This review focuses on the consequences of the early and rapid deployment of carbon dioxide (CO₂) capture and storage (CCS) technologies, which is currently recognized as a critical problem in fulfilling climate change mitigation objectives and as a viable alternative for countries throughout the world. Currently, the geological storage of CO₂ is the most effective and, in many cases, the only viable short- to medium-term alternative for considerably moving towards CO₂ sequestration in geological sinks and, thus, lowering net carbon emissions into the atmosphere. Furthermore, this review explores the global and environmental measurements of CO₂ emissions, as well as the emphasis behind more efficient energy usage. The components of the CCS system are briefly examined, with an emphasis on the technologies that have been developed by previous scholars to support carbon capture, as well as the kinds of carbon geological formations that are suitable sinks for CO₂. Additionally, the importance of carbon interaction and sequestration in unconventional formations are examined through case studies that are applied to coalbed seams and shale gas reservoirs. Numerous trapping processes are grouped and introduced in a constructive matrix to easily distinguish the broad trapping mechanisms, which are (1) chemical, (2) physicochemical, and (3) physical trapping, and each of these categories are further classified in depth based on their contribution to CO₂ storage.

Despite the significant advancements in geomodelling techniques over the past few decades, it is still quite challenging to obtain accurate assessments of hydraulic fracture propagation. This work investigates the effect of fluid leak-off in a dual-porosity system on the hydraulic fracture propagation geometry, which, in turn, affects hydrocarbon recovery from tight and unconventional reservoirs. Fracture propagation within tight reservoirs was analyzed using the Pseudo Three-Dimensional-Carter II model for single- (P3D-C) and dual-porosity systems (P3D-C-DP). Previous studies have accounted for leak-off in single-porosity models; however, studies within dual-porosity systems are still quite limited. We present a novel approach to coupling fluid leak-off in a dual-porosity system along with a fracture-height growth mechanism. Our findings provide important insights into the complexities within hydraulic fracturing treatment design using our new and pragmatic modeling approach. The simulation results illustrate that fluid leak-off in dual-porosity systems contributes to a confined fracture half-length ($x_f)$, that is 31% smaller using the P3D-C-DP model as opposed to the single-porosity model (P3D-C). As for the fracture height growth ($h_f)$, the P3D-C-DP model resulted in a 40% shorter fracture height compared to the single-porosity model.

Geological carbon storage and utilization is widely regarded as the most realistic method of reducing carbon emissions throughout the energy transition era. In recent times, the implementation of carbon dioxide (CO₂) injection has emerged as a potential method for increasing the recovery of hydrocarbon and facilitating the interaction of CO₂ in shale reservoirs. This methodology enables the mitigation of total carbon emissions released into the earth's atmosphere. The concept of using CO₂ geological sequestration in unconventional shale formations seems to be a prudent approach in responding to both the growing energy demand and mandating environmental requirements simultaneously. Shale reservoirs have received significant interest in the global context because to their substantial reserves and widespread distribution. This research offers a comprehensive analysis of the essential components involved in the sequestration of CO₂ in shales, therefore improving the trapping and long‐term storage of CO₂. In addition, it explores the extraction of hydrocarbons in this context. Gaining a comprehensive understanding of the fundamental factors that contribute to the storativity and trappability of CO₂ is crucial for improving the displacement of methane gas (CH₄) during shale gas recovery. This is particularly relevant in depleted the reservoirs of shale gas, where the aim is to enhance the effectiveness of in situ CO₂ sequestration while reducing the leakage risk.