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• The impact of delivery pressure on the design and cost of CO 2 liquefaction is investigated. • Different impurity and purity requirement scenarios are considered. • The CO 2 liquefaction cost decreases significantly with pressure for the range 7–40 bar. • Impurities have a strong impact on design, cost and comparison of the different pressures. • Purity requirements can have a strong impact on the pressure level comparison. As a first step towards identifying the optimal transport conditions for shipping CO 2 , this study investigates the impact of post-liquefaction delivery pressure on the design and cost of CO 2 liquefaction for (a) pure CO 2 (b) three impurity scenarios (c) two purity requirements. For pure CO 2 , the highest liquefaction cost is obtained at 7 bar amongst the range considered (7 to 70 bar), while a minimum lies around 40–50 bar. When different potential impurity scenarios are considered, impurities need to be purged for the low-pressure cases as these are not necessarily soluble in the liquefied CO 2 stream. As a consequence, the liquefaction cost increases significantly for low-pressure cases (up to 34% compared to the pure CO 2), and wider differences between the pressure levels are obtained. Purity requirements also have a significant impact on comparisons of delivery pressures, although this impact depends on both the impurities present and the purity requirement considered. [ABSTRACT FROM AUTHOR]

Abstract Cost engineering and economic analysis are key elements of the performance assessment of carbon capture and storage (CCS) technology. The CCS field has seen noticeable advances in the transparency and rigor of costing studies, but there is still significant room for improvement in three major areas: the more rigorous application of good cost engineering practices; the inclusion (and progression) of recent methodological advances; and adaptation to changing policy focus. Here, we discuss each of these three areas, bringing diverse information sources together into one paper, and summarising important advances made in recent years, with the goal of strengthening CCS cost engineering and economic analysis in general. The first part of the paper discusses equipment design and sizing; cost indices and location factors; process and project contingency costs; CO 2 transport and storage costs; and uncertainty analysis and validation. The second part discusses new insights and advances in capture plant integration costs; the costs of steam supply; flexible dispatch of power plants with CCS; a hybrid method for the costing of advanced CCS technologies; qualitative uncertainty analysis methods; and calculation methods for CO 2 avoidance costs in non-power industries. The third part highlights several recent changes in the policy environments and how they affect the requirements of CCS costing studies. We close the paper by echoing earlier calls for the transparent reporting of assumptions and input variables underlying costing studies and by prioritising three CCS costing issues for further methods and guideline development. [ABSTRACT FROM AUTHOR]

This work discusses methods for calculating the CO2 avoidance cost for Carbon Capture and Storage from the non-power generation industry. Unlike the power generation sector, three calculation methods are often used to evaluate the CO2 avoidance cost in the case of CCS from industrial sources. However, each of these methods relies on different assumptions of which potential users are not always aware. The links between these three methods are here presented and verified over an illustrative case to highlight the conditions that are required to ensure their reliable use, as well as their associated shortcomings. Finally, the basis to ensure the selection of the CO2 avoidance cost calculation method that is both valid and most efficient for cases considered by potential users are presented. Abbreviations: CCS, carbon capture and storage; CAPEX, capital expenditure; FCC, fluid catalytic cracker; OPEX, operating costs; TCR, total capital requirement. [ABSTRACT FROM AUTHOR]

This paper investigates the cost reduction opportunity of lower CO 2 capture ratios (CCR) on membrane-based CO 2 capture. A numerical model based on the attainable region approach is used to optimise and assess the cost of membrane-based processes for CO 2 capture from post-combustion flue gases containing 10–35% CO 2 , analysing five membranes and CO 2 capture ratios from 50 to 90%. Overall, these cost evaluations demonstrate that membrane-based post-combustion CO 2 capture can significantly benefit from lower CCRs (up to 55% reduction in CO 2 avoidance cost for a flue gas containing 35% CO 2 ). Considering lower CCRs could therefore enable early deployment of CCS despite low carbon emission cost, however the evaluations show that the optimal CCR and corresponding cost reduction potential shall be assessed considering the whole chain characteristics (CO 2 content in the flue gas, impurities, membrane module properties, CO 2 transport system, etc.). [ABSTRACT FROM AUTHOR]

