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Sökning: WFRF:(Odenberger Mikael 1977)

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4.
  • Goop, Joel, 1986, et al. (författare)
  • Distributed solar and wind power - Impact on distribution losses
  • 2016
  • Ingår i: Energy. - : Elsevier BV. - 0360-5442. ; 112, s. 273-284
  • Tidskriftsartikel (refereegranskat)abstract
    • Introducing renewable electricity as distributed generation may be an attractive option in the shift towards a more sustainable electricity system. Yet, it is not clear to what extent an increased use of distributed generation is beneficial from a systems perspective. We therefore investigate the impacts from increased employment of distributed solar and wind power on losses and transformer capacity requirements in distribution systems. The analysis is based on a dispatch model with a simple representation of typical voltage levels in the distribution system. When electricity is transferred between voltage levels, we subtract losses estimated as the transferred energy times a constant loss factor. Our results show that the losses depend on how load is distributed between voltage levels. For total penetration levels up to 40–50% on an energy basis, we find that wind and solar power could potentially reduce distribution losses. Results further indicate that solar photovoltaic capacity in the low voltage level has a limited potential to decrease peak power flows between voltage levels in a setting where seasonal variations in demand and solar output are opposite to each other. Thereby distributed solar generation also has limited potential to defer investments in transformer capacity between voltage levels.
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5.
  • Goop, Joel, 1986, et al. (författare)
  • Impact of electricity market feedback on investments in solar photovoltaic and battery systems in Swedish single-family dwellings
  • 2021
  • Ingår i: Renewable Energy. - : Elsevier BV. - 0960-1481 .- 1879-0682. ; 163, s. 1078-1091
  • Tidskriftsartikel (refereegranskat)abstract
    • The profitability of investments in photovoltaics (PVs) and batteries in private households depends on the market price of electricity, which in turn is affected by the investments made in and the usage of PVs and batteries. This creates a feedback mechanism between the centralised electricity generation system, and household investments in PVs and batteries. To investigate this feedback effect, we connect a local optimisation model for household investments with a European power generation dispatch model. The local optimisation is based on the consumption profiles measured for 2104 Swedish households. The modelling compares three different scenarios for the centralised electricity supply system in Year 2032, as well as several sensitivity cases. Our results show total investment levels of 5–20 GWp of PV and 0.01–10 GWh of battery storage capacity in Swedish households in the investigated cases. These levels are up to 33% lower than before market feedback is taken into account. The profitability of PV investments is affected most by the price of electricity and the assumptions made regarding grid tariffs and taxes. The value of investments in batteries depends on both the benefits of increased self-consumption of PV electricity and market arbitrage.
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6.
  • Goop, Joel, 1986, et al. (författare)
  • The effect of high levels of solar generation on congestion in the European electricity transmission grid
  • 2017
  • Ingår i: Applied Energy. - : Elsevier BV. - 1872-9118 .- 0306-2619. ; 205, s. 1128-1140
  • Tidskriftsartikel (refereegranskat)abstract
    • The increasing levels of solar power affect the usage and development of electricity grids, both at local distribution level and with respect to potential congestion within the transmission grid. We use a cost-minimising investment model (ELIN) to determine the development of the European electricity generation system up to Year 2050, for two renewable-dominated scenarios: the Green Base scenario, with a Europe-wide, technology-neutral renewable certificate scheme; and the Net Metering scenario, with an additional net metering support scheme for solar power. The system compositions are extracted from the ELIN results for the years 2022 and 2032, and analysed in an hourly dispatch model (EPOD) to study the effects of solar power on marginal electricity costs and transmission congestion. From the results of the investment model, it is clear that the presence of a net metering subsidy scheme significantly affects both the pace at which solar power continues to expand and the geographical distribution of the new capacity. In the dispatch modelling, it can be seen that high penetration levels of solar power have a strong effect on the marginal costs of electricity, since production is concentrated around a few hours each day. At penetration levels of 20–30% of annual electricity demand, solar power production entails a predictable daily marginal cost difference between the solar peak and the evening price peak, which could make short-term storage competitive. Transmission congestion during summer is consistently higher in the systems from the Net Metering scenario than in those from the Green Base scenario, while the opposite is true during winter. Solar power production correlates strongly with congestion 6–9 h after the solar peak, whereas wind power correlates with congestion with respect to more slowly evolving and longer-term variations.
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7.
  • Gudmunds, D., et al. (författare)
  • Self-consumption and self-sufficiency for household solar producers when introducing an electric vehicle
  • 2020
  • Ingår i: Renewable Energy. - : Elsevier BV. - 0960-1481 .- 1879-0682. ; 148:April, s. 1200-1215
  • Tidskriftsartikel (refereegranskat)abstract
    • The aim of this study was to analyse how electric vehicles (EVs) affect the levels of electricity self-consumption and self-sufficiency in households that have in-house electricity generation from solar photovoltaics (PV). A model of the household electricity system was developed, in which real-time measurements of household electricity consumption and vehicle driving, together with modelled PV generation were used as inputs. The results show that using an EV for storage of in-house-generated PV electricity has the potential to achieve the same levels of self-consumption and self-sufficiency for households as could be obtained using a stationary battery. As an example, the level of self-sufficiency (21.4%) obtained for the households, with a median installed PV capacity of 8.7 kWp, was the same with an EV as with a stationary battery with a median capacity of 2.9 kWh. However, substantial variations (up to 50% points) were noted between households, primarily reflecting driving profiles.
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8.
  • Göransson, Lisa, 1982, et al. (författare)
  • Impact of thermal plant cycling on the cost-optimal composition of a regional electricity generation system
  • 2017
  • Ingår i: Applied Energy. - : Elsevier BV. - 1872-9118 .- 0306-2619. ; 197, s. 230-240
  • Tidskriftsartikel (refereegranskat)abstract
    • A regional cost-minimizing investment model that accounts for cycling properties (i.e., start-up time, minimum load level, start-up cost and emissions, and part-load costs and emissions) is developed to investigate the impact of thermal plant cycling on the cost-optimal composition of a regional electricity generation system. The model is applied to an electricity system that is rich in wind resources with and without accounting for cycling in two scenarios: one with favorable conditions for flexible bio-based generation (Bio scenario); and one in which base load is favored (Base load scenario) owing to high prices for biomass. Both scenarios are subject to a tight cap on carbon dioxide emissions, limiting the investment options to technologies that have low or no carbon emissions. We report that in the Bio scenario, the cost-optimal system is dominated by wind power and flexible bio-based generation, whereas base-load generation dominates the Base load scenario, in line with the assumptions made, and the level of wind power is reduced. In the Base load scenario, 19% of the capacity is cycling-dependent, i.e., for this share of installed capacity, the choice of technology is different if cycling properties are included, compared to a case in which they are omitted. In the Bio scenario, in which flexible bio-based generation is less costly, 9% of the capacity is cycling-dependent. We conclude that it is critical to include cycling properties in investment modeling, to assess investments in thermal generation technologies that compete at utilization times in the range of 2000–5000 h.
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9.
  • Göransson, Lisa, 1982, et al. (författare)
  • Linkages between demand-side management and congestion in the European electricity transmission system
  • 2014
  • Ingår i: Energy. - : Elsevier BV. - 0360-5442. ; 69, s. 860-872
  • Tidskriftsartikel (refereegranskat)abstract
    • We evaluate the possibility to reduce congestion in the transmission grid through large-scale implementation of demand-side management (DSM) in the form of load shifting for the EU-27 countries, Norway, and Switzerland for Year 2020. A linear, cost-minimising, dispatch model that includes a DC load-flow description of the transmission system and a general representation of load shifting is used. It is assumed that the EU Member States fulfil the targets for Year 2020 in their national renewable energy action plans. In the model calculations, a reference case without load shifting is compared with cases in which the load shifting is 5%, 10%, 15% or 20% of the load. The possibility to shift load in time is added exogenously and economic incentives for DSM are not evaluated. Three types of congestion are identified: peak-load-hour congestion, low-load-hour congestion and all-hour congestion. Peak-load-hour congestion is reduced as the DSM share of the load increases, whereas low-load-hour congestion, which is typically associated with a high level of wind generation, persists at all the DSM penetration levels investigated. We show that all-hour congestion occurs between systems that have large differences in supply structure, and that the impact of DSM on all-hour congestion is low. (C) 2014 Elsevier Ltd. All rights reserved.
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10.
