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In this paper an approach for analysing the potential for implementation of different technology pathways for the European pulp and paper industry (PPI) is presented. The approach is based on detailed technical research and aggregates the knowledge from previous studies to incorporate the whole European PPI. Thus, the potential for different technology pathways can be estimated on a European level whilst still considering important characteristics of individual mills. The usefulness of the approach was exemplified by applying it to a case study of the potential for introduction of carbon capture and storage (CCS) within the European PPI. The results from the case study show that for the European PPI, CCS has an up-hill road in order to be a viable, large scale alternative for reduction of CO2 emissions. If CCS is to be introduced in large scale within the European PPI, large biomass-based point sources of CO2 emissions need to be included when planning for CCS infrastructure and also the infrastructure needs to be built out for clusters emitting <20 MtCO2/yr. [ABSTRACT FROM AUTHOR]

Abstract: Black liquor gasification (BLG) is being developed as an alternative technology for energy and chemical recovery in kraft pulp mills. This study compares BLG – with downstream production of DME (dimethyl ether) or electricity – with recovery boiler-based pulping biorefinery concepts for different types of mills. The comparison is based on profitability as well as CO2 emissions, using different future energy market scenarios. The possibility for carbon capture and storage (CCS) is considered. The results show that, if commercialised, BLG with DME production could be profitable for both market pulp mills and integrated pulp and paper mills in all energy market scenarios considered. Recovery boiler-based biorefinery concepts including extraction of lignin or solid biomass gasification with DME production could also be profitable for market and integrated mills, respectively. If the mill is located close to an infrastructure for CO2 collection and transportation, CCS significantly improves profitability in scenarios with a high CO2 emissions charge, for both combustion- and gasification-based systems. Concepts that include CCS generally show a large potential for reduction of global CO2 emissions. Few of the concepts without CCS achieve a significant reduction of CO2 emissions, especially for integrated mills. [Copyright &y& Elsevier]

CO 2 carriers are considered as a solution for CO 2 transport as a part of Carbon Capture and Storage. CO 2 carriers' design is similar to that of commercial liquefied gas carriers and core technology of liquefied gas carriers is to handle boil-off gas during voyages. This paper introduced newly developed CO 2 boil-off gas re-liquefaction processes making use of cold LNG fuel and investigated economic feasibility of newly developed processes by comparison with a conventional boil-off gas re-liquefaction process. New processes enabled considerable main equipment costs saving and additional fuel cost saving for re-liquefying boil-off gas. Simulation study results showed total amount of boil-off gas in a LNG fueled CO 2 carrier could be re-liquefied by LNG fuel consumed during the voyage and comparative cost assessment results demonstrated those newly developed processes could be applied into a LNG fueled CO 2 carrier with insignificant additional cost. The finding of this paper confirms those newly introduced processes are technically and commercially feasible at present and will contribute to growing the potential market of LNG as a marine fuel as well as commercializing CCS technology by providing more cost-effective solution for CO 2 shipping. [ABSTRACT FROM AUTHOR]

In this paper, the methods of the integration of a supercritical coal-fired power plant with membrane CCS installation are shown. In addition to membrane modules, the CCS installation also consists of two vacuum pumps and two CO2 compressors. In this paper, the relationship between the auxiliary power required to drive these machines and the recoverable amount of heat is shown. This relationship is the reason for the integration of the supercritical coal unit with the CCS installation, which is used for cooling compressed CO2 in the CCS installation by use of condensate (or feed water) from the supercritical coal unit cycle. This cooling process causes both a reduction of the auxiliary power required to drive the compressors and vacuum pumps and increase of power ratio of a steam turbine. In this paper, the optimisation method for minimising the decrease of overall efficiency of the power plant connected with its integration with CCS installation is shown. This results in choosing the optimal pressure ratios in the applied compressors and vacuum pumps under the condition of sufficient heat transmission to the steam turbine cycle. For investigated units, the cost of CO2 emission avoidance and the break-even price of electricity were also calculated. [Copyright &y& Elsevier]

Engineering efforts to handle contemporary energy supply challenges and mitigate pollutant emission lead towards more complicated systems. Power plants are supplementing with additional processing units, alternative production modes and higher level of automation. Wind and solar sources, biomass combustion, gasification, carbon capture and storage (CCS), and cogeneration have appeared as important players in the energy systems. The increasing complexity comprises a risk that the systems become less manageable and less stable than currently. Traditional steady-state engineering methods cannot fully address these challenges that are inherently dynamic in their nature. Dynamic process simulation appears as important tool to the systems design and optimisation tasks. A large variety of dynamic process modelling and simulation approaches has been presented recent years. This paper presents a brief review of methods and simulation packages that are generally applied for studying energy systems' transient behaviour. A CCS capable power plant is presented as an example of utilizing dynamic process simulation for virtual evaluation of a novel electricity production concept. The modelling was performed using two simulators Apros and Aspen Plus Dynamics, which were linked together for dynamic simulating the full chain of cryogenic oxygen distillation, oxy combustion, turbine islands and carbon dioxide purification and liquefaction operations. • Dynamic simulations for design and optimisation of contemporary energy systems have been reviewed. • A case study for evaluating oxy combustion CFB boiler cycle with carbon capturing is presented. • Co-simulation with two dynamic process simulation software: Apros and Aspen Plus Dynamics were shown. • Flexibility aspects of oxy combustion power plant are discussed. [ABSTRACT FROM AUTHOR]

