to be critically affected by the variability characteristics of PV generation. The integration of distributed PV systems into conventional remote electricity networks has noteworthy impacts on their technical and non-technical operations that pose new challenges for PV deployment. Significant technical issues are observed in these networks as PV penetration levels increase, such as reduced power quality, inadequate diesel generator dispatch for spinning reserve, increased complexities in network operation and management, unintended islanding and even system blackouts. Utility adopted operational and control strategies significantly influence PV penetration levels in different remote networks around the world, including Australia. This paper reviews the current electrification scenarios in remote Australian networks and focuses on the impacts and technical challenges of distributed PV deployment and the control strategies adopted by remote area power utilities. Some suggestions and recommendations, such as the development of robust control mechanisms incorporating PV forecasting technology, modern network equipment, real-time measurements and network ancillary services provided by inverter coupled generation systems to enhance networks' operational stability and reliability are also presented. This review is of benefit to scientific researchers, investors and different stakeholders, who wish to have a better understanding of distributed PV systems' deployment scenarios into remote electricity networks. As the inherent characteristics of Australian remote electricity networks are similar to those in African and Asian rural electricity networks; the findings, reviews and recommendations presented are also relevant to those networks.

Abstract Gradual technical advancement and rapidly decreasing costs have led to widespread deployment of solar photovoltaic (PV) systems. In Australia, distributed PV systems make up the vast majority of installed PV capacity. In remote communities, distributed PV systems offer a supplementary solution to existing diesel-based electricity generation. However, remote electricity networks, being different from urban networks primarily due to their limited generation capacity and spinning reserve are likely to be critically affected by the variability characteristics of PV generation. The integration of distributed PV systems into conventional remote electricity networks has noteworthy impacts on their technical and non-technical operations that pose new challenges for PV deployment. Significant technical issues are observed in these networks as PV penetration levels increase, such as reduced power quality, inadequate diesel generator dispatch for spinning reserve, increased complexities in network operation and management, unintended islanding and even system blackouts. Utility adopted operational and control strategies significantly influence PV penetration levels in different remote networks around the world, including Australia. This paper reviews the current electrification scenarios in remote Australian networks and focuses on the impacts and technical challenges of distributed PV deployment and the control strategies adopted by remote area power utilities. Some suggestions and recommendations, such as the development of robust control mechanisms incorporating PV forecasting technology, modern network equipment, real-time measurements and network ancillary services provided by inverter coupled generation systems to enhance networks' operational stability and reliability are also presented. This review is of benefit to scientific researchers, investors and different stakeholders, who wish to have a better understanding of distributed PV systems' deployment scenarios into remote electricity networks. As the inherent characteristics of Australian remote electricity networks are similar to those in African and Asian rural electricity networks; the findings, reviews and recommendations presented are also relevant to those networks.

Autonomous microgrids (MGs) are being installed in large remote areas to supply power where access to the utility grid is unavailable or infeasible. The power generation of such standalone MGs is largely dominated by renewable based energy sources where overloading or power deficiencies can be common due to the high intermittency and uncertainty in both load and power generation. Load-shedding is the most common mechanism to alleviate these problems to prevent system instability. To minimize load-shedding, most MGs are equipped with local battery energy storage (BES) systems to provide additional support. Furthermore, in the event of severe overloading or when BES capacity is insufficient to alleviate the overload, neighboring MGs can be provisionally coupled to provide mutual support to each other which is a more effective, economic and reliable approach. Such a coupling is preferred to be via power electronic converters to enhance the autonomy of the MGs. This paper proposes a two-stage, coordinated power sharing strategy among BESs and coupled MGs for overload management in autonomous MGs, through dynamic frequency control. Both local BES and the neighboring MGs can work in conjunction or individually to supply the required overload power demand. For this, BES' state of charge should be above a minimum level and extra power generation capacity needs to be available in the neighboring MGs. A predefined framework with appropriate constraints and conditions, under which the power exchange will take place, are defined and formulated. The proposed mechanism is a decentralized approach, operating based on local frequency and state of charge measurements, and without any data communication amongst the MGs. The dynamic performance of such a network, is evaluated through extensive simulation studies in PSIMR and verifies that the proposed strategy can successfully alleviate the overloading situation in the MGs through proper frequency regulation.

Autonomous microgrids (MGs) are being installed in large remote areas to supply power where access to the utility grid is unavailable or infeasible. The power generation of such standalone MGs is largely dominated by renewable based energy sources where overloading or power deficiencies can be common due to the high intermittency and uncertainty in both load and power generation. Load-shedding is the most common mechanism to alleviate these problems to prevent system instability. To minimize load-shedding, most MGs are equipped with local battery energy storage (BES) systems to provide additional support. Furthermore, in the event of severe overloading or when BES capacity is insufficient to alleviate the overload, neighboring MGs can be provisionally coupled to provide mutual support to each other which is a more effective, economic and reliable approach. Such a coupling is preferred to be via power electronic converters to enhance the autonomy of the MGs. This paper proposes a two-stage, coordinated power sharing strategy among BESs and coupled MGs for overload management in autonomous MGs, through dynamic frequency control. Both local BES and the neighboring MGs can work in conjunction or individually to supply the required overload power demand. For this, BES' state of charge should be above a minimum level and extra power generation capacity needs to be available in the neighboring MGs. A predefined framework with appropriate constraints and conditions, under which the power exchange will take place, are defined and formulated. The proposed mechanism is a decentralized approach, operating based on local frequency and state of charge measurements, and without any data communication amongst the MGs. The dynamic performance of such a network, is evaluated through extensive simulation studies in PSIMR and verifies that the proposed strategy can successfully alleviate the overloading situation in the MGs through proper frequency regulation.