  • Hartvigsson, Elias, 1986, et al. (författare)
  • Comparison and Analysis of GPS Measured Electric Vehicle Charging Demand: The Case of Western Sweden and Seattle
  • 2021
  • Ingår i: Frontiers in Energy Research. - : Frontiers Media SA. - 2296-598X. ; 9
  • Tidskriftsartikel (refereegranskat)abstract
    • Electrification of transportation using electric vehicles has a large potential to reduce transport related emissions but could potentially cause issues in generation and distribution of electricity. This study uses GPS measured driving patterns from conventional gasoline and diesel cars in western Sweden and Seattle, United States, to estimate and analyze expected charging coincidence assuming these driving patterns were the same for electric vehicles. The results show that the electric vehicle charging power demand in western Sweden and Seattle is 50–183% higher compared to studies that were relying on national household travel surveys in Sweden and United States. The after-coincidence charging power demand from GPS measured driving behavior converges at 1.8 kW or lower for Sweden and at 2.1 kW or lower for the United States The results show that nominal charging power has the largest impact on after-coincidence charging power demand, followed by the vehicle’s electricity consumption and lastly the charging location. We also find that the reduction in charging demand, when charging is moved in time, is largest for few vehicles and reduces as the number of vehicles increase. Our results are important when analyzing the impact from large scale introduction of electric vehicles on electricity distribution and generation.
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11.
  • Hartvigsson, Elias, 1986, et al. (författare)
  • Dataset for generating synthetic residential low-voltage grids in Sweden, Germany and the UK
  • 2021
  • Ingår i: Data in Brief. - : Elsevier BV. - 2352-3409. ; 36
  • Tidskriftsartikel (refereegranskat)abstract
    • Assessing grid capacity on national and local levels is important in order to formulate renewable energy targets, calculate integration costs of distributed generation (such as residential solar PV and electric vehicles). Currently, 70–96% of the residential solar PV installations in Germany and Italy are found in the low-voltage grid. Previous grid assessments have relied on grid data from individual low-voltage grids, making them limited to a few cases. This article presents synthetic low-voltage grid data from a reference network model. The reference network model generates synthetic low-voltage grids using publicly available data and national regulations and standards. In addition, the article presents data of residential solar photovoltaic hosting capacity in low-voltage grids. The datasets are high-resolution (1 × 1 km) and contains data on electricity peak demand, share of population living in apartments and important grid metrics such as transformer capacity, maximum feeder length and estimations of residential solar photovoltaic hosting capacity. Datasets on grid components are rare and the dataset can be used to assess grid impacts from other residential end-use technologies, and function as baseline for other reference network models.
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12.
  • Hartvigsson, Elias, 1986, et al. (författare)
  • Estimating national and local low-voltage grid capacity for residential solar photovoltaic in Sweden, UK and Germany
  • 2021
  • Ingår i: Renewable Energy. - : Elsevier BV. - 0960-1481 .- 1879-0682. ; 171, s. 915-926
  • Tidskriftsartikel (refereegranskat)abstract
    • The electric grid's available capacity to accommodate solar photovoltaic on national scales is currently uncertain. This makes decisions about grid capacity expansion, which can be very costly for local grid operators, difficult to make. Yet, knowledge of national solar photovoltaic grid capacity is central in order to formulate realistic solar PV targets and strategies. We present a methodology based on publicly available data to estimate the grid's hosting capacity of residential solar photovoltaic at both the national and local scale. The model is applied to Sweden, Germany and the UK and shows that low-voltage grid capacity for residential solar photovoltaic is very large, 33 (+5/-7) GW (Sweden), 248 (+5/-24) GW (Germany) and 63 (+1/-14) GW UK, and similar to current total generation capacity. Based on our estimations, we find that with the capacity of the present grid Sweden can supply 24%, Germany 60% and UK 21% of their current annual net electricity consumption from residential solar photovoltaic. In addition, we find that the grid-supported individual solar PV system sizes increase as population density decreases. Finally, our work highlights the importance of implementing sizing incentives for customers when installing their solar PV systems.
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13.
  • Hartvigsson, Elias, 1986, et al. (författare)
  • Generating low-voltage grid proxies in order to estimate grid capacity for residential end-use technologies: The case of residential solar PV
  • 2021
  • Ingår i: MethodsX. - : Elsevier BV. - 2215-0161. ; 8
  • Tidskriftsartikel (refereegranskat)abstract
    • Due to data restrictions and power system complexity issues, it is difficult to estimate grid capacity for solar PV on regional or national scales. We here present a novel method for estimating low-voltage grid capacity for residential solar PV using publicly available data. High-resolution GIS data on demographics and dwelling dynamics is used to generate theoretical low-voltage grids. Simplified power system calculations are performed on the generated low-voltage grids to estimate residential solar PV capacity with a high temporal resolution. The method utilizes previous developments in reference network modelling and solar PV hosting capacity assessments. The method is demonstrated using datasets from Sweden, UK and Germany. Even though the method is designed to estimate residential solar PV grid capacity, the first block of the method can be utilized to estimate grid capacity or impacts from other residential end-use technologies, such as electric heating or electric vehicle charging. This method presents: • A method for estimating peak demand based on population density and dwelling type. • Generation of low-voltage grids based on peak demand. • Sizing of transformers and cables based on national low-voltage regulations and standards.
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14.
  • Heinisch, Verena, 1991, et al. (författare)
  • Interconnection of the electricity and heating sectors to support the energy transition in cities
  • 2019
  • Ingår i: International Journal of Sustainable Energy Planning and Management. - 2246-2929. ; 24, s. 57-66
  • Tidskriftsartikel (refereegranskat)abstract
    • The electricity, heating, and transport sectors in urban areas all have to contribute to meeting stringent climate targets. Cities will face a transition from fossil fuels to renewable sources, with electricity acting as a cross-sectorial energy carrier. Consequently, the electricity demand of cities is expected to rise, in a situation that will be exacerbated by ongoing urbanisation and city growth. As alternative to an expansion of the connection capacity to the national grid, local measures can be considered within city planning in order to utilize decentralised electricity generation, synergies between the heating and electricity sectors, and flexibility through energy storage technologies. This work proposes an optimisation model that interconnects the electricity, heat, and transport sectors in cities. We analyse the investments in and operation of an urban energy system, using the City of Gothenburg as an example. We find that the availability of electricity from local solar PV together with thermal storage technologies increase the value of using power-to-heat technologies, such as heat pumps. High biomass prices together with strict climate targets enhance the importance of electricity in the district heating sector. A detailed understanding of the integration of local low-carbon energy technologies can give urban planners and other city stakeholders the opportunity to take an active role in the city’s energy transition.
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15.
  • Heinisch, Verena, 1991, et al. (författare)
  • Organizing prosumers into electricity trading communities: Costs to attain electricity transfer limitations and self‐sufficiency goals
  • 2019
  • Ingår i: International Journal of Energy Research. - : Hindawi Limited. - 1099-114X .- 0363-907X. ; 43:13, s. 7021-7039
  • Tidskriftsartikel (refereegranskat)abstract
    • Among household electricity end users, there is growing interest in local renewable electricity generation and energy independence. Community‐based and neighborhood energy projects, where consumers and prosumers of electricity trade their energy locally in a peer‐to‐peer system, have started to emerge in different parts of the world. This study investigates and compares the costs incurred by individual households and households organized in electricity trading communities in seeking to attain greater independence from the centralized electricity system. This independence is investigated with respect to: (i) the potential to reduce the electricity transfer capacity to and from the centralized system and (ii) the potential to increase self‐sufficiency. An optimization model is designed to analyze the investment and operation of residential photovoltaic battery systems. The model is then applied to different cases in a region of southern Sweden for year 2030. Utilizing measured electricity demand data for Swedish households, we show that with a reduced electricity transfer capacity to the centralized system, already a community of five residential prosumers can supply the household demand at lower cost than can prosumers acting individually. Grouping of residential prosumers in an electricity trading community confers greater benefits under conditions with a reduced electricity transfer capacity than when the goal is to become electricity self‐sufficient. It is important to consider the local utilization of photovoltaic‐generated electricity and its effect on the net trading pattern (to and from the centralized system) when discussing the impact on the electricity system of a high percentage of prosumers.
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16.
  • Heinisch, Verena, 1991, et al. (författare)
  • Prosumers in the Electricity System—Household vs. System Optimization of the Operation of Residential Photovoltaic Battery Systems
  • 2019
  • Ingår i: Frontiers in Energy Research. - : Frontiers Media SA. - 2296-598X. ; 6
  • Tidskriftsartikel (refereegranskat)abstract
    • An increase in distributed small-scale generation and storage in residential prosumer households requires an understanding of how the household-controlled operation of these distributed technologies differ from a system-optimal utilization. This paper aims at investigating how residential photovoltaic (PV)-battery systems are operated, given different assumed incentives, and whether or not a prosumer induced operational pattern differs from what is desirable from a total electricity system point of view. The work combines a household optimization model that minimizes the annual household electricity bill for two price zones in southern Sweden with a dispatch model for the northern European electricity supply system. The results show significant differences in the charging and discharging patterns of residential batteries. A household annual electricity cost minimization gives many hours in which only a fraction of the battery capacity is used for charging and discharging, mainly driven by incentives to maximize self-consumption of PV-generated electricity. In contrast, in a total electricity system operational cost minimization larger fractions of the available battery capacity are utilized within single hours. In the total system optimization case, the batteries are charged and discharged less frequently and the energy turnover in the batteries is only half that of the household optimization case. For all the cases studied, the hourly electricity price provides only a limited incentive for households to operate their batteries in a system-optimal manner.
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17.
  • Heinisch, Verena, 1991, et al. (författare)
  • Smart electric vehicle charging strategies for sectoral coupling in a city energy system
  • 2021
  • Ingår i: Applied Energy. - : Elsevier BV. - 1872-9118 .- 0306-2619. ; 288
  • Tidskriftsartikel (refereegranskat)abstract
    • The decarbonization of city energy systems plays an important role to meet climate targets. We examine the consequences of integrating electric cars and buses into the city energy system (60% of private cars and 100% of public buses), using three different charging strategies in a modelling tool that considers local generation and storage of electricity and heat, electricity import to the city, and investments to achieve net-zero emissions from local electricity and heating in 2050. We find that up to 85% of the demand for the charging of electric cars is flexible and that smart charging strategies can facilitate 62% solar PV in the charging electricity mix, compared to 24% when cars are charged directly when parked. Electric buses are less flexible, but the timing of charging enables up to 32% to be supplied by solar PV. The benefit from smart charging to the city energy system can be exploited when charging is aligned with the local value of electricity in the city. Smart charging for cars reduces the need for investments in stationary batteries and peak units in the city electricity and heating sectors. Thus, our results point to the importance of sectoral coupling to exploit flexibility options in the city electricity, district heating and transport sectors.
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18.
  • Heinisch, Verena, 1991, et al. (författare)
  • The impact of limited electricity connection capacity on energy transitions in cities
  • 2021
  • Ingår i: Smart Energy. - : Elsevier BV. - 2666-9552. ; 3
  • Tidskriftsartikel (refereegranskat)abstract
    • We study the impacts of the connection capacity for electricity transfer between a city and a regional energy system on the design and operation of both systems. The city energy system is represented by the aggregate energy demand of three cities in southern Sweden, and the regional energy system is represented by Swedish electricity price area SE3. We minimize the investment and running costs in the electricity and district heating sectors, considering different levels of connection capacity between the city and the regional energy systems; connection capacities equal to 100%, 75%, 50% and 0% of the maximum city electricity demand. We find that a system design with 50% connection capacity is only 3% more expensive in terms of total costs than a system with 100% connection capacity. However, shifting electricity generation capacity from the regional to the city energy system with 50%, as compared to 100%, connection capacity leads to a higher marginal cost for electricity in the city than in the region. With the highest connection capacities, 75% and 100%, the district heating sector in the city can support wind power integration in the regional energy system by means of power-to-heat operation. Modeling systems with different connection capacities makes our results applicable to other fast-growing cities with potential to increase local electricity production and sector coupling between the electricity, district heating and electrified transport sectors.
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19.
  • Ingvarsson, Simon, 1992, et al. (författare)
  • The chemical pulp mill as a flexible prosumer of electricity
  • 2023
  • Ingår i: Energy Conversion and Management: X. - 2590-1745. ; 20
  • Tidskriftsartikel (refereegranskat)abstract
    • Chemical pulp mills act as industrial-scale prosumers of energy, in that they demand heat and electricity for the production processes while supplying heat and electricity from the combustion of by-products. As such, they have potential relevance as providers of flexibility to the electricity system, supporting the integration of variable renewable electricity generation. In this study, a novel dispatch optimisation model is presented and applied to a generic mill, covering the production processes, boilers, and turbines, together with the associated storage of intermediate products. We analyse the trade in electricity between the mill and the central grid, the economic value of pulp mill flexibility, and the internal dynamics of the mill, when flexibility measures in different parts of the mill are combined. The results show that the suggested flexibility measures increase the amount of sold electricity during high-value hours and reduce the amount of sold electricity during low-value hours. In the present electricity market, the value of the electricity traded with the central grid is, thereby, increased by 1–8% compared to steady-state operation, without impacting the pulp production volume. The results reveal both synergies and conflicts between the different flexibility measures, underlining the importance of mill-wide optimisation.
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20.
  • Johansson, Viktor, 1991, et al. (författare)
  • Value of wind power – Implications from specific power
  • 2017
  • Ingår i: Energy. - : Elsevier BV. - 0360-5442. ; 126, s. 352-360
  • Tidskriftsartikel (refereegranskat)abstract
    • This paper investigates the marginal system value of increasing the penetration level of wind power, and how this value is dependent upon the specific power (the ratio of the rated power to the swept area). The marginal system value measures the economic value of increasing the wind power capacity. Green-field power system scenarios, with minimised dispatch and investment costs, are modelled for Year 2050 for four regions in Europe that have different conditions for renewable electricity generation. The results show a high marginal system value of wind turbines at low penetration levels in all four regions and for the three specific powers investigated. The cost-optimal wind power penetration levels are up to 40% in low-wind-speed regions, and up to 80% in high-wind–speed regions. The results also show that both favourable solar conditions and access to hydropower benefit the marginal system value of wind turbines. Furthermore, the profile value, which measures how valuable a wind turbine generation profile is to the electricity system, increases in line with a reduction in the specific power for wind power penetration levels of >10%. The profile value shows that the specific power becomes more important as the wind power penetration level increases. © 2017 Elsevier Ltd
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21.
  • Johnsson, Filip, 1960, et al. (författare)
  • Challenges to integrate CCS into low carbon electricity markets
  • 2014
  • Ingår i: Energy Procedia. - : Elsevier BV. - 1876-6102. ; 63, s. 7485-7493
  • Konferensbidrag (refereegranskat)abstract
    • Published by Elsevier Ltd. This paper discusses challenges for integration of CCS into competitive electricity markets by using the European electricity supply system as an example. The work is based on techno-economic modelling of the European electricity generation sector up to Year 2050, assuming a tightening cap on CO2 emissions down to almost no emissions by 2050. It is concluded that natural gas fired conventional power plants is likely to be a serious competitor to coal CCS in the short to medium term providing large emission reduction by fuel shifting from existing coal power plants to new high efficiency gas fired plants. This can be a barrier for early deployment of CCS without additional support. It is also concluded that for regions with large amount of intermittent electricity generation, short term balance in generation will impose challenges to handle CCS plants in relation to load following requirements. Yet, there are regions with good availability of coal combined with unfavorable conditions for wind power, for which CCS can operate in typical base load.
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22.
  • Johnsson, Filip, 1960, et al. (författare)
  • The importance of CO2 capture and storage: A geopolitical discussion
  • 2012
  • Ingår i: Thermal Science. - 0354-9836. ; 16:3, s. 655-668
  • Tidskriftsartikel (refereegranskat)abstract
    • The CO2 capture and storage (CCS) technology is since more than ten years considered one of the key options for the future climate change mitigation. This paper discusses the implications for the further development of CCS, particularly with respect to climate change policy in an international geopolitics context. The rationale for developing CCS should be the over-abundance of fossil fuel reserves (and resources) in a climate change context. From a geopolitical point, it can be argued that the most important outcome from the successful commercialisation of CCS will be that fossil fuel-dependent economies with large fossil fuel resources will find it easier to comply with stringent greenhouse gas reduction targets (i. e. to attach a price to CO2 emissions). This should be of great importance since, from a geopolitical view, the curbing on greenhouse gas emissions cannot be isolated from security of supply and economic competition between regions. Thus, successful application of CCS may moderate geopolitical risks related to regional differences in the possibilities and thereby willingness to comply with large emission cuts. In Europe, application of CCS will enhance security of supply by fuel diversification from continued use of coal, especially domestic lignite. Introduction of CCS will also make possible negative emissions when using biomass as a fuel, i. e. in so called Biomass Energy CCS (BECCS). Yet, the development of BECCS relies on the successful development of fossil fuelled CCS since BECCS in itself is unlikely to be sufficient for establishing a cost efficient CCS infrastructure for transport and storage and because BECCS does not solve the problem with the abundant resources of fossil fuels. Results from research and development of capture, transport and storage of CO2 indicate that the barriers for commercialization of CC'S should not be technical. Instead, the main barriers for implementation of CCS seem to be how to reach public acceptance, to reduce cost and to establish a high enough price on CO2 emissions. Failure to implement CCS will require that the global community, including Europe, agrees to almost immediately to start phasing out the use of fossil fuels, an agreement which seems rather unlikely, especially considering the abundant coal reserves in developing economies such as China and India.
