ABSTRACT The ReAct Cement process represents a significant advancement in sustainable cement manufacturing and offers a practical pathway toward low‐carbon or near‐zero‐carbon cement. In this process, reactive calcium oxide (CaO) is utilized during the secondary production stage to facilitate in situ CO 2 mineralization, enabling the formation of a high‐performance cement product without compromising durability or strength. The system integrates monoethanolamine (MEA)‐based post‐combustion CO 2 capture with advanced heat‐transfer exchangers, fuel‐efficient rotary kilns, and air‐preheating technologies. Together, these units enhance thermal integration, reduce kiln fuel demand, and enable the captured CO 2 to be reused directly within clinker formation, thereby closing the carbon cycle within the process itself. The ReAct configuration leverages natural gas and extensive waste‐heat recovery from flue gases, reducing overall CO 2 emissions from combustion by approximately 30%–35%, whereas the combined effect of CO 2 capture and in‐process mineralization achieves an additional reduction of around 60%. By converting remaining process emissions into mineralized cementitious phases, the system has the potential to achieve net‐zero or near‐zero CO 2 output from cement production. The approach also yields economic benefits by lowering fuel consumption, improving thermal efficiency, and utilizing resources that would otherwise be lost to the environment. Overall, this research demonstrates a technically feasible and environmentally transformative approach for decarbonizing cement production and contributes meaningfully to global efforts aimed at achieving a net‐zero future for the construction materials sector.

ABSTRACT The objective of this article is to analyse previous studies conducted on the impact of wellbore interfaces (casing–cement, cement–formation) and cement matrix defects in geological CO 2 storage. In addition, assessment was conducted on the causes of interface and cement defects in a well, followed by a review on the available remediation techniques to solve wellbore interface and cement defects failure. Previous studies have shown that wellbore interface defects play a significant role in ensuring the integrity of geological CO 2 storage. The main findings of previous studies are the creation of zones during carbonation in cement and the mixed minerals of cement and steel during the corrosion process, which could potentially accelerate the corrosion of steel. It is recommended that more experiments be conducted assessing casing, cement and formation as a system in understanding the chemical reaction with CO 2 for long‐term storage to predict the reaction rates of cement and steel with CO 2 . Furthermore, performing numerical modelling with experimental data further deepens the assessment of carbonation zones in cement and its function as a barrier against continued reaction between CO 2 and cement and the impact of mixed calcium‐iron mineral on the steel surface disrupting the creation of a protective film on the steel surface.

ABSTRACT This study presents a method for the preparation of polymeric adsorbents which involves the simultaneous radiation‐induced grafting of glycidyl methacrylate onto Polyamide 6 fibres (GMA‐g‐PA6), followed by the functionalization of the grafted fibres with ethanolamine. The factors, like monomer concentration and radiation dose, which affect the degree of grafting are studied. The prepared polymeric adsorbents were characterized using Fourier‐transform infrared (FTIR), field emission scanning electron microscopy (FE‐SEM), thermogravimetric analysis (TGA) and differential scanning calorimetry (DSC). The adsorbents were evaluated for CO 2 adsorption from a gas mixture of N 2 and CO 2 containing 5%–15% CO 2 , using pressure swing adsorption at four different (1, 3, 5 and 7 bar) pressures. The sample with the highest degree of amination has shown maximum adsorption capacity 1.64 mmol g −1 at 7 bar for 15% CO 2 concentration at 20°C. The CO 2 adsorption on the prepared adsorbents followed a fractional‐order kinetic model. The experimental data aligned effectively with the Freundlich model, reflecting the non‐uniform nature of the adsorbent surface. The regeneration ability of the adsorbent was evaluated over five adsorption–desorption cycles, demonstrating good stability with minimal loss in adsorption capacity. 2025 Society of Chemical Industry and John Wiley & Sons, Ltd.

ABSTRACT CO 2 storage in low‐permeability reservoirs is a key technology for achieving the strategic goals of carbon peak and carbon neutrality. The evaluation of the sealing performance of the geological storage body is an important measure to ensure the safe storage of CO 2 . The injection of CO 2 into the reservoir may cause fault instability within the geological storage body, leading to CO 2 leakage. Therefore, it is particularly important to assess the fault sealing integrity for CO 2 storage. This study integrates geological and mechanical theories to establish a multiparameter evaluation methodology for fault sealing in CO 2 storage within low‐permeability reservoirs. By utilizing seismic interpretation data, laboratory experiments, and stress analysis via a three‐dimensional geomechanical model, the methodology achieves a quantitative assessment of fault sealing performance. This evaluation system comprehensively considers both the lateral and vertical sealing of faults, integrated with mechanical analysis. It enables a comprehensive evaluation of fault sealing under CO 2 storage conditions. The research indicates that, from a geological perspective, the fault sealing integrity of the G block is predominantly low to medium risk, and the overall sealing performance is favorable. In terms of mechanical integrity, the fault sealing safety factor is high. The fault is resistant to tensile rupture and shear slip, and the sealing integrity is good. The multiparameter evaluation method proposed in this article fully incorporates the influence of both geological and mechanical factors on fault sealing in CO 2 storage, providing a scientific basis for the evaluation of geological seal integrity and the prevention and control of leakage risks in CO 2 storage projects.

