|
|
|
Sort Order |
|
|
|
Items / Page
|
|
|
|
|
|
|
| Srl | Item |
| 1 |
ID:
125410
|
|
|
|
|
| Publication |
2013.
|
| Summary/Abstract |
Wind power generation and its impacts on electricity prices has strongly increased in the EU. Therefore, appropriate mark-to-market evaluation of new investments in wind power and energy storage plants should consider the fluctuant generation of wind power and uncertain electricity prices, which are affected by wind power feed-in (WPF). To gain the input data for WPF and electricity prices, simulation models, such as econometric models, can serve as a data basis.
This paper describes a combined modeling approach for the simulation of WPF series and electricity prices considering the impacts of WPF on prices based on an autoregressive approach. Thereby WPF series are firstly simulated for each hour of the year and integrated in the electricity price model to generate an hourly resolved price series for a year. The model results demonstrate that the WPF model delivers satisfying WPF series and that the extended electricity price model considering WPF leads to a significant improvement of the electricity price simulation compared to a model version without WPF effects. As the simulated series of WPF and electricity prices also contain the correlation between both series, market evaluation of wind power technologies can be accurately done based on these series.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 2 |
ID:
099299
|
|
|
|
|
| Publication |
2010.
|
| Summary/Abstract |
Increased interconnection has been highlighted as potentially facilitating the integration of wind generation in power systems by increasing the flexibility to balance the variable wind output. This paper utilizes a stochastic unit commitment model to simulate the impacts of increased interconnection for the island of Ireland with large penetrations of wind generation. The results suggest that increased interconnection should reduce average prices in Ireland, and the variability of those prices. The simulations also suggest that while increased interconnection may reduce carbon dioxide emissions in Ireland, Great Britain would experience an increase in emissions, resulting in total emissions remaining almost unchanged. The studies suggest that increased interconnection would not reduce excess wind generation. This is because under unit commitment techniques which incorporate wind power forecasts in the scheduling decisions, wind curtailment is minimal even with low levels of interconnection. As would be expected an increase in interconnection should improve system adequacy considerably with a significant reduction in the number of hours when the load and reserve constraints are not met.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 3 |
ID:
107634
|
|
|
|
|
| Publication |
2011.
|
| Summary/Abstract |
Large integration of intermittent wind generation in power system has necessitated the inclusion of more innovative and sophisticated approaches in power system investment planning. This paper presents a novel framework on the basis of a combination of stochastic dynamic programming (SDP) algorithm and game theory to study the impacts of different regulatory interventions to promote wind power investment in generation expansion planning. In this study, regulatory policies include Feed-in-Tariff (FIT) incentive, quota and tradable green certificate. The intermittent nature and uncertainties of wind power generation will cause the investors encounter risk in their investment decisions. To overcome this problem, a novel model has been derived to study the regulatory impacts on wind generation expansion planning. In our approach, the probabilistic nature of wind generation is modeled. The model can calculate optimal investment strategies, in which the wind power uncertainty is included. This framework is implemented on a test system to illustrate the working of the proposed approach. The result shows that FITs are the most effective policy to encourage the rapid and sustained deployment of wind power. FITs can significantly reduce the risks of investing in renewable energy technologies and thus create conditions conducive to rapid market growth.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 4 |
ID:
096750
|
|
|
|
|
| Publication |
2010.
|
| Summary/Abstract |
This work examines the effects of large-scale integration of wind powered electricity generation in a deregulated energy-only market on loads (in terms of electricity prices and supply reliability) and dispatchable conventional power suppliers. Hourly models of wind generation time series, load and resultant residual demand are created. From these a non-chronological residual demand duration curve is developed that is combined with a probabilistic model of dispatchable conventional generator availability, a model of an energy-only market with a price cap, and a model of generator costs and dispatch behavior. A number of simulations are performed to evaluate the effect on electricity prices, overall reliability of supply, the ability of a dominant supplier acting strategically to profitably withhold supplies, and the fixed cost recovery of dispatchable conventional power suppliers at different levels of wind generation penetration. Medium and long term responses of the market and/or regulator in the long term are discussed.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 5 |
ID:
097605
|
|
|
|
|
| Publication |
2010.
|
| Summary/Abstract |
This work examines the effects of large-scale integration of wind powered electricity generation in a deregulated energy-only market on loads (in terms of electricity prices and supply reliability) and dispatchable conventional power suppliers. Hourly models of wind generation time series, load and resultant residual demand are created. From these a non-chronological residual demand duration curve is developed that is combined with a probabilistic model of dispatchable conventional generator availability, a model of an energy-only market with a price cap, and a model of generator costs and dispatch behavior. A number of simulations are performed to evaluate the effect on electricity prices, overall reliability of supply, the ability of a dominant supplier acting strategically to profitably withhold supplies, and the fixed cost recovery of dispatchable conventional power suppliers at different levels of wind generation penetration. Medium and long term responses of the market and/or regulator in the long term are discussed.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 6 |
ID:
125852
|
|
|
|
|
| Publication |
2013.
|
| Summary/Abstract |
We compare the cost of generating electricity with coal and wind in Chile. On average, we estimate that the levelized cost of coal, including externalities, is $84/MWh. It is efficient to abate air pollutants (SOx, NOx and PM2.5) but not CO2. With abatement the cost wrought by environmental externalities equals $23/MWh or 27% of total cost. Depending on the price of coal, the levelized cost may vary between $72 and $99/MWh.
The levelized cost of wind is $144/MWh with capacity factor of 24%. This cost includes backup capacity to maintain LOLP, which equals $13/MWh or 9% of total cost. The levelized cost of wind varies between $107/MWh with capacity factors of 35% to $217/MWh with capacity factors of 15%.
Wind is competitive only with capacity factors around 35% and very high coal prices. Alternatively, a carbon price of $73/tCO2 ($268/tc) would make coal and wind equally costly. But this value implies a marginal damage at the 98th percentile of the distribution deduced from Tol's (2011) estimates, rather far from the mean, $16/tCO2 ($59/tc).
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|