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The impacts of high V2G participation in a 100% renewable Åland energy system
Abstract
In this work, a 100% renewable energy (RE) scenario that featured high participation in vehicle-to-grid (V2G) services was developed for the Åland islands for 2030 for all energy sectors (power, heat and transport). The EnergyPLAN modelling tool was used to find a least-cost system configuration that suited the regional context. Hourly data was analysed to determine the roles of various energy storage solutions, including V2G connections that extended into electric boat batteries, thermal storage and grid gas storage for Power-toGas (PtG) technologies. Two weeks of interest (max/min RE) generation were studied in detail to determine the roles of energy storage solutions in the energy system. Broad participation in V2G connections facilitated high shares of variable RE on a daily and weekly basis. In the Sustainable Mobility scenario developed, high participation in V2G (2750 MWhe) results in less need for gas storage (1200 MWhth), electrolyser capacity (6.1 MWe), methanation capacity (3.9 MWhgas) and offshore wind power capacity (55 MWe) than other scenarios that featured lower V2G participation. As a result, total annualised costs were lower (225 M€/a). The influence of V2G connections on seasonal storage is an interesting result for a relatively cold, northern geographic area. Analysis revealed several functions of V2G batteries. In total, 139.8 GWhe was charged from the grid. Of this, 78.2 GWhe returned to the grid, 53.2 GWhe satisfied transport demand, and the remainder (8.4 GWhe) constituted losses. A key point is that stored electricity need not only be considered as storage for future use by the grid, and V2G batteries can provide a buffer between generation of intermittent RE and its use by end-users. Direct consumption of intermittent RE further reduces the need for storage and generation capacities. In this study a strong relationship between RE generation and V2G battery charging was observed.
Supplementary resource (1)
... An open issue, however, is the extent to which an expected large amount of battery electric vehicle storage and vehicle-to-grid connections could be utilised within future energy systems. Optimised charging and vehicle-to-grid participation have already been seen in previous studies to reduce overall costs, installed generation capacities, and storage capacities [48], [49], [50]. This influence has also recently been shown to have a possible cost reducing effect on the European energy system [40]. ...
... MichaelChild et al. / Energy Procedia 155 (2018) [44][45][46][47][48][49][50][51][52][53][54][55][56][57][58][59][60] Author name / Energy Procedia 00 (2018) 000-000 ...
A transition towards a 100% renewable energy (RE) power sector by 2050 is investigated for Europe. Simulations using an hourly resolved model define the roles of storage technologies in a least cost system configuration. The investigated technologies are batteries, pumped hydro storage, adiabatic compressed air energy storage, thermal energy storage, and power-to-gas technology. Modelling proceeds from 2015 to 2050 in five-year time steps, and considers current power plant capacities, their corresponding lifetimes, and current and projected electricity demand to determine an optimal mix of plants needed to achieve a 100% RE power system by 2050. This optimization is carried out with regards to the assumed costs and technological status of all technologies involved. The total power capacity required by 2050, shares of resources, and storage technologies are defined. Results indicate that the levelised cost of electricity falls from a current level of 69 €/MWhe to 51 €/MWhe in 2050 through the adoption of low cost RE power generation, improvements in efficiency, and expanded power interconnections. Additionally, flexibility of and stability in the power system are provided by increasing shares of energy storage solutions over time, in parallel with expected price decreases in these technologies. Total storage requirements include up to 3320 GWhe of batteries, 396 GWhe of pumped hydro storage, and 218,042 GWhgas of gas storage (8% for synthetic natural gas and 92% for biomethane) for the time period depending on the scenario. The cost share of levelised cost of storage in the total levelised cost of electricity increases from less than 2 €/MWh (2% of total) to 16 €/MWh (28% of total) over the same time. Outputs of power-to-gas begin in 2020 when renewable energy generation reaches 50% in the power system, increasing to a total of 44 TWhgas in 2050. A 100% RE system can be a more economical and efficient solution for Europe, one that is also compatible with climate change mitigation targets set out in the Paris Agreement.
