Power-to-Methanol at Refineries as a Precursor to Green Jet Fuel Production: a Simulation and Assessment Study

Wassermann, Timo; Schnuelle, Christian; Kenkel, Philipp; Zondervan, Edwin

doi:10.1016/b978-0-12-823377-1.50243-3

Cited by 16 publications

(16 citation statements)

References 5 publications

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“…The carbon capture section provides CO 2 as a raw material for thermochemical synthesis. Three different technologies, namely low temperature direct air capture (LT-DAC), oxyfuel fired cement factory with subsequent cooling and water separation (OXY) as well as oil refinery flue gas scrubbing using monoethanolamine (MEA-CC) are included in the superstructure [16][17][18]. While LT-DAC and MEA-CC produce low-pressure CO 2 at 1 bar, OXY internally prepares the carbon dioxide at 70 bar.…”

Section: Carbon Capturementioning

confidence: 99%

“…The surrogate model is based on a detailed model provided by Wassermann et al with yield factors of the methanol reaction, as given in Table 1. [18]. Three H 2 compressors with different compression ratios are included in this superstructure.…”

Section: Thermochemical Synthesis and Upgradingmentioning

confidence: 99%

“…The surrogate model is based on a detailed model provided by Wassermann et al with yield factors of the methanol reaction, as given in Table 1. [18]. The pure methanol is upgraded using the general concept of methanol-to-jet based on consecutive methanol-to-olefins, olefins oligomerization and hydrofinishing.…”

Section: Algae Raw Materialsmentioning

confidence: 99%

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Renewable Fuels from Integrated Power- and Biomass-to-X Processes: A Superstructure Optimization Study

2022

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This work presents a superstructure optimization study for the production of renewable fuels with a focus on jet fuel. Power-to-X via the methanol (MTJ) and Fischer–Tropsch (FT) route is combined with Biomass-to-X (BtX) via an algae-based biorefinery to an integrated Power- and Biomass-to-X (PBtX) process. Possible integration by algae remnant utilization for H2/CO2 production, wastewater recycling and heat integration is included. Modeling is performed using the novel Open sUperstrucTure moDeling and OptimizatiOn fRamework (OUTDOOR). Novel methods to account for advanced mass balances and uncertain input data are included. Economic optimization proposes a PBtX process. This process combines algae processing with MTJ and depicts a highly mass- and energy integrated plant. It produces fuels at 211 EUR/MWhLHV (ca. 2530 EUR/t), a cost reduction of 21% to 11.5% compared to stand-alone electricity- or bio-based production at algae costs of 25 EUR/tAlgae-sludge and electricity costs of 72 EUR/MWh. Investigation of uncertain data indicates that a combination of BtX and MTJ is economically superior to FT for a wide parameter range. Only for high algae costs of >40 EUR/tAlgae-sludge stand-alone electricity-based MTJ is economically superior and for high MTJ costs above 2000–2400 EUR/tJet FT is the optimal option.

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Section: Carbon Capturementioning

confidence: 99%

Section: Thermochemical Synthesis and Upgradingmentioning

confidence: 99%

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Renewable Fuels from Integrated Power- and Biomass-to-X Processes: A Superstructure Optimization Study

2022

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“…The methanol, in turn, could be further processed to 50 kt/y of jet fuel with diesel, gasoline and LPG as byproducts, using Lurgi's MtSynfuels process [37,38]. This would double the capacity of the algae refinery and substitute about 320 MW electrolyser capacity, compared to an electricity-based approach [39]. If the ATR case is considered, about 16 kt/y of CO 2 is produced, which corresponds to 1.4% of the total CO 2 input of the algae refinery.…”

Section: Biogas Reforming As a Precursor For Integrated Algae Biorefineriesmentioning

confidence: 99%

Biogas Reforming as a Precursor for Integrated Algae Biorefineries: Simulation and Techno-Economic Analysis