The United Nations (UN) have formulated seventeen Sustainable Development Goals (SDGs) and thus, humans were trying to traverse the sustainable path. Meanwhile, the COVID-19 pandemic has emerged and forced out the ephemeral conventional approaches. Thus, the post-COVID world indicates the need for sustainable development and strategies in par with the ecosystem. The authors propose this study as a guide to direct the post-pandemic scenario into the sustainable pathway by prioritizing energy sustainability to engage the actions for achieving the SDGs. The analysis in this study commences with the investigation of pronounced impacts in the energy sector with its influence on the progress towards sustainability. To pursue the path of energy sustainability, a qualitative analysis is performed in a parallel approach from the key viewpoint of the renewable and sustainable energy transition, digital transformation of the energy sector and energy affordability in the post-COVID world. A SWOT-AHP hybrid methodology is employed to identify the significance of each strategy or issues to be focused on immediately in the post-COVID world. The study also discusses energy sustainability from political bodies and policy makers’ perspective, and the actual scenario where we are headed is revealed with the aid of process-tracing method. Furthermore, a novel quantitative analysis is established to represent the SDG’s interaction and the result shows that the SDG 7 is the underpinning goal in relative to other SDGs. In context with it, the mapping of energy sustainability to the sustainable world is accomplished. The ultimate inference from envisioning the SDGs through energy sustainability shows that a sustainable world would result after the pandemic. However, the changes in the energy market, investment preferences and more importantly, the decisions influenced by the political bodies in the post-COVID-world is decisive in achieving the same in a stipulated time frame.

The United Nations (UN) have formulated seventeen Sustainable Development Goals (SDGs) and thus, humans were trying to traverse the sustainable path. Meanwhile, the COVID-19 pandemic has emerged and forced out the ephemeral conventional approaches. Thus, the post-COVID world indicates the need for sustainable development and strategies in par with the ecosystem. The authors propose this study as a guide to direct the post-pandemic scenario into the sustainable pathway by prioritizing energy sustainability to engage the actions for achieving the SDGs. The analysis in this study commences with the investigation of pronounced impacts in the energy sector with its influence on the progress towards sustainability. To pursue the path of energy sustainability, a qualitative analysis is performed in a parallel approach from the key viewpoint of the renewable and sustainable energy transition, digital transformation of the energy sector and energy affordability in the post-COVID world. A SWOT-AHP hybrid methodology is employed to identify the significance of each strategy or issues to be focused on immediately in the post-COVID world. The study also discusses energy sustainability from political bodies and policy makers’ perspective, and the actual scenario where we are headed is revealed with the aid of process-tracing method. Furthermore, a novel quantitative analysis is established to represent the SDG’s interaction and the result shows that the SDG 7 is the underpinning goal in relative to other SDGs. In context with it, the mapping of energy sustainability to the sustainable world is accomplished. The ultimate inference from envisioning the SDGs through energy sustainability shows that a sustainable world would result after the pandemic. However, the changes in the energy market, investment preferences and more importantly, the decisions influenced by the political bodies in the post-COVID-world is decisive in achieving the same in a stipulated time frame.

Abstract One of the primary technical challenges of integrating high levels of PV generation into standalone off-grid power supply systems is their variable power output characteristics. In dealing with this issue, the integration of reliable PV forecasting techniques and preferably energy storage, are highly effective. Applying a short-term PV forecasting method, together with a compensatory controllable resource, can help in the management of system operation. This study incorporates the development of an energy flow modelling tool that has been used to analyse the benefits of 1-min ahead PV forecasting and battery storage for different system configurations. Based on the five days of 1-min ahead forecasting results analysed, it is found that PV forecasting enables the prosumer to install more than double the PV capacity, compared to the allowed installed PV capacity when no forecasting is employed. This additional PV capacity saves around 24–25% (on average) of diesel fuel per day for the diesel-PV-battery configuration. The outcomes evidently indicate that incorporating 1-min ahead PV forecasting enables a significant increase of PV hosting capacity of the system, without compromising the reliability of the system.

Abstract One of the primary technical challenges of integrating high levels of PV generation into standalone off-grid power supply systems is their variable power output characteristics. In dealing with this issue, the integration of reliable PV forecasting techniques and preferably energy storage, are highly effective. Applying a short-term PV forecasting method, together with a compensatory controllable resource, can help in the management of system operation. This study incorporates the development of an energy flow modelling tool that has been used to analyse the benefits of 1-min ahead PV forecasting and battery storage for different system configurations. Based on the five days of 1-min ahead forecasting results analysed, it is found that PV forecasting enables the prosumer to install more than double the PV capacity, compared to the allowed installed PV capacity when no forecasting is employed. This additional PV capacity saves around 24–25% (on average) of diesel fuel per day for the diesel-PV-battery configuration. The outcomes evidently indicate that incorporating 1-min ahead PV forecasting enables a significant increase of PV hosting capacity of the system, without compromising the reliability of the system.