Modelling the Energy Future of Switzerland after the Phase Out of Nuclear Power Plants

Redondo, Paula Díaz; Vliet, Oscar van

doi:10.1016/j.egypro.2015.07.843

Cited by 34 publications

(15 citation statements)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…With the renewable variant "E", demand and supply challenges are in particular great as the expansion of renewables will most likely occur with volatile electricity produced by PV [15], while simultaneously base-load electricity from NPP is discarded [16,17]. Moreover, without load shifting strategies, also the electricity demand will become more volatile, partly because of additional demand peaks due to heat pumps and BEV, but also due to peer-to-peer trades in a liberalized electricity market causing non-grid friendly impacts without corresponding regulations and controls [18].…”

Section: Introductionmentioning

confidence: 99%

“…In existing studies, typically bottom-up energy system (optimization) models are used to investigate the future Swiss energy system based on given targets in the ES2050 [16,[23][24][25][26][27]. These models rely on forecasts and fixed scenarios of the whole energy system and use cost optimization to generate cost-optimal energy scenarios under technological, resource, environmental, and/or policy constraints [23].…”

Section: Introductionmentioning

confidence: 99%

“…For the Swiss energy system, there are models with a high (mostly hourly) temporal resolution, but only in the electricity sector [24,28,29]; and models with a distinction between the electricity, heat and mobility sector, but only at a coarse (weekly, monthly) temporal resolution [25,26] or only with typical (averaged) days per season [27]. While electricity-only models also (indirectly) incorporate the penetration of BEV and heat pumps by taking annual demand values (e.g., from "POM", which implicitly also includes additional BEV and heat pumps) and linearly scaling them to historic (hourly) load profiles [16], they are still not capable of representing additional and/or shifted demand peaks due to BEV and heat pumps. On the other hand, models that explicitly include the heat and mobility sector [25,30] typically do not have input data at an adequately high temporal resolution.…”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Impacts of an Increased Substitution of Fossil Energy Carriers with Electricity-Based Technologies on the Swiss Electricity System

2019

View full text Add to dashboard Cite

Electrifying the energy system with heat pumps and battery electric vehicles (BEV) is a strategy of Switzerland and many other countries to reduce CO2 emissions. A large electrification, however, poses several new challenges for the electricity system, particularly in combination with a simultaneous substitution of nuclear power plants (NPP) by volatile renewables such as photovoltaics (PV). In this study, these challenges in terms of additional electricity demands, deficits and surpluses as well as effective CO2 mitigation are assessed in a dynamic and data-driven approach. To this end, electricity demand and production profiles are synthesized based on measured data and specifications and assumptions of the key technologies at a high temporal resolution. The additional electricity demand of heat pumps is estimated from hourly measured heat demand profiles of a Swiss district heating provider, while for BEV different recharging patterns are combined. For electricity production, NPP are deducted from the current electricity production profile, while PV is added at an hourly resolution. In order to estimate CO2 emissions, life-cycle analysis (LCA) CO2 intensities of the different technologies are used. It is shown that with a BEV and heat pump penetration of 20% and 75%, respectively, there is an almost 25% (13.7 TWh/year) increase of the electricity demand and—just as challenging—an additional maximum power requirement of 5.9 GWh/h (hourly-averaged power). Without additional storage options, large amounts of electricity must be imported in winter and at night, while in summer at noon there is a large surplus from PV. Due to their high CO2 intensities—at least for the next decades—electricity imports and PV may—depending on the reference scenario (with or without NPP) and assumptions on other key parameters—even offset the overall CO2 savings of a highly electrified Swiss energy system.

show abstract

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Impacts of an Increased Substitution of Fossil Energy Carriers with Electricity-Based Technologies on the Swiss Electricity System

2019

View full text Add to dashboard Cite

show abstract

“…However, Switzerland has almost reached its maximum capacity for hydropower production, and projections of future energy mix show that renewables (e.g. wind and photovoltaics) will need to play a significant role in supplementing the energy deficit left by the phase out of nuclear energy (Redondo and Van Vliet, 2015).…”

