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| 1 |
ID:
124179
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2013.
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| Summary/Abstract |
Ambitious targets have been set for expanding electricity generation from renewable sources, including wind. Expanding wind power impacts needs for other electricity generating resources. As states plan for increasing levels of wind generation in their portfolio of generation resources it is important to consider how this intermittent resource impacts the need for other generation resources. A case study for Indiana estimates the value of wind capacity and demonstrates how to optimize its level and the levels of other generation resources. Changes are driven by temporal patterns of wind power output and load. System wide impacts are calculated for energy, capacity, and costs under multiple wind expansion scenarios which highlight the geographic characteristics of a systems portfolio of wind generation. The impacts of carbon prices, as proposed in the Bingaman Bill, are considered. Finally, calculations showing the effect increasing levels of wind generation will have on end use Indiana retail rates are included.
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| 2 |
ID:
096651
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2010.
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| Summary/Abstract |
The increasing prevalence of renewable and intermittent energy sources in the electricity system is creating new challenges for the interaction of the system. In Denmark, high renewable shares have been achieved without great difficulty, mainly due to the flexibility of the nearby Nordic hydro-power dominated system. Further increases in the share of renewable energy sources require that additional options are considered to facilitate integration with the lowest possible cost.
With large shares of intermittent energy, the impact can be observed on wholesale prices, giving both lower prices and higher volatility. A lack of wind that causes high prices is rarely seen because long periods without wind are uncommon. Therefore we focus on the low price effects and the increased value of flexible demand options. On the supply side, there is an increase in the value of other flexible generation technologies and the attractiveness of additional interconnection capacity. This paper also analyses options for increasing the flexibility of heat generation involving large and decentralized CHP plants and heat generation based on electricity. The incentives that the market provides for shifting demand and using electricity for heat production are discussed based on the variability of prices observed from 2006 to 2008.
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| 3 |
ID:
097487
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2010.
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| Summary/Abstract |
The increasing prevalence of renewable and intermittent energy sources in the electricity system is creating new challenges for the interaction of the system. In Denmark, high renewable shares have been achieved without great difficulty, mainly due to the flexibility of the nearby Nordic hydro-power dominated system. Further increases in the share of renewable energy sources require that additional options are considered to facilitate integration with the lowest possible cost.
With large shares of intermittent energy, the impact can be observed on wholesale prices, giving both lower prices and higher volatility. A lack of wind that causes high prices is rarely seen because long periods without wind are uncommon. Therefore we focus on the low price effects and the increased value of flexible demand options. On the supply side, there is an increase in the value of other flexible generation technologies and the attractiveness of additional interconnection capacity. This paper also analyses options for increasing the flexibility of heat generation involving large and decentralized CHP plants and heat generation based on electricity. The incentives that the market provides for shifting demand and using electricity for heat production are discussed based on the variability of prices observed from 2006 to 2008.
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| 4 |
ID:
109614
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2011.
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| Summary/Abstract |
The envisaged increase in the share of electricity generation from intermittent renewable energy sources (RES-E) like wind and photovoltaics will pose challenges to the existing electricity system. A successful integration of these sources requires a cost-efficient use of system flexibility. The literature on the options to improve system flexibility, and thus the costs of successfully integrating intermittent electricity generating units, is still growing but what is lacking is an overarching systematic view on when to adopt which option in particular energy systems. This paper aims to bridge this gap in literature. We use existing insights on market and network integration of intermittent electricity sources within a regulatory road map framework. The framework allows policy makers and other electricity system stakeholders to arrive at a consistent strategy in dealing with integration issues over a longer period of time. In this contribution we present and explain the framework and apply it for the case of The Netherlands.
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| 5 |
ID:
109323
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2011.
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| Summary/Abstract |
Large scale storage offers the prospect of capturing and using excess electricity within a low carbon energy system, which otherwise might have to be wasted. Incorporating the role of storage into current scenario tools is challenging, because it requires high temporal resolution to reflect the effects of intermittent sources on system balancing. This study draws on results from a model with such resolution. It concludes that large scale storage could become economically viable for scenarios with high penetration of renewables. As the proportion of intermittent sources increases, the optimal type of storage shifts towards solutions with low energy related costs, even at the expense of efficiency. However, a range of uncertainties have been identified, concerning storage technology development, the regulatory environment, alternatives to storage and the stochastic uncertainty of year-on-year revenues. All of these negatively affect the cost of finance and the chances of successful market uptake. We argue, therefore, that, if the possible wider system and social benefits from the presence of storage are to be achieved, stronger and more strategic policy support may be necessary. More work on the social and system benefits of storage is needed to gauge the appropriate extent of support measures.
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| 6 |
ID:
177402
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| Summary/Abstract |
We examine different scenarios with large amounts of intermittent generation to achieve close to a 100% renewable electricity market in New Zealand. We use a cost based dispatch model to simulate market prices. Previous modelling has estimated electricity prices using the Long Run Marginal Cost approach. Our study is the first to model market prices explicitly, for scenarios with close to 100% renewable electricity, to see if the “energy only market” revenues are enough for investment cost recovery. Our modelling suggest that large amounts of wind on its own are better than mixed wind and solar scenarios. We also see a collapse in spot prices, as we get very close to 100% renewable. These prices are well below those needed to cover investment costs. We argue that there should be a market design change to a design that includes direct payments for capacity, as well as for electricity output, to ensure investment cost recovery.
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