Identification of CO2 sequestration opportunities: CO2 miscible flooding guidelines

Zhang, Na; Yin, Mingfei; Wei, Mingzhen; Bai, Baojun

doi:10.1016/j.fuel.2018.12.072

Cited by 56 publications

(22 citation statements)

References 18 publications

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“…CO 2 miscible flooding is a very effective way to improve oil recovery, which is achieved by injecting supercritical or liquid CO 2 into the reservoir to reach the minimum miscibility pressure (MMP) and blended with crude oil [ 10 ]. Crude oil miscible with CO 2 is greatly swelled, reducing its viscosity and interfacial tension, thereby improving the fluidity of crude oil [ 11 ]. In addition, the production pressure in the mining well can be also increased [ 12 ].…”

Section: Introductionmentioning

confidence: 99%

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Zhang

Sheng

et al. 2021

Membranes

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CO2 enhanced oil recovery (CO2-EOR) technology is a competitive strategy to improve oil field economic returns and reduce greenhouse gas emissions. However, the arbitrary emissions or combustion of the associated gas, which mainly consists of CO2 and CH4, will cause the aggravation of the greenhouse effect and a huge waste of resources. In this paper, the high-performance facilitated transport multilayer composite membrane for CO2/CH4 separation was prepared by individually adjusting the membrane structure of each layer. The effect of test conditions on the CO2/CH4 separation performance was systematically investigated. The membrane exhibits high CO2 permeance of 3.451 × 10−7 mol·m−2·s−1·Pa−1 and CO2/CH4 selectivity of 62 at 298 K and 0.15 MPa feed gas pressure. The cost analysis was investigated by simulating the two-stage system. When the recovery rate and purity of CH4 are 98%, the minimum specific cost of separating CO2/CH4 (45/55 vol%) can be reduced to 0.046 $·Nm−3 CH4. The excellent short-to-mid-term stability indicates the great potential of large industrial application in the CH4 recovery and CO2 reinjection from oilfield associated gas.

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Section: Introductionmentioning

confidence: 99%

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Zhang

Sheng

et al. 2021

Membranes

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“…Enhanced oil recovery (EOR) was the process that extracting residual oil after primary/secondary oil recovery process [ 1 ]. EOR mainly included three methods: miscible enhanced oil recovery (M-EOR) [ 2 , 3 ], thermal enhanced oil recovery (T-EOR) [ 4 , 5 ], and chemical enhanced oil recovery(C-EOR) [ 6 , 7 ]. C-EOR has been industrialized, which showed unique properties than other methods.…”

Section: Introductionmentioning

confidence: 99%

Surfactants Enhanced Heavy Oil–Solid Separation from Carbonate Asphalt Rocks-Experiment and Molecular Dynamic Simulation

Hou

Sun

2021

Nanomaterials

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In this study, surfactants were used to enhance heavy oil–solid separation, and a detailed mechanism was explored by SARA (saturates, aromatics, resins, asphaltenes) analysis, element analysis, AFM measurement, and molecular dynamic simulation. Surfactants could effectively decrease oil/solid interaction force and then oil–solid separation would be enhanced. The oil–solid interactive force was in relation to surfactants concentration, pH value, asphaltene content, and salinity. The molecular dynamics simulation results show that the dissociation of saturated hydrocarbon, aromatic hydrocarbon, resin, and asphaltene (SARA) on carbonate minerals is gradually weakened for all surfactants. In the process of molecular dynamics simulation of surfactant stripping SARA, firstly, the surfactant molecules adsorb on the surface of SARA molecules. After that, the surfactant peels SARA molecules off the surface of calcite under the influence of molecular thermal motion. In this process, surfactant molecules will not be directly adsorbed on the surface of trace minerals. The results of energy/temperature balance indicated that saturates, aromatics and resins could remain stable when the molecular dynamics simulation time reached 2000 ps with the phenomenon that saturates, aromatics could liberate from minerals totally within 2000 ps. The molecular dynamics simulation of asphaltenes will not liberate from calcite surface within 6000 ps, meanwhile, they could not reach the energy balance/energy balance within 6000 ps. The functional groups of surfactant molecules would have interactions with the SARA functional group, resulting in different dissociation effects of SARA. The results of molecular dynamics simulation are consistent with the experiment results. The separation effect of saturated hydrocarbon, aromatic hydrocarbon, resin, and asphaltene in five kinds of surfactants were different. The molecular dynamic simulation results were in accordance with the SARA analysis.

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“…CO 2 flooding is an effective method to improve oil recovery. There are two displacement modes: CO 2 miscible flooding and CO 2 immiscible flooding, depending on whether the reservoir pressure can reach the minimum miscible pressure (MMP) of CO 2 -crude oil (Zhang et al, 2019;Syed et al, 2020;Han et al, 2018;Jishun et al, 2015). CO 2 miscible flooding can result in much higher oil recovery than CO 2 immiscible flooding because the miscible condition can reduce capillary pressure to zero, and residual oil can be significantly reduced in flooded areas/zones.…”

Section: Introductionmentioning

confidence: 99%

The Effect of Formation Water Salinity on the Minimum Miscibility Pressure of CO2-Crude Oil for Y Oilfield

Liu

et al. 2021

Front. Earth Sci.

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CO2 miscible flooding is an important technology for enhancing oil recovery and greenhouse gas storage in the world. As a tertiary recovery technology, it is usually applied after water flooding. Therefore, the actual reservoirs usually contain a lot of injected water in addition to connate water. The salinity of these formation waters varies from place to place. CO2 is an acid gas. After it is injected into the reservoir, it easily reacts with formation water and rock and affects the physical properties of the reservoir. However, no research results have been reported whether this reaction affects the minimum miscibility pressure (MMP) of CO2-crude oil, a key parameter determining miscible flooding in formation water. Based on CO2-formation water–rock interaction experiments, this paper uses the core flooding method to measure the CO2-crude oil MMP under different salinity in formation water. Results show that CO2 causes a formation water pH decrease from 7.4 to 6.5 due to its dissolution in formation water. At the same time, CO2 reacts with formation water, albite, potassium feldspar, and carbonate minerals in the cores to generate silicate and carbonate precipitates, which could migrate to the pore throat together with the released clay particles. Overall, CO2 increased core porosity by 5.63% and reduced core permeability by 7.43%. In addition, when the salinity of formation water in cores was 0, 4,767, and 6,778 mg/L, the MMP of CO2-crude oil was 20.58, 19.85, and 19.32 MPa, respectively. In other words, the MMP of CO2-crude oil decreased with the increase of salinity of formation water.

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Identification of CO2 sequestration opportunities: CO2 miscible flooding guidelines

Cited by 56 publications

References 18 publications

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Surfactants Enhanced Heavy Oil–Solid Separation from Carbonate Asphalt Rocks-Experiment and Molecular Dynamic Simulation

The Effect of Formation Water Salinity on the Minimum Miscibility Pressure of CO2-Crude Oil for Y Oilfield

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