... The literature on V2X has evolved rapidly over the last decade [12][13][14][15][16][17][18][19][20][21][22][23][24]. Although these studies indicate that V2X brings new technological innovation to the energy market, they also note that a cost-effective application of V2X (specifically V2G, V2H, V2B) will depend on the electricity tariff design structure. ...
The adoption of electric vehicles (EVs) may contribute to decarbonisation of the transport sector and has the potential to offer value to consumers and electricity grid operators through its energy storage capabilities. While electricity tariffs can play an important role in consumer uptake of EVs, little is known about how EV charging tariff design affects EV users’ behaviour in participating in applications that can support the electricity grid, such as those applications classed under Vehicle-to-Everything (V2X). Examining the case of Australia, this study reviews the literature on electromobility with a focus on EV charging tariffs and its impact on consumer behaviour within the V2X context. The main findings drawn from up-to-date publications show that a well-designed EV tariff structure, available parking, and EV charging facilities can increase consumer participation in V2X. However, cooperation between EV users and grid operators is needed to establish a form of controlled charging agreement to harness the full potential of the EV electricity storage system for grid stability and battery support operations. To achieve this, the right tariff structure will have to be established to incentivise EV consumers to subscribe to V2X services. We also present recommendations for EV tariff design to support Australian consumer participation in V2G. Finally, we identify research gaps for further research.
... The outputs are PES, share of renewable energy sources (RES), CO 2 emissions, import/export electricity imbalance, fuel consumption and critical excess electricity production (CEEP). As a simulation tool EnergyPLAN offers the opportunity to model and analyze an energy system through different scenarios showing their advantages and weaknesses, depending of the input parameters as type of energy sources, emission factors, costs etc [48]. ...
In today’s energy system, the diffusion of renewable-based technologies is accelerating rapidly. Development of mechanisms that support the large-scale deployment of renewables towards global warming and climate change mitigation continues to remain an issue of utter importance. The most important challenges the energy system of Kosovo faces today is the difficulty to meet all the demand for electricity, low operating efficiency and high release of greenhouse gas emissions, but specifically a large source of carbon dioxide (CO2). Consequently, this influences not only the stability of the system but the society as a whole. This paper addresses several possibilities for designing an adaptable energy system in Kosovo with the ability to balance electricity supply and demand which will meet the requirements for a more efficient, reliable and secure system. A new way of energy generating through integration of new renewable and non-renewable technologies is developed using the EnergyPLAN model. The system is based on available technologies: existing hydro, wind, photovoltaic (PV), combined heat and power (CHP) and new solar thermal, heat pumps and biomass. The baseline scenario 2015 was expanded by four additional scenarios, two for the year 2030 and two for the year 2050. The contribution of renewable sources in the primary energy supply (PES) in the performed scenarios was 14.8%, 34.1%, 38.4%, 69.7% and 68.3% respectively. Further, a very important component of this paper is the investigation of integrating carbon capture and sequestration (CCS) technology in the coal-based power plant as part of the analysis in the second scenario for 2050. The shift to zero-carbon energy system in Kosovo requires additional research and assessment in order to identify the untapped potential of renewable sources. However, from the results obtained it can be concluded that the goal of a secure, competitive and sustainable energy system in Kosovo state which will meet its long-term energy needs can be certainly achieved.
... This represents an interesting further area of investigation that would require more detailed modelling of the transport sector. However, important roles of optimal charging and vehicle-to-grid participation has been noted in previous studies to reduce overall costs of energy systems through reduced installed generation and storage capacities [43], [44]. Finally, as high shares of RE in general, and prosumer PV and batteries more specifically, are projected to be seen in the BSR more rapidly than Europe as a whole, the BSR can develop a leadership role in European climate action. ...
The Baltic Sea Region could become the first area of Europe to reach a 100% renewable energy (RE) power sector. Simulations of the system transition from 2015 to 2050 were performed using an hourly resolved model that defines the roles of storage technologies in a least cost system configuration. Investigated technologies are batteries, pumped hydro storage, adiabatic compressed air energy storage, thermal energy storage, and power-to-gas. Modelling proceeds in five-year time steps, and considers current energy system assets and projected demands to determine the optimal technology mix needed to achieve 100% RE electricity by 2050. This optimization is carried out under the assumed cost and status of all technologies involved. Results indicate the levelised cost of electricity (LCOE) falls from 60 €/MWhe to 45 €/MWhe over time through adoption of low cost RE power generation and from inter-regional grid interconnection. Additionally, power system flexibility and stability are provided by ample resources of storable bioenergy, hydropower, inter-regional power transmission, and increasing shares of energy storage, together with expected price decreases in storage technologies. Total storage requirements include 0-238 GWhe of batteries, 19 GWhe of pumped hydro storage, and 0-16,652 GWhgas of gas storage. The cost share of storage in total LCOE increases from under 1 €/MWh to up to 10 €/MWh over time. Outputs of power-to-gas begin in 2040 when RE generation approaches a share of 100% in the power system, and total no more than 2 GWhgas due to the relatively large roles of bioenergy and hydropower in the system, which preclude the need for high amounts of additional seasonal storage. A 100% RE system can be an economical and efficient solution for the Baltic Sea Region, one that is also compatible with climate change mitigation targets set out at COP21. Concurrently, effective policy and planning is needed to facilitate such a transition.
... This represents an interesting further area of investigation that would require more detailed modelling of the transport sector. However, important roles of optimal charging and vehicle-to-grid participation has been noted in previous studies to reduce overall costs of energy systems through reduced installed generation and storage capacities [43], [44]. Finally, as high shares of RE in general, and prosumer PV and batteries more specifically, are projected to be seen in the BSR more rapidly than Europe as a whole, the BSR can develop a leadership role in European climate action. ...
The Baltic Sea Region could become the first area of Europe to reach a 100% renewable energy (RE) power sector. Simulations of the system transition from 2015 to 2050 were performed using an hourly resolved model which defines the roles of storage technologies in a least cost system configuration. Investigated technologies are batteries, pumped hydro storage, adiabatic compressed air energy storage, thermal energy storage, and power-togas. Modelling proceeds in five-year time steps, and considers current energy system assets and projected demands to determine the optimal technology mix needed to achieve 100% RE electricity by 2050. This optimization is carried out under the assumed cost and status of all technologies involved. Results indicate the levelised cost of electricity (LCOE) falls from 60 €/MWhe to 45 €/MWhe over time through adoption of low cost RE power generation and from interregional grid interconnection. Additionally, power system flexibility and stability are provided by ample resources of storable bioenergy, hydropower, interregional power transmission, and increasing shares of energy storage, together with expected price decreases in storage technologies. Total storage requirements include 0-238 GWhe of batteries, 19 GWhe of pumped hydro storage, and 0-16,652 GWhgas of gas storage. The cost share of storage in total LCOE increases from under 1 €/MWh to up to 10 €/MWh over time. Outputs of power-togas begin in 2040 when RE generation approaches a share of 100% in the power system, and total no more than 2 GWhgas due to the relatively large roles of bioenergy and hydropower in the system, which preclude the need for high amounts of additional seasonal storage. A 100% RE system can be an economical and efficient solution for the Baltic Sea Region, one that is also compatible with climate change mitigation targets set out at COP21. Concurrently, effective policy and planning is needed to facilitate such a transition.
... An open issue, however, is the extent to which an expected large amount of battery electric vehicle storage and vehicle-to-grid connections could be utilised within future energy systems. Optimised charging and vehicle-to-grid participation have already been seen in previous studies to reduce overall costs, installed generation capacities, and storage capacities [48], [49], [50]. This influence has also recently been shown to have a possible cost reducing effect on the European energy system [40]. ...
A transition towards a 100% renewable energy (RE) power sector by 2050 is investigated for Europe. Simulations using an hourly resolved model define the roles of storage technologies in a least cost system configuration. The investigated technologies are batteries, pumped hydro storage, adiabatic compressed air energy storage, thermal energy storage, and power-togas technology. Modelling proceeds from 2015 to 2050 in five-year time steps, and considers current power plant capacities, their corresponding lifetimes, and current and projected electricity demand to determine an optimal mix of plants needed to achieve a 100% RE power system by 2050. This optimization is carried out with regards to the assumed costs and technological status of all technologies involved. The total power capacity required by 2050, shares of resources, and storage technologies are defined. Results indicate that the levelised cost of electricity falls from a current level of 69 €/MWhe to 51 €/MWhe in 2050 through the adoption of low cost RE power generation, improvements in efficiency, and expanded power interconnections. Additionally, flexibility of and stability in the power system are provided by increasing shares of energy storage solutions over time, in parallel with expected price decreases in these technologies. Total storage requirements include up to 3320 GWhe of batteries, 396 GWhe of pumped hydro storage, and 218,042 GWhgas of gas storage (8% for synthetic natural gas and 92% for biomethane) for the time period depending on the scenario. The cost share of levelised cost of storage in the total levelised cost of electricity increases from less than 2 €/MWh (2% of total) to 16 €/MWh (28% of total) over the same time. Outputs of power-togas begin in 2020 when renewable energy generation reaches 50% in the power system, increasing to a total of 44 TWhgas in 2050. A 100% RE system can be a more economical and efficient solution for Europe, one that is also compatible with climate change mitigation targets set out in the Paris Agreement.
... However, given the possibility of integrating an expected electrified transport demand and potential substitution of electric vehicle batteries for some of the stationary batteries used in this model, further savings in LCOS can be foreseen, as well as possible revenue for electric car owners. Several studies have indicated that the integration of electric vehicle batteries into an energy system can not only support higher shares of intermittent RE, but can reduce the need for high capacities of stationary batteries [12], [35], [36]. This also represents a further area of inquiry for the Ukrainian energy system. ...
A transition towards a 100% renewable energy (RE) power sector by 2050 is investigated for Ukraine. Simulations using an hourly resolved model define the roles of storage technologies in a least cost system configuration. Results indicate that the levelised cost of electricity will fall from a current level of 82 €/MWhe to 60 €/MWhe in 2050 through the adoption of low cost RE power generation and improvements in efficiency. If the capacity in 2050 would have been invested for the cost assumptions of 2050, the cost would be 54 €/MWhe, which can be expected for the time beyond 2050. In addition, flexibility of and stability in the power system are provided by increasing shares of energy storage solutions over time, in parallel with expected price decreases in these technologies. Total storage requirements include 0-139 GWhe of batteries, 9 GWhe of pumped hydro storage, and 0-18,840 GWhgas of gas storage for the time period. Outputs of power-to-gas begin in 2035 when renewable energy production reaches a share of 86% in the power system, increasing to a total of 13 TWhgas in 2050. A 100% RE system can be a more economical and efficient solution for Ukraine, one that is also compatible with climate change mitigation targets set out at COP21. Achieving a sustainable energy system can aid in achieving other political, economic and social goals for Ukraine, but this will require overcoming several barriers through proper planning and supportive policies.
... However, given the possibility of integrating an expected electrified transport demand and potential substitution of electric vehicle batteries for some of the stationary batteries used in this model, further savings in LCOS can be foreseen, as well as possible revenue for electric car owners. Several studies have indicated that the integration of electric vehicle batteries into an energy system can not only support higher shares of intermittent RE, but can reduce the need for high capacities of stationary batteries [12], [35], [36]. This also represents a further area of inquiry for the Ukrainian energy system. ...
A transition towards a 100% renewable energy (RE) power sector by 2050 is investigated for Ukraine. Simulations using an hourly resolved model define the roles of storage technologies in a least cost system configuration. Modelling of the power system proceeds from 2015 to 2050 in five-year time steps, and considers current power plant capacities as well as their corresponding lifetimes, and current and projected electricity demand in order to determine an optimal mix of plants needed to achieve a 100% RE power system by 2050. Results indicate that the levelised cost of electricity will fall from a current level of 94 €/MWhe to 54 €/MWhe in 2050 through the adoption of low cost RE power generation and improvements in efficiency. In addition, flexibility of and stability in the power system are provided by increasing shares of energy storage solutions over time, in parallel with expected price decreases in these technologies. Total storage requirements include 0-139 GWhe of batteries, 9 GWhe of pumped hydro storage, and 0-18,840 GWhgas of gas storage for the time period. Outputs of power-togas begin in 2035 when renewable energy production reaches a share of 86% in the power system, increasing to a total of 13 TWhgas in 2050. A 100% RE system can be a more economical and efficient solution for Ukraine, one that is also compatible with climate change mitigation targets set out at COP21. Achieving a sustainable energy system can aid in achieving other political, economic and social goals for Ukraine, but this will require overcoming several barriers through proper planning and supportive policies. Several solutions are identified which can enable the transition towards the long-term sustainability of the Ukraine energy system.
... However, given the possibility of integrating an expected electrified transport demand and potential substitution of electric vehicle batteries for some of the stationary batteries used in this model, further savings in LCOS can be foreseen, as well as possible revenue for electric car owners. Several studies have indicated that the integration of electric vehicle batteries into an energy system can not only support higher shares of intermittent RE, but can reduce the need for high capacities of stationary batteries [12], [35], [36]. This also represents a further area of inquiry for the Ukrainian energy system. ...
Presentation on the occasion of the Sustainable Energy Forum and Exhibition (SEF-2016), Kiev, October 11, 2016.
Multiple energy-related crises require a fast transition towards a sustainable energy system. The European Green Deal aims for zero CO 2 emission by 2050, while accelerating climate change impacts obligate a faster phase-out of fossil fuels. Energy transition studies for Europe at and near 100% renewable energy are used as a benchmark for two newly introduced scenarios for Europe reaching zero CO 2 emissions by 2050 and 2040. A technology-rich energy system model was applied in hourly resolution for Europe in 20 interconnected regions and in full sector coupling covering all energy demands. The results reveal a cost-neutral energy transition towards 2050 based on declining levelised cost of electricity and a pathway with 9% higher energy costs leading to 17% lower total CO 2 emissions with an accelerated energy transition by 2040. The two scenarios find shares of solar photovoltaic (PV) in total generation of 61%-63% by 2050, the highest ever estimated for Europe, still below the highest global average shares ranging between 75% and 77% form three independent studies. The central energy system components are solar PV, wind power, batteries, electrolysers and CO2 direct air capture for carbon capture and utilisation. The core characteristic of the European energy future may be best described by a power-to-X economy, which may evolve on the global scale to a solar-to-X economy.
Technical Report "Global Energy System based on 100% Renewable Energy – Power Sector", published at the Global Renewable Energy Solutions Showcase event (GRESS), a side event of the COP23, Bonn, November 8, 2017
A global transition to 100% renewable electricity is feasible at every hour throughout the year and more cost effective than the existing system, which is largely based on fossil fuels and nuclear energy. Energy transition is no longer a question of technical feasibility or economic viability, but of political will.
Existing renewable energy potential and technologies, including storage can generate sufficient and secure power to cover the entire global electricity demand by 2050 . The world population is expected to grow from 7.3 to 9.7 billion. The global electricity demand for the power sector is set to increase from 24,310 TWh in 2015 to around 48,800 TWh by 2050.
Total levelised cost of electricity (LCOE) on a global average for 100% renewable electricity in 2050 is 52 €/MWh (including curtailment, storage and some grid costs), compared to 70 €/MWh in 2015.
Solar PV and battery storage drive most of the 100% renewable electricity supply due to a significant decline in costs during the transition.
Due to rapidly falling costs, solar PV and battery storage increasingly drive most of the electricity system, with solar PV reaching some 69%, wind energy 18%, hydropower 8% and bioenergy 2% of the total electricity mix in 2050 globally.
Wind energy increases to 32% by 2030. Beyond 2030 solar PV becomes more competitive. Solar PV supply share increases from 37% in 2030 to about 69% in 2050.
Batteries are the key supporting technology for solar PV. Storage output covers 31% of the total demand in 2050, 95% of which is covered by batteries alone. Battery storage provides mainly short-term (diurnal) storage, and renewable energy based gas provides seasonal storage.
100% renewables bring GHG emissions in the electricity sector down to zero, drastically reduce total losses in power generation and create 36 million jobs by 2050.
Global greenhouse gas emissions significantly reduce from about 11 GtCO2eq in 2015 to zero emissions by 2050 or earlier, as the total LCOE of the power system declines.
The global energy transition to a 100% renewable electricity system creates 36 million jobs by 2050 in comparison to 19 million jobs in the 2015 electricity system. Operation and maintenance jobs increase from 20% of the total direct energy jobs in 2015 to 48% of the total jobs in 2050 that implies more stable employment chances and economic growth globally.
The total losses in a 100% renewable electricity system are around 26% of the total electricity demand, compared to the current system in which about 58% of the primary energy input is lost.
A 100% renewable energy scenario was developed for Finland in 2050 using the EnergyPLAN modelling tool to find a suitable, least-cost configuration. Hourly data analysis determined the roles of various energy storage solutions. Electricity and heat from storage represented 15% of end-user demand. Thermal storage discharge was 4% of end-user heat demand. In the power sector, 21% of demand was satisfied by electricity storage discharge, with the majority (87%) coming from vehicle-to-grid (V2G) connections. Grid gas storage discharge represented 26% of gas demand. This suggests that storage solutions will be an important part of a 100% renewable Finnish energy system.
As electricity generation based on volatile renewable resources is subject to fluctuations, data with high temporal and spatial resolution on their availability is indispensable for integrating large shares of renewable capacities into energy infrastructures. The scope of the present doctoral thesis is to enhance the existing energy modelling environment REMix in terms of (i.) extending the geographic coverage of the potential assessment tool REMix-EnDaT from a European to a global scale, (ii.) adding a new plant siting optimization module REMix-PlaSMo, capable of assessing siting effects of renewable power plants on the portfolio output and (iii.) adding a new alternating current power transmission model between 30 European countries and CSP electricity imports from power plants located in North Africa and the Middle East via high voltage direct current links into the module REMix-OptiMo. With respect to the global potential assessment tool, a thorough investigation is carried out creating an hourly global inventory of the theoretical potentials of the major renewable resources solar irradiance, wind speed and river discharge at a spatial resolution of 0.45°x0.45°. A detailed global land use analysis determines eligible sites for the installation of renewable power plants. Detailed power plant models for PV, CSP, wind and hydro power allow for the assessment of power output, cost per kWh and respective full load hours taking into account the theoretical potentials, technological as well as economic data. The so-obtined tool REMix-EnDaT can be used as follows: First, as an assessment tool for arbitrary geographic locations, countries or world regions, deriving either site-specific or aggregated installable capacities, cost as well as full load hour potentials. Second, as a tool providing input data such as installable capacities and hourly renewable electricity generation for further assessments using the modules REMix-PlasMo and OptiMo. The plant siting tool REMix-PlaSMo yields results as to where the volatile power technologies photovoltaics and wind are to be located within a country in order to gain distinct effects on their aggregated power output. Three different modes are implemented: (a.) Optimized plant siting in order to obtain the cheapest generation cost, (b.) a minimization of the photovoltaic and wind portfolio output variance and (c.) a minimization of the residual load variance. The third fundamental addition to the REMix model is the amendment of the module REMix-OptiMo with a new power transmission model based on the DC load flow approximation. Moreover, electricity imports originating from concentrating solar power plants located in North Africa and the Middle East are now feasible. All of the new capabilities and extensions of REMix are employed in three case studies: In case study 1, using the module REMix-EnDaT, a global potential assessment is carried out for 10 OECD world regions, deriving installable capacities, cost and full load hours for PV, CSP, wind and hydro power. According to the latter, photovoltaics will represent the cheapest technology in 2050, an average of 1634 full load hours could lead to an electricity generation potential of some 5500 PWh. Although CSP also taps solar irradiance, restrictions in terms of suitable sites for erecting power plants are more severe. For that reason, the maximum potential amounts to some 1500 PWh. However, thermal energy storage can be used, which, according to this assessment, could lead to 5400 hours of full load operation. Onshore wind power could tap a potential of 717 PWh by 2050 with an average of 2200 full load hours while offshore, wind power plants could