CO 2 carriers are considered as a solution for CO 2 transport as a part of carbon capture and storage (CCS) and ship fuel cost is an important parameter impacting total cost of CO 2 shipping. Heavy fuel oil (HFO) is a traditional marine fuel but alternative marine fuels such as MGO and LNG shall be considered for future researches on CO 2 shipping because low sulphur content fuel is required in sulphur Emission Control Areas (SECAs) from January 2015. However, LNG has not been seriously considered as a marine fuel for CO 2 carriers and its economic feasibility has not been studied so far. This paper assesses economics of LNG fueled CO 2 carriers based on a CO 2 shipping scenario in North Sea and fuel price in June 2016. Parameter studies are conducted to understand the influence of important parameters such as a marine fuel price, LNG fuel system cost, and small LNG distribution cost. The results show that LNG fueled CO 2 carriers are more cost-effective than CO 2 carriers utilizing MGO based on fuel price in June 2016 and when crude oil price is higher than approximately 30–50 USD/bbl. Furthermore, technology development on LNG fuel system and bunkering infrastructure could strengthen the competitiveness of LNG as a marine fuel for CO 2 carriers. [ABSTRACT FROM AUTHOR]

Abstract: The introduction of CO2 removal processes causes usually generation of waste heat. As the temperature of waste heat carriers is usually moderately high (ca. 100 °C), there is a potential possibility for using them in district heating systems. The main goal of present paper is thus the energy and CO2 emission analysis of CHP (combined heat and power production) plants equipped with CO2 removal and utilizing waste heat generated within the plant. First case is dealing with the CFB (circulating fluidized bed) plant equipped with post-combustion chemical CO2 absorption. The second case is dealing with an IGCC (integrated gasification combined cycle) equipped with the pre-combustion CO2 removal by physical absorption. Both plants have been modeled on the Thermoflex software. The reference, CFB-based CHP plant without CO2 removal has also been modeled. The obtained results indicate that IGCC plant has better thermodynamic indicators than CFB-based unit. Moreover, the CO2 emission considering system interconnections within the electricity production network is negative for both plants equipped with CCS (carbon capture and storage). The highest exergy efficiency is achieved for the reference CFB plant. The decrease of exergy efficiency caused by CO2 capture and compression is ca. 8 percentage points, but in case of IGCC CHP plant the exergy efficiency is only 3 percentage points lower than for the reference system. [Copyright &y& Elsevier]

Abstract: In this paper we investigate the value of capture-readiness by modeling the cost effectiveness of various alternative technological options and focusing on different clean-coal technology pathways. The modeling framework developed is based on stochastic net present value calculations. It allows for consideration of path-dependent and technology-specific risk combinations inherent in the input and output commodities that are relevant for operating the plant. We find that capture-readiness competes with alternative options of power plant replacements and that capture-readiness is not necessarily preferable from an economic perspective. [Copyright &y& Elsevier]

Abstract: In this paper, different electricity demand scenarios for Spain are presented. Population, income per capita, energy intensity and the contribution of electricity to the total energy demand have been taken into account in the calculations. Technological role of different generation technologies, i.e. coal, nuclear, renewable, combined cycle (CC), combined heat and power (CHP) and carbon capture and storage (CCS), are examined in the form of scenarios up to 2050. Nine future scenarios corresponding to three electrical demands and three options for new capacity: minimum cost of electricity, minimum CO2 emissions and a criterion with a compromise between CO2 and cost (CO2-cost criterion) have been proposed. Calculations show reduction in CO2 emissions from 2020 to 2030, reaching a maximum CO2 emission reduction of 90% in 2050 in an efficiency scenario with CCS and renewables. The contribution of CCS from 2030 is important with percentage values of electricity production around 22–28% in 2050. The cost of electricity (COE) increases up to 25% in 2030, and then this value remains approximately constant or decreases slightly. [Copyright &y& Elsevier]

Abstract: This paper assesses the three leading technologies for capture of CO2 in power generation plants, i.e., post-combustion capture, pre-combustion capture and oxy-fuel combustion. Performance, cost and emissions data for coal and natural gas-fired power plants are presented, based on information from studies carried out recently for the IEA Greenhouse Gas R&D Programme by major engineering contractors and process licensors. Sensitivities to various potentially significant parameters are assessed. [Copyright &y& Elsevier]

The study explores future development of biomass uses across different climate policy scenarios and under different assumptions of biomass supply availability and technology performances. Broad bioenergy technology portfolios and generations provide flexibility to allocate bioenergy to supply a specific final energy mix and to remove carbon dioxide by combining bioenergy with carbon capture and sequestration (BECCS). The paper aim is to perform a detailed and focused analysis of the availability of biomass gasification and methanisation and the role of these green gas energy carriers in the decarbonisation strategies using a model based approach to see how some countries technology appropriation evolves through the XXIst century. The results show that the future of bioenergy depends mostly on countries bioenergy supply and demand that are partly triggered by climate policies. Besides, very diverse local biomass end use patterns are highlighted depending on local resource availability, economic growth and climate policies. The majority of modern uses will be possible with a biomass transformation through the gas vector thanks to methanisation and gasification processes. Technology maturities and efficiencies are also essential for bioenergy development for the field competitiveness. In presence of climate policies, the deployment of biomass methanisation and gasification increases two or three times faster due to higher competitiveness compared to highly taxed fossil fuel. The possibility to implement CCS fosters even more the use of bioenergy for decarbonisation strategies in the long term and switching the allocation of the resource in favor of gasification with CCS. • Bioenergy potential is used from 25% in 2015 to 75–85% in 2100. • With climate policies, methanisation and gasification develop 2–3 times faster. • Biomass valorization plays a major role in electricity and fuels conversion. • Electricity and heat valorizations are prominent in North, biofuels elsewhere. • Methanisation develops earlier than gasification but it catches up after 2050. [ABSTRACT FROM AUTHOR]