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23.
  • Johnsson, Filip, 1960, et al. (författare)
  • The importance of CO2 Capture and Storage - a geopolitical discussion
  • 2011
  • Ingår i: The 6th Dubrovnik Conference on Sustainable Development of Energy, Water and Environment Systems.
  • Konferensbidrag (refereegranskat)abstract
    • The CO2 capture and storage (CCS) technology is now considered to be one of the key options for climate change mitigation. This paper discusses the implications for the further development of CCS, particularly with respect to climate change policy in an international geopolitics context.The rationale for developing CCS should be the over-abundance of fossil fuel reserves (and resources) in a climate change context. From a geopolitical point, it can be argued that the most important outcome from the successful commercialisation of CCS will be that fossil fuel-dependent economies will find it easier to comply with stringent greenhouse gas (GHG) reduction targets (i.e. to attach a price to CO2 emissions). This should be of great importance since, from a geopolitical view, the curbing on GHG emissions cannot be isolated from security of supply and economic competition between regions. Thus, successful application of CCS may moderate geopolitical risks related to regional differences in the possibilities and thereby willingness to comply with large emission cuts. In Europe, application of CCS will enhance security of supply by fuel diversification from continued use of coal, especially domestic lignite. In contrast, failure to implement CCS will require that the global community, including Europe, agrees to almost immediately to start phasing out the use of fossil fuels, an agreement which seems rather unlikely, especially considering the abundant coal reserves in developing economies such as China and India.
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24.
  • Jönsson, Johanna, 1981, et al. (författare)
  • Perspectives on the potential for CCS in the European pulp and paper industry
  • 2013
  • Ingår i: Systems Perspectives on Biorefineries 2013. - 9789198097320 ; , s. 81-91
  • Bokkapitel (övrigt vetenskapligt/konstnärligt)abstract
    • The Pulp and Paper Industry (PPI), like other energy-intensive industry branches, is suitable for implementation of carbon capture and storage (CCS) since they have large on-site emissions of CO2 and usually also excess heat available which can be utilised in the capture process. Further, since a large share of the CO2 emissions associated with the European PPI originates from biomass, if CCS is implemented the levels of CO2 in the atmosphere can be further reduced in com- parison to implementing CCS only on fossil emission sources, i.e. provided the biomass is grown in a sustainable way. This fact makes CCS within the European PPI an interesting alternative.1 This chapter assumes that world governments adopt policy measures that stimulate significant CO2 reductions and the purpose of this chapter is to discuss CCS as an option for the PPI to significantly reduce its CO2 emissions. The chapter gives an introduction to CCS in general and CCS in the PPI in particular. Some main opportunities and challenges are presented and discussed and an example of the potential for CCS in the European PPI is presented. The chapter ends with a list of main conclusions.
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25.
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26.
  • Karlsson, Ida, 1980, et al. (författare)
  • Mistra Carbon Exit Technical roadmap - Buildings and transport infrastructure
  • 2020
  • Rapport (övrigt vetenskapligt/konstnärligt)abstract
    • This report explores different possible trajectories of technological developments in the supply chains of buildings and transportation infrastructure. By linking short-term and long-term goals with specific technology options, the Mistra Carbon Exit roadmaps describe key decision points and potential synergies, competing goals and lock-in effects. The analysis combines quantitative analytical methods, i.e. scenarios and stylized models, with participatory processes involving relevant stakeholders in the roadmap assessment process. The roadmaps outline material and energy flows along with costs associated with different technical and strategical choices and explore interlinkages and interactions across sectors. The results show how strategic choices with respect to process technologies, energy carriers and the availability of biofuels, carbon capture, transport and storage (CCS) and carbon neutral electricity may have very different implications on energy use and CO2 emissions over time.
  •  
27.
  • Karlsson, Ida, 1980, et al. (författare)
  • Mistra Carbon Exit Technical roadmap - Cement industry
  • 2020
  • Rapport (övrigt vetenskapligt/konstnärligt)abstract
    • This report explores different possible trajectories of technological developments in the primary production of cement. By linking short-term and long-term goals with specific technology options, the Mistra Carbon Exit roadmaps describe key decision points and potential synergies, competing goals and lock-in effects. The analysis combines quantitative analytical methods, i.e. scenarios and stylized models, with participatory processes involving relevant stakeholders in the roadmap assessment process. The roadmaps outline material and energy flows along with costs associated with different technical and strategical choices and explore interlinkages and interactions across sectors. The results show how strategic choices with respect to process technologies, energy carriers and the availability of biofuels, carbon capture, transport and storage (CCS) and carbon neutral electricity may have very different implications on energy use and CO2 emissions over time.
  •  
28.
  • Karlsson, Ida, 1980, et al. (författare)
  • Roadmap for climate transition of the building and construction industry – a supply chain analysis including primary production of steel and cement
  • 2020
  • Ingår i: Eceee Industrial Summer Study Proceedings. - 2001-7987 .- 2001-7979. ; 2020-September, s. 67-77
  • Konferensbidrag (refereegranskat)abstract
    • Sweden has, in line with the Paris agreement, committed to reducing greenhouse gas emissions to net-zero by 2045. Emissions arising from manufacturing, transporting and processing of construction materials to buildings and infrastructure account for approximately one fifth of Sweden’s annual CO2 emissions. This work provides a roadmap with an analysis of different pathways of technological developments in the supply chains of the buildings and construction industry, including primary production of steel and cement. By matching short-term and long-term goals with specific technology solutions, these pathways make it possible to identify key decision points and potential synergies, competing goals and lock-in effects. The analysis combines quantitative analysis methods, including scenarios and stylized models, with participatory processes involving relevant stakeholders in the assessment process. The roadmap outline material and energy flows associated with different technical and strategical choices and explores interlink-ages and interactions across sectors. The results show that it is possible to reduce CO2 emissions associated with construction of buildings and transport infrastructure by 50 % to 2030 and reach close to zero emissions by 2045, while indicating that strategic choices with respect to process technologies, energy carriers and the availability of biofuels, CCS and zero CO2 electricity may have different implications on energy use and CO2 emissions over time. The results also illustrate the importance of intensifying efforts to identify and manage both soft (organisation, knowledge sharing, competence) and hard (technology and costs) barriers and the importance of both acting now by implementing available measures (e.g. material efficiency and material/fuel substitution measures) and actively planning for long-term measures (low-CO2 steel or cement). Unlocking the full potential of the range of emission abatement measures will require not only technological innovation but also innovations in the policy arena and efforts to develop new ways of cooperating, coordinating and sharing information between actors.
  •  
29.
  • Karlsson, Ida, 1980, et al. (författare)
  • Roadmap for Decarbonization of the Building and Construction Industry - A Supply Chain Analysis Including Primary Production of Steel and Cement
  • 2020
  • Ingår i: Energies. - : MDPI AG. - 1996-1073 .- 1996-1073. ; 13:16
  • Tidskriftsartikel (refereegranskat)abstract
    • Sweden has committed to reducing greenhouse gas (GHG) emissions to net-zero by 2045. Around 20% of Sweden's annual CO(2)emissions arise from manufacturing, transporting, and processing of construction materials for construction and refurbishment of buildings and infrastructure. In this study, material and energy flows for building and transport infrastructure construction is outlined, together with a roadmap detailing how the flows change depending on different technical and strategical choices. By matching short-term and long-term goals with specific technology solutions, these pathways make it possible to identify key decision points and potential synergies, competing goals, and lock-in effects. The results show that it is possible to reduce CO(2)emissions associated with construction of buildings and transport infrastructure by 50% to 2030 applying already available measures, and reach close to zero emissions by 2045, while indicating that strategic choices with respect to process technologies and energy carriers may have different implications on energy use and CO(2)emissions over time. The results also illustrate the importance of intensifying efforts to identify and manage both soft and hard barriers and the importance of simultaneously acting now by implementing available measures (e.g., material efficiency and material/fuel substitution measures), while actively planning for long-term measures (low-CO(2)steel or cement).
