Explore the vast range of titles available.

We examine whether the unbundling of generation from transmission and distribution services at state-owned power plants in India improved operating efficiency at these power plants. Between 1995 and 2009, 85 percent of coal-based generation capacity owned by state governments was unbundled from vertically integrated State Electricity Boards into state generating companies. We find that generating units in states that unbundled before the Electricity Act of 2003 experienced reductions in forced outages of about 25% and improvements in availability of about 10%, with the largest results occurring 3–5 years after unbundling. We find no evidene of improvements in thermal efficiency at state-owned power plants due to unbundling.

The Middle East and North Africa's (MENA) resource-rich economies are pursuing two parallel strategies in their electricity sectors: (i) increasing and integrating renewables into their power generation mix to mitigate the impact of rising domestic oil and gas demand on their economies and boost hydrocarbon export capacities; and (ii) undertaking power sector reforms to attract investment in generation capacity and networks, remove subsidies, and improve operational efficiency. These goals imply that the design of reforms (including regulations governing wholesale and retail markets and networks) needs to be carried out with a view to a rising share of non-dispatchable resources. The lack of an integrated approach to simultaneously address these two strategies is likely to lead to several misalignments between renewables and various components of future electricity markets, as the share of intermittent resources increases in the generation mix. The key challenge is that the 'ultimate model' capable of reconciling these two goals is as yet unknown, and is still evolving, due to uncertainties around the development of technologies, institutions, and consumer preferences. We argue that resource-rich MENA countries can, however, move towards adopting a transition model of electricity markets, the individual elements of which can be adapted to suit either centralized or decentralized future electricity sector outcomes. We outline the key components of this model for the wholesale market, retail market, and network regulation, considering governments' objectives and the specific contexts of the countries in the region.

The aim of the article is to systematize the main problems of the development of the domestic electricity sector and compare the ways of solving them in Ukraine with the practice of EU countries. In particular, to identify the problems that under domestic conditions are being tackled not effectively enough, or the mechanism for solving which is not created at all. The systematization of the problems, the addressing of which is a prerequisite for the efficient functioning of Ukraine’s electricity sector, made it possible to divide them into general ones, which arise due to the specificity of electricity as a commodity, and those specific to the Ukrainian conditions. The general problems in Ukraine as a whole are being solved with consideration for the experience of EU countries, although the tackling of some of them is still at the initial stage. In particular, for the introduction of the European experience in the field of the functioning of the Electricity Exchange, at this stage a basic law has been adopted, the implementation of which is still ahead. The comparison of the domestic and European practice of solving the problems of the electricity sector shows the gradual adoption by Ukraine of the positive European experience in tackling a group of general problems, however, mechanisms to overcome the specific for domestic conditions problems have not been created yet. First of all, this concerns the issue of restoration and expansion of the electricity generation capacities, which are on the verge of exploitation.

Marginal emissions of CO₂ from the electricity sector are critical for evaluating climate policies that rely on shifts in electricity demand or supply. This paper provides estimates of marginal CO₂ emissions from US electricity generation using the most recently available and comprehensive data. The estimates vary by region, hour of the day, and year to year over the last decade. We identify an important and somewhat counterintuitive finding: While average emissions have decreased substantially over the last decade (28% nationally), marginal emissions have increased (7% nationally). We show that underlying these trends is primarily a shift toward greater reliance on coal to satisfy marginal electricity use. We apply our estimates to an analysis of the Biden administration’s target of having electric vehicles (EVs) make up 50% of new vehicle purchases by 2030. We find that, without significant and concurrent changes to the electricity sector, the increase in electricity emissions is likely to offset more than half of the emission reductions from having fewer gasoline-powered vehicles on the road. Moreover, using average rather than marginal emissions to predict the impacts significantly overestimates the emission benefits. Overall, we find that the promise of EVs for reducing emissions depends, to a large degree, on complementary policies that decarbonize both average and marginal emissions in the electricity sector.

