Gothenburg, Sweden
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Agency: Cordis | Branch: FP7 | Program: CP | Phase: ENERGY.2012.8.8.2 | Award Amount: 26.01M | Year: 2013

The CELSIUS City Consortium is going to deploy 12 new technically and economically innovative demonstrators. Another up to 20 state-of-art demonstrators (already in operation) will proof the CELSIUS City Concept covering the full FP7 8.8.2 requirements. CELSIUS has a clear strategy and a pro-active approach to Market Outreach, which will strive to commit 50 new cities to the CELSIUS Roadmap by the end of 2016. When fully implemented, this will lead to 20-45 TWh reduction in the use of primary energy p.a. CELSIUS City is well positioned to deliver those targets due a strong partnership of major front running European cities and their respective utilities, and further outstanding innovative organizations, with track records both in creating technically and economically innovative demonstrators, as well as in understanding and overcoming the barriers for large scale deployment (e.g. Imperial College (UK), SP (S), TU Delft (NL), Cologne University of Applied Sciences (D), DAppalonia (IT), LSE (UK)). CELSIUS has eight work packages targeting on the successful deployment of the 13 new demonstrators (WP3), supported by a collaborative approach to harvest beyond state-of-the-art insights from Tech & Innovation (WP5) and Stakeholder Acceptance (WP6). The local demonstrator perspective is enriched by the Integration & Roadmap (WP2). The final goal for Communication & Market Outreach (WP8) is based on developing the CELSIUS in the Market Uptake (WP7). A powerful project management office (WP1), seconded by rigor monitoring (WP4), coordinates all work packages and assuring over the time of the CELSIUS Consortium, both impactful deployment and sustainable market outreach. The total cost of the CELSIUS 13 new demonstrators is 69m EUR, of which the cities themselves will provide 55m EUR. The requested EU funding enables these activities laying the foundation for the successful large scale deployment of the CELSIUS City Concept across Europe and beyond 2020.

Svensson E.,Chalmers University of Technology | Eriksson K.,Goteborg Energi AB | Wik T.,Chalmers University of Technology
Biofuels, Bioproducts and Biorefining | Year: 2015

The implementation of a biorefinery concept through the integration of new biomass conversion processes with existing industrial plants offers a potential for high overall biomass-to-product efficiencies and cost-effective production. To reach this potential, a high degree of process integration is essential. This implies that there will be strong interconnections between the different processing units in the original plant and the new biorefinery process, and thereby a risk of operability difficulties. Consequently, there is a need to consider operational objectives, together with economic and environmental ones in biorefinery integration design problems. This paper focuses on the operability of an industrial plant that is retrofitted with a new biorefinery process. The existing industrial plant is considered to be an energy-intensive, mature, commodity-producing plant and retrofit of this plant is necessary for enabling efficient integration and synergy effects of co-locating the biorefinery process with the existing process, instead of building a stand-alone greenfield plant. A wide range of operability issues associated with the integration of the biorefinery is considered, including flexibility, controllability, and reliability. The main issues that affect the operability when integrating a new biorefinery process to an existing industrial plant are investigated. Core operability issues to consider in the design and evaluation of future biorefinery concepts are highlighted and opportunities for further research and methodology development activities are identified. © 2014 Society of Chemical Industry and John Wiley & Sons, Ltd.

Isaksson J.,Chalmers University of Technology | Asblad A.,Goteborg Energi AB | Berntsson T.,Chalmers University of Technology
Biomass and Bioenergy | Year: 2013

Integration of biomass gasification with a pulp and paper mill is a possible route to create more value-added products. This route facilitates, for example, more advanced electricity generation and production of biomass based transportation fuels or chemical feedstock. Each unit operation in such a process affects overall efficiency as well as possibilities for process integration. In this paper, the impact of different dryer types in a biomass gasification combined cycle (BIGCC) has been evaluated in terms of efficiency and economic performance. The BIGCC was sized so that the excess heat would replace the current steam production from bark and oil. The results show that the dryer type can have a significant impact on economic performance and efficiencies. A BIGCC with an integrated belt dryer, utilizing excess heat to heat the drying air from the mill, can result in electrical efficiencies of up to around 40%, while e.g. a steam dryer can reach 36-37%. Choice of oxidant, air or oxygen, in the gasifier affects both capital and operational cost. Air was proven to be the most cost efficient solution for the cases evaluated in this study. The investment of around 100 to 140 million Euros for a BIGCC facility is profitable for most evaluated cases for an annuity factor of 0.1, while the net annual profit is negative for most cases when the annuity factor was increased to 0.2, even when including financial support for renewable electricity. © 2013 Elsevier Ltd.

