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This paper investigates various alternatives for the application of CCS at a cement plant which is one of the focus site for CCS deployment in Norway. A matrix consisting of nine CCS alternative chains is analysed in order to quantify cost reduction potentials across the CCS value chain based on an in-house techno-economic assessment methodology and tool called iCCS. In particular, the paper quantifies the strong cost reduction potential of second generation capture technologies and transport technology selection. CO 2 EOR is also identified to have a strong potential to reduce the overall CCS cost, however the cost benefits are strongly dependent on the oil value and the considered EOR injection period. The impact of the inclusion of CO 2 capture and conditioning in the cost of cement shows that public financial support will be required to ensure that the plant remain competitive under current cement market price. Finally, comparison of the full-scale capture versus part-scale capture shows, in this case, that the economies of scale are nearly compensated by the additional steam cost, therefore limiting the interest for full-scale implementation. However, joint deployment with the two other CCS potential sites in Norway (Yara and Klemenstrud) may bring more synergies. [ABSTRACT FROM AUTHOR]

Abstract Integrating solar-thermal energy into the power plant with post-combustion carbon capture and storage can reduce the energy penalty derived from solvent regeneration. However, few metrics exist to evaluate the trade-off associated with technic, economic and ecological perspectives for different integration schemes of the three subsystems, namely the solar field, power plant and carbon capture system. This paper analysis five configurations of coal-fired power plant with and without solar field as well as CCS technology based on the resilience concept. Still at the budding stage, the status of resilience definitions and evaluation methods related to energy system is reviewed. The resilience level for five configurations of coal-fired power plant both with and without solar-field, together with the CCS system is measured, which takes into consideration five critical characteristics towards resilience: fossil fuel depletion potential (CADP), global warming potential (GWP), levelized cost of energy (LCOE), solar to electricity fraction and spare capacity. Results indicate that among all the configurations, the solar-assisted power generation CCS power plant with 90% capture rate shows the highest resilience level. However, the scheme which utilizes solar energy to assisted solvent regeneration, shows limited advantage in terms of resilience level due to high CADP and LCOE. Highlights • Resilience concept and evaluation studies concerning energy systems are reviewed. • A resilience index measure is proposed for solar-assisted CCS energy systems. • Five resilience indicators are covered. • The solar hybrid CCS power plant shows the highest resilience level [ABSTRACT FROM AUTHOR]

The LNG market connects numerous export and import markets, and the global LNG trade has been growing steadily. Despite the availability of multiple alternatives, only a small fraction of this global cryogenic potential is currently utilized, and a negligible number of regasification terminals are equipped with cold energy recovery systems. This paper explores various options for recovering cold energy from LNG regasification processes including electricity production, refrigeration, cryogenic separation processes, CO 2 capture and liquefaction. The present study examines the industrial recovery options, proposing both conventional and innovative process schemes and analysing them in terms of their thermodynamic modelling and feasibility. Nine case studies were selected and simulated using Aspen Hysys software, considering material and energy balances. Specific energy consumptions are calculated, and an exergetic comparison methodology is adopted to provide a unified approach capable to embrace heterogeneous systems utilizing mechanical/electrical energy, thermal energy, and "chemical energy". The temperature profiles are examined, and sensitivity analyses are performed on key parameters. The integration of direct cooling and condensation brings high exergy efficiency of above 40% and economic advantages due to the absence of an external refrigeration cycle. Coupling regasification with CO 2 liquefaction reduces specific energy consumption by 53% compared to the conventional process. Similarly, in the case of an ethylene production plant, energy consumption is reduced by 95%. Simulations for electricity generation using an ORC cycle with LNG as the cold source achieve around 25% exergy efficiency, but the LCOE (Levelized Cost of Electricity) is attractive, ranging from 0.07 to 0.09 €/kWh. Integration with an Air Separation Unit (ASU) for cryogenic distillation leads to a 41% decrease in specific energy consumption. Further integration with Allam and cascade ORC cycles has been simulated. Globally, air separation shows exergy efficiencies of 37–38%, which is higher than the average 25% obtained from conventional thermodynamic cycles with low-temperature hot sources. Regarding cryogenic CO 2 capture, it exhibits lower specific energy consumption compared to traditional processes. The exergy efficiency is high at 22%, and the LCOP (Levelized Cost of CO2 Production) of 55 €/ton is attractive for carbon capture processes that can be coupled with regasification units and NG utilization (a.e. for hydrogen and electricity production). [ABSTRACT FROM AUTHOR]