  •  
30.
  • Karlsson, Sebastian, 1994, et al. (författare)
  • Modeling the development of a carbon capture and transportation infrastructure for Swedish industry
  • 2023
  • Ingår i: International Journal of Greenhouse Gas Control. - : Elsevier BV. - 1750-5836. ; 124
  • Tidskriftsartikel (refereegranskat)abstract
    • This work presents and applies a mixed integer programming (MIP) optimization model that minimizes the net present costs for CO2 capture and storage (CCS) systems for cases with defined emissions costs and/or capture targets. The model covers capture from existing large point sources of CO2 emissions in Sweden, liquefaction, intermediate storage and transportation using trucks to hubs on the coast, followed by ship transport to a storage location (excluding storage cost). The results show that the capture and transportation infrastructure, in terms of both the sites chosen for capture and the associated transportation setup, differs depending on whether the system is incentivized to capture biogenic or fossil CO2, or both. Waste-fired combined heat and power (CHP) plants are only chosen for capture at scale when biogenic capture targets and fossil emissions costs are combined, since the emissions from these sites comprise a combination of biogenic and fossil CO2. The value for the system in mitigating the costs from fossil CO2 emissions exceeds the increased cost of BECCS at waste-fired CHPs compared to larger pulp mills given the fossil emissions cost development assumed in this work. Although the cost for capture and liquefaction dominates the total cost of the CCS system, it is not the only factor determining the choice of sites for capture. Proximity to transport hubs with short offshore transportation distances to the final storage location is also an important factor. For the transportation infrastructure, it is shown that the cost for ships is the main cost driver.
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31.
  • Kjärstad, Jan, 1956, et al. (författare)
  • Development of a methodology to analyze the geographical distribution of CCS plants and ramp-up of CO2-flow over time
  • 2014
  • Ingår i: Energy Procedia. - : Elsevier BV. - 1876-6102. ; 63, s. 6871-6877
  • Konferensbidrag (refereegranskat)abstract
    • Development of large scale CO2 transport systems will obviously depend on geographical distribution of CCS installations and CO2 volumes over time and their location relative to appropriate storage sites with sufficient injectivity. However, installation of CCS at any facility is likely to be based on company specific planning and company specific strategies with the risk that there will be a considerable geographical spread of such installations over time leading to several small scale and single source-sink transport systems which will be more costly, affect the surroundings more and potentially also lead to increased local opposition to CCS. Additionally, such a development is also likely to require longer overall lead times since each system will have to be treated individually by for instance permitting authorities. This paper presents a methodology to distribute capture installations and captured volumes geographically over time in order to identify, analyze and visualize potential problems related to large scale build-up of CCS installations within Europe.
  •  
32.
  • Kjärstad, Jan, 1956, et al. (författare)
  • Modelling large-scale CCS development in Europe linking technoeconomic modelling to transport infrastructure
  • 2013
  • Ingår i: Energy Procedia. - : Elsevier BV. - 1876-6102. ; 37, s. 2941-2948
  • Konferensbidrag (refereegranskat)abstract
    • This paper a studies the potential lay-out of CCS infrastructure in Europe, by combining techno-economic modelling of Europs's electricity sector with a detailed modelling and analysis of a CO2 transport infrastructure. First, the electricity sector is described using the Chalmers Electricity Investment Model, which, for each EU member state, yields the technology mix including CCS - until the year 2050. The model gives the lowest system cost under a given CO2 emission reduction target. Thus, the model gives the annual flows of CO2 being captured by country and fuel. Secondly, these flows are used as input to InfraCCS, a cost optimization tool for bulk CO2 pipelines. Finally, the results from InfraCCS are applied along with Chalmers databases on power plants and CO2 storage sites to design the development over time of a detailed CO2 transport network across Europe considering the spatial distribution of power plants and storage locations. Two scenarios are studied: with and without onshore aquifer storage. The work shows that the spatial distribution of capture plants over time along with individual reservoir storage capacity and injectivity are key factors determining routing and timing of the pipeline network. The results of this work imply that uncertainties in timing for installation of capture equipment in combination with uncertainties related to accurate data on storage capacity and injectivity on reservoir level risk to seriously limit the build-up of large-scale pan-European CO2 transportation networks. The study gives that transport cost will more than double if aquifer storage is restricted to offshore reservoirs. Thus, it is found that the total investments for the pan-European pipeline system is € 31 billion.when storage in onshore aquifers is allowed and € 72 billion. if aquifer storage is restricted to offshore reservoirs with corresponding specific cost of € 5.1 to € 12.2 CO2 transported.
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33.
  • Lehtveer, Mariliis, 1983, et al. (författare)
  • Actuating the European Energy System Transition: Indicators for Translating Energy Systems Modelling Results into Policy-Making
  • 2021
  • Ingår i: Frontiers in Energy Research. - : Frontiers Media SA. - 2296-598X. ; 9
  • Tidskriftsartikel (refereegranskat)abstract
    • In this paper, we define indicators, with a focus on the electricity sector, that translate the results of energy systems modelling to quantitative entities that can facilitate assessments of the transitions required to meet stringent climate targets. Such indicators, which are often overlooked in model scenario presentations, can be applied to make the modelling results more accessible and are useful for managing the transition on the policy level, as well as for internal evaluations of modelling results. We propose a set of 13 indicators related to: 1) the resource and material usages in modelled energy system designs; 2) the rates of transition from current to future energy systems; and 3) the energy security in energy system modelling results. To illustrate its value, the proposed set of indicators is applied to energy system scenarios derived from an electricity system investment model for Northern Europe. We show that the proposed indicators are useful for facilitating discussions, raising new questions, and relating the modelling results to Sustainable Development Goals and thus facilitate better policy processes. The indicators presented here should not be seen as a complete set, but rather as examples. Therefore, this paper represents a starting point and a call to other modellers to expand and refine the list of indicators.
  •  
34.
  • Norwood, Zack, 1979, et al. (författare)
  • The Future of the European Electricity Grid Is Bright: Cost Minimizing Optimization Shows Solar with Storage as Dominant Technologies to Meet European Emissions Targets to 2050
  • 2017
  • Ingår i: Energies. - : MDPI AG. - 1996-1073 .- 1996-1073. ; 10:12
  • Tidskriftsartikel (refereegranskat)abstract
    • The European roadmap for the power sector dictates an 80–95% cut of existing levels of carbon dioxide emissions is needed by the year 2050 to meet climate goals. This article describes results from a linear cost optimization investment model, ELIN, coupled with a solar technology model, Distributed Concentrating Solar Combined Heat and Power (DCS-CHP), using published investment costs for a comprehensive suite of renewable and conventional electricity generation technologies, to compare possible scenarios for the future electricity grid. The results of these model runs and sensitivity analyses indicate that: (1) solar photovoltaics (PV) with battery storage will likely play a very large role in meeting European targets; (2) concentrating solar power (CSP) with thermal energy storage is at a slight economic disadvantage with respect to PV to compete economically; (3) the economic potential of wind power is only comparable with solar PV if high wind penetration levels are allowed in the best wind sites in Europe; and (4) carbon capture and nuclear technologies are unlikely to compete economically with renewable technologies in creating a low-carbon future grid.
  •  
35.
  • Nyholm, Emil, 1984, et al. (författare)
  • An economic assessment of distributed solar PV generation in Sweden from a consumer perspective - The impact of demand response
  • 2017
  • Ingår i: Renewable Energy. - : Elsevier BV. - 0960-1481 .- 1879-0682. ; 108, s. 169-178
  • Tidskriftsartikel (refereegranskat)abstract
    • We present an economic assessment of the impacts of Demand Response (DR) and pricing schemes on the conditions for distributed solar photovoltaics, with the focus on individual households. An optimization model has been developed that minimizes the electricity cost for individual households with the option of dispatching DR loads. DR of appliances and hydronic heating (electrical water heating for both space heating and hot water) are investigated, as well as the effects of applying a monthly, hourly or net metering pricing scheme for selling excess generated electricity and a tax reduction scheme for electricity sold to the grid. We show that for Swedish conditions a monthly net metering pricing scheme would result in the largest PV installations per household (median rated capacity of 4.21 Wpihousehold). The use of the tax reduction scheme reduces the installation per household (2.1 kWp/household), but with an installation being profitable for a larger fraction of the households. Furthermore, the tax reduction scheme retains an incentive for engaging in DR. The use of hydronic DR can support the same installations sizes as the tax reduction scheme, whilst Appliance DR is shown to have only a low impact on the profitability of a PV installation. (C) 2017 Elsevier Ltd. All rights reserved.
