|
|
|
Sort Order |
|
|
|
Items / Page
|
|
|
|
|
|
|
| Srl | Item |
| 1 |
ID:
192780
|
|
|
|
|
| Summary/Abstract |
Distributed rooftop photovoltaics (PV) is one of the pillars of the energy transition yet their widespread integration strains grids, leading to over-voltage, reverse power flow, and infrastructure strain. Furthermore, increased PV self-consumption reduces imported electricity, posing challenges for cost recovery by Transmission System Operators (TSOs) and Distribution System Operators (DSOs), whose grid costs were traditionally tied to volumetric tariffs. To investigate whether alternative tariffs could mitigate PV impacts at the distribution level without hampering PV development, we assess five electricity tariffs that could help the DSOs to recover the costs of maintaining the distribution grid. We also analyze their effects on private storage investment and their implications for urban, semi-urban, and rural low-voltage networks. We found that tariffs with a capacity-based component promote further adoption of PV and storage. At the same time, they allow the DSOs to recover the grid cost without incurring relevant economic differences for the customer. Our study found that alternative tariffs like dynamic and capacity-based tariffs promote the adoption of storage and PV systems. While no single tariff alone can fully mitigate PV impacts at the distribution level, our results point towards the need of managing PV export through solutions like PV curtailment.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 2 |
ID:
115670
|
|
|
|
|
| Publication |
2012.
|
| Summary/Abstract |
There is an increasing impetus to transform the U.S transportation sector and transition away from the uncertainties of oil supply. One of the most viable current solutions is the adoption of electric vehicles (EVs). These vehicles allow for a transportation system that would be flexible in its fuel demands. However, utilities may need to address questions such as distribution constraints, electricity tariffs and incentives and public charging locations before large scale electric vehicle adoption can be realized. In this study, the effect of electric vehicles on households in Indianapolis is examined. A four-step traffic flow model is used to characterize the usage characteristics of vehicles in the Indianapolis metropolitan area. This data is then used to simulate EV usage patterns which can be used to determine household electricity usage characteristics. These results are differentiated by the zones with which the households are associated. Economic costs are then calculated for the individual households. Finally, possible public charging locations are examined.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 3 |
ID:
191160
|
|
|
|
|
| Summary/Abstract |
Renewable energy sources (RES) dominance in Uganda's electricity mix is challenged by affordability and theft. To assess electricity affordability, the study proposed a probabilistic method to quantify the households into different electricity categories for both urban and rural areas. Alternative electricity billing schemes based on Scenarios A to D for the households to enhance legal connection and consumption of electricity were proposed. The study established that the utility registers the highest electricity theft losses in rural households. The monthly utility revenue collected in urban areas was about 2.9 times that collected in rural areas because of the higher number of legally connected households with a monthly consumption of 1.5 times than that of rural households. From the monthly income spendable on electricity, rural and urban households could only afford 25.07 kWh and 38.29 kWh, respectively, which are less than the average household electricity consumption for Uganda. Also, the initial connection fee to the power grid is very high for the households to afford it in a single down payment. Of the proposed alternative billing schemes, Scenario B and Scenario D yield the least monthly utility revenue collected for the urban and rural households, respectively.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 4 |
ID:
181766
|
|
|
|
|
| Summary/Abstract |
Electricity distribution networks that contain large photovoltaic solar systems can experience power flows between customers. These may create both technical and socio-economic challenges. This paper establishes how these challenges can be addressed through the combined deployment of Community-scale Energy Storage (CES) and local network tariffs. Our study simulates the operation of a CES under a range of local network tariff models, using current Australian electricity prices and current network prices as a reference. We assess the financial outcomes for solar and non-solar owning customers and the distribution network operator. We find that tariff settings exist that create mutual benefits for all stakeholders. Such tariffs all apply a discount of greater than 50% to energy flows within the local network, relative to regular distribution network tariffs. The policy implication of these findings is that the, historically contentious, issue of network tariff reform in the presence of local solar power generation can be resolved with a mutually beneficial arrangement of local network tariffs and CES. Furthermore, the challenge of setting appropriate tariffs is eased through clear and intuitive conditions on local network tariff pricing.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 5 |
ID:
111329
|
|
|
|
|
| Publication |
2012.
|
| Summary/Abstract |
Drawing from relevant experiences in power systems around the world, this paper offers a review of existing policy support mechanisms for RES-E, with a detailed analysis of their regulatory implications. While recent studies provide an account of current RES-E support systems, in this paper we focus on some of the impacts these mechanisms have on the overall energy market structure and its performance. Given the rising importance of RES-E in systems everywhere, these impacts should no longer be overlooked.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|