Experimental investigation of CO2 storage and oil production of different CO2 injection methods at pore-scale and core-scale

Hao, Yawei; Li, Zongfa; Su, Yuliang; Kong, Chuixian; Chen, Hong; Yang, Meng

doi:10.1016/j.energy.2022.124349

Cited by 33 publications

(12 citation statements)

References 28 publications

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“…The larger the displacement pressure differential, the larger the swept range. 25 While mass transfer plays a leading role after gas breakthrough, the crude oil in the pores was extracted by molecular diffusion and carried by the subsequently injected gas. 22 3.2.…”

Section: Resultsmentioning

confidence: 99%

“…According to previous microscopic and macroscopic visualization studies, the displacement pressure differential before gas breakthrough is the main controlling factor in terms of the oil displacement efficiency, and the crude oil within the pores can be recovered by convective diffusion. The larger the displacement pressure differential, the larger the swept range . While mass transfer plays a leading role after gas breakthrough, the crude oil in the pores was extracted by molecular diffusion and carried by the subsequently injected gas …”

Section: Resultsmentioning

confidence: 99%

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Study on Enhanced Oil Recovery Mechanism of CO₂ Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Chen

Cao

et al. 2023

ACS Omega

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The mechanism by which oil recovery can be enhanced by different injection methods of CO 2 miscible flooding to alleviate the influence of heterogeneous reservoirs was studied to optimize the injection methods, further improving oil recovery. According to the reservoir heterogeneity characteristics of the TI oil formation group in Lunnan Oilfield, a 1 m double-layer long core was designed and prepared for four CO 2 miscible displacement experiments with different injection methods. By analyzing the variation in the injection-production parameters, the displacement effects of different injection methods were compared, and the mechanism of enhanced oil recovery (EOR) was summarized. The results indicate the following. ① The displacement efficiency of the different injection methods lies in the following order. Alternate CO 2 −water injection, continuous CO 2 flooding, cyclic CO 2 flooding, and alternate CO 2 −hydrocarbon gas injection. ② The recovery of crude oil via CO 2 miscible flooding in heterogeneous reservoirs relies on both convective diffusion and miscible mass transfer. Convective diffusion depends mainly on control of the displacement pressure differential and the plugging of preferential seepage channels in high-permeability areas, while miscible mass transfer depends mainly on the swept range of the convective diffusion and the degree of miscibility between CO 2 and crude oil. ③ To improve the recovery efficiency of CO 2 miscible flooding in heterogeneous reservoirs, it is necessary to choose an injection method that optimizes these two aspects.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

Study on Enhanced Oil Recovery Mechanism of CO₂ Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Chen

Cao

et al. 2023

ACS Omega

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“…With the continuous injection of CO2, the wettability reversal process was triggered, resulting in a decrease in the oil wettability and an improvement in the CO2 connectivity with brine. Hao et al [81] conducted multiphase and multiple injection experiments. It was found that under the immiscible phase condition, the porous media showed remarkable gas coverage and flow stratification owing to gas buoyancy.…”

Section: Microscopic Flow Of Co2 In Different Phase Statesmentioning

confidence: 99%

Microscopic Flow of CO<sub>2</sub> in Complex Pore Structures: A Recent 10-Year Review

Liu¹,

Li²,

Liang³

et al. 2023

Preprint

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To prevent CO2 leakage and ensure the safety of long-term CO2 storage, it is essential to investigate the flow mechanism of CO2 in complex pore structures at the pore scale. This study focuses on reviewing the experimental, theoretical, and numerical simulation studies on the microscopic flow of CO2 in complex pore structures during the last decade. For example, advanced imaging techniques, such as X-ray computed tomography (CT) and nuclear magnetic resonance (NMR), are used to reconstruct the complex pore structures of rocks. Mathematical methods, such as Darcy's law, Young–Laplace’s law, and the Navier-Stokes equation, are used to describe the microscopic flow of CO2. Numerical methods, such as the lattice Boltzmann method (LBM) and pore network (PN) model, are used for numerical simulation. The application of these experimental and theoretical models and numerical simulation studies is discussed, considering the effect of complex pore structures. Finally, future research is suggested to focus on: (1) Conducting real-time CT scanning experiments of CO2 displacement combined with the developed real-time CT scanning clamping device to realize real-time visualization and provide quantitative description of the flow behavior of CO2 in complex pore structures; (2) The effect of pore structures change on the CO2 flow mechanism caused by the chemical reaction between CO2 and the pore surface, the flow theory of CO2 considering wettability and damage theory in a complex pore structures; (3) The flow mechanism of multi-phase CO2 in complex pore structures; (4) The flow mechanism of CO2 in the pore structures at multiscale and the scale upgrade from microscopic to mesoscopic to macroscopic. Generally, this study focuses on reviewing the research progress of CO2 flow mechanisms in complex pore structures at the pore scale and affords an overview of potential advanced developments to enhance the current understanding of CO2 microscopic flow mechanisms.

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“…Extensive laboratory experiments and field tests have demonstrated that under the mode of pure-CO 2 injection, appropriately increasing the injection rate is instrumental in improving the recovery of residual oil and the sequestration of CO 2. − However, it is crucial to note that there exists an upper limit beyond which further increases in the injection rate do not yield additional benefits in terms of residual oil recovery . Moreover, excessively high injection rates can impose substantial fluid pressure and reservoir stress, potentially leading to reservoir rock fracturing and an elevated risk of CO 2 leakage .…”

Section: Introductionmentioning

confidence: 99%

Lattice Boltzmann Multiphase Flow Simulations for CO₂-Enhanced Oil Recovery Using Various Modes of Immiscible CO₂ Injection

et al. 2023

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We conducted lattice Boltzmann simulations to investigate the efficiency of various immiscible CO2 injection modes in enhancing oil recovery and CO2 sequestration during CO2-enhanced oil recovery (CO2-EOR) in a heterogeneous porous medium saturated with residual oil and water. The objective was to gain insights into the promotion mechanisms associated with these injection modes. The results obtained from the oil–water–CO2 three-phase flow model, along with the corresponding computer codes, demonstrated excellent agreement with the results of theoretical analyses of classical examples and exhibited a good match with measured results from CO2 flooding experiments. Further simulations indicate the following: (1) Under the pure-CO2 injection mode, the heterogeneous pore structure facilitated the formation of preferential flow paths for CO2, enabling the displacement of residual oil and sequestration of CO2. However, it was observed that increasing the injection rate beyond a certain threshold had limited impact on expanding the sweep area of CO2, thereby contributing minimally to the displacement effect on residual oil and the overall oil recovery efficiency. (2) For water-alternating-gas (WAG) injection, which involved alternating cycles of water and gas injection, the injected water infiltrated specific pores along the pre-established CO2 flow path, displacing the inner residual oil and effectively expanding the sweep area for subsequent CO2 injection. The performance of WAG injection reached its upper limit after two cycles, with additional cycles offering negligible improvements in enhancing oil recovery and CO2 sequestration efficiency. (3) Throughout the whole injection process, certain residual oil droplets remained undisplaced. These droplets were typically located in the pores with narrow entrances, which presented significant capillary resistance, hindering the entry of the outer fluids. Additionally, there were pore spaces where residual oil droplets were finally replaced by water rather than CO2, which needs to be considered when evaluating the capacity of CO2 sequestration.

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Experimental investigation of CO2 storage and oil production of different CO2 injection methods at pore-scale and core-scale

Cited by 33 publications

References 28 publications

Study on Enhanced Oil Recovery Mechanism of CO₂ Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Study on Enhanced Oil Recovery Mechanism of CO₂ Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Microscopic Flow of CO<sub>2</sub> in Complex Pore Structures: A Recent 10-Year Review

Lattice Boltzmann Multiphase Flow Simulations for CO₂-Enhanced Oil Recovery Using Various Modes of Immiscible CO₂ Injection

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Experimental investigation of CO2 storage and oil production of different CO2 injection methods at pore-scale and core-scale

Cited by 33 publications

References 28 publications

Study on Enhanced Oil Recovery Mechanism of CO2 Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Study on Enhanced Oil Recovery Mechanism of CO2 Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Microscopic Flow of CO<sub>2</sub> in Complex Pore Structures: A Recent 10-Year Review

Lattice Boltzmann Multiphase Flow Simulations for CO2-Enhanced Oil Recovery Using Various Modes of Immiscible CO2 Injection

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Product

Resources

About

Study on Enhanced Oil Recovery Mechanism of CO₂ Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Study on Enhanced Oil Recovery Mechanism of CO₂ Miscible Flooding in Heterogeneous Reservoirs under Different Injection Methods

Lattice Boltzmann Multiphase Flow Simulations for CO₂-Enhanced Oil Recovery Using Various Modes of Immiscible CO₂ Injection