Performance evaluation of CO2 flooding process in tight oil reservoir via experimental and numerical simulation studies

Carbon dioxide (CO 2 ) geosequestration in deep saline aquifers has been currently deemed as a preferable and practicable mitigation means for reducing anthropogenic greenhouse gases (GHGs) emissions to the atmosphere, as deep saline aquifers can offer the greatest potential from a capacity point of view. Hence, research on core-scale CO 2 /brine multiphase migration processes is of great significance for precisely estimating storage efficiency, ensuring storage security, and predicting the long-term effects of the sequestered CO 2 in subsurface saline aquifers. This review article initially presents a brief description of the essential aspects of CO 2 subsurface transport and geological trapping mechanisms, and then outlines the state-of-the-art laboratory core flooding experimental apparatus that has been adopted for simulating CO 2 injection and migration processes in the literature over the past decade. Finally, a summary of the characteristics, components and applications of publicly reported core flooding equipment as well as major research gaps and areas in need of further study are given in relevance to laboratory-scale core flooding experiments in CO 2 geosequestration under reservoir conditions.

https://cyberleninka.org/article/n/1337984.pdf

Laboratory core flooding experimental systems for CO2 geosequestration: An updated review over the past decade

Relaxation and relaxation exchange NMR to characterise asphaltene adsorption and wettability dynamics in siliceous systems

The Guarani Aquifer System (GAS) is the largest transboundary aquifer system in South America. One great challenge of managing the GAS is determining the effect of its exploitation for urban, industrial and agricultural use. The fully distributed, process-oriented hydrological model J2000 implemented in the Jena Adaptable Modelling System (JAMS) was used in this study to simulate the water balance in the Ribeirao da Onca (Onca Creek) watershed, because this is an outcrop zone of the Guarani Aquifer System (GAS). The J2000 model proved to be a flexible and easy-to-use tool. The constructed model was effective in predicting the hydrological response of the basin, showing a Nash-Sutcliffe coefficient of 0.76 and 0.81 during periods of model calibration and validation, respectively. The model adequately predicted the discharge volume, presenting percent biases of −0.66 and −2.80 % and root mean square error of 0.14 and 0.18 m3 s−1 for the two periods. The historical reconstruction of the flow series demonstrated that baseflow represents 86–98 % of the total annual discharge and 24–30 % of the total rainfall volume in the Ribeirao da Onca watershed. These estimates can be used to estimate the groundwater recharge rate, in order to establish quantitative targets to prevent overexploitation in the GAS water management. Additionally, the model can be used for further studies to determine the effects of land use and climate change on the hydrologic cycle of the basin.

Hydrologic Simulation for Water Balance Improvement in an Outcrop Area of the Guarani Aquifer System

In recent years, large amounts of CO2 emissions have led to many environmental problems. Developing a reasonable approach to carbon dioxide emissions is one of the most important issues for the sustainable development of human civilization. Compared with CO2 geological storage, CO2 flooding has greater advantages and a higher utilization efficiency. CO2 flooding technology has been successfully applied to many types of reservoirs, such as conventional sandstone reservoirs, low-permeability reservoirs, and carbonates. In this paper, the feasibility of CO2 flooding in glutenite reservoirs is studied. First, the glutenite reservoir is divided into fine stages, and reasonable vertical development units are determined. On this basis, the distribution scale, genetic environment and formation mode of the glutenite reservoir are characterized in detail and their spatial distribution rules are depicted in three dimensions. Then, the influencing factors of CO2 flooding in the glutenite reservoir are analysed via reservoir numerical simulation technology. The effects of reservoir thickness, reservoir heterogeneity, macropores, dominant channels and fracturing on CO2 flooding efficiency are evaluated individually, and a set of reasonable parameters constituting an evaluation system for CO2 flooding in the glutenite reservoir is established. Finally, based on parameter optimization, the disadvantaged conditions of CO2 flooding in glutenite reservoirs are optimized, and their effects are gradually eliminated. In view of the characteristics of glutenite reservoirs, a unique three-dimensional well pattern arrangement is designed, different injection modes are optimized, and suitable injection agents are tested. These methods are conducive to improving the effect of reservoir parameters on CO2 flooding efficiency, allowing these reservoirs to be used for CO2 flooding. Based on these new methods, the displacement effect of the Yanjia-Yongan glutenite reservoir is predicted. Our results show that the reservoir has been developed efficiently and achieved a high recovery rate, the displacement front of the CO2 has become more uniform, and the sweep range has become wider. After extending the successful application of CO2 flooding in this reservoir to all of the glutenite reservoirs in the entirety of the Bohaiwan Basin, we predict that the oil recovery rate may reach 40%, with a cumulative oil recovery rate of approximately 3.04 × 108 t and a total CO2 consumption of 1.672 × 108 t. Thus, the proposed approach not only can improve the atmospheric environment but can also greatly improve the efficiency of oil displacement.

/pdf/influencing-factors-and-application-prospects-of-co-2-v6z9vl8uol.pdf

Influencing factors and application prospects of CO 2 flooding in heterogeneous glutenite reservoirs

Understanding CO2/brine multiphase migration processes is critical for effectively evaluating potential storage capacity, ensuring storage security, and predicting the long-term fate of CO2 storage in saline aquifers. Success depends on the development and application of appropriate research methods. This paper accordingly reviews the progress made in research methods on CO2/brine two-phase migration. Due to intrinsic linkage between CO2 migration and trapping in saline aquifers, prediction of CO2/brine migration processes requires an accurate understanding of CO2 trapping mechanisms. Six recognized physical or geochemical mechanisms, including structural and stratigraphic trapping, residual gas trapping, hydrodynamic trapping, solubility trapping, local capillary trapping and mineral trapping, can impede or prevent CO2 migration according to different dominating variables, and consequently immobilize CO2 in brine formations at varying time and spatial scales. Laboratory experiments, field-scale monitoring and computational modeling are the main approaches in studies on CO2/brine multiphase migration. Different techniques have been designed and developed within each of these methods in terms of physical conditions and spatial scales of multiphase migration phenomena. Due to multi-scale characteristics of CO2/brine multiphase migration processes and complementary relationships among these methods and techniques, different research methods and techniques are often used in combination. Based on a systematic analysis of limitations and weaknesses, improvements are recommended which could potentially increase the accuracy, reliability and applicability of the approaches.

Review: Approaches to research on CO 2 /brine two-phase migration in saline aquifers

In the present study, three types of experiments on immiscible CO2 flooding in porous media were conducted and high-resolution images of asphaltene precipitation obtained using X-ray micro-CT scanner. It was found that the effective oil mobility is reduced due to the adsorption of deposited asphaltene onto the rock which blocks the pore throats, whereby the formation wettability is changed and both the effective porosity and permeability are reduced. The deposited asphaltene cannot be redissolved or displaced by the reinjected crude oil, and the formation damage is irreversible. In addition, the porosity-based permeability model was applied to study the effective permeability reduction that results from porosity reduction. The porosity-based permeability was calculated based on the Kozeny–Carman equation and experimental data. The effective permeability variation rate obtained by the porosity-based permeability model agreed well with the results obtained by Darcy’s law, which demonstrates that the method is feasible in evaluating the effective permeability variation rate based on the porosity of the cores acquired from micro-CT images.

Visualization of asphaltene deposition effects on porosity and permeability during CO2 flooding in porous media

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Review: Approaches to research on CO 2 /brine two-phase migration in saline aquifers

Visualization of asphaltene deposition effects on porosity and permeability during CO2 flooding in porous media