Social acceptance of wind and solar power in the Brazilian electricity system

2016 ◽  
Vol 18 (5) ◽  
pp. 1457-1476 ◽  
Author(s):  
Lunardo Alves de Sena ◽  
Paula Ferreira ◽  
Ana Cristina Braga
Keyword(s):  
Social Acceptance ◽  
Solar Power ◽  
Electricity System

scholarly journals Impacts of Electric Road Systems on the German and Swedish Electricity Systems—An Energy System Model Comparison

2021 ◽  
Vol 9 ◽  
Author(s):  
Johanna Olovsson ◽  
Maria Taljegard ◽  
Michael Von Bonin ◽  
Norman Gerhardt ◽  
Filip Johnsson
Keyword(s):  
Wind Power ◽  
Peak Power ◽  
Large Scale ◽  
Solar Power ◽  
Energy System ◽  
Transport Sector ◽  
Electricity System ◽  
Road Systems ◽  
The Impact ◽  
Electricity Systems

This study analyses the impacts of electrification of the transport sector, involving both static charging and electric road systems (ERS), on the Swedish and German electricity systems. The impact on the electricity system of large-scale ERS is investigated by comparing the results from two model packages: 1) a modeling package that consists of an electricity system investment model (ELIN) and electricity system dispatch model (EPOD); and 2) an energy system investment and dispatch model (SCOPE). The same set of scenarios are run for both model packages and the results for ERS are compared. The modeling results show that the additional electricity load arising from large-scale implementation of ERS is mainly, depending on model and scenario, met by investments in wind power in Sweden (40–100%) and in both wind (20–75%) and solar power (40–100%) in Germany. This study also concludes that ERS increase the peak power demand (i.e., the net load) in the electricity system. Therefore, when using ERS, there is a need for additional investments in peak power units and storage technologies to meet this new load. A smart integration of other electricity loads than ERS, such as optimization of static charging at the home location of passenger cars, can facilitate efficient use of renewable electricity also with an electricity system including ERS. A comparison between the results from the different models shows that assumptions and methodological choices dictate which types of investments are made (e.g., wind, solar and thermal power plants) to cover the additional demand for electricity arising from the use of ERS. Nonetheless, both modeling packages yield increases in investments in solar power (Germany) and in wind power (Sweden) in all the scenarios, to cover the new electricity demand for ERS.

scholarly journals Keep it local and low-key: Social acceptance of alpine solar power projects

2020 ◽  
pp. 110516
Author(s):  
Pascal Vuichard ◽  
Alexander Stauch ◽  
Rolf Wüstenhagen
Keyword(s):  
Social Acceptance ◽  
Solar Power

scholarly journals Adequacy of Renewable Energy Mixes with Concentrated Solar Power and Photovoltaic in Morocco: Impact of Thermal Storage and Cost

Energies ◽  
2020 ◽  
Vol 13 (19) ◽  
pp. 5087
Author(s):  
Ayat-allah Bouramdane ◽  
Alexis Tantet ◽  
Philippe Drobinski
Keyword(s):  
Solar Power ◽  
Climate Data ◽  
Concentrated Solar Power ◽  
Maximum Cost ◽  
Electricity System ◽  
Risk Increase ◽  
Time Space ◽  
Technological Diversification ◽  
Regional Diversification

In this paper, we analyze the sensitivity of the optimal mixes to cost and variability associated with solar technologies and examine the role of Thermal Energy Storage (TES) combined to Concentrated Solar Power (CSP) together with time-space complementarity in reducing the adequacy risk—imposed by variable Renewable Energies (RE)—on the Moroccan electricity system. To do that, we model the optimal recommissioning of RE mixes including Photovoltaic (PV), wind energy and CSP without or with increasing levels of TES. Our objective is to maximize the RE production at a given cost, but also to limit the variance of the RE production stemming from meteorological fluctuations. This mean-variance analysis is a bi-objective optimization problem that is implemented in the E4CLIM modeling platform—which allows us to use climate data to simulate hourly Capacity Factors (CFs) and demand profiles adjusted to observations. We adapt this software to Morocco and its four electrical zones for the year 2018, add new CSP and TES simulation modules, perform some load reduction diagnostics, and account for the different rental costs of the three RE technologies by adding a maximum-cost constraint. We find that the risk decreases with the addition of TES to CSP, the more so as storage is increased keeping the mean capacity factor fixed. On the other hand, due to the higher cost of CSP compared to PV and wind, the maximum-cost constraint prevents the increase of the RE penetration without reducing the share of CSP compared to PV and wind and letting the risk increase in return. Thus, if small level of risk and higher penetrations are targeted, investment must be increased to install more CSP with TES. We also show that regional diversification is key to reduce the risk and that technological diversification is relevant when installing both PV and CSP without storage, but less so as the surplus of energy available for TES is increased and the CSP profiles flatten. Finally, we find that, thanks to TES, CSP is more suited than PV and wind to meet peak loads. This can be measured by the capacity credit, but not by the variance-based risk, suggesting that the latter is only a crude representation of the adequacy risk.

scholarly journals Combined solar power and storage as cost-competitive and grid-compatible supply for China’s future carbon-neutral electricity system

2021 ◽  
Vol 118 (42) ◽  
pp. e2103471118
Author(s):  
Xi Lu ◽  
Shi Chen ◽  
Chris P. Nielsen ◽  
Chongyu Zhang ◽  
Jiacong Li ◽  
...  
Keyword(s):  
Solar Power ◽  
Average Power ◽  
Energy Transition ◽  
Energy System ◽  
Solar Pv ◽  
Electricity System ◽  
Technical Potential ◽  
Technical Advances ◽  
The Cost ◽  
And Storage

As the world’s largest CO2 emitter, China’s ability to decarbonize its energy system strongly affects the prospect of achieving the 1.5 °C limit in global, average surface-temperature rise. Understanding technically feasible, cost-competitive, and grid-compatible solar photovoltaic (PV) power potentials spatiotemporally is critical for China’s future energy pathway. This study develops an integrated model to evaluate the spatiotemporal evolution of the technology-economic-grid PV potentials in China during 2020 to 2060 under the assumption of continued cost degression in line with the trends of the past decade. The model considers the spatialized technical constraints, up-to-date economic parameters, and dynamic hourly interactions with the power grid. In contrast to the PV production of 0.26 PWh in 2020, results suggest that China’s technical potential will increase from 99.2 PWh in 2020 to 146.1 PWh in 2060 along with technical advances, and the national average power price could decrease from 4.9 to 0.4 US cents/kWh during the same period. About 78.6% (79.7 PWh) of China’s technical potential will realize price parity to coal-fired power in 2021, with price parity achieved nationwide by 2023. The cost advantage of solar PV allows for coupling with storage to generate cost-competitive and grid-compatible electricity. The combined systems potentially could supply 7.2 PWh of grid-compatible electricity in 2060 to meet 43.2% of the country’s electricity demand at a price below 2.5 US cents/kWh. The findings highlight a crucial energy transition point, not only for China but for other countries, at which combined solar power and storage systems become a cheaper alternative to coal-fired electricity and a more grid-compatible option.

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