In this work, four illustrative CO 2 capture, utilization and storage chains are investigated in order to evaluate the economic feasibility of CCUS technologies in connection to the cement industry. A CCS reference chain in which 90% of the CO 2 emissions (or 0,694 MtCO 2 /y) are stored in a saline aquifer is first studied. Due to emissions related to energy usage in the capture, conditioning and transport processes, a total of 0,504 MtCO 2 /y are avoided, or 65% of the CO 2 emitted by the cement plant at a cost of 114 €/t CO 2 avoided. Then, production of ethanol, polyols or food-grade CO 2 is integrated to the chain, composing three alternative CCUS chains. These products are chosen based on an assessment of market, energy demand, and technology readiness level of technologies. For CCUS, we show that the economic feasibility is case dependent. The cost of producing blue ethanol is estimated as 656 €/t, slightly above the market value of 633 €/t. The cost per tonne of CO 2 avoided drops from 114€ (CCS) to 111€ (sugarcane-based displacement) and the amount of CO 2 avoided increases by 3%, to 0,518 MtCO 2 /y. In the second CCUS scenario, we have evaluated the integrated production of polyols. The entire CCUS chain avoids 0,708 MtCO 2 /y, and produces 288 kt/y of polyols, generating a profit of 18 €/t CO 2 avoided. In the third CCUS scenario, we show that the production of food-grade CO 2 is feasible as long as it is used to replace fossil-derived CO 2 , with a total CO 2 avoidance of 0,504 MtCO 2 /y at a cost of 108 €/t. A general conclusion from this work is that the average cement plant emits much more CO 2 than can be utilized in a single CO 2 utilization plant. That is either due to market constrains or limited availability of raw materials. For the routes evaluated in this work, the fraction of the emitted CO 2 directed to the utilization plant was always below 10%. Therefore, when connected to the cement industry, utilization is not likely to be applied as a stand-alone solution, but as an integrated link in the CCUS chain. • The economic feasibility of CCUS is case dependent. • Cement plants emit more CO2 than can be utilized. • Polyols may lead to profitable CCUS scenarios. • The economic benefits of synthetic ethanol are limited. • The economic benefits of using captured CO2 in greenhouses are limited. [ABSTRACT FROM AUTHOR]

Highlights: [•] We illustrate the functionality of two transport assessment modules developed. [•] Onshore pipeline and shipping are compared for different distances and capacities. [•] The base case enables to draw conclusions on particular cases. [•] Sensitivity analyses highlight the most important factors involved in the technology selection. [Copyright &y& Elsevier]

Abstract: The timing and selection of CO2 sources will affect the cost of achieving projected CCS based emission reductions. Performed process simulations and cost estimations clearly point out the impact of CO2 concentration and steam supply when capturing CO2 from an atmospheric gas stream with MEA-based chemical absorption. An incremental increase in CO2 concentration reduces both operating and investment costs, mainly due to lower energy consumption and reduced equipment capacity. Reduced investment costs dominate the sharp decline in net present value of costs when increasing CO2 concentration from 2.5% to 10%, while a more moderate cost decline is present when going from 10% to 20% CO2. The impact of steam cost is evident for all studied CO2 concentrations. The cost sensitivity illustrate how important it is to understand the dynamics of cost components when selecting sources appropriate for CCS or struggle to improve performance of capture processes. This work contribute to highlight the relative importance of CO2 concentration and steam supply, realizing that final selection of CO2 source for CCS will involve addition decision variables. [Copyright &y& Elsevier]

Abstract: Coupling flexible power generation with Carbon Capture and Sequestration (CCS) technology may be important for substantial reductions in CO2 emissions. In this paper we consider some of the implications of flexible power plant operation on the CCS process. Specifically, we consider the CCS chain capacity selection decision, by which we mean the choice of the optimal plant size, to understand what determines the amount of CO2 that is efficient to capture and how the decision to invest in CCS chain capacity is affected by price volatility of CO2 emissions quotas. We found that the plant''s emissions profile determined a range of CCS capacities that could be efficient with the tradeoff between the price of CO2 emissions quotas and the cost of CCS technology determining the specific optimal chain capacity. Secondly, investment into CCS technology for a flexible load power plant was more likely to be delayed in a multiple time point investment decision tree model as a result of price volatility, compared to investment in CCS technology on a base load power plant. [Copyright &y& Elsevier]