2021

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Biogas is a significant by-product produced in algae processing and may be used for many different applications, not only as a renewable energy carrier but also as a chemical intermediate in integrated algae-based biorefineries. In this work, the reforming of biogas to H2/CO2 mixtures (referred to as SynFeed) as feed for the direct hydrogenation of CO2 to methanol is investigated. Two conventional processes, namely steam methane and autothermal reforming, with upstream CO2 separation from raw biogas are compared to novel concepts of direct biogas bi- and tri-reforming. In addition, downstream CO2 separation from SynFeed using the commercial Selexol process to produce pure H2 and CO2 is considered. The results show that upstream CO2 separation with subsequent steam methane reforming is the most economic process, costing 142.48 €/tSynFeed, and taking into consideration the revenue from excess hydrogen. Bi-reforming is the most expensive process, with a cost of 413.44 €/tSynFeed, due to the high demand of raw biogas input. Overall, SynFeed from biogas is more economical than SynFeed from CO2 capture and water electrolysis (464 €/tSynFeed), but is slightly more expensive than using natural gas as an input (107 €/SynFeed). Carbon capture using Selexol comes with costs of 22.58–27.19 €/tCO2, where approximately 50% of the costs are derived from the final CO2 compression.

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“…Similarly, Najjar and Habeebullah [ 4 ] designed a gas‐turbine‐based cogeneration system that utilizes the refinery flue gases and other exhaust gases in a heat recovery steam generator. While these analyses focused on energy conservation, some other studies, such as those of Wassermann et al [ 5 ] and Ma et al [ 6 ] are oriented towards the conversion of flue gas to valuable chemicals. Ma et al [ 6 ] developed a methanol (MET) synthesis system that utilized the captured CO 2 from fluid catalytic cracking unit (FCCU) flue gas along with the CH 4 and H 2 streams from dry gas in a dry‐reforming process.…”

Section: Introductionmentioning

confidence: 99%

Valorization of refinery flue gas through tri‐reforming and direct hydrogenation routes

Sunkara,

Pankhedkar,

Gudi

2024

Can J Chem Eng

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The rising amount of greenhouse gases has been contributing to global warming and, subsequently, climate change. Industries such as refineries and power plants emit a significant amount of CO2 into the atmosphere. It is imperative to curb anthropogenic CO2 emissions, and hence, in this effort, we explore the utilization of a refinery emission stream to produce value‐added chemicals. The chosen emission stream for the said purpose is a typical flue gas stream from refineries. Following the capture step, this CO2 stream has been leveraged for subsequent valorization processes. Two strategies have been proposed in this paper to valorize the captured carbon dioxide. The first strategy employs the tri‐reforming process with a refinery‐specific fuel gas stream as the co‐reactant. The resulting syngas from tri‐reforming has been converted to chemicals such as methanol (MET) and ethanol. Furthermore, to improve the amount of CO2 valorized, another approach with green hydrogen has been considered. The second strategy aims at direct hydrogenation of the captured CO2 stream to produce MET and ethanol. The proposed strategies analyze the feasibility of valorizing captured CO2 from flue gas to MET and ethanol in terms of gross margin per feed and percentage of CO2 valorization. The performance assessment and analysis of the proposed processes have been carried out using simulations in Aspen Plus® that exhibited up to 74% valorization of CO2 into valuable chemicals.

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Power-to-Methanol at Refineries as a Precursor to Green Jet Fuel Production: a Simulation and Assessment Study

Cited by 16 publications

References 5 publications

Renewable Fuels from Integrated Power- and Biomass-to-X Processes: A Superstructure Optimization Study

Renewable Fuels from Integrated Power- and Biomass-to-X Processes: A Superstructure Optimization Study

Biogas Reforming as a Precursor for Integrated Algae Biorefineries: Simulation and Techno-Economic Analysis

Valorization of refinery flue gas through tri‐reforming and direct hydrogenation routes

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