An optimization framework for integrating electric vehicles and carbon capture: Bridging cost gaps via electric vehicles deployment

• Formulated a ship decarbonization design integrating PCC with the ship energy system. • Developed a hybrid model to capture the PCC dynamics under varying ship engine loads. • Designed an EMPC for energy-efficient PCC operation with high carbon capture rate. • Employed cross-entropy to efficiently solve the complex EMPC optimization problem. • Conducted extensive simulations verifying superior modeling and control performance. Implementing carbon capture technology on-board ships holds promise as a solution to facilitate the reduction of carbon intensity in international shipping, as mandated by the International Maritime Organization. In this work, we address the energy-efficient operation of shipboard carbon capture processes by proposing a hybrid modeling-based economic predictive control scheme. Specifically, we consider a comprehensive shipboard carbon capture process that encompasses the ship engine system and the shipboard post-combustion carbon capture plant. To accurately and robustly characterize the dynamic behaviors of this shipboard plant, we develop a hybrid dynamic process model that integrates available imperfect physical knowledge with neural networks trained using process operation data. An economic model predictive control approach is proposed based on the hybrid model to ensure carbon capture efficiency while minimizing energy consumption required for the carbon capture process operation. The cross-entropy method is employed to efficiently solve the complex non-convex optimization problem associated with the proposed hybrid model-based economic model predictive control method. Extensive simulations, analyses, and comparisons are conducted to verify the effectiveness and illustrate the superiority of the proposed framework. The proposed hybrid model-based economic model predictive control reduced the overall economic cost by 8.07% compared to conventional optimal set-point tracking nonlinear model predictive control and achieved a 4.20% lower economic cost with a 9.10% higher carbon capture rate than the imperfect first-principles model-based economic model predictive control.

South Korea has positioned hydrogen and carbon capture, utilization and storage (CCUS) as key technological pillars of its 2050 carbon neutrality strategy. Despite sustained and ambitious policy intervention, however, empirical evidence on how policy interventions have reshaped public R&D portfolios and early industrial diffusion remains limited. This study examines hydrogen and CCUS in South Korea through a policy−R&D−industrial diffusion framework, focusing on policy sequencing and institutional design. The analysis combines qualitative content analysis with project-level R&D data from the National Science and Technology Information Service (NTIS) and interrupted time series analysis to identify policy-induced structural breaks, while industrial diffusion is assessed using deployment indicators such as hydrogen vehicles, hydrogen refueling stations, and large-scale (>100,000 tons/year) CCUS projects. The results indicate a clear divergence in policy outcomes between the two sectors. Hydrogen policy interventions rapidly shifted public R&D toward utilization and industry-oriented development stages and were accompanied by a sharp increase in public R&D expenditures, thereby accelerating deployment. By contrast, CCUS experienced fragmented R&D adjustments, continued public-sector dominance, and limited large-scale demonstration. These findings highlight that while policy-driven, mission-oriented innovation pathways can mobilize R&D and early markets, their effectiveness depends on timely legal frameworks, the institutional coherence of the policy framework, and market-supporting infrastructure. In the case of CCUS, delayed legal institutionalization has constrained the transition from public R&D accumulation to industrial-scale deployment, highlighting the need for stronger regulatory clarity, market-creation instruments, and supporting data infrastructures. • Green innovation follows a policy-driven, top-down pathway in South Korea. • Study links policy, R&D, and industry using legislative and project-level data. • Hydrogen policy synchronization accelerated market-oriented R&D and deployment. • Delayed CCUS legislation caused policy lags and fragmented R&D trajectories. • Innovation requires timely legal frameworks and supportive market environments.

This study critically evaluates Russia’s carbon capture, utilization, and storage (CCUS) policy within the framework of low-carbon hydrogen development, with a particular focus on the feasibility of “blue” hydrogen. Using a multivocal literature review of 44 high-quality academic and gray sources, the analysis compares Russia’s emerging CCUS framework with established international policy models. The results show that blue hydrogen production in Russia is technically feasible and cost-competitive at the production stage, with estimated costs of approximately USD 2.8–3.5 per kg H 2 when CCUS is applied, compared to USD 0.5–1.7 per kg H 2 for unabated hydrogen. Lifecycle emissions of blue hydrogen range from 7.6 to 9.3 kg CO 2 -eq/kg H 2 , representing a 30–45% reduction relative to grey hydrogen but remaining significantly higher than renewable-based green hydrogen (0.6–2.5 kg CO 2 -eq/kg H 2 ). Russia possesses substantial geological CO 2 storage potential, estimated at over 7.3 Gt, with individual projects capable of injecting up to 1 Mt CO 2 annually; however, only about 22.6% of this capacity is suitable for CO 2 -enhanced oil recovery. Despite these technical advantages, large-scale CCUS deployment is constrained by high capital intensity, leakage risks, geopolitical barriers, and a “soft” regulatory regime lacking enforceable carbon pricing or targeted fiscal incentives. In contrast to countries such as the United States, Norway, and Canada, where tax credits, carbon pricing, and dedicated storage regulation underpin commercial CCUS projects, Russia’s current policy framework remains insufficient to ensure investment viability. The study concludes that without the rapid introduction of robust carbon pricing, legally defined CO 2 storage regimes, and performance-based financial incentives, CCUS in Russia will remain confined to pilot projects, limiting the environmental credibility and export competitiveness of Russian blue hydrogen. • Russian blue hydrogen is technically and cost competitive • Blue hydrogen reduces emissions but lags green • Vast CO 2 storage, limited practical capacity • Policy gaps block CCUS scale-up in Russia • Stronger policies needed for blue hydrogen success

Techno-economic assessment of bioenergy with carbon capture and storage for Brazilian thermoelectric power plants

The global climate crisis requires immediate and comprehensive action to reduce greenhouse gas emissions and limit global temperature rises "well below" 2°C. The UK has committed to reaching Net Zero by 2050 (Scotland 2045) with several policies proposed to achieve this goal and ambitious aims to decarbonise whole industries. The UK marine environment is expanding its activities and capitalising on blue growth. Here, we review current marine policies in the context of Net Zero and find that, despite the proliferation of Net Zero policies, there are crucial gaps impeding how Net Zero will be achieved in the marine environment. With the increasing demand for ocean space and the transition to Net Zero, conflicts have arisen between the drive for green energy through offshore wind (OSW) and maintaining space for existing marine users. Better protection and restoration of blue carbon sites and environmental protection targets will be required to meet Net Zero but could lead to further spatial squeeze. Synergies between marine sectors have emerged or are being considered, which may reduce tensions as industries look to expand to achieve Net Zero, e.g. OSW accommodating certain types of fishing, decarbonising oil and gas production, and decommissioned oil and gas infrastructure being repurposed for green energy production or carbon capture and storage. As marine industries expand and decarbonise, trade-offs are likely, and it remains to be seen whether Net Zero will be prioritised, or if policy gaps and outdated policies will impact the UK meeting its legal Net Zero obligations.

Emerging environmental risks are often shaped not by a lack of knowledge alone, but by fragmented information across systems, disciplines, and levels of governance. This fragmentation limits the ability of local decision-makers to identify and respond effectively to rapidly developing technologies. This paper introduces a novel bow tie risk assessment framework as a practical tool for identifying and organizing these risks. By integrating engineering, environmental, and policy perspectives, the approach captures interactions across land use, water systems, and governance structures. We apply the framework to carbon capture, utilization, and storage (CCUS) development in Colorado. Analysis shows that tracking how CCS, CCU, and CCUS are defined and applied across institutions reveals gaps in accountability, coordination, and risk identification. These inconsistencies contribute to policy drift, obscure system-level impacts, and limit stakeholder engagement. The bow tie framework makes these gaps visible, drawing attention to risks that remain hidden within fragmented knowledge and governance systems. Findings from the Colorado case study indicate that current CCUS governance lacks consistent mechanisms to define, measure, and account for water use and impacts across institutions. The analysis highlights a critical gap in how water is conceptualized and measured, particularly where it may be permanently removed or altered through subsurface injection, storage, or disposal in ways that do not align with conventional distinctions between consumptive and non-consumptive use. The method provides a practical tool for local and regional governments to identify risks, engage broader stakeholders, and support coordinated, interdisciplinary, and adaptive decision-making.

Thermodynamic analysis of a copper-chlorine cycle integrated with carbon capture and methanol synthesis for industrial waste heat recovery and power generation

Synthesis of nitrogen doped carbon flowers and studies on their carbon capture behaviors

Electrochemical carbon capture from a magnesite calcination plant

Utilisation of calcium carbonate derived from pilot-scale indirect CO2 mineral carbonation of waste concrete: Impacts on mechanical and microstructural properties of mortar

Machine learning reveals insufficient carbon capture storage deployment to meet climate goals

Mineral carbonation using seawater as an alternative solvent represents a promising approach for carbon capture, utilization and storage (CCUS). Unlike conventional mineral carbonation that relies heavily on freshwater or chemical reagents, seawater provides an abundant and sustainable alternative solvent with inherent alkalinity and metal ions conducive to carbonation reactions; hence, mineral carbonation using seawater not only offers a viable solution to address freshwater scarcity concerns but also simultaneously reduces the cost and avoids the waste chemical generation. This study systematically investigated the effects of introduced CO₂ concentration (5–30%) and reaction temperature (10–30 °C) on carbonation performance in Ca and Mg systems using seawater. Results revealed distinct carbonation behaviors: the Ca system exhibited faster reaction kinetics with CO 2 predominantly captured as solid carbonates (CO 2 fixation capacity: 0.59 g-CO 2 /g-CaO), while the Mg system showed higher overall CO 2 uptake capacity (1.45 g-CO 2 /g-MgO) but lower CO 2 fixation capacity (0.03 g-CO 2 /g-MgO) due to greater retention in the aqueous phase. Lower introduced CO 2 concentrations and extended reaction times promoted solid carbonate formation, particularly in Mg systems. Temperature significantly influenced carbonate polymorphs in both Ca and Mg system. Orthogonal array analysis identified the relative significance of factors affecting CO 2 fixation capacity as: introduced CO 2 concentration > solid-liquid ratio > material type > temperature. The demonstrated effectiveness under low CO 2 concentrations suggests promising applicability for industrial flue gas without requiring costly purification and pressurization processes. These findings provide fundamental insights for optimizing seawater-based mineral carbonation as a sustainable CCUS technology.

Partial oxidation for blue hydrogen production: Techno-economic assessment of low-temperature carbon capture technologies

Heat pump assisted absorption carbon capture with mechanical vapor recompression for biogas purification

A comprehensive review of metal–organic frameworks (MOFs) applications as sorbents and membranes for carbon capture through direct air capture (DAC) technology

COF-based IL/bacterial cellulose composite membranes for carbon capture

CESAR1 Unlocked: A validated rate-based model enabling next-generation carbon capture design

China suffers from a severe geospatial mismatch between industrial and energy CO2 emission sources and geological storage sinks, while existing carbon storage assessments lack national-scale high-resolution and land-sea synergy analysis. This study develops a high-resolution (1 km × 1 km) techno-economic framework integrating hierarchical storage capacity, site suitability, and full-chain carbon capture and storage (CCS) source-sink matching to clarify China's geological carbon storage characteristics. The results show nearly balanced onshore-offshore theoretical (2.5 trillion tons) and P50 effective (1.5 trillion tons) storage capacities, with distinct cost gaps: onshore storage costs of 3-10 USD/t and offshore costs of 10-60 USD/t. Benefiting from regional capacity and transportation economic heterogeneity, 60-75% of China's coal-based captured CO2 achieves a levelized cost below 90 USD/t. This fine-scale framework maps national CCS distribution heterogeneities across multiple scales. We further propose cross-regional CCS coalitions via infrastructure sharing, land-sea storage integration, and cross-region carbon corridors to mitigate imbalance and could manage about 80% of coal-sector emissions, providing a scalable solution for Global South countries with unbalanced carbon development.

Steam methane reforming (SMR) remains the dominant industrial route for large-scale hydrogen production due to its technological maturity and economic competitiveness. However, conventional SMR is associated with significant carbon dioxide emissions, limiting its sustainability in the context of global decarbonization goals. This study presents a comprehensive process modeling and analysis of hydrogen production via SMR integrated with the water–gas shift reaction (WGSR) and post-combustion CO₂ capture. A detailed steady-state model was developed using Aspen HYSYS to evaluate mass and energy balances, hydrogen yield, and purification performance. The modeled process reflects an industrially relevant SMR–WGSR configuration and is assessed in the context of blue hydrogen production. In addition, a location-based feasibility analysis is conducted for Kazakhstan, identifying the Atyrau region as a favorable deployment site due to existing natural gas infrastructure and industrial integration potential. The results demonstrate high hydrogen purity (>97%) and confirm that integration of CO₂ capture significantly reduces carbon intensity while preserving process efficiency, supporting SMR with carbon capture as a viable transitional hydrogen technology. Keywords: Steam methane reforming; Hydrogen production; Water–gas shift; Blue hydrogen; Aspen HYSYS; Carbon capture