China's steel sector, contributing 40% of world steel production, are moving the plants out of highly-populated areas in China. Carbon capture and storage (CCS) is an important technology to achieve a deep reduction of emissions in steel plants. Given by high cost and lack of policy incentive in deploying the CCS process, there has been a lack of progress in CCS within the steel sector in China. Capture readiness is a design concept to ease future CCS retrofit and avoid the carbon lock-in effect in steel plants. Capture Readiness design requires moderate upfront investment, i.e. less than 0.5% additional capital expenditure, but could easily enable the plant to be retrofitted with CCS technologies in their lifetime. The paper develops a novel linear programming model to assess the economic cost of Capture Readiness design in a generic steel plant in China. The Baowu Steel Zhanjiang project was used as a reference plant to develop the generic steel plant for the model. Through a Monte Carlo simulation, the results show that the economic cost of making new steel plants in capture readiness for 0.5 million tonnes capture is CNY 65 million (USD 9.5 million) in a conservative 5% carbon price growth rate scenario. The paper found the value of flexibility brought by capture readiness design is significant and is equal to approximately 15% of initial capital investment. The economically viable chance of retrofitting steel plants with CCS technologies in the lifetime is 49%. In an uncertainty analysis, for a 6% growth rate of carbon price, the option value could be increased to CNY 145 million while the probability of retrofit increases to 79%. China's CCS policy should consider a requirement for newly built steel plants to adopt capture readiness design to capture the significant economic value and ease emissions reduction in the iron and steel sector in the long term. • This is the first study investigating CCS readiness in the iron and steel sector. • Capture readiness steel plant can ease retrofit processes with carbon capture and storage in a plant's lifetime. • The paper proposes the key criteria for designing a CCS readiness steel plant. • A novel model is developed in assessing the value of capture readiness. • The retrofit option value of a steel plant is higher than the estimated additional cost for making CCS readiness. [ABSTRACT FROM AUTHOR]

Many of the world's electricity systems are decarbonising, driven in most cases by the deployment of variable renewable energy technologies. This paper studies such systems using generation expansion planning in the form of a linear program to determine and understand least-cost pathways to deep decarbonisation of existing wholesale electricity markets over a 30-year horizon. This work extends previous generation expansion modelling with several, additional options that now enable the substitution of woody biomass for coal and biomethane for natural gas, the retrofit of carbon capture and storage to existing and new build fossil plant, and different constraints on variable renewable energy that differentiate between renewable resource adequacy, system security and economic performance. The most recent, independent, and authoritative technical and financial input data are also used. In all decarbonisation pathways studied, emission reductions are primarily driven by the replacement of the existing coal fleet with utility-scale solar photovoltaic and wind generation. Nonetheless, systematic application of these additional options gives rise to a wide range of different technologies for 'firming' renewable-rich, decarbonised systems, with batteries, pumped hydroelectric energy storage, fossil plant with co-fired biomass and biomethane, carbon capture and storage and nuclear small modular reactors all playing significant roles in different cases. This range of observed pathways is thought to have several implications for system planning, with variable renewable energy tending to be economically competitive up to an imposed technical limit, but with that limit being uncertain and therefore requiring continuous re-evaluation as our understanding evolves. The results of an extensive range of sensitivity studies also suggest that deep decarbonisation is achievable without large increases in costs for consumers, that we should embrace the optionality and competition between different technologies, and that stakeholders have significant choice about non-cost related impacts and preferences, which are manifold. • Generation expansion demonstrates diverse pathways of power system decarbonisation. • ∼90% abatement projected to be achieved via renewables competing solely on cost. • Constraints on VRG integration impact prospects of firm-low carbon technologies. • Additional costs of decarbonisation are relatively insensitive to technology mix. • We should embrace optionality and competition between different technologies. [ABSTRACT FROM AUTHOR]

