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| 1 |
ID:
115681
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2012.
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| Summary/Abstract |
We report new experimental evidence of the household response to weekday differentials in peak and off-peak electricity prices. The data come from Auckland, New Zealand, where peak residential electricity consumption occurs in winter for heating. Peak/off-peak price differentials ranged over four randomly selected groups from 1.0 to 3.5. On average, there was no response except in winter. In winter, participant households reduced electricity consumption by at least 10%, took advantage of lower off-peak prices but did not respond to the peak price differentials. Response varied with house and household size, time spent away from home, and whether water was heated with electricity.
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| 2 |
ID:
103452
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2011.
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| Summary/Abstract |
Plug-in hybrid electric vehicles (PHEVs) will soon start to be introduced into the transportation sector, thereby raising a host of issues related to their use, adoption and effects on the electricity sector. Their introduction has the potential to significantly reduce carbon emissions from the transportation sector, which has led to government policies aimed at easing their introduction. If their widespread adoption is set as a target it is imperative to consider the effects of existing policies that may increase or decrease their adoption rate. In this study, we present a micro level electricity demand model that can gauge the effects of PHEVs on household electricity consumption and the subsequent economic attractiveness of the vehicles. We show that the electricity pricing policy available to the consumer is a very significant factor in the economic competitiveness of PHEVs. Further analysis shows that the increasing tier electricity pricing system used in California will substantially blunt adoption of PHEVs in the state; and time of use electricity pricing will render PHEVs more economically attractive in any state.
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| 3 |
ID:
105814
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| Publication |
2011.
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| Summary/Abstract |
Facing growing technological and environmental challenges, the electricity industry needs effective pricing mechanism to promote efficient risk management and investment decisions. In a restructured electricity market with competitive wholesale prices and traditionally regulated retail rates, however, there are technical and institutional barriers that prevent dynamic pricing with price responsive demand. In regions with limited energy storage capacity, intermittent renewable resources present special challenges. This could adversely affect the effectiveness of public policies causing inefficient investments in energy technologies. In this paper, we present an updated economic model of pricing and investment in restructured electricity market and use the model in a simulation study for an initial assessment of renewable energy strategy and alternative pricing mechanisms. A key objective of the study is to shed light on the policy issues so that effective decisions can be made to improve efficiency.
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| 4 |
ID:
116945
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| Publication |
2012.
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| Summary/Abstract |
Due largely to recent dramatic cost reductions, photovoltaics (PVs) are poised to make a significant contribution to electricity supply. In particular, distributed applications of PV on rooftops, brownfields, and other similar applications - hold great technical potential. In order for this potential to be realized, however, PV must be "cost-effective"-that is, it must be sufficiently financially appealing to attract large amounts of investment capital.
Electricity costs for most commercial and industrial end-users come in two forms: consumption (kWh) and demand (kW). Although rates vary, for a typical larger commercial or industrial user, demand charges account for about ~40% of total electricity costs. This paper uses a case study of PV on a large university campus to reveal that even very large PV installations will often provide very small demand reductions. As a result, it will be very difficult for PV to demonstrate cost-effectiveness for large commercial customers, even if PV costs continue to drop. If policymakers would like PV to play a significant role in electricity generation - for economic development, carbon reduction, or other reasons - then rate structures will need significant adjustment, or improved distributed storage technologies will be needed.
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| 5 |
ID:
166570
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| Summary/Abstract |
Modern electricity markets are characterized by an increasing share of renewable electricity generation. This growth in the share of renewables yields a highly intermittent generation structure. To efficiently integrate renewable electricity generation into our energy system, flexibility options ranging from storage facilities to demand-side management will play a major role in the low-carbon energy transformation. Keeping up with the growing demand for flexibility, energy law must reduce current investment obstacles for flexibility options and establish a climate for future investments with sufficient incentives for private investors. By taking up perspectives from different disciplines, this paper summarizes current investment barriers, presents an overview of the existing legal energy investment framework of the EU and Germany, and elaborates on challenges of the presented legislation. As we argue, a well-designed energy market legislation will be one of the keys to a successful energy transition. However, policy makers will have to (i) lower investment uncertainty for private investors, (ii) avoid a distortion of energy investment law towards specific flexibility options and technologies, and (iii) reduce the complexity of the current legislation.
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| 6 |
ID:
177437
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| Summary/Abstract |
Distributed energy resources (DERs) may enable prosumers to deliver demand response under dynamic energy pricing schemes. Facing wholesale market prices, the DER scheduling of a profit-maximising prosumer minimises the total system energy cost as well. However, regulated electricity bill components, i.a., distribution tariffs for recovering grid costs, may distort these price signals. To study the impact of distribution tariff structures on DER scheduling, we develop a short-term linear optimisation model that determines the cost-optimal DER schedule based on wholesale electricity prices and a distribution tariff. We compare five distribution tariff structures for four combinations of PV, batteries, and heat pumps, and define two metrics to characterise the results: (i) the novel ‘relative flexibility value’, which quantifies energy cost inefficiencies, and (ii) ‘rate of self-consumption’. In a case study, we show how prosumers make trade-offs between energy and distribution costs, depending on the distribution tariff structure. We describe the mechanisms through which different distribution tariff structures alter DER operations, and quantify the tariffs' impact on the system energy cost. Generally, we find that tariff types which stimulate self-consumption increase the system energy cost and vice versa.
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| 7 |
ID:
123279
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| Publication |
2013.
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| Summary/Abstract |
This paper has studied electricity pricing under a regulated structure during post power sector reform in Odisha, India. It is found that Odisha has adopted the average cost pricing principle for determining electricity price with the rate of return regulation. This process of tariff determination not only takes a long time but also involves huge cost. Further, actual tariffs levied by the Odisha Electricity Regulatory Commission (OERC) are at variance with the broad principles of rational pricing policy. This uneconomic pricing policy has adverse impact on the financial health of the distribution companies. However, the Electricity Act of 2003 has brought about a radical change in the power scenario across the country, including the state of Odisha, by introducing open access and trading of power.
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| 8 |
ID:
166957
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| Summary/Abstract |
We use a discounted cash flow model to explore the impact of electricity pricing and cost sharing rules on the economics of a small wind-powered mini-grid project in Kenya, designed around local tea factories as a demand anchor and connected to the national grid. The results show that including rural domestic and small business consumers in the project increases the overall economic benefit, illustrating the potential gains from using the tea factories as a demand anchor. However, the results also demonstrate that how costs are allocated to different consumer types impacts on participation and on whether the full benefits could be attained. If all consumers must pay towards the infrastructure they use according to their consumption, domestic consumers with low energy demands would not join the mini-grid. Cost sharing rules can be designed where tea factories, small businesses and domestic consumers all individually benefit and would therefore have incentives to participate. However, when the mini-grid is owned by the tea factories there are also possible outcomes where they might prefer to exclude domestic consumers. The results emphasise the need for policy makers to consider appropriate mini-grid tariffing regulation and how these tariffs interact with any existing national electricity pricing systems.
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