Andersson V.,Chalmers University of Technology | Franck P.-A.,Goteborg Energi AB | Berntsson T.,Chalmers University of Technology
Energy Procedia | Year: 2013

A study has been conducted in order to investigate how the specific heat requirements in the stripper reboiler of a MEA capture plant changes with changing temperature. It was found that the increase in heat demand is dramatic when lowering the temperature, approximately 40% when the temperature changes from 120 to 90° C. Heat integration with a refinery was also studied, and showed that even if the heat demand was larger for the lower temperature the heat integration possibilities were also larger for the base case.

Paulinder J.,Goteborg Energi AB
IET Conference Publications | Year: 2013

With the new network regulation model in Sweden, the financial reality for the network utilities has become tougher. It is more important than ever to ensure that the right investments are made. Reliability analysis is a tool to improve the basis for decision making when planning an investment. It can be seen as a way of quantifying the quality of supply. The result can then, together with economical and other technical aspects, form a thorough base for the decision-making process. Goteborg Energi Nat AB has recently introduced reliability analysis as a tool in network planning. The method is used to compare different investment alternatives, and to ascertain whether a planned investment will result in the expected improvement in quality of supply. This paper shows, using a practical example, how the theories of reliability analysis can be applied, what land of results to expect and how these results can be implemented.

Johansson D.,Goteborg Energi AB | Franck P.-T.,Goteborg Energi AB | Berntsson T.,Chalmers University of Technology
Energy | Year: 2012

In this paper, the global CO 2 effect of integrating different biomass gasification concepts to meet an increasing demand of hydrogen in an oil refinery is examined and presented in comparison with a conventional steam reformer. The studied refinery is a hydro skimming refinery with a future hydrogen deficit of 16,000Nm 3/h. Three gasification concepts are considered: Entrained Flow (EF), Circulated Fluidised Bed (CFB) and Double Bed (DB). The system analysis is made with respect to global CO 2 emissions and primary energy use. The results show that if biomass is considered as an unlimited resource (i.e. sufficient biomass is considered to be available to substitute for all fossil fuels in society), biomass gasification concepts have a potential to reduce CO 2 emissions. The EF case shows the largest reduction potential. However, if biomass is considered as a limited resource (i.e. increased use of biomass at the refinery will lead to increased use of fossil fuel elsewhere in society), all concepts show an increase of CO 2 emissions. Here, the CFB gasifier shows lowest increase of CO 2 emission. The CO 2 effect of the different alternatives shows sensitivity to assumptions regarding alternative biomass user. © 2011 Elsevier Ltd.

Tuna P.,Lund University | Hulteberg C.,Lund University | Hansson J.,Nordlight AB | Asblad A.,Goteborg Energi AB | Andersson E.,Goteborg Energi AB
Biomass and Bioenergy | Year: 2012

In this paper, the prospect of integrating a combined paper&pulp mill with fuel production via biomass gasification was investigated. In the study, three different types of gasifiers (circulating fluidised bed, entrained flow and indirect gasification) and three fuel processes (dimethyl ether, methanol and Fischer-Tropsch wax synthesis) were investigated using computer simulations. The paper reports differences from the stand-alone cases and the integrated cases, using the electricity equivalence efficiency as a measure. Only 6 out of the 18 integrated cases studied displayed a positive result from integration and no obvious fuel selection that stand out as the most beneficial one, however the synthesis of dimethyl ether is, in combination with all gasifiers assessed a rather good choice, with an change in efficiency from integration ranging from -1% to 4%.Dimethyl ether is not the best choice if the electrical equivalence is to be maximised however. In this case the combination of circulating fluidised bed gasification and methanol synthesis should be pursued. The production of Fischer-Tropsch wax should according to the chosen measure not be produced; however there is an added value in the production of a non-oxygenated fuel which has not been taken into account in this particular study. All cases leads to a reduction of 0.4-0.9 kg CO2 per kg of dry biomass used in the process for fuel synthesis and the possibility to export bark is a more significant factor in this respect than which type of fuel is synthesised. © 2012 Elsevier Ltd.