Growth remained strong in the region in 2012, with regional GDP rates increasing in most countries (excluding Nigeria and South Africa). Projections point to a moderate, broad-based acceleration in growth to around 5½ percent in 2013¬14, reflecting a gradually strengthening global economy and robust domestic demand. Investment in export-oriented sectors remains an important economic driver, and an agriculture rebound in drought-affected areas will also help growth. Uncertainties in the global economy are the main risk to the region's outlook, but plausible adverse shocks would likely not have a large effect on the region's overall performance.

Electric power sectors around the world have changed dramatically in the last 25 years as a result of sector liberalization policies. Many electricity sectors are now pursuing deep decarbonization goals which will entail replacing dispatchable fossil generation primarily with intermittent renewable generation (wind and solar) over the next 20–30 years. This transition creates new challenges for both short-term wholesale market design and investment incentives consistent with achieving both decarbonization commitments and security of supply criteria. Thinking broadly about the options for institutional change from a Williamsonian perspective – thinking like Williamson – provides a useful framework for examining institutional adaptation. Hybrid markets that combine ‘competition for the market’ that relies on competitive procurement for long-term purchased power agreements with wind, solar, and storage developers, ideally in a technology neutral fashion, and ‘competition in the market’ that relies on short-term markets designed to produce efficient and reliable operations of intermittent generation and storage, is identified as a promising direction for institutional adaptation. Many auction, contract, and market integration issues remain to be resolved.

This paper documents the changing trends in US carbon emissions and discusses the main factors that contributed to the historical carbon emissions rollercoaster. We divide the discussion into four periods: up to 1920, 1920–1960, 1960–2005 and after 2005. For each period, we discuss the main drivers of national carbon emissions. We then discuss trends in carbon emissions in the electricity sector. Electricity sector emissions were initially very small, but would become the largest source of US carbon emissions over the period 1980–2015, and the largest contributor to decarbonization since 2007. In the last section, we offer some lessons for what developing economies might learn from the US experience.

The ground-breaking research on the electricity sector and its effects on energy efficiency (EE) in advanced and emerging economies are crucial in developing a futuristic pathway, leading to self-sustainable energy use. Therefore, this research investigates the functions of sustainable investments to ensure EE in advanced and emerging economies in a decade, ranging from 2008 to 2018, by applying the data envelopment analysis (DEA) method. The findings reveal a lower degree of EE in advanced and emerging economies (0.44), discovering only seven nations, saving energy with DEA and the West Asia and North Africa groups as the top energy savers. Moreover, the mean EE ratio of the advanced and emerging countries plummeted, dating back to 2013, whereas financial investment positively impacts EE. Similarly, the study perceives how open structures in the nations' economic systems can advance ecological conditions by reducing pollution levels and graft enable EE and reduce pollution levels. Simultaneously, natural resources and technological advancements can accelerate the course of EE and ecological dimensions. Therefore, analysis of causality reinforce the response hypotheses between EE, Environmental carbon emissions levels, financial advancements, graft control, proceeds from mineral resources, technological creativity, commerce, and localization of industries, respectively.

I examine developments in the application of performance-based regulation (PBR) to electricity distribution and transmission in the United States. Applications of comprehensive PBR to electricity distribution had been slow to diffuse in the U.S. prior to roughly 2000. PBR mechanisms are now being applied more frequently to electricity distribution, which reflects the changing structure of the electric power industry and the increasing obligations that are being placed on electric distribution companies. The new obligations are a consequence primarily of aggressive targets for decarbonizing the electricity sector in nearly half the states and the goal of using “clean” electricity to electrify transportation, buildings, and other sectors. PBR should be viewed as a set of “building blocks” that can be adopted in various combinations and should recognize that PBR and traditional cost-of-service regulation (COSR) are properly viewed as complements rather than substitutes. Recent reforms in the regulation of distribution companies in Great Britain—“RIIO”—have been influential in the U.S. The main reforms contained in RIIO are discussed. There has been essentially no application of PBR by the Federal Energy Regulatory Commission (FERC) to owners of transmission assets or to independent transmission operators. FERC has applied targeted incentives to encourage investment in transmission facilities and membership in independent system operator organizations. However, the regulation of transmission rates relies primarily on COSR in the form of formula rates and has poor incentive properties. Regulation of independent system operators is a challenge because they are non-profit organizations with no equity to put at risk. Reforms here are suggested.