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When the power generator faces uncertain and independent electricity spot price and renewable energy source supply, two different conditions need to be considered: the distributions of renewable energy source electricity and electricity spot price are independent or dependent. The purpose of this paper is to explore the capacity investment strategy under volatile electricity spot price when renewable energy penetration rate is low, taking into account these two conditions.

The authors design a capacity investment model under dual uncertainties and consider how to optimize the investment capacity in order to maximize profit under two different conditions.

The authors find that when renewable energy supply fluctuation is unrelated to spot electricity price fluctuation, the renewable energy power profitability is determined by the average cost of spot electricity price and equivalent cost. When renewable energy supply fluctuation is related to spot electricity price fluctuation, the renewable energy power profitability is determined by the market value and the construction and maintenance cost.

Faced with the conflict of the renewable energy supply, the authors need to understand how to plan the generation capacity with intermittent renewable sources. The result helps renewable energy become competitive in the electricity market under loose regulations.

The authors compare two capacity investment strategies that the renewable energy supply fluctuation is related and unrelated to spot electricity price.

This paper studies the efficiency of Indian coal-fired thermal power plants (CTPPs) in by-production of electricity and particulates also known as Suspended Particulate Matter (SPM).

A non-radial directional distance function is optimized using data envelopment analysis to enumerate the overall inefficiency of CTPPs and its components in recent times. Further, second-stage regression analysis is conducted to identify factors that affect the inefficiency of plants.

The low inefficiency score for electricity generation suggests that most CTPPs operate close to the good output frontier. A high degree of emissions inefficiency is a challenge for Indian CTPPs. Ever-rising coal use inefficiency is a hindrance to control SPM emissions. The second stage regression analysis concludes that factors like ownership and capacity utilization play vital roles in determining a plant’s inefficiency level. Privately owned CTPPs have performed better in terms of technical inefficiency and emission inefficiency than plants owned by Central and State governments.

To the best of the authors’ knowledge, this study is one of the few published works that benchmark the productive and environmental performance of Indian CTPPs.

The purpose of this paper is to understand the issues related to the deployment of renewable electricity technologies (RETs) in remote indigenous communities by examining the views of key informants in a remote northern Ontario community through the lens of a wicked problem approach, with the goal to identify policy direction and strategies for the further development of renewable electricity projects.

The paper uses semi-structured interviews with community key informants, informed discussions with community members and energy conference participants and literature reviews of academic, policy and utility documents as complementary data sources for triangulation of results.

According to informants, the complexity surrounding the deployment of RETs in remote Canadian indigenous communities is the result of different stakeholder perspectives on the issues that RETs are expected to address. Furthermore, institutional complexity of the electricity generation system and uncertainty over both the choice of off-grid renewable technology and the future of electricity generation systems structure and governance add to this complexity.

Given the governments’ legal obligation to consult with indigenous people for projects within their territories, community perspectives provide insights for policy design to support both the deployment of RETs and address indigenous communities sustainability goals.

This paper offers views and opinions of community members from an off-grid Canadian indigenous community. Community members describe how they envision their electricity systems and the desired contribution of community owned renewable electricity generation to increase local control and economic development.

The electric power industry has been moving from a regulated monopoly structure to a deregulated market structure in many countries. The purpose of this study is to comprehensively review the existing markets to study advantages, issues involved and lessons learnt to benefit emerging electricity markets.

The paper employs a comprehensive review of existing competitive electricity market models in USA (California), UK, Australia, Nordic Countries (Norway), and developing country (Chile) to analyze the similarities, differences, weaknesses, and strengths among these markets based on publically available data, literature review and information.

Ongoing or forthcoming electricity sector restructuring activities in some countries can be better designed based on lessons learnt from existing markets and incorporating their own political, technical and economical contexts. A template for design of successful electricity market has also been presented.

This study is limited to a comparative analysis of five markets and can be extended in the future for other existing and emerging electricity markets.

The discussed weaknesses and strengths of existing electricity markets in this study can be practically utilized to improve the electricity industry market structures leading to several social benefits including lower electricity cost.

The comprehensive review and analysis of five existing markets, physically located in different continents, may be used as an assistance or reference guide to benefit the emerging electricity markets in other countries.

This study aims to assess volatility spillovers and directional connectedness between electricity (EPs) and natural gas prices (GPs) in the Canadian electricity market, based on a hydrothermal power generation market strongly dependent on exogenous variables such as fossil fuel prices and climatology factors.

The methodology is divided into two stages. First, a quantile vector autoregression model is used to evaluate the direction and magnitude of the influence between natural gas and electricity prices through different quantiles of their distributions. Second, a cross-quantilogram is estimated to measure the directional predictability between these prices. The data set consists of daily electricity and natural gas prices between January 2015 and December 2023.

The main finding shows that electricity prices are pure shock receivers of volatility from natural gas prices for the different quantiles. In this way, natural gas price fluctuations explain 0.20%, 0.98% and 22.72% of electricity price volatility for the 10th, 50th and 90th quantiles, respectively. On the other hand, a significant and positive correlation is observed in the high quantiles of the electricity prices for any natural gas price value.

The study described the risk to the electricity market caused by nonrenewable source price fluctuations and provided evidence for designing regulatory policies to reduce its exposure in Alberta, Canada. It also allows us to understand the importance of natural gas in the energy transition process and define it as the fundamental determinant of the electricity market dynamic.

The purpose of this paper is to examine how active consumers, i.e. consumers that can inter-temporally shift their load, can influence electricity prices. As demonstrated in this paper, inter-temporal load shifting can induce negative electricity prices, a recurring phenomenon on power exchanges.