This paper focuses on identifying the cost limits of two single-stage pressure–vacuum swing adsorption (PVSA) cycles for post-combustion CO 2 capture if the "ideal" zero-cost adsorbent can be discovered. Through an integrated techno-economic optimisation, we simultaneously optimise the adsorbent properties (adsorption isotherms and particle morphology) and process design variables to determine the lowest possible cost of CO 2 avoided (excluding the CO 2 conditioning, transport and storage) for different industrial flue gas CO 2 compositions and flow rates. The CO 2 avoided cost for PVSA ranges from 87.1 to 10.4 € per tonne of CO 2 avoided, corresponding to CO 2 feed compositions of 3.5 mol% to 30 mol %, respectively. The corresponding costs for a monoethanolamine based absorption process, using heat from a natural gas plant, are 76.8 to 54.8 € per tonne of CO 2 avoided, respectively showing that PVSA can be attractive for flue gas streams with high CO 2 compositions. The "ideal" adsorbents needed to attain the lowest possible CO 2 avoided costs have a range of CO 2 affinities with close to zero N 2 adsorption, demonstrating promise for adsorbent discovery and development. The need for simultaneously optimising the particle morphology and the process conditions are emphasised. • Minimum cost of capture for the ideal "zero-cost" adsorbent calculated. • Process inversion optimises adsorbent properties and process simultaneously. • Minimum CO 2 avoided cost: 10.4 €/t (30% CO 2 in feed) to 87.1 €/t (3.5% CO 2 in feed). • PVSA attractive for high CO 2 concentration streams (steel, cement). • Ideal adsorbent: Wide range of CO 2 affinity and negligible N 2 affinity. [ABSTRACT FROM AUTHOR]

The pipeline has historically been the preferred means to transport CO2 due to its low cost for short distances and opportunities for economies of scale. However, interest in vessel-based transport of CO2 is growing. While most of the literature has assumed that CO2 shipping would take place at low pressure (at 7 barg and −46 °C), the issue of identifying best transport conditions, in terms of pressure, temperature, and gas composition, is becoming more relevant as ship-based carbon capture and storage chains move towards implementation. This study focuses on an in-depth comparison of the two primary and relevant transport pressures, 7 and 15 barg, for annual volumes up to 20 MtCO2/year and transport distances up to 2000 km. We also address the impact of a number of key factors on optimal transport conditions, including (a) transport between harbours versus transport to an offshore site, (b) CO2 pressure prior to conditioning, (c) the presence of impurities and of purity constraints, and (d) maximum feasible ship capacities for the 7 and 15 barg options. Overall, we have found that 7 barg shipping is the most cost-efficient option for the combinations of distance and annual volume where transport by ship is the cost-optimal means of transport. Furthermore, 7 barg shipping can enable significant cost reductions (beyond 30%) compared to 15 barg shipping for a wide range of annual volume capacities. [ABSTRACT FROM AUTHOR]

• We develop improved guidelines for cost evaluation of CCS from industry. • We recommend understanding the impact of possible energy supply strategies on cost. • We provide basis on how to better account for retrofitting costs. • We recommend including case representative transport and storage costs. • We discuss how to better reflect technological maturity for industrial applications. This paper contributes to the development of improved guidelines for cost evaluation of Carbon Capture and Storage (CCS) from industrial applications building on previous work in the field. It discusses key challenges and factors that have a large impact on the results of cost evaluations, but are often overlooked or insufficiently addressed. These include cost metrics (especially in the context of industrial plants with multiple output products), energy supply aspects, retrofitting costs, CO 2 transport and storage, maturity of the capture technology. Where possible examples are given to demonstrate their quantitative impact and show how costs may vary widely on a case-by-case basis. Recommendations are given to consider different possible heat and power supply strategies, as well as future energy and carbon price scenarios, to better understand cost performances under various framework conditions. Since retrofitting CCS is very relevant for industrial facilities, further considerations are made on how to better account for the key elements that constitute retrofitting costs. Furthermore, instead of using a fixed unit cost for CO 2 transport and storage, cost estimates should at least consider the flowrate, transport mode, transport distance and type of storage, to make more realistic cost estimates. Recommendations are also given on factors to consider when assessing the technological maturity level of CCS in various industrial applications, which is important when assessing cost contingencies and cost uncertainties. Lastly, we urge techno-economic analysis practitioners to clearly report all major assumptions and methods, as well as ideally examine the impact of these on their estimates. [ABSTRACT FROM AUTHOR]

