Biomass-based hydrogen for oil refining: Integration and performances of two gasification concepts

Brau, Jean-Florian; Morandin, Matteo

doi:10.1016/j.ijhydene.2013.10.157

Cited by 16 publications

(7 citation statements)

References 19 publications

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“…Thus, renewable hydrogen has been investigated as one possible source to replace hydrogen from fossil fuels. H 2 is required for ammonia and methanol synthesis, as well as in refineries and for energetic purposes [2][3][4][5][6][7]. In 2007, the worldwide hydrogen demand was about 65 million tons, with a growing tendency caused by the greater amounts needed for the hydrotreatment of heavier raw oil fractions [8].…”

Section: Introductionmentioning

confidence: 99%

Hydrogen production from biomass: The behavior of impurities over a CO shift unit and a biodiesel scrubber used as a gas treatment stage

Loipersböck

Lenzi

Rauch

et al. 2017

Korean J. Chem. Eng.

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Most of the hydrogen produced is derived from fossil fuels. Bioenergy2020+ and TU Wien have been working on hydrogen production from biomass since 2009. A pilot plant for hydrogen production from lignocellulosic feedstock was installed onsite using a fluidized bed biomass gasifier in Güssing, Austria. In this work, the behavior of impurities over the gas conditioning stage was investigated. Stable CO conversion and hydration of sulfur components could be observed. Ammonia, benzene, toluene, xylene (BTX) and sulfur reduction could be measured after the biodiesel scrubber. The results show the possibility of using a commercial Fe/Cr-based CO shift catalyst in impurity-rich gas applications. In addition to hydrogen production, the gas treatment setup seems to also be a promising method for adjusting the H 2 to CO ratio for synthesis gas applications.

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Section: Introductionmentioning

confidence: 99%

Hydrogen production from biomass: The behavior of impurities over a CO shift unit and a biodiesel scrubber used as a gas treatment stage

Loipersböck

Lenzi

Rauch

et al. 2017

Korean J. Chem. Eng.

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“…Many studies adopt a bottom-up approach to assess the impact of integrating new technologies into existing processes in order to decrease their carbon footprint. Examples are the integration of biomass-to-hydrogen options (Brau and Morandin, 2014) and Fischer-Tropsch fuels production from biomass (Johansson et al, 2014) in oil refineries, or biomass gasification-based syngas production into petrochemical processes (Arvidsson et al, 2014). For oil refining, there is also a techno-economic analysis of excess heat driven post combustion carbon capture and storage (Andersson et al, 2016).…”

Section: Existing Studies Related To the Assessment Of Process Electrmentioning

confidence: 99%

Bottom–Up Assessment Framework for Electrification Options in Energy-Intensive Process Industries

2020

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Electrification of industrial processes is one of the frequently discussed options to reduce greenhouse gas emissions from energy-intensive industries. This paper presents a bottom-up framework to assess process electrification options for energy-intensive industrial process plants in terms of greenhouse gas emissions and energy costs. The framework is based upon pinch analysis energy targetting methods, and accounts for site-specific conditions, including the effects on heat recovery potential and overall mass and energy balances. Furthermore, interactions between the process site and the background energy system are considered and scenarios are introduced in order to assess the impact of electrification options under different possible future energy market conditions. The framework is illustrated by a case study for an existing chemical plant for which there is a broad variety of electrification options that affect the process in different ways. The option of replacing the natural gas based syngas production unit with electrified syngas and steam production is analysed in detail. The results indicate natural gas savings of 173 MW whereas the electricity demand increases by 267 MW, leading to a strong increase in energy costs but also avoided greenhouse gas emissions of 333 kt/a. For two selected energy market scenarios for 2030 and 2040, the energy costs increase by 59 and 50 M€/a, respectively. The framework can be used to compare electrification with other process greenhouse gas emission reduction measures and to support policy and industrial decision making.

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“…Considerable efforts have been put into decreasing the environmental impact of the refinery process and motor fuel products, for instance by improving the conversion of difficult oil fractions and by extending the refinery to process biomass derived feedstocks, thereby increasing the Considerable efforts have been put into decreasing the environmental impact of the refinery process and motor fuel products, for instance by improving the conversion of difficult oil fractions and by extending the refinery to process biomass derived feedstocks, thereby increasing the renewable share in conventional motor fuels. Opportunities for CO 2 mitigation have been investigated, including integration of large scale biomass gasification based biorefineries [42], or by integration of post-combustion CO 2 capture technologies [43]. In parallel, energy targeting [44] and retrofit studies [45] have also been performed.…”

Section: The Refinery Case Studymentioning

confidence: 99%

“…Energies 2020, 13, 958 6 of 28 renewable share in conventional motor fuels. Opportunities for CO2 mitigation have been investigated, including integration of large scale biomass gasification based biorefineries [42], or by integration of post-combustion CO2 capture technologies [43]. In parallel, energy targeting [44] and retrofit studies [45] have also been performed.…”

Section: The Refinery Case Studymentioning

confidence: 99%

Studying the Role of System Aggregation in Energy Targeting: A Case Study of a Swedish Oil Refinery

et al. 2020

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The definition of appropriate energy targets for large industrial processes is a difficult task since operability, safety and plant layout aspects represent important limitations to direct process integration. The role of heat exchange limitations in the definition of appropriate energy targets for large process sites was studied in this work. A computational framework was used which allows to estimate the optimal distribution of process stream heat loads in different subsystems and to select and size a site wide utility system. A complex Swedish refinery site is used as a case study. Various system aggregations, representing different patterns of heat exchange limitations between process units and utility configurations were explored to identify trade-offs and bottlenecks for energy saving opportunities. The results show that in spite of the aforementioned limitations direct heat integration still plays a significant role for the refinery energy efficiency. For example, the targeted hot utility demand is reduced by 50–65% by allowing process-to-process heat exchange within process units even when a steam utility system is available for indirect heat recovery. Furthermore, it was found that direct process heat integration is motivated primarily at process unit level, since the heat savings that can be achieved by allowing direct heat recovery between adjacent process units (25–42%) are in the same range as those that can be obtained by combining unit process-to-process integration with site-wide indirect heat recovery via the steam system (27–42%).

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Biomass-based hydrogen for oil refining: Integration and performances of two gasification concepts

Cited by 16 publications

References 19 publications

Hydrogen production from biomass: The behavior of impurities over a CO shift unit and a biodiesel scrubber used as a gas treatment stage

Hydrogen production from biomass: The behavior of impurities over a CO shift unit and a biodiesel scrubber used as a gas treatment stage

Bottom–Up Assessment Framework for Electrification Options in Energy-Intensive Process Industries

Studying the Role of System Aggregation in Energy Targeting: A Case Study of a Swedish Oil Refinery

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