Section: Energy Demandmentioning

confidence: 99%

Risks and opportunities for a Swiss hydropower company in a changing climate

Hakala

Addor

Gobbe³

et al. 2019

Preprint

View full text Add to dashboard Cite

Abstract. Anticipating and adapting to climate change impacts on water resources requires a detailed understanding of future hydroclimatic changes and of stakeholders' vulnerability to these changes. However, climate change impact studies are often conducted at a spatial scale that is too coarse to capture the specificity of individual catchments, and more importantly, the changes they focus on are not necessarily the changes most critical to stakeholders. While recent studies have combined hydrological and electricity market modeling, they tend to aggregate all climate impacts by focusing solely on reservoir profitability, and thereby provide limited insights into climate change adaptation. Here, we collaborated with Groupe E, a hydropower company operating several reservoirs in the Swiss pre-Alps and worked with them to produce hydroclimatic projections tailored to support their upcoming water concession negotiations. We started by identifying the vulnerabilities of their activities to climate change and then together chose streamflow and energy indices to characterize the associated risks. We provided Groupe E with figures showing the projected climate change impacts, which were refined over several meetings. The selected indices enabled us to simultaneously assess a variety of impacts induced by changes on i) the seasonal water volume distribution, ii) low flows, iii) high flows, and iv) energy demand. We were hence able to identify key opportunities (e.g., the future increase of reservoir inflow in winter, when electricity prices are historically high) and risks (e.g., the expected increase of consecutive days of low flows in summer and fall, which is likely to make it more difficult to meet residual flow requirements). This study highlights that the hydrological opportunities and risks associated with reservoir management in a changing climate depend on a range of factors beyond those covered by traditional impact studies. We also illustrate the importance of identifying stakeholder needs and using them to inform the production of climate impact projections. Our user-centered approach is transferable to other impact modeling studies, in the field of water resources and beyond.

show abstract

“…INTRODUCTION Environmental concerns and recent developments in renewable energy technologies are leading towards replacing conventional generation in favor of production from renewables. For instance, in Switzerland, governmental goals have set to phase out nuclear generation by 2050, thus opening the way to production from distributed energy resources (DERs) [1]. The main challenge of this transition is the increasing demand for controllable resources that need to be deployed to compensate for the intermittent characteristic of renewable generation and guarantee the frequency/voltage regulation, power quality, and congestion management [2]- [4].…”

Section: F Maxmentioning

confidence: 99%

Allocation of Active Power Reserve from Active Distribution Networks Using a Cost-Benefit Approach: Application to Swissgrid Network

Kalantar-Neyestanaki

Bozorg

Sossan

et al. 2019

2019 IEEE Milan PowerTech

View full text Add to dashboard Cite

The flexibility of distributed energy resources (DERs) accommodated in active distribution networks (ADNs) can be aggregated and then used to provide ancillary services to the transmission system. In this context, this paper presents a linear optimization method for the transmission system operator (TSO) to allocate its required active power reserve from aggregated resources installed in active distribution systems (ARADSs) as well as dispatchable bulk power plants (DBPPs). It consists in a linear optimization problem that minimizes the sum of the expected cost of active power reserve allocated from all possible providers (including ARADSs and DBPPs) and the expected cost of load not served over a desired time horizon. The value of lost load (VOLL) index is used as a criterion to realize an economical balance between the expected cost of allocated reserve and expected cost of load not served. The method leverages scenarios of power system contingencies and forecast errors of loads and renewable generation to represent typical operational uncertainties. A simulation proofof-concept using real-data from the transmission system operator of Switzerland, Swissgrid, is provided to illustrate the performance of the method. Index Terms-Active distribution network (ADN), active power reserve, aggregated resources of active distribution system (ARADS), energy storage system (ESS), distributed energy resource (DER).

show abstract

Modelling the Energy Future of Switzerland after the Phase Out of Nuclear Power Plants

Cited by 34 publications

References 3 publications

Impacts of an Increased Substitution of Fossil Energy Carriers with Electricity-Based Technologies on the Swiss Electricity System

Impacts of an Increased Substitution of Fossil Energy Carriers with Electricity-Based Technologies on the Swiss Electricity System

Risks and opportunities for a Swiss hydropower company in a changing climate

Allocation of Active Power Reserve from Active Distribution Networks Using a Cost-Benefit Approach: Application to Swissgrid Network

Contact Info

Product

Resources

About