  •  
36.
  • Nyholm, Emil, 1984, et al. (författare)
  • Demand response potential of electrical space heating in Swedish single-family dwellings
  • 2016
  • Ingår i: Building and Environment. - : Elsevier BV. - 0360-1323. ; 96:1, s. 270-282
  • Tidskriftsartikel (refereegranskat)abstract
    • This paper investigates the potential and economics of electrical space heating in Swedish single-family dwellings (SFDs) to provide Demand Response (DR) for the electricity load in Sweden.A dynamic and detailed building-stock model, is used to calculate the net energy demand by end-use of a set of sample buildings taken as representative of all Swedish SFDs with electrical heating. A new sub-model optimizes the dispatch of heating systems on an hourly basis, for each representative building, minimizing the cost of electricity purchased from the hourly spot market.The analysis of the Swedish SFD buildings indicates a technical DR capacity potential of 7.3 GW, which is considerable and can be used for the management of intermittent electricity generation. This potential could also prove to be valuable in the operating reserve market. However, this requires that the DR, rather than being governed by a single hourly electricity price signal, would instead be subject to a more centralized control. The modeling shows that DR can be expected to result in up to 5.5 GW of decreased load and 4.4 GW of increased load, if applying current Swedish electricity prices. The modeling shows that DR shifts up to 1.46 TWh of electric heating, corresponding to 1% of total Swedish electricity demand. The potential savings from DR for individual SFDs is found to be low, 0.9–330 €/year, given current Swedish electricity prices.
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37.
  • Nyholm, Emil, 1984, et al. (författare)
  • Solar photovoltaic-battery systems in Swedish households - Self-consumption and self-sufficiency
  • 2016
  • Ingår i: Applied Energy. - : Elsevier BV. - 1872-9118 .- 0306-2619. ; 183, s. 148-159
  • Tidskriftsartikel (refereegranskat)abstract
    • This work investigates the extent to which domestic energy storage, in the form of batteries, can increase the self-consumption of electricity generated by a photovoltaic (PV) installation. The work uses real world household energy consumption data (measurements) as the input to a household energy consumption model. The model maximizes household self-sufficiency, by minimizing the amount of electricity purchased from the grid, and thereby also maximizing the level of self-consumption of PV electricity, i.e., the amount of PV-generated electricity that is consumed in-house. This is done for different combinations of PV installation sizes (measured in array-to-load ratio; ALR: ratio of the PV capacity to the average annual electric load of a household) and battery capacities for different categories of single-family dwellings in Sweden (i.e., northern latitudes). The modeling includes approximately 2000 households (buildings). The results show that the use of batteries with capacities within the investigated range, i.e., 0.15-100 kW h, can increase the level of self-consumption by a practical maximum of 20-50 percentage points (depending on the load profile of the household) compared to not using a battery. As an example, for a household with an annual electricity consumption of 20 MW h and a PV installation of 7 kW,,, this range in increased self-consumption of PV-generated electricity requires battery capacities in the range of 1524 kW h (actual usable capacity), depending on the load profile of the specific household. The practical maximum range is determined by the seasonality of PV generation at Swedish latitudes, i.e., higher levels of increased self-consumption are possible, however, it would require substantially larger batteries than the up to 100 kW h investigated in this work. Thus, any additional marginal increment in battery capacity beyond the range investigated results in a low level of utilization and poor additional value. Furthermore, our results reveal that when a battery is used to store PV-generated electricity in-house, self-sufficiency increases (as compared to not using a battery) by 12.5-30 percentage points for the upper range of the investigated PV capacities (ALR. of 6). (C) 2016 Elsevier Ltd. All rights reserved.
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38.
  • Odenberger, Mikael, 1977, et al. (författare)
  • Achieving 60 % CO2 reductions within the UK energy system - Implications for the electricity generation sector
  • 2007
  • Ingår i: Energy Policy. - : Elsevier BV. - 0301-4215. ; 35:4, s. 2433-2452
  • Tidskriftsartikel (refereegranskat)abstract
    • This paper explores how investment in the UK electricity generation sector can contribute to the UK goal of reducing CO2 emissions with 60% by the year 2050 relative to the 1990 emissions. Considering likely development of the transportation sector and industry over the period, i.e. a continued demand growth and dependency on fossil fuels and electricity, the analysis shows that this implies CO2 emission reductions of up to 90% by 2050 for the electricity sector. Emphasis is put on limitations imposed by the present system, described by a detailed database of existing power plants, together with meeting targets on renewable electricity generation (RES) including assumptions on gas acting as backup technology for intermittent RES. In particular, it is investigated to what extent new fossil fuelled and nuclear power is required to meet the year 2050 demand as specified by the Royal Commission on Environmental Pollution (RCEP). In addition, the number of sites required for centralized electricity generation (large power plants) is compared with the present number of sites. A simulation model was developed for the analysis. The model applies the UK national targets on RES, taken from Renewable Obligation (RO) for 2010 and 2020 and potentials given by RCEP for 2050, and assumed technical lifetimes of the power plants of the existing system and thus, links this system with targets for the years 2010, 2020 and 2050.The results illustrate the problem with lock-in effects due to long capital stock turnover times, which can either lead to political difficulty meeting targets in established policy or costly early retirement of power plants (stranded assets) to comply with emission goals prescribed in Kyoto targets or the 60% emission reduction goal. Assuming typical technical lifetimes of the power plants it can be concluded that the present electricity generation system continues to play a significant role for several decades generating about 50% of projected electricity demand in 2025. In addition, the results show that although the high degree of fuel switch from coal to natural gas which has taken place in the UK over the last decade (which seems to continue) which enables the UK to fulfill the Kyoto target, the resulting dependency on gas gives a more or less constant level of CO2 emissions between 2010 and 2020. Hence, meeting stricter abatement targets in a second Kyoto period requires emission reductions in other sectors or penetration levels of RES faster than prescribed in the RO.
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39.
  • Odenberger, Mikael, 1977, et al. (författare)
  • CCS in the European electricity supply system - Assessment of national conditions to meet common EU targets
  • 2011
  • Ingår i: Energy Procedia. - : Elsevier BV. - 1876-6102. ; 4, s. 5869-5876
  • Konferensbidrag (refereegranskat)abstract
    • This paper investigates how the European electricity generation system can meet deep cuts in CO2 emissions until the year 2050 with special focus on national conditions for CCS. An 85% reduction in CO2 emissions until 2050 is imposed. The analysis is carried out with a techno-economic model (minimizing the system cost) including a detailed description of the present stationary European electricity generation system (power plants) and potential CO2 storage sites as obtained from the Chalmers Energy Infrastructure Database. The modeling puts a cap on CO 2 emissions from the system which gives a price on these emissions, i.e. similar to the effect of the European Emission Trading Scheme (EU-ETS), which is the main policy instrument for controlling GHG emissions within EU. Emphasize is put on analyzing turn-over in capital stock of the existing power plant infrastructure, timing of investments and the infrastructural implications of large scale introduction of CCS on a regional perspective, including the effect of investing in new transmission capacity between member states. The work compares two scenarios, one used in a previous work with significant growth in electricity consumption and one assuming that energy efficiency measures are successfully applied in line with the recent EU energy policy package. The results show that it is possible to meet an 85% CO2 reduction target by 2050 at a cost of some 50 to 80€/ton CO2 over the period up to 2050, but this will require large contributions from CCS and electricity from renewable sources (mainly wind and biomass). Yet, without significant energy efficiency measures it is questionable if such large investments in generation technologies are feasible. Thus, to reach an 85% reduction in CO2 emissions from the electricity generation system by 2050 is not a matter of choice between different technologies and energy efficiency measures but all of these are required and the crucial point is if there will be a high enough price on CO2 emissions.
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40.
  •  
41.
