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CO2 geological storage combined with deep saline water recovery technology (CO2-EWR) is one of the most effective ways to reduce carbon emissions. Due to the complex structural features, it is difficult to use CO2-EWR technology in Huaiyin Sag, Subei basin, East China. In this study, the multi-source information superposition evaluation technology of GIS was utilized for the selection of CO2 storage sites and water displacement potential target areas in this area, which mainly focused on the sandstone reservoirs of Cretaceous Pukou Formation. Based on the results, a three-dimensional injection–extraction model was established. Various scenarios with different production/injection well ratios (PIR) were simulated. Research has shown that the suitability of the surrounding site of Huaiyin Power Plant can be divided into two levels: relatively suitable and generally suitable; the area in the generally suitable level accounts for more than 80%. At a PIR of 1, CO2 is distributed asymmetrically, whereas at PIRs of 2 or 4, CO2 is distributed symmetrically. When the number of production wells is constant, a higher injection rate results in a faster expansion rate of the CO2 plume. This means that the time taken for the CO2 plume to reach the production wells is shorter. Reservoir pressure increases rapidly after more than 60 years of CO2 injection at lower PIR values, while at higher PIRs, reservoir pressure eventually stabilizes. Higher PIR values correspond to higher gas saturation, indicating a greater capacity for CO2 sequestration with more producing wells. When PIR = 4, the total CO2 injection increased by 55.73% compared to PIR = 1. However, the extraction of saline decreases with an increase in the number of producing wells, resulting in a decrease in replacement efficiency. This study provides a theoretical basis and technical support for the implementation of large-scale CO2-EWR engineering and technology demonstration in this region. [ABSTRACT FROM AUTHOR]

The industrial development of Xinjiang is facing serious carbon emissions and water shortage problems in this region. It is urgent to find a sustainable development way. CO 2 geological storage combined with enhanced water recovery (CO 2 -EWR) is a win-win technology that can increase CO 2 geological storage potential and obtain abundant groundwater resources meanwhile. A 3D heterogeneous geologic model was built to estimate the potential of field-scale CO 2 geological storage combined with enhanced water recovery according to the seismic, well logging data and well testing data of the Cretaceous Donggou Formation in the eastern Junggar Basin of China. Twelve injection-production scenarios were designed. The results show that CO 2 -EWR technology can greatly reduce the pressure buildup with the minimum pressure increase of 1.3 MPa and thus increase CO 2 injection with a maximum cumulative amount of 100 Mt, three times more than that for sole CO 2 injection. Also, it can enhance total production of deep saline water by a factor of ~100 compared to that for sole water production. Formation parameters such as permeability, porosity and slope of the reservoir primarily control the migration and dissolution of CO 2. The heterogeneity of the reservoir plays an important role in the CO 2 spatial distribution and even saline water production. One injection well with constant rate injection of CO 2 and one production well with constant pressure production of saline water scenario is the preferred option in engineering practice of eastern Junggar Basin, which can obtain the maximum amount of CO 2 injection and saline water resources. This study provides a technical reference for implementation of CO 2 -EWR at the field-scale or industrial-scale to solve CO 2 emission reduction and water shortage problems. [Display omitted] [ABSTRACT FROM AUTHOR]

• A high precision CCUS source-sink matching model was proposed. • Deployment potential of CCUS in coal-fired power plants in China was evaluated. • Early opportunities for China to develop CCUS were identified. • Suggestions on CCUS deployment in China were put forward. Carbon capture utilization and storage is regarded as an important option to achieve deep CO 2 reduction in the power sector, especially in China. An optimization model was developed without considering the CCUS costs constraints to determine the CO 2 reduction potential of existing coal-fired power plants with CCUS in China from the perspective of source-sink matching. Saline aquifers and oil fields located in major onshore sedimentary basins in China were considered as potential sinks. The results showed that: i) the storage potential of the saline aquifers and enhanced oil recovery are over 1 × 1012 t and 5 × 109 t, respectively; ii) 401 power plants could be matched with storage sites within 100 km without considering the CO 2 injection capacity, and the annual CO 2 sequestration amount was about 1204 Mt. If the maximum transport distance were increased to 250 km and 800 km, respectively, and the annual CO 2 sequestration amount would more than 1620 Mt and 1017 Mt. iii) The CO 2 sequestration amount would be cut by about 2% to 38% if the CO 2 injection capacity was considered as a constraint; the sequestration amount was primarily affected by the transport distance. iv) Junggar Basin, Turpan-Hami Basin, Ordos Basin, Songliao Basin, and Bohai Bay Basin were considered priority areas to deploy carbon capture utilization and storage technology, including CO 2 enhanced oil recovery. [ABSTRACT FROM AUTHOR]

• The time-lapse 2D vertical seismic profiling (VSP) technology can support the monitoring and numerical modeling of CO 2 plume migration at the CO 2 geological storage site. • Results of time-lapse VSP data and numerical modeling show some new characteristics of CO 2 plume migration in multi-layer reservoirs with strong heterogeneity and low permeability. • A new 3D geological model of Shenhua CCS demonstration project in China is constructed. • Characteristics of CO 2 plume migration during the injection period and after site closure at the Shenhua CCS demonstration project storage site are much clearer than previous studies. One of the great challenges in carbon capture and storage (CCS) development is the monitoring and determination of the underground CO 2 plume migration. We show that time-lapse 2D vertical seismic profiling (VSP) technology can support the monitoring and numerical modeling of CO 2 plume migration at a storage site. Using the Shenhua CCS demonstration project in China as a case study, we predicted the physical parameters of the main reservoir, including the distribution of bodies of sandstone and their porosity and permeability, required to upgrade the geological model. We also interpreted the characteristics of historical CO 2 plume migration in one seismic profile of the second and third periods of VSP monitoring. Based on a new upgraded geological model, we simulated the historical CO 2 plume migration characteristics under the actual injection scenario of the demonstration project. The results of the simulation exhibited good consistency with the time-lapse VSP monitored in the profile, thus indicating that both the geological and numerical models have a certain degree of credibility. We further simulated the characteristics of CO 2 plume migration after the injection well shutoff before 2035. [ABSTRACT FROM AUTHOR]