achieve a total power generation of 224 PWh with an average of 3000 full load hours. The electricity generation potential of hydro power exceeds 3 PWh, 4600 full load hours of operation are reached on average. In case study 2, using the module REMix-PlaSMo, an assessment for Morocco is carried out as to determine limits of volatile power generation in portfolios approaching full supply based on renewable power. The volatile generation technologies are strategically sited at specific locations to take advantage of available resources conditions. It could be shown that the cost optimal share of volatile power generation without considering storage or transmission grid extensions is one third. Moreover, the average power generation cost using a portfolio consisting of PV, CSP, wind and hydro power can be stabilized at about 10 €ct/kWh by the year 2050. In case study 3, using the module REMix-OptiMo, a validation of a TRANS-CSP scenario based upon high shares of renewable power generation is carried out. The optimization is conducted on an hourly basis using a least cost approach, thereby investigating if and how demand is met during each hour of the investigated year. It could be shown, that the assumed load can safely be met in all countries for each hour using the scenario's power plant portfolio. Furthermore, it was proven that dispatchable renewable power generation, in particular CSP imports to Europe, have a system stabilizing effect. Using the suggested concept, the utilization of the transfer capacities between countries would decrease until 2050.
Globally, small islands below 100,000 inhabitants represent a large number of diesel based mini-grids. With volatile fossil fuel costs which are most likely to increase in the long-run and competitive renewable energy technologies the introduction of such sustainable power generation system seems a viable and environmental friendly option. Nevertheless the implementation of renewable energies on small islands is quite low based on high transaction costs and missing knowledge according to the market potential.
Integrating high shares of renewable energy (RE) sources in future energy systems requires a variety of storage solutions and flexibility measures. In this work, a 100% RE scenario was developed for Finland in 2050 for all energy sectors using the EnergyPLAN modelling tool to find a least-cost system configuration that suited the national context. Hourly data was analysed to determine the roles of various energy storage solutions, including stationary batteries, vehicle-to-grid (V2G) connections, thermal energy storage and grid gas storage for Power-toGas (PtG) technologies. V2G storage and stationary batteries facilitated use of high shares of variable RE on a daily and weekly basis. Thermal energy storage and synthetic grid gas storage aided in resolving seasonality issues related to variable RE generation plus facilitated efficient use of other forms of RE, such as biomass, and Combined Heat and Power to maintain the reliability and independence of the energy system throughout the year. In this scenario, 30 GWp of installed solar PV, 35 GWe of onshore wind power and 5 GWe of offshore wind power are supported by 20 GWh of stationary Lithium-ion batteries, 150 GWh of V2G storage (Li-ion), 20 GWhth of thermal energy storage, and 3800 GWhth of grid gas storage. Discharge of electricity and heat from storage represented 15% of end-user demand. Thermal storage discharge was 4% of end-user heat demand. In the power sector, 21% of end-user demand was satisfied by electricity storage discharge, the majority of this (87%) coming from V2G connections. Grid gas storage discharge represented 26% of gas demand. These observations suggest that storage solutions will be an important part of a 100% renewable Finnish energy system.
The paper reviews different approaches, technologies, and strategies to manage large-scale schemes of variable renewable electricity such as solar and wind power. We consider both supply and demand side measures. In addition to presenting energy system flexibility measures, their importance to renewable electricity is discussed. The flexibility measures available range from traditional ones such as grid extension or pumped hydro storage to more advanced strategies such as demand side management and demand side linked approaches, e.g. the use of electric vehicles for storing excess electricity, but also providing grid support services. Advanced batteries may offer new solutions in the future, though the high costs associated with batteries may restrict their use to smaller scale applications. Different “P2Y”-type of strategies, where P stands for surplus renewable power and Y for the energy form or energy service to which this excess in converted to, e.g. thermal energy, hydrogen, gas or mobility are receiving much attention as potential flexibility solutions, making use of the energy system as a whole. To “functionalize” or to assess the value of the various energy system flexibility measures, these need often be put into an electricity/energy market or utility service context. Summarizing, the outlook for managing large amounts of RE power in terms of options available seems to be promising.
The excellent solar resources of Israel make it possible to reach the target of 100% RE, independent of fossil fuel supply in a rather close future. For now the development of large PV capacities is restrained by battery storage costs: before reaching a cost level of 200 €/kWh, batteries are not competitive and installations of thermal storages and CSP are cost optimal. The role of CSP remains unclear; however, the high competitiveness of PV-battery may limit CSP to a minor role. PV self-consumption plays a significant role in the energy transformation in Israel.
While increasing the share of renewable energy to 20% is a challenge for grid
stability, working towards a 100% renewable energy supply requires a
completely new approach. Small island grids are the ideal platform to start
achieving tomorrow’s energy concepts today.
To develop the necessary technologies for a high level renewable energy
island system, Younicos AG built a hardware and software development and test
site in Berlin. The actual system testing shows that the ability to switch off the
diesel generator – i.e. guarantee a stable grid exclusively using fluctuating
sources and batteries and without rotating masses, gives the freedom to choose
any renewable energy configuration between 0 and 100%. Consequently, the
renewable energy system layout can be set up according to the island’s
ecological and economical goals.
A hybrid system with a high renewable penetration can generate substantial
savings by substituting large shares of fuel for electricity generation. Therefore,
in addition to the technological solutions, procedures and business models are
being developed to identify the economic optimal configuration for isolated
systems under a given set of climate and load conditions. The technical
approach, results of the test phase and key parameters of a supply system based
on renewables and storage will be summarized in this paper.
Keywords: island, island energy system, renewable energy, renewable energy
integration, battery storage, grid stability, system optimization.
Integrating a high share of electricity from non-dispatchable Renewable
Energy Sources in a power supply system is a challenging task. One option
considered in many studies dealing with prospective power systems is the
installation of storage devices to balance the fluctuations in power
production. However, it is not yet clear how soon storage devices will be
needed and how the integration process depends on different storage parameters.
Using long-term solar and wind energy power production data series, we present
a modelling approach to investigate the influence of storage size and
efficiency on the pathway towards a 100% RES scenario. Applying our approach to
data for Germany, we found that up to 50% of the overall electricity demand can
be met by an optimum combination of wind and solar resources without both
curtailment and storage devices if the remaining energy is provided by
sufficiently flexible power plants. Our findings show further that the
installation of small, but highly efficient storage devices is already highly
beneficial for the RES integration, while seasonal storage devices are only
needed when more than 80% of the electricity demand can be met by wind and
solar energy. Our results imply that a balance between the installation of
additional generation capacities and storage capacities is required.
Graciosa, an island of the Azores is to be provided with an electricity generation system based mainly on photovoltaics (PV) and wind energy. This system includes a stationary battery-electric storage and a diesel backup generator and will produce electricity with more than 80 % of demand covered by renewable sources. The most economic sizing of the components will lead to excess energy amounting to about one third of the total electricity produced. Incorporating more flexible consumers will match demand closer to production and reduce overall costs per energy consumed. This paper looks into the possibility of electric vehicles (EV) as additional demanders and an active part of the system.
The oil-dependent electricity generation situation met in the Aegean Archipelago Islands is in great deal determined by increased rates of fuel consumption and analogous electricity production costs, this being also the case for other island autonomous electrical networks worldwide. Meanwhile, the contribution of renewable energy sources (RES) to the constant increase recorded in both the Aegean islands’ annual electricity generation and the corresponding peak load demand is very limited. To compensate the unfavorable situation encountered, the implementation of energy storage systems (ESS) that can both utilize the excess/rejected energy produced from RES plants and improve the operation of existing thermal power units is recommended. In the present study, a techno-economic comparison of various RES-ESS configurations supported by the supplementary or back-up use of existing thermal units is undertaken. From the results obtained, the shift of direction from the existing oil-dependent status to a RES-based alternative in collaboration with certain storage technologies entails – apart from the clear environmental benefits – financial advantages as well.
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