This study focuses on the techno-economic assessment integrated with detailed optimisation of a four step vacuum swing adsorption (VSA) process for post-combustion CO 2 capture and storage (CCS) from steam-methane reformer dried flue gas containing 20 mol% CO 2. The comprehensive techno-economic optimisation model developed herein takes into account VSA process model, peripheral component models, vacuum pump performance, scale-up, process scheduling and a thorough cost model. Three adsorbents, namely, Zeolite 13X (current benchmark material for CO 2 capture) and two metal–organic frameworks, UTSA-16 (widely studied metal–organic framework for CO 2 capture) and IISERP MOF2 (good performer in recent findings) are optimised to minimise the CO 2 capture cost. Monoethanolamine (MEA)-based absorption technology serves as a baseline case to assess and compare optimal techno-economic performances of VSA technology for three adsorbents. The results show that the four step VSA process with IISERP MOF2 outperforms other two adsorbents with a lowest CO 2 capture cost (including flue gas pre-treatment) of 33.6 € per tonne of CO 2 avoided and an associated CO 2 avoided cost of 73.0 € per tonne of CO 2 avoided. Zeolite 13X and UTSA-16 resulted in CO 2 avoided costs of 90.9 and 104.9 € per tonne of CO 2 avoided, respectively. The CO 2 avoided costs obtained for the VSA technology remain higher than that of the baseline MEA-based absorption process which was found to be 66.6 € per tonne of CO 2 avoided. The study also demonstrates the importance of using cost as means of evaluating the separation technique compared to the use of process performance indicators. Accounting for the efficiency of vacuum pumps and the cost of novel materials such as metal–organic frameworks is highlighted. • Techno-economic study of CO 2 capture from steam-methane reformer flue gas (20 mol% CO 2). • Capture costs (€/tonne CO 2 avoided): IISERP-MOF2=33.6; Zeolite 13X=51.4; MEA=30.1. • Cost, instead of energy/productivity, should be used to compare capture technologies. • Effect of Vacuum pump efficiency, L/D ratio and cost of Zeolite and MOF explored. • Complexity of adsorption process is high: multiple columns & multiple trains. [ABSTRACT FROM AUTHOR]

In Waste-to-Energy (WtE) plants, municipal solid waste (MSW) is combusted while power and/or heat are produced. This approach will largely remain as a promising option to handle the MSW capacities in the future. Due to the organic waste fractions present in MSW, net negative CO 2 emissions are feasible when integrating carbon capture and storage (CCS) processes into WtE plants. The calcium looping (CaL) process represents one option to capture CO 2 from WtE plant exhaust gases. Hereby, CO 2 is separated by a circulating limestone-based sorbent being exposed to cyclic carbonation-calcination reaction regimes. Within this study, a techno-economic analysis of a CaL retrofit on a generic 60 MW th WtE plant is conducted. The analysis considerers three different types of supplementary fuel for the CaL process, namely coal, natural gas (NG) and solid recovered fuel (SRF). Based on a detailed process model, economic key performance indicators were calculated by means of a bottom-up approach. Additionally, different heat integration concepts were proposed and assessed. The techno-economic results are discussed in comparison to a benchmark MEA scrubbing process. It was found that levelized cost of electricity increases quite significantly, which leads to cost of CO 2 avoidance in the range of 119 EUR/t CO2,av (CaL-SRF) up to 288 EUR/t CO2,av (MEA). It is important to note, that the supply of negative CO 2 emissions from a CCS equipped WtE plant enables a cost-efficient solution to at the same time treat MSW in a carbon neutral way while clean heat and/or power as well as negative CO 2 emissions are delivered. [ABSTRACT FROM AUTHOR]

