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In the future, electric power distribution utilities will need to plan, operate and innovate in a variety of new ways to contend with the changing nature of electricity system resources and opportunities. A distributed energy future leads to changing paradigms, changing needs in planning and innovation by distribution utilities, and changing regulatory directions. The changing paradigm encompasses two-way power flows, local integration and balancing, functional control of distributed resources, the changing nature of the boundary between transmission and distribution systems, the changing nature of resources and customers, and new business models. Changing needs in planning and innovation include handling two-way reversible power flows; interconnecting storage and electric vehicles; controlling flexible-demand resources; distribution system monitoring, analysis and modeling; renewable energy output forecasting; smart inverters; and data networks, analysis, and storage. Examples of changing regulatory directions are seen in New York, California, and Australia.

Regulators worldwide are aiming to increase system flexibility by leveraging the untapped potential of demand response. In this article we review and compare the literature on current practice and thinking about the role of demand response in three distinctly different markets that represent leading global examples of demand response: two regional electricity markets in the United States (PJM and ERCOT) and the national market in Germany. Furthermore, we describe the share of demand response in each market segment and the corresponding market design. We found, firstly, that interruptible loads and emergency generators (demand response) are used as a contingency reserve only, for no more than 30 h per year. Secondly, the share of demand response is about 4 % of the unforced capacity requirement (including emergency generators). Thirdly, the discussion of demand response also shows that there is a lot of uncertainty on how an appropriate level playing field between flexible resources should look in detail. Nevertheless, regulators are aiming to further enhance the reliability and competiveness of demand response programmes.

Purpose of Review Rapid economic development accompanied by urbanization, motorization, and industrialization, together with population growth, puts great pressure on the power sector in Southeast Asia (SEA) to meet energy demand. This paper reviews the past 20-year power generation in SEA countries to analyze potential impacts on atmospheric pollution using DPSIR framework. Recent Findings In 2020, total region electricity generation reached 1050 TWh, 3.1 times above that of 2000, and is projected to further increase by 2.5 times in 2050. During the period, the annual per capita generation increased 2.4 times. Indonesia, Malaysia, Thailand, and Vietnam were the main electricity producers, sharing 83% in 2020. Coal and natural gas based thermal power plants (TPPs) were dominant with 72% of the total electricity produced, whereas low-carbon renewable energy, although increased during the period, shared only 25% in 2020. In 2018, the sectoral atmospheric emissions of different species increased by 2.4–11.5 times above 2000, contributing 55.3%, 26.8%, and 26.7% to the region’s total anthropogenic emissions of SO 2 , CO 2 , and NO x , respectively. Summary Heavy reliance on fossil fuels makes the power sector a key emission source of air pollutants and greenhouse gases. SEA governments have promulgated policies and regulations for TPPs and set net zero emissions targets. These policies, directly and/or indirectly address atmospheric pollution, once fully implemented, bring in more secure and sustainable power sources in the region, along with multiple benefits to air quality, human health, environment, ecosystem, and the climate.

In this paper, we analyze the level of efficiency in the use of electricity in the European residential sector relying on a cross-sectional data set comprised of 1375 households located in Italy, the Netherlands, and Switzerland and observed in 2016. To do this, we estimate an electricity demand frontier function using a stochastic frontier approach. The empirical results show that the residential sector in these three European countries could save approximately 20% of its total electricity consumption on average if it improves the level of efficiency in the use of electricity. These figures are in line with recent studies for Switzerland and for the US residential sector. Moreover, we link energy efficiency to energy-related financial literacy. We find that while energy-relevant knowledge per se does not play a significant role, stronger cognitive abilities are associated with higher levels of energy efficiency.

Purpose of Review This article reviews trends for micro-grid tariffs in Sub-Saharan Africa from two perspectives: guidelines for setting tariffs and methods for structuring tariffs. Different approaches are briefly described, and general benefits and drawbacks presented based on recent experiences and available literature. Recent Findings The pace of micro-grid deployment has suffered from a lack of private sector investment, which is often inhibited by unfavorable policies and uncertainty around tariffs. Traditional utility tariffs are too low to allow micro-grid investors to recover their full costs, but a variety of new approaches can be applied to address these challenges. Summary Broad consensus suggests that cost-reflective tariffs are a critical enabler for micro-grid scale-up. Such tariffs can be coupled with subsidies or with hybridized approaches as well as unique new methods of tapping alternative revenue streams to maintain affordability for low-income customers and financial sustainability for micro-grids. There is no one-size-fits-all approach so long as lifetime costs can be recouped.