In this paper, a quadrinomial model based on the theory of real options is developed to evaluate the investment in carbon capture and storage (CCS) retrofitting for existing coal-fired power plants in China. Uncertainties in carbon price, fossil fuel price, investment cost and government subsidy are considered. An existing typical 600 MW supercritical pulverized coal-fired (SCPC) plant is taken as a case study to illustrate the proposed model, and the effects of government subsidy under different scenarios on the critical carbon price to invest in CCS are analyzed. The results indicate that the real options approach has an advantage over the application of traditional net present value (NPV) method when handling uncertainty. And government subsidy has significant effects on reducing critical carbon price for investment in CCS. The critical carbon prices are 103.56 RMB/ton with 100% subsidy and 217.95 RMB/ton without subsidy, while the current average carbon price is 85.2 RMB/ton. This means that the current trading environment is not positive enough to attract investment in CCS retrofitting. These conclusions provide theoretical foundation for decision-making of CCS investment and related policy-making. [ABSTRACT FROM AUTHOR]

Carbon Capture and Storage (CCS) has been viewed as an emission abatement option with great potential in China as coal has dominated China's energy consumption. China has already started to pay attention to CCS, as well as to the proposed the concept of ‘CCUS’ (which adds CO 2 Utilization into the chain of capture, transportation and storage). However, CCS is still in the early stages of its technological development, and the high cost, with several internal and external uncertainties make the role that CCS can play in China's future emission reduction unclear. From the perspective of general equilibrium analysis, this paper introduces CCS into a regional energy–economy–environment integrated assessment model, and makes a comprehensive evaluation of CCS's potential for future development and contribution to emission abatement in China. At climate policy level, the potential contribution of CCS in emission abatement has been evaluated against different future emission constraint scenarios in China. At technological level, the effects of endogenous learning and policy incentives on CCS have been investigated, and the substitution capacities of CCS and Non-hydro renewables to fossil energy have been discussed, as well as their technology penetration rates. Furthermore, the impact of CO 2 utilization on the development of CCS has also been discussed. [ABSTRACT FROM AUTHOR]

The carbon dioxide emission from the industrial sector and the power plant contribute significantly to global climate change for several decades. The carbon capture and storage technology is the primary solution to reach the reduction target of carbon dioxide emissions. The carbon capture and storage activities involve CO 2 capturing, transporting, and storing in geological storage, requires number planning. The process integration approach by pinch analysis method can be used for the carbon capture and storage planning problem and to develop the carbon capture and storage network design. However, the applicability of the method needs to be evaluated when some constraints in carbon capture and storage network design are applied. This paper proposes an improved pinch analysis based method for carbon capture and storage target and network design. The method begins with targeting the maximum carbon exchange in the carbon capture and storage system, which is followed by designing the carbon capture and storage network. Next, the capital-carbon trade-off is introduced as a new strategy for assessing carbon capture and storage network design to show the economic feasibility of the design. Four case studies demonstrate the applicability of the proposed method to the carbon capture and storage systems in the central and western part of Indonesia. The application of this new strategy in the western part of Indonesia as a single region system revealed that the flat minimum of the total annual cost is obtained at a five year time difference with the amount of up to US$ 149.3 million. Image 1 • A CCS cascade analysis in central and western part of Indonesia was introduced. • A systematic approach in multi-region and multi- period was proposed. • Cascade analysis with minimum time difference was shown to be a good method. • Grid diagram showing the pairing between source and sink was a power tool. • Capital-carbon trade-off as a new strategy was proposed to assess CCS system design. [ABSTRACT FROM AUTHOR]