  • Odenberger, Mikael, 1977, et al. (författare)
  • Integrating electric vehicles in electricity system models – representing individual driving patterns
  • 2018
  • Ingår i: 31st International Electric Vehicle Symposium and Exhibition, EVS 2018 and International Electric Vehicle Technology Conference 2018, EVTeC 2018. ; 2, s. 1020-1026
  • Konferensbidrag (refereegranskat)abstract
    • This study takes initial steps in developing a method that includes a representation of road transportation demand on individual EV level (based on GPS driving measurements) in an optimisation electricity system model to also represent the spread in the individual driving patterns. The main conclusions are that different driving profiles do have an impact on the charging and discharging back to grid depending on the individual driving distance, battery capacity and driving profile. This have shown to have an impact on, e.g. investments in peak power and the potential role of EVs facilitating the integration of more intermittent renewable power.
  •  
42.
  • Odenberger, Mikael, 1977 (författare)
  • Pathways for the European electricity supply system to 2050 – Implications of stringent CO2 reductions
  • 2009
  • Doktorsavhandling (övrigt vetenskapligt/konstnärligt)abstract
    • This thesis, which consists of four separate papers, investigates possible pathways forthe European electricity supply systems to meet stringent CO2 emission reductions.Assessments are made for single EU member states, selected regions and the EU as awhole. The analyses are based on modelling scenarios with the aid of a technoeconomicmodel developed during the thesis work. This model has the objective offinding cost-efficient investment strategies within the electricity supply system untilmid-century (2050). Special emphasis is put on the transition from the present systemto a system which meets stringent CO2 reduction targets, considering timing of newinvestments and technology choices. Thus, the existing capital stock (power plants)is included in the model through application of a detailed database, the Chalmersenergy infrastructure database, providing information (e.g. fuel type, capacity andage structure) on present and planned power plants down to block level for Europeanpower plants. Assuming technical lifetimes for power plants in the database givesresidual capacities remaining over the period studied, which together with newinvestments meet projected electricity demand. New investment options are limitedto presently known technologies and aggregated into technology classes (e.g. hardcoal condensing power and onshore wind power). European analyses includeassessments of fully integrated markets for electricity, CO2 emission allowances anda joint European effort to meet the targets for renewables.The results indicate that technology options at hand and efficiency measures can helpto reduce CO2 emissions from European electricity supply substantially. The studiespresented here assume emission reductions within the electricity sector of up to 85%by 2050, compared to 1990 emission levels. To meet these goals, however,significant changes are required in the current infrastructures of the electricity-supplysystem. The challenge is not due to a lack in technologies – these are available atcosts which should not be prohibitive for society and which, indeed, are expectedfrom the EU Emission Trading Scheme (ETS) – but due to the large investmentramp-up required and to fuel-market implications as well as the institutional andlogistic challenges (permitting procedures, establishing CO2 transportation systems,finding sites for wind power etc). Key measures included in this research are CarbonCapture and Storage (CCS) and large-scale employment of renewables in electricitygeneration. In addition, it can be seen that efficiency measures to reduce electricitydemand are of great importance to reduce the strain in capacity ramp-up of CCS andrenewables. Common targets on CO2 emission reductions point to differentiatedstrategy between member states. Thus, regions which currently have high carbonintensity and are located near suitable storage sites will benefit most from CCSimplementation, whereas other regions have large potential for renewable electricitygeneration (e.g. coastal areas with high expectations in annual average load hours forwind power). Finally, this study has presupposed that emission targets must be met.The focus has been on how to meet the targets and what implications we may expectfrom different technological choices that are at hand in order to meet these targets.However, it is also clear in this analysis that the investigated technological transitionswill not come about automatically. Additional policy measures will be necessary.The EU-ETS, as we know it today, is merely a beginning.
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43.
  • Odenberger, Mikael, 1977, et al. (författare)
  • Pathways for the European electricity supply system to 2050—The role of CCS to meet stringent CO2 reduction targets
  • 2010
  • Ingår i: International Journal of Greenhouse Gas Control. - : Elsevier BV. - 1750-5836. ; 4:2, s. 327-340
  • Tidskriftsartikel (refereegranskat)abstract
    • This paper investigates the role of CCS technologies as part of a portfolio for reducing CO2 emissions fromthe European electricity supply system until the year 2050. The analysis is carried out with the aid of atechno-economic model (with the objective to minimize the total system cost) including a detaileddescription of the present stationary European electricity supply system (power plants) and potentialCO2 storage sites as obtained from the Chalmers Energy Infrastructure databases. The ability of differentEU Member States and regions to facilitate and to benefit from CCS will most likely depend on localconditions in terms of current energy mix, fuel supply chains and distance to suitable storage locations.Special emphasis is therefore put on analyzing turn-over in capital stock of the existing power plantinfrastructure, timing of investments and the infrastructural implications of large scale introduction ofCCS on a regional perspective. The paper discusses the role of and the requirements on CCS for meetingstrict CO2 emission reduction targets of 85% reduction from power generation by 2050 relative 1990emissions in three different scenarios. All analysed scenarios apply the same cap on CO2 emissions. Thefirst scenario includes a continued growth in electricity demand (as presented in EU base-lineprojections). The second scenario includes stated EU targets for 2020 and indicative targets for 2050 withrespect to increased energy efficiency, and thus, considers a lower growth in electricity demandcompared to the base-line. The third scenario includes EU targets (to 2020 and indicative targets to 2050)on energy efficiency, equal to the second scenario, and EU targets of electricity from renewables.The results show that it is possible for the European electricity generation system to meet an 85% CO2reduction target by 2050 with a potentially large contribution from CCS. Up to 50% of the electricitygeneration will come from plants with CCS with a peak capture estimated to 1.8 GtCO2 per year andcumulative CO2 capture of about 39 GtCO2 between 2020 and 2050 (it is assumed that CCS will becommercially available from 2020). As expected, countries which currently have high carbon intensityand which are located nearby suitable storage sites will benefit the most from CCS implementation.Hence, the results suggest that Italy has the largest demand for CCS with annual peak capture at around0.5 GtCO2 in the base-line scenario. The model results indicate a steep ramp-up of CCS post-2020, whichimposes challenges for timely investments in corresponding CCS infrastructure including transportationand storage. A continued growth in electricity demand can lead to demand for CCS to such extent (in thebase-line capacity build up is about 300 GW of CCS between 2020 and 2050) that the actual penetrationlevel could be limited by fuelmarkets and power industries’ ability to supply fuel and CCS power plants.
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44.
  • Odenberger, Mikael, 1977, et al. (författare)
  • Pathways for the North European electricity supply
  • 2009
  • Ingår i: Energy Policy. - : Elsevier BV. - 0301-4215. ; 37:5, s. 1660-1677
  • Tidskriftsartikel (refereegranskat)abstract
    • This paper investigates the development of the electricity-supply systems in Northern Europe(Germany, UK, Denmark, Finland, Sweden and Norway) until the year 2050. The focus is onthe response to an assumed common stringent CO2-reduction target and on the role of carbon captureand storage technologies (CCS). Special emphasis is put on turn-over in capital stock, timingof investments and the infrastructural implications of large-scale introduction of CCS. The analysis iscarried out through scenario analysis with the aid of a techno-economic model, in which a caseincluding CCS is compared to a case excluding this option. The phase out of the present capitalstock (power plants) is included from the Chalmers energy infrastructure databases, which givesinformation on present and planned power plants down to block level for plants exceeding 10MW netelectric power. Assuming technical lifetimes for these plants yield residual capacities in each year, herereferred to as the phase-out pattern. CCS technologies are assumed to become commercially availablein 2020.The age structure of the power plants indicate that full turn-over in capital stock will take severaldecades with the present generation capacities accounting for around 50% of generated electricity in2020. The results show that CO2 emission reductions of 20% and 60% by the years 2020 and 2050,respectively, relative to 1990, can be met at a marginal cost of abatement of about 25–40 h/ton CO2 overthe period studied if CCS is included as an option from 2020. At the same time the marginal cost ofgenerating electricity lies in the range 45–60 h/MWh. Excluding CCS raises the marginal cost ofabatement with about 10 h/ton CO2, whereas the marginal cost of electricity generation increases withroughly 5–10 h/MWh. The CO2 target by the year 2020 is met by implementation of renewableelectricity and fuel shifting from coal to gas. After 2020 CCS technologies constitute an attractive wayfor cost efficient and almost CO2-free base load. However, wide-spread application of CCS is aninfrastructural challenge with respect to implementing capture plants as well as building up acorresponding CO2 infrastructure for transportation and storage as well as in coal supply systems. Giventhe price assumptions applied, gas may not be competitive once CCS enters the system causing earlyretirements of such units or possibly stranded assets.