Holmgren K.M.,Chalmers University of Technology | Holmgren K.M.,IVL Swedish Environmental Research Institute Ltd | Andersson E.,Goteborg Energi AB | Berntsson T.,Chalmers University of Technology | Rydberg T.,IVL Swedish Environmental Research Institute Ltd
Energy | Year: 2014

This study evaluates the potential for reducing life cycle greenhouse gas (GHG) emissions of biomass gasification-based methanol production systems based on energy balances. Configurations which are process integrated with a chemical cluster have been compared to stand-alone units, i.e. units with no connection to any other industry but with the possibility to district heating connection. Two different uses of methanol are considered: the use as a vehicle fuel and the use for production of olefins via the methanol-to-olefins process. An added value of the integration can be the availability of excess hydrogen. For the studied case, the methanol production could be increased by 10% by using excess hydrogen from the cluster. The results show that the integrated systems have greater potential to reduce GHG emissions than the stand-alone systems. The sensitivity analysis demonstrated that the references for electricity production and district heating production technology have important impacts on the outcomes. Using excess heat for district heating was found to have positive or negative impacts on GHG emissions depending on what heat production technologies it replaces. The investigated olefins production systems resulted in GHG emissions reductions that were similar in magnitude to those of the investigated biofuel production systems. © 2014 Elsevier Ltd.

Johansson D.,Chalmers University of Technology | Franck P.-T.,Goteborg Energi AB | Pettersson K.,Chalmers University of Technology | Berntsson T.,Chalmers University of Technology
Energy | Year: 2013

The impact on CO2 emissions of integrating new technologies (a biomass-to-Fischer-Tropsch fuel plant and a post-combustion CO2 capture plant) with a complex refinery has previously been investigated separately by the authors. In the present study these designs are integrated with a refinery and evaluated from the point-of-view of economics and GHG (greenhouse gas emissions) emissions and are compared to a reference refinery. Stand-alone Fischer-Tropsch fuel production is included for comparison. To account for uncertainties in the future energy market, the assessment has been conducted for different future energy market conditions. For the post-combustion CO2 capture process to be profitable, the present study stresses the importance of a high charge for CO2 emission. A policy support for biofuels is essential for the biomass-to-Fischer-Tropsch fuel production to be profitable. The level of the support, however, differs depending on scenario. In general, a high charge for CO2 economically favours Fischer-Tropsch fuel production, while a low charge for CO2 economically favours Fischer-Tropsch fuel production. Integrated Fischer-Tropsch fuel production is most profitable in scenarios with a low wood fuel price. The stand-alone alternative shows no profitability in any of the studied scenarios. Moreover, the high investment costs make all the studied cases sensitive to variations in capital costs. © 2013 Elsevier Ltd.

Johansson D.,Chalmers University of Technology | Franck P.-A.,Goteborg Energi AB | Berntsson T.,Chalmers University of Technology
Energy Conversion and Management | Year: 2013

The application of post-combustion CO2 capture represents an alternative strategy to reduce significantly CO2 emissions from the oil refining industry. Previous studies have shown that the highest costs are related to the provision and use of energy and that these costs could be reduced by utilising excess heat. In the present study, we investigated whether this principle could be applied to the oil refining industry. Four heat supply alternatives were evaluated: Natural Gas Combined Cycle; Natural Gas Boiler; Biomass Boiler; and Excess Heat. These alternatives were evaluated using future energy market scenarios and two levels of heat demand. The Natural Gas Combined Cycle alternative generated high levels of electricity (with CO2 capture), thereby producing the greatest reduction in global CO2 emissions. However, the avoided CO2 emissions from onsite the refinery were highest when excess heat or a biomass boiler was used. In the present study, the capture avoidance cost ranged from 40 to 263 €/tCO 2 avoided (excluding transportation and storage costs), depending on the heat supply alternative used and the heat demand. Moreover, with a high cost for CO2, CO2 capture using excess heat could be a cost-effective alternative to reduce CO2 emissions for oil refineries. © 2012 Elsevier Ltd. All rights reserved.

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