The paper presents a novel electricity-market model assuming a nodal-pricing, energy-only spot market with active consumers. This study formulates an economic equilibrium problem as a linear program and uses an established six-node case study to compare equilibrium prices of a model with inflexible demand to a model with flexible demand of active consumers.

This study illustrates that temporal coupling of hourly market clearing through load shifting of active consumers can cause negative electricity prices that are not observed in a model with ceteris paribus inflexible demand. In such situations, where compared to the case of inflexible demand more flexibility is available in the system, negative electricity prices signal lower total system costs. These negative prices result from the use of demand flexibility, which, however, cannot be fully exploited due to limited transmission capacities, respectively, loop-flow restrictions.

Literature indicates that negative electricity prices result from lacking flexibility. The results illustrate that active consumers and their additional flexibility can lead to negative electricity prices in temporally coupled markets, which in general contributes to increased system efficiency as well as increased use of renewable energy sources. These findings extend existing research in both the area of energy flexibility and causes for negative electricity prices. Therefore, policymakers should be aware of such (temporal coupling) effects and, e.g. continue to allow negative electricity prices in the future that can serve as investment signals for active consumers.

In the hybrid electricity market consisting of renewable and conventional energy, the generation output of renewable power is uncertain because of its intermittency, and the power market demand is also fluctuant. Meanwhile, there is fierce competition among power producers in the power supply market and retailers in the demand market after deregulation, which increases the difficulty of renewable energy power grid-connection. To promote grid-connection of renewable energy power in the hybrid electricity market, the authors construct different contract decision-making models in the “many-to-many” hybrid power supply chain to explore the pricing strategy of renewable energy power grid-connecting.

Considering the dual-uncertainty of renewable energy power output and electricity market demand, the authors construct different decision-making models of wholesale price contract and revenue-sharing contract to compare and optimize grid-connecting pricing, respectively, to maximize the profits of different participants in the hybrid power supply chain. Besides, the authors set different parameters in the models to explore the influence of competition intensity, government subsidies, etc. on power pricing. Then, a numerical simulation is carried out, they verify the existence of the equilibrium solutions satisfying the supply chain coordination, compare the differences of pricing contracts and further analyze the variation characteristics of optimal contract parameters and their interaction relations.

Revenue-sharing contract can increase the quantity of green power grid-connection and realize benefits Pareto improvement of all parties in hybrid power supply chain. The competition intensity both of power supply and demand market will have an impact on the sharing ratio, and the increase of competition intensity results in a reduction of power supply chain coordination pressure. The power contract price, spot price and selling price have all been reduced with the increase of the sharing ratio, and the price of renewable power is more sensitive to the ratio change. The sharing ratio shows a downward trend with the increase of government green power subsidies.

On the basis of expanding the definition of hybrid power market and the theory of newsvendor model, considering the dual-uncertainty of green power generation output and electricity market demand, this paper builds and compares different contract decision-making models to study the grid-connection pricing strategy of renewable energy power. And as an extension of supply chain structure types and management, the authors build a “many-to-many” power supply chain structure model and analyze the impact of competition intensity among power enterprises and the government subsidy on the power grid-connecting pricing.

Agile manufacturers depend on low cost, abundant electricity to remain competitive in the global marketplace. Self‐generation of electricity or cogeneration of electricity and thermal energy at the manufacturer’s location can provide both economical and uninterrupted service. Generation methods are standby, peak‐shaving, baseload, commercial, and mobile generation. Each of these represents opportunities in agile manufacturing. The number of countries that have deregulated, market‐driven electrical utilities are growing and will include most of Europe and the USA by 2005. The demands of agile manufacturing are to produce high‐quality, market‐sensitive products at the lowest possible cost in an environment that has constant dynamic changes. Cogeneration will provide both flexible and cost‐efficient electricity as part of an overall energy strategy. Further, it will provide an agile energy resource that will complement the pursuit of competitive advantage in the global market for customized goods and services.

The aim of this paper is to investigate how green certificates markets have developed in the European Union, with a view to producing consistent recommendations that could be used in future environmental strategies and policies to improve existing schemes for renewable energy promotion and support.

The study was conducted by combining a wide variety of sources, such as regulations, position papers, road‐maps, as well as articles and research reports. European experiences in using green certificates to support renewable energies were compared from the point‐of‐view of the legislative framework and national support systems.

The findings reveal that improvements in three major areas (legislative framework, national support systems, and cost reduction) are needed in order to achieve a better support for renewable energy generation.

The conclusions justify the effort invested in developing green certificates markets and are relevant for policy makers in a very sensitive sector to accomplish sustainability goals – the use of renewable energy. The study may represent a starting‐point for further research into renewable energy support systems, environmental issues and economic implications.

The paper provides a rational and comparative approach for finding solutions to the problems of green certificates markets in the European Union. The methodology and the results reported in this research could be used for exploring green certificates markets opportunities in other European countries.

This paper aims to explore the increasing role of financialisation on investment decisions in the power generation industry in Great Britain (GB). Such decisions affect society, and the relative role of financialisation in these macro-levels decisions has not been explored from a historical perspective.

The paper draws on historical material and interview data. Specifically, we use an approach inspired by institutional sociology drawing on elements of Scott’s (2014) pillars of institutions. Applying concepts stemming from regulative and normative pressures, we explore changes in investments over the analysis period to determine forces which institutionalised practices – such as accounting – into investment in power generation.

Investments in electricity generation have different levels of public and private participation. However, the common logics that underpin such investment practices provide an important understanding of political-economics and institutional change in the UK. Thus, the heightened use of accounting in investment has been, to some extent, a contributory factor to the power supply problems now faced by the British public.

This paper contributes to prior literature on the effects of financialisation on society, adding power generation/energy supply to the many societal level issues already explored. It also provides brief but unique insights into the changing nature of the role of accounting in an industry sector over an extended timeframe.