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45.
  • Odenberger, Mikael, 1977, et al. (författare)
  • Prospects for CCS in the EU energy roadmap to 2050
  • 2013
  • Ingår i: Energy Procedia. - : Elsevier BV. - 1876-6102. ; 37, s. 7573-7581
  • Konferensbidrag (refereegranskat)abstract
    • The aim of this paper is to estimate the prospects of carbon capture and storage (CCS) in the European electricity supply system taking into account possible forthcoming policy based on the recent EU Energy Roadmap communication, which suggests a 93 to 99% reduction in CO2 emissions relative 1990 levels from the electricity sector by the year 2050. Furthermore, the effect of whether or not onshore storage will be accepted is investigated. The work is based on techno-economic modeling of the European electricity generation sector under different assumptions (scenarios) of the future with respect to electricity demand and fuel prices. The results indicate that the contribution from CCS on a member state level depends on local conditions, e.g., access to local fuels like lignite, and whether or not onshore storage will be allowed. Excluding on-shore storage in aquifers, the modeling results give that CCS is centralized around the North Sea. Natural gas fired conventional power plants is likely to be a serious competitor to coal CCS in the short to medium term providing large emission reduction opportunities by fuel shifting from existing coal power plants to new high efficient gas fired combined cycles. Such development can be a barrier for early deployment of CCS, and hence, result in a delay in commercialization of CCS. The scenarios presented in the Energy Roadmap prescribe power systems almost without net CO2 emissions by 2050, which implies that CCS technologies by the year 2050 must be of a zero-emission type. The modeling presented here indicates in general a large increase in technologies with low CO2 emissions, renewables as well as a significant contribution from CCS technologies, where CCS in the investigated scenarios have the potential to contribute as much as 25-35% of total electricity generation at around year 2050.
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46.
  •  
47.
  • Odenberger, Mikael, 1977, et al. (författare)
  • Ramp-up of CO2 capture and storage within Europe
  • 2008
  • Ingår i: International Journal of Greenhouse Gas Control. - : Elsevier BV. - 1750-5836. ; 2:4, s. 417-438
  • Tidskriftsartikel (refereegranskat)abstract
    • This paper investigates the role of CO2 capture and storage (CCS) technologies as part of a portfolio for reducing CO2 emissions from the European electricity generation system until the year 2050. Special emphasis is put on the ramp-up of CCS with respect to timing of investments and requirement of corresponding CO2 transportation and storage infrastructure. The investigation comprises scenario analysis through modeling possible development of the electricity supply system for EU25 and together with a more detailed analysis of Northern Europe (Germany, UK, Denmark, Finland, Sweden and Norway). The modeling has been carried out with a techno-economic model (minimizing the system cost) including a detailed description of the present stationary European electricity generation system as obtained from the Chalmers Energy Infrastructure database.It is concluded that CCS can play a significant role in reducing CO2 emissions at a cost in the range of 20–60 €/t over the period studied. In EU25 as much as 39 Gt CO2 may be captured over the period 2020–2050 implying a steep ramp-up, i.e. most CCS capacity is added during the first two decades after 2020 from which it is assumed to be commercially available. Corresponding capture in Germany and UK amounts to 9 and 4 Gt, respectively. The analysis show that a transportation infrastructure can be put in place for about 2–5 €/t CO2. However, the steep ramp-up obtained from the model obviously do not take into account other issues which must be resolved for a large scale implementation of CCS. Examples of such issues are discussed in the paper and concern establishment of a legal framework regulating subsurface storage of CO2, inclusion of captured CO2 in the European Union emission trading scheme and issues related to fuel markets and fuel supply to accommodate an increased use of coal as a fuel.
  •  
48.
  • Odenberger, Mikael, 1977, et al. (författare)
  • The role of CCS in the European electricity supply system
  • 2009
  • Ingår i: Energy Procedia. - : Elsevier BV. - 1876-6102. ; 1:1, s. 4273-4280
  • Konferensbidrag (refereegranskat)abstract
    • This paper investigates the role of CO2 capture and storage (CCS) technologies as part of a portfolio for reducing CO2 emissionsfrom the European electricity supply system until the year 2050. The analysis is carried out with a techno-economic model(minimizing the system cost) including a detailed description of the present stationary European electricity generation system(power plants) and potential CO2 storage sites as obtained from the Chalmers Energy Infrastructure Database. Since the ability ofdifferent EU Member States and regions to facilitate and to benefit from CCS will most likely depend on local conditions interms of current energy mix, fuel supply chains and distance to suitable storage locations, special emphasize is put on analyzingturn-over in capital stock of the existing power plant infrastructure, timing of investments and the infrastructural implications oflarge scale introduction of CCS on a regional perspective. The paper discusses the role of and requirements on CCS for meetingstrict emission targets of 85% reduction while having a continued growth in electricity demand (according to EU projections).The results show that it is possible to meet an 85% CO2 reduction target by 2050, but this will require large contribution fromCCS. As expected, regions which are currently high in carbon intensity and which are located nearby suitable storage sites willbenefit mostly from CCS as an option. With the assumption that CCS will be commercially available in 2020 the model resultsgive a steep ramp-up in the use of CCS post 2020 which imposes challenges for timely investments in corresponding CCSinfrastructure.
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49.
  • PERSPEKTIV PÅ FÖRNYBAR EL
  • 2015
  • Samlingsverk (redaktörskap) (refereegranskat)abstract
    • El driver en ökande mängd mänskliga aktiviteter och har utvecklats till industrisamhällets livsnerv. Trots energieffektiviserande åtgärder kommer den globala efterfrågan på elkraft sannolikt att fortsätta att växa i årtionden framöver. I sig är el en ren och lättanvänd energibärare, men produktionen av elenergi från icke-förnybara energikällor leder till klimatförändringar och miljöproblem och skapar inte sällan sociala och politiska dilemman. En radikal omställning till förnybar elkraft är därför önskvärd. Omställningen till förnybar elenergi är dock inte problemfri. Det finns många frågor som kräver svar: Finns det tillräckligt med förnybar energi för att ersätta alla icke förnybara energikällor? Vilken miljöpåverkan har produktion och användning av nya typer av kraftverk? Hur balanseras tillgång och efterfrågan när solen inte lyser och vinden inte blåser? Vad krävs av beslutsfattare och investerare för att en storskalig expansion av den nya tekniken skall komma till stånd och hur genomförs förändring om etablerade maktstrukturer hotas av det nya som vill in? Det saknas slutgiltiga svar på dessa och andra viktiga frågor. Men om vi studerar förnybar el från olika perspektiv kan vi berika bilden, döda myter, klargöra konflikter och fördjupa förståelsen. Perspektiv på förnybar el är en levande e-bok med regelbundna uppdateringar. Du kanske också vill läsa böckerna "Perspektiv på eldrivna fordon" och "Perspektiv på förädling av bioråvara".
  •  
50.
  • Perspektiv på förnybar el 2014
  • 2014
  • Samlingsverk (redaktörskap) (refereegranskat)abstract
    • MÖJLIGHETER OCH UTMANINGAR MED PRODUKTION OCHANVÄNDNING AV EL FRÅN FÖRNYBARA ENERGIKÄLLOREl driver en ökande mängd mänskliga aktiviteter och har utvecklats till industrisamhälletslivsnerv. Trots energieffektiviserande åtgärder kommer den globala efterfråganpå elkraft sannolikt att fortsätta att växa i årtionden framöver. I sig är el enren och lättanvänd energibärare, men produktionen av elenergi från icke-förnybaraenergikällor leder till klimatförändringar och miljöproblem och skapar inte sällansociala och politiska dilemman. En radikal omställning till förnybar elkraft är därförönskvärd.Omställningen till förnybar elenergi är dock inte problemfri. Det finns många frågorsom kräver svar: Finns det tillräckligt med förnybar energi för att ersätta alla ickeförnybaraenergikällor? Vilken miljöpåverkan har produktion och användning av nyatyper av kraftverk? Hur balanseras tillgång och efterfrågan när solen inte lyser ochvinden inte blåser? Vad krävs av beslutsfattare och investerare för att en storskaligexpansion av den nya tekniken skall komma till stånd och hur genomförs förändringom etablerade maktstrukturer hotas av det nya som vill in?Det saknas slutgiltiga svar på dessa och andra viktiga frågor. Men om vi studerarförnybar el från olika perspektiv kan vi berika bilden, döda myter, klargöra konflikteroch fördjupa förståelsen.
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