• A CO 2 absorption system is developed for marine engines with varying loads. • The operational limit and off-design performance are analyzed for the capture system. • The cost-optimal capacity and CO 2 avoided rate are identified for an actual sailing profile. • The capture unit costs less than equivalent biofuel usage for an intermediate CO 2 avoided rate. The International Maritime Organization has adopted a strategy aiming for net-zero greenhouse gas emissions from international shipping, prompting various mitigation technologies to comply with this strengthened strategy. Carbon capture technologies are increasingly being considered to satisfy the IMO strategy. In particular, amine-based carbon capture technologies, which are emerging as the most mature option, have been proposed for onboard application. However, the conventional design approach for onboard carbon capture systems, which assumes a fixed high engine load (75–100 %), does not reflect ship operations in a low engine load range, consequently leading to oversizing and unnecessary capital investment. This study designs five MEA-based onboard carbon capture systems with different capacities (sizes) based on the exhaust gas conditions. The study investigates the off-design performance over the entire engine load range while maintaining the capacity of the capture systems at their design values. To identify the optimal capacity of the onboard carbon capture system, the off-design performance is applied to an actual sailing profile in order to quantify the energy requirement, potential CO 2 reduction rate, and capture cost. The results show that smaller systems can reach a similar level of CO 2 reduction as other larger systems while reducing capture costs. This means that it is possible to reduce capture costs by decreasing the capture capacity while maintaining the carbon reduction potential. The small capacity capture system also achieves a more competitive CO 2 avoidance cost (236 € per tonne) compared to biofuel (304 € per tonne) for a similar CO 2 avoidance rate (59 %). Thus, this study demonstrates a new approach to the design of amine-based onboard carbon capture systems under variable engine loads and presents the potential of the decarbonization technology for shipping industry. [ABSTRACT FROM AUTHOR]

• Techno-economic study of heat supply for partial carbon capture in process industry. • New method to estimate heat supply cost to enhances abatement cost curves. • Method includes multi-period optimization of heat sources; provides cost functions. • Result: Temporal variations in residual heat impact capture cost significantly. • Result: Site energy system of a refinery can supply heat to mitigate > 75% emissions. Carbon capture and storage (CCS) activities need to be ramped up to address the climate crisis. Abatement cost curves can help to identify low-cost starting points and formulate roadmaps for the implementation of CCS at industrial sites. In this work, we introduce the concept of energy supply cost curves to enhance the usefulness and accuracy of abatement cost curves. We use a multi-period mixed-integer linear programming (MILP) approach to find an optimal mix of heat sources considering the existing site energy system. For a Swedish refinery, we found that residual heat and existing boiler capacities can provide the heat necessary for CCS that avoids >75% of the site's CO 2 emissions. Disregarding the existing site energy system and relying on new heat supply capacities instead, would lead to capture costs that are 40–57% higher per tonne of CO 2 -avoided (excl. CO 2 liquefaction, transport, and final storage). Furthermore, we estimated that temporal variations of heat sources (intermittent residual heat) increases the heat supply cost and emissions by 7–26% and 9–66%, respectively. The proposed method for optimization of the energy supply mix considering temporal variations of heat sources enables detailed estimates of energy supply costs for CO 2 capture rates ranging from partial to full capture, and thus, improve abatement cost curves. [ABSTRACT FROM AUTHOR]

Large-scale deployment of CO 2 capture, transport, and storage (CCTS) requires the rolling-out of extensive value chains. This study presents the development, design, techno-economic, environmental, and regulatory analysis of four pioneering chains that capture and condition CO 2 from existing European industrial plants and their multi-modal transport to selected ports in Northern Europe. The pioneering chains can avoid between 65% and 87% of the industrial emissions, including scope 3, with a cost of CO 2 avoided ranging between 100 and 300 €/tCO 2. The economic and environmental performance of the CCTS chains are substantially affected by the geographic location of the industrial emitters and the CO 2 volumes to be transported. The analysis relies on the assumption that the four industrial plants would be early movers. While, in the future, technology maturation and infrastructure development are expected to reduce costs and emissions associated with the CCTS chain, this study quantifies and presents the current economic burden that must be overcome to initiate a needed widespread implementation of CCTS. • Development, design, techno-economic, environmental, and regulatory analysis of four pioneering CCTS chains. • Focus on the challenges of early movers from hard-to-abate sectors, using commercially available technologies and existing infrastructure. • The pioneering chains achieve CO 2 avoidance between 65% and 87% and a cost of CO 2 avoided between 100 and 300 €/tCO 2. • A key factor affecting the results is the geographic location, followed by the scale of the industrial plant. • A set of recommendations for deploying CCTS is outlined to ease the burden of early movers. [ABSTRACT FROM AUTHOR]