ABSTRACT Consumption‐based accounting (CBA) is gaining momentum as a transformative approach that complements production‐based accounting (PBA) by capturing the emissions embedded in global trade and final demand. Although PBA accounts for emissions generated within territorial production boundaries, CBA reallocates emissions according to final consumption, offering a broader view on carbon flows and responsibilities across regions. This article moves beyond traditional reviews by integrating insights from policy frameworks of international organizations and governments, offering a systematic exploration of the methodological advancements, data innovations, and multi‐scale applications of CBA. Novel contributions include identifying the gaps between current CBA approach and practical applications, particularly in aligning research with policymaking to achieve actionable outcomes. By addressing persistent challenges such as data limitations, model inconsistencies, and policy integration, this study proposes forward‐looking strategies to enhance the robustness and policy relevance of CBA.

ABSTRACT Geologic carbon storage in depleted oil and gas reservoirs is a key CO 2 mitigation strategy, utilizing existing infrastructure such as injection wells and pipelines, while capitalizing on well‐characterized subsurface properties. This article introduces a versatile methodology designed to estimate critical parameters, including the number of wells needed for CO 2 storage, recoverable oil volumes, the CO 2 content in produced oil, maximum storage capacity, and additional recovery time. This approach is based on established correlations and literature data, providing a simplified cost‐effective preliminary assessment prior to investing resources (labor and capital) into detailed site‐specific studies, which is particularly advantageous in underexplored or emerging basins. The methodology has been validated against field data for a real mature oil field in Brazil, demonstrating its broad applicability and yielding relatively accurate predictions for key performance indicators. This practical tool facilitates the screening of reservoirs worldwide and supports decision‐making for CO 2 ‐enhanced oil recovery (CO 2 ‐EOR) and long‐term carbon sequestration initiatives. 2025 Society of Chemical Industry and John Wiley & Sons, Ltd.

ABSTRACT Carbon dioxide (CO 2 ) capture, as a critical pathway for carbon neutrality, is the first step for carbon storage and utilization. The emerging swirl or vortex‐flow technologies offer effective strategies to enhance CO 2 capture by absorption, particularly in intensifying mass transfer. Unfortunately, in such fields, more efforts have been placed on achieving chemical process‐based improvement instead of green, lightweight, and miniaturization‐based physical process intensification, which is a lost opportunity. This work provides a reflection on vortex‐flow‐based CO 2 capture and advocates for a switch in mindset toward the simplified and environment‐friendly carbon capture process. It analyzes the recent advances in vortex‐flow principle, technology, and process methods for enhancing absorption‐based CO 2 capture, with an emphasis on the multidimensionality of vortex‐flow dynamics, gas–liquid contact and patterns toward carbon capture, enhancement effect, process mechanisms of mass transfer, and modeling and simulation methodologies. Finally, the challenges of vortex‐flow‐based technology for CO 2 capture are also prospected for future development in this field. 2025 Society of Chemical Industry and John Wiley & Sons, Ltd.

ABSTRACT To consume fossil energy and to mitigate global warming, carbon dioxide (CO 2 ) released from burning fossil energy needs to be captured and stored, because it is believed that released carbon will lead to global temperature rise. Most of the CO 2 captured is stored in geological formations like saline aquifers and oil or gas reservoirs. This article addresses the challenges in these areas. When an aquifer has a closed boundary, the storage capacity which is the compressibility‐limited incremental storage is about 1% of the pore volume or at most a few percent because of pressure buildup. Because of this limit, many authors argue that actual aquifer boundaries are semi‐closed or open so that the aquifer size is very large or infinite. Such a large aquifer faces the challenges of reservoir characterization, and monitoring, reporting, and verification (MRV), because the large aquifer needs to be characterized, tested, and monitored, and the semi‐closed boundaries also need to be tested for CO 2 leakage. To relieve the pressure buildup, production wells are used to simulate the process of CO 2 displacing water. Then another challenge emerges from the displacement process: separation of CO 2 and water, treatment of a large volume of produced water, and reinjection of CO 2 . Water disposal can be even more problematic than CO 2 emission. Although oil and gas reservoirs are well characterized, their storage capacity is limited. The wells used in oil and gas reservoirs are Class II which does not satisfy the specifications of Class VI used for permanent CO 2 storage. CO 2 may leak through cement and interfaces of cement with reservoirs and casings, and so forth. The leakage was widely observed in existing abandoned wells and the leak rates varied significantly depending on the well conditions. Although CO 2 helps to produce oil and can be stored in a CO 2 ‐enhanced oil recovery (EOR) process, CO 2 emitted from capturing CO 2 and burning the extra oil is not lower than the amount stored. Because of these challenges and economic hurdles, the executed CO 2 storage projects are far fewer than what was planned and needed to achieve the net‐zero target, being about 6%–30%. This article suggests that more fundamental research is needed to study the techno‐economic feasibility to safely store CO 2 in geological formations and to estimate the economic burden from CO 2 storage.