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Integrated absorption–mineralization (IAM) involves the transformation of CO2 in a chemical-based solution with brine used as the absorbent to form insoluble carbonates and is promising for carbon capture, utilization, and storage. Various types of absorbents such as monoethanolamine (MEA), diethanolamine (DEA), triethanolamine (TEA), and aminomethyl propanol (AMP) were examined in multicycle integrated absorption–mineralization (multicycle IAM) involving absorption, precipitation, and regeneration steps between 20 °C and 25 °C at atmospheric pressure in order to reveal their performance in terms of CO2 absorption and conversion and absorbent degradation. We found that 5 wt.% AMP offered 89.5% CO2 absorption capacity per unit of absorbent converted into the amount of solid carbonate within 4 cycles. In addition, it was moderately degraded by 64.02% during the first cycle and then reduced from 30% to 10% in the next cycle (>2 cycles). In comparison with MEA, which was used as the initial absorbent, AMP provided a fivefold increase in the speed of multicycle IAM.

Combating climate change by reducing greenhouse gas (GHG) emissions has become an obligation for countries that ratified the Paris Agreement. Saudi Arabia, as a member of the Paris Agreement, pledged to achieve net zero emissions (NZE) by 2060. This endeavor is challenging for all countries. This paper provides an analysis and assessment of the Saudi measures to achieve NZE by 2060. The analysis reveals that Saudi Arabia will reduce the total net emissions to 49.67 Mt of CO2eq, whereas under a business-as-usual scenario, the emissions would reach 1.724 million tons (Mt) of CO2 equivalent (CO2eq). The study reveals that sectors conducting environmental, social, and governance ratings (ESG) and those where the government is a stakeholder are on the right track and will facilitate the government’s efforts in reaching NZE. The gap in reaching NZE will be mainly due to the Saudi steel and cement industries.

It is of great significance for the engineering popularization of CO 2 -ECBM technology to evaluate the potential of CCUS source and sink and study the matching of pipeline network of deep unworkable seam. In this study, the deep unworkable seam was taken as the research object. Firstly, the evaluation method of CO 2 storage potential in deep unworkable seam was discussed. Secondly, the CO 2 storage potential was analyzed. Then, the matching research of CO 2 source and sink was carried out, and the pipe network design was optimized. Finally, suggestions for the design of pipe network are put forward from the perspective of time and space scale. The results show that the average annual CO 2 emissions of coal-fired power plants vary greatly, and the total emissions are 58.76 million tons. The CO 2 storage potential in deep unworkable seam is huge with a total amount of 762 million tons, which can store CO 2 for 12.97 years. During the 10-year period, the deep unworkable seam can store 587.6 million tons of CO 2 , and the cumulative length of pipeline is 251.61 km with requiring a cumulative capital of $ 4.26 × 10 10 . In the process of CO 2 source-sink matching, the cumulative saving mileage of carbon sink is 98.75 km, and the cumulative saving cost is $ 25.669 billion with accounting for 39.25% and 60.26% of the total mileage and cost, respectively. Based on the three-step approach, the whole line of CO 2 source and sink in Huainan coalfield can be completed by stages and regions, and all CO 2 transportation and storage can be realized. CO 2 pipelines include gas collection and distribution branch lines, intra-regional trunk lines, and interregional trunk lines. Based on the reasonable layout of CO 2 pipelines, a variety of CCS applications can be simultaneously carried out, intra-regional and inter-regional CO 2 transport network demonstrations can be built, and integrated business models of CO 2 transport and storage can be simultaneously built on land and sea. The research results can provide reference for the evaluation of CO 2 sequestration potential of China's coal bases, and lay a foundation for the deployment of CCUS clusters.