International shipping is crucial for freight transport, but it relies primarily on fossil fuels, contributing 3% of global greenhouse gas emissions. This calls for urgent action to decarbonize the shipping industry. While renewable-based e-fuels are a strong candidate for decarbonization of this sector in the long run, deploying these to the required scale will take significant time, considering technical modifications onboard the vessels, as well as the changes in fuel production and infrastructure for distribution. Carbon capture from ships is another route to emission reduction that can be implemented faster due to the relatively high maturity of the technology. Tankers, dry bulk carriers, and container vessels contribute a majority of global shipping emissions and are therefore prime candidates for carbon capture and storage. Solvent-based post-combustion capture is chosen for this study as it is mature and suitable for marine applications, though technical, economic, environmental, and practical challenges remain. This paper assesses the technical feasibility of the capture system for ships; both retrofit and newbuild vessels. While achieving zero-emissions presents a significant challenge, it is feasible to attain 70%–90% CO 2 reduction through carbon capture in the near term. This reduction is crucial for transforming the industry into a more sustainable and environmentally friendly state. The limitation of space onboard is identified as a key factor in determining the viability, and the 70%–100% increase in energy consumption between existing ships and newbuild will be a substantial operational challenge. However, the high fuel consumption of the capture system could be economically acceptable if the price of alternative fuels remains high. [ABSTRACT FROM AUTHOR]

This paper investigates the deployment over time of a shipping infrastructure to enable carbon capture and storage from Norwegian industries. In particular, optimal transport investments, routing, shipping portfolio, and transport conditions required cost-efficiently connect nine Norwegian and Swedish industrial facilities to the Northern Light Initiative are identified based on a multi-period mixed-integer model. Optimization of the shipping portfolio allows us to analyze the potential benefits of economics of scale and how sailing multi-stop routes can utilize the potential benefits. Analyses show that the transport cost can be reduced by 12% when the optimal shipping portfolio is implemented instead of operating an independent transport chain for each emission source. Shipping at 7-bar is expected to result in lower costs compared 15-bar shipping, but a significant drawback is the technological maturity of the 7-bar transport technology. The model proposes two transport chains run in parallel as cost optimal, the average transport cost of the 15-bar chain is 32.4 €/ton, and the 7-bar has an average cost of 25.4 €/ton. A net present value criterion is used to identify the conditions for when retrofitting of the 15-bar transport chain is economically sound. Break-even is achieved when the ship's re-sale price is 60% of the purchase price, and the cost of retrofitting a 15-bar conditioning plant to a 7-bar is 40% of the investment cost. While retrofitting may be an attractive solution, the decisions lead to a less robust shipping portfolio, and the retrofitting of a fully operating carbon capture and storage value chain is regarded as unlikely. [ABSTRACT FROM AUTHOR]

Industry is responsible for one-quarter of the global CO 2 emissions. In this study, four different climate pathways are analyzed with a cost minimizing multihorizon stochastic optimization model, in order to analyze possible realizations of carbon capture and storage (CCS) in the power sector and main industrial sectors in Europe. In particular, we aim to achieve a deeper understanding of the distribution of capture by country and key sector (power, steel, cement and refinery), as well as the associated transport and storage infrastructure for CCS. Results point to the synergy effect of sharing common CCS infrastructres among power and major industrial sectors. The contribution of CCS is mainly found in three industrial sectors, particularly steel, cement and refineries) but also in the power sector to a lesser extent. It is worth noting that retrofitting of CCS in the power sector was not considered in this study. The geographical location for capture and storage, as well as timing and capacity needs are presented for different socio-economic pathways and corresponding emission targets. It has been shown that contributions of the three industry sectors in emissions reductions are neither geographically nor sector-wise homogeneous across the pathways. • Study of potential synergies between shared CCS infrastructure in the power sector and industry. • Study of the interplay between CCS and renewables in the power sector. • CCS strategies for the steel, cement and refinery sectors of Europe. • Timing and investment volumes needed to capture, transport and store CO 2. • Guided by climate targets of socio-economic pathways of IPCC. [ABSTRACT FROM AUTHOR]