The impact of asphaltene deposition on fluid flow in sandstone

Mehana, Mohamed; Abraham, Jocin James; Fahes, Mashhad

doi:10.1016/j.petrol.2018.11.056

Cited by 36 publications

(21 citation statements)

References 24 publications

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“…Visual molecular dynamics (VMD) was used to prepare visualizations [188]. Mehana et al studied the system's physical conditions and composition on asphaltene aggregation dynamics [189]. The third reason is separation and selective extraction by CO 2 [190].…”

Section: Asphaltene Precipitationmentioning

confidence: 99%

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Cai

et al. 2021

Geofluids

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The difficulty of deploying remaining oil from unconventional reservoirs and the increasing CO2 emissions has prompted researchers to delve into carbon emissions through Carbon Capture, Utilization, and Storage (CCUS) technologies. Under the confinement of nanopore in unconventional formation, CO2 and hydrocarbon molecules show different density distribution from in the bulk phase, which leads to a unique phase state and interface behavior that affects fluid migration. At the same time, mineral reactions, asphaltene deposition, and CO2 pressurization will cause the change of porous media geometry, which will affect the multiphase flow. This review highlights the physical and chemical effects of CO2 injection into unconventional reservoirs containing a large number of micro-nanopores. The interactions between CO2 and in situ fluids and the resulting unique fluid phase behavior, gas-liquid equilibrium calculation, CO2 adsorption/desorption, interfacial tension, and minimum miscible pressure (MMP) are reviewed. The pore structure changes and stress distribution caused by the interactions between CO2, in situ fluids, and rock surface are discussed. The experimental and theoretical approaches of these fluid-fluid and fluid-solid reactions are summarized. Besides, deficiencies in the application and safety assessment of CCUS in unconventional reservoirs are described, which will help improve the design and operation of CCUS.

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Section: Asphaltene Precipitationmentioning

confidence: 99%

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Cai

et al. 2021

Geofluids

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“…Based on geological statistics, carbonate reservoirs account for about 35.7% of global oil and gas resources, and deep and ultra-deep carbonate gas reservoirs (depth > 4500 m) have become one of the popular resources for exploration and development [1,2]. Abundant marine origin carbonate gas reservoirs have been found in Sichuan Basin, SW China [3,4]; the reserves of Sinian and Cambrian gas reservoirs exceed 1 × 10 12 m 3 , and have become one of the important gas producing areas [5][6][7][8].…”

Section: Introductionmentioning

confidence: 99%

“…The most direct way to research the influence is to compare the changes in porosity and permeability after the removal of SB. As is known, bitumen is a heavy component in crude oil, which is soluble in aromatic solvents such as benzene and toluene, SB can be removed from cores by extraction [32,34,35]. However, there are few studies on gas reservoirs, and the related studies were mainly concentrated in the Longwangmiao Formation in Moxi Area, SW China.…”

Section: Introductionmentioning

confidence: 99%

Influence of Pore Structure and Solid Bitumen on the Development of Deep Carbonate Gas Reservoirs: A Case Study of the Longwangmiao Reservoir in Gaoshiti–Longnusi Area, Sichuan Basin, SW China

Chen

Yang

et al. 2020

Energies

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A variable sedimentary environment and accumulation process leads to a complex pore structure in deep carbonate gas reservoirs, and the physical properties are quite different between layers. Moreover, some pores and throats are filled with solid bitumen (SB), which not only interferes with reservoir analysis, but also affects efficient development. However, previous studies on SB mainly focused on the accumulation process and reservoir analysis, and there are few reports about the influence on development. In this paper, through scanning electron microscope analysis, SB extraction, gas flow experiments and depletion experiments, and a similar transformation between experimental results and reservoir production, the production characteristics of carbonate gas reservoirs with different pore structures were studied, and the influence of SB on pore structure, reservoir analysis and development were systematically analyzed. The results show that permeability is one of the key factors affecting gas production rate and recovery, and the production is mainly contributed by high-permeability layers. Although the reserves are abundant, the gas production rate and recovery of layers with a low permeability are relatively low. The SB reduces the pore and throat radius, resulting in porosity and permeability being decreased by 4.73–6.28% and 36.02–3.70%, respectively. With the increase in original permeability, the permeability loss rate decreases. During development, the loss rate of gas production rate is much higher than that of permeability. Increasing the production pressure difference is conducive to reducing the influence. SB also reduces the recovery, which leads to the loss rate of gas production being much higher than that of porosity. For reservoirs with a high permeability, the loss rates of gas production rate and the amount produced are close to those of permeability and porosity. Therefore, in the reservoir analysis and development of carbonate gas reservoirs bearing SB, it is necessary and significant to analyze the influence of reservoir types.

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“…On the other hand, a Darcy‐based simulation is the most commonly used approach in reservoir simulation studies 26–28 . It is also used to model CO 2 flow in porous media for CO 2 ‐enhanced oil recovery (EOR) 29–33 and plume migration in aquifers 34–36 .…”

Section: Introductionmentioning

confidence: 99%

Modeling CO₂ plume migration using an invasion‐percolation approach that includes dissolution

et al. 2020

Self Cite

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Geological carbon dioxide (CO 2 ) sequestration has been proposed as a viable technique to decrease effective emissions of CO 2 into the atmosphere. However, the security of this sequestration is tied to our understanding of the long-term migration of CO 2 in subsurface. The dissolution of CO 2 in the reservoir brine is one of the main long-term trapping mechanisms. However, the assumptions used in large-scale reservoir simulations usually lead to an overestimation of the dissolution volume. We propose a modified approach based on the macroscopic invasion-percolation (MIP) theory that allows the dissolution of CO 2 into brine. We used a high-resolution geological model to compare the Darcy-, modified MIP-, and classic MIP-based simulation results. We observed a significant shrinkage in the nonaqueous plume volume when dissolution is considered during the MIP simulation. In the case of Darcy-based simulation, the plume was completely trapped inside the reservoir with limited migration even after a thousand-year simulation. On the other hand, the majority of the plume migrated out of the simulated reservoir in the case of MIP. Our approach provides more realistic estimation of the dissolution volume and nonaqueous plume extent while leveraging the computational efficiency enjoyed by MIP. C Several modeling approaches are available to forecast the fate of CO 2 in the underground. [8][9][10][11][12] One of these approaches is modified invasion percolation (MIP), which assumes negligible effect for viscous forces on fluid displacement. Therefore, the balance between the buoyancy and capillary forces is the key factor in the MIP method to predict the plume migration. 13,14 On the other hand, Darcy-based approaches solve a set of

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The impact of asphaltene deposition on fluid flow in sandstone

Cited by 36 publications

References 24 publications

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Influence of Pore Structure and Solid Bitumen on the Development of Deep Carbonate Gas Reservoirs: A Case Study of the Longwangmiao Reservoir in Gaoshiti–Longnusi Area, Sichuan Basin, SW China

Modeling CO₂ plume migration using an invasion‐percolation approach that includes dissolution

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The impact of asphaltene deposition on fluid flow in sandstone

Cited by 36 publications

References 24 publications

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Influence of Pore Structure and Solid Bitumen on the Development of Deep Carbonate Gas Reservoirs: A Case Study of the Longwangmiao Reservoir in Gaoshiti–Longnusi Area, Sichuan Basin, SW China

Modeling CO2 plume migration using an invasion‐percolation approach that includes dissolution

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Modeling CO₂ plume migration using an invasion‐percolation approach that includes dissolution