To mitigate dangerous climate change effects, the 195 countries that signed the 2015 Paris Agreement agreed to “keep the increase in average global surface temperature below 2 °C and limit the increase to 1.5 °C” by reducing carbon emissions. One promising option for reducing carbon emissions is the deployment of carbon capture, utilization, and storage technologies (CCUS) to achieve climate goals. However, for large-scale deployment of underground carbon storage, it is essential to develop technically sound, safe, and cost-effective CO2 injection and well control strategies. This involves sophisticated balancing of various factors such as subsurface engineering policies, technical constraints, and economic trade-offs. Optimization techniques are the best tools to manage this complexity and ensure that CCUS projects are economically viable while maintaining safety and environmental standards. This work reviews thoroughly and critically carbon storage studies, along with the optimization of CO2 injection and well control strategies in saline aquifers. The result of this review provides the foundation for carbon storage by outlining the key subsurface policies and the application of these policies in carbon storage development plans. It also focusses on examining applied optimization techniques to develop CO2 injection and well control strategies in saline aquifers, providing insights for future work and commercial CCUS applications.

This study explores the evolutionary characteristics and driving factors of innovative cooperation networks in the field of carbon capture, utilization, and storage (CCUS) technology in China, laying a foundation for the governance of those networks. Taking the patents in the field of CCUS technology in China as the research object, this study analyzes the evolutionary characteristics of innovative cooperation networks based on social network theory. The exponential random graph model (ERGM) reveals the factors driving the evolution of innovative cooperation networks from three perspectives: endogenous structure, node assortment, and node attribute. Based on the technology life cycle theory and the network topology characteristics of each stage, this study reveals a four-stage evolution of the China CCUS innovation network, including the fragmented exploration network (1988–2007), the star-shaped radiation network (2008–2011), the multi-core structured network (2012–2018), and the cross-domain synergistic integration network. ERGM analysis indicates that star-shaped structures and closed triads are the core endogenous driving forces promoting the evolution of the innovation collaboration network in the CCUS technology field. The geographical adjacency effect weakens as the stages progress. The promoting effect of organizational assortment on network evolution and development begins to emerge. In contrast, the role of R&D capability shifts from facilitation to inhibition, and the “Matthew Effect” becomes ineffective. Meanwhile, the structural hole inhibition effect reveals the predicament of technological barriers. Constructing an efficient and interactive innovation collaboration network for CCUS in China requires adherence to the rigid coupling requirements inherent in the CCUS technology chain. It is essential to enhance substantive collaboration based on geographical adjacency while addressing collaboration barriers arising from structural hole effects and technological monopolies.

Carbon capture is pivotal for achieving carbon neutrality; however, its high energy consumption severely limits the operational flexibility of power plants and remains a key challenge. This study, targeting a full flue gas carbon capture scenario for a 1000 MW coal-fired power plant, identified the dual-element (“steam” and “power generation”) coupling convergence mechanism. Based on this mechanism, a comprehensive set of mathematical model equations for the “carbon–electricity–heat” coupling process is established. This model quantifies the dynamic relationship between key operational parameters (such as unit load, capture rate, and thermal consumption level) and system performance metrics (such as power output and specific power penalty). To address the challenge of flexible operation, this paper further proposes two innovative coupled modes: steam thermal storage and chemical solvent storage. Model-based quantitative analysis indicated the following: (1) The power generation impact rate under full THA conditions (25.7%) is lower than that under 30% THA conditions (27.7%), with the specific power penalty for carbon capture decreasing from 420.7 kW·h/tCO2 to 366.7 kW·h/tCO2. (2) Thermal consumption levels of the capture system are a critical influencing factor; each 0.1 GJ/tCO2 increase in thermal consumption leads to an approximate 2.83% rise in unit electricity consumption. (3) Steam thermal storage mode effectively reduces peak-period capture energy consumption, while the chemical solvent storage mode almost fully eliminates the impact on peak power generation and provides optimal deep peak-shaving capability and operational safety. Furthermore, these modeling results provide a basis for decision-making in plant operations.

The technology called carbon capture, utilization, and storage (CCUS) is important for capturing CO2 emissions before they enter the air. Because everyone wants to stop global warming by reducing CO2 emissions, CCUS is an important and emerging technology that can help slow down climate change, lower emissions in many areas, and support the move toward a sustainable and carbon-neutral future. As CCUS technology and its adaptation increases, it is very important to pay attention to the CCUS risks from a supply chain (SC) point of view. The goal of this study was to identify CCUS supply chain risks and develop a conceptual framework (CF) that provides a structured approach to ensure safe and reliable CCUS supply chain operations. Therefore, this study analyzed the literature related to the SCs of different sectors and identified the SC risks, which was the foundation for CCUS SC risk identification. This study demonstrates that there is no research article that provides a comprehensive CCUS SC risk management framework that connects with risk management strategies. The conceptual framework that is proposed in this study connects CCUS SC functions, risks, and risk management strategies to construct a complete CCUS supply chain risk management system. Moreover, the CF provides guidelines for future research, which will enrich the CCUS supply chain risk management system as well as fight climate change.

Recently, hydrogen has emerged as an extremely versatile energy source and an important component of the global decarbonization drive. Green hydrogen, produced by electrolysis of renewable resources, is gaining popularity due to its significant impact on reducing Carbon Dioxide (CO₂) emissions. The review paper aims to provide an overview of current advancements, challenges, and future potential in hydrogen generation, storage, and transportation technologies, with a focus on the most promising and innovative approaches investigated. This article offers a comprehensive overview a variety researches on hydrogen production systems, focuses on advancements in storage and transportation technologies. The efficiency, cost, and environmental effect of conventional and renewable hydrogen generation techniques such as biomass gasification, PhotoCatalysis (PC), and water electrolysis have been compared for various studies. Furthermore, different control strategies studies for enhancing the reliability and productivity of hydrogen based solar systems have been examined. The energy density and adaptability of various storage researches technologies such as metal hydrides, liquid hydrogen, compressed gas, and Liquid Organic Hydrogen Carriers (LOHCs) are discussed. This article provides a summary comparison of the recent research on hydrogen technologies. The article concentrates on reviewing numerous strategies for each stage of hydrogen lifecycle. In addition, industrial operations, transportation, and integration with microgrids and smart grids in general for different techniques is covered. Future research developments and trends are also discussed.

Carbon capture, utilization, and storage (CCUS) is a key technology for decarbonizing existing or newly designed fossil fuel power plants, which in the short to medium term remains essential to offset the variability of nonprogrammable renewable sources in power generation. In this paper, the authors focus on the CO2 compression phase of CCUS systems, integrated with power plants, and propose, according to the technical literature, a plant layout aimed at minimizing energy consumption; then, they carry out the preliminary design of all compressors, identifying compact and efficient configurations. The case study concerns an advanced ultra-supercritical steam plant (RDK8 Rheinhafen-Dampfkraftwerk in Karlsruhe, Germany) with a nominal net thermal efficiency of 47.5% and an electrical output of 919 MW. The main results obtained can be summarized as follows. The overall compression in the IGC configuration requires only six stages and each compressor is single-stage, while in the inline configuration, ten stages are needed; the diameters in the IGC solution, also due to a higher rotational speed, are smaller, despite the in-line solution being multistage. An interesting further investigation could be related to modifications of the plant scheme, especially to test whether CO2 liquefaction at an intermediate stage of compression could result in reductions in energy consumption, as well as even more compact design solutions.

This study investigates the energy performance and preliminary turbomachinery design of post-combustion CO2 compression systems integrated into an ultra-supercritical coal-fired power plant with carbon capture and storage (CCS). To enable pipeline transport, CO2 must be delivered at 150 bar and 15 °C, i.e., in liquid phase. Unlike conventional configurations that compress CO2 entirely in the gaseous/supercritical phase before final cooling, two alternative layouts are proposed, introducing an intermediate liquefaction step prior to liquid-phase compression. Each layout uses a chiller system that operates at CO2 condensation temperatures of 10 °C and 20 °C. The energy performance and the system layout architecture are evaluated and compared with the conventional gaseous-phase compression configuration. An in-depth sensitivity analysis, which varies the flow coefficient, the working coefficient, and the degree of reaction, confirms that the turbomachinery preliminary design, based on input parameters related to the specific speed, is a high-efficiency design. The results indicate that the 10 °C liquefaction layout requires the least compression power (60 MW), followed by the 20 °C layout (62.5 MW) and the conventional system (67 MW). Including the consumption of the chiller, the proposed systems require an additional power of 11–12 MW, compared to just over 1 MW for the conventional layout with simple CO2 cooling. These results highlight the significant influence of the integration of the chiller on the overall power requirement of the system. Although the proposed configurations result in a larger equipment footprint, the integrated capture and compression/liquefaction system allows for very low CO2 emissions, making the power plant more sustainable.