Intermittent CO 2 and viscosity-reducing gas (VRG) injection for enhanced heavy oil recovery

Seyyedsar, Seyyed Mehdi; Sohrabi, Mehran

doi:10.1016/j.fuproc.2017.04.013

Cited by 19 publications

(10 citation statements)

References 31 publications

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“…Although studying these fluid–fluid interactions is of great interest, due to the complexity of these interactions and their molecular scale, studying them at the lab scale is limited to pore-scale studies, such as micromodel − and conventional phase-behavior studies known as the PVT analysis. − According to the conducted micromodel studies and PVT analysis, − CO 2 –oil interactions lead to reduction in oil viscosity and an increase in oil volume known as oil swelling, which could lead to the production of trapped oil in reservoirs. Several laboratory studies , via using core flooding experiments identified the oil recovery potential of these mechanisms, which highlight their importance on pore-scale displacement efficiency of CO 2 injection. However, all of these lab studies could only identify and discuss the impacts of these interactions on the oil displacement efficiency of CO 2 , and none of them could study these complex interactions at the molecular scale where they first occurred.…”

Section: Introductionmentioning

confidence: 99%

Molecular Dynamics Simulation of Transport and Structural Properties of CO₂–Alkanes

2021

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Carbone dioxide emissions have imposed serious threats on the environment and health. As such, industrially viable CO 2 storage and utilization technologies are of high demand. This study by performing a combined Monte Carlo and molecular dynamics simulations in osmotic and NPT ensembles aims to provide new insights into the complex CO 2 interactions with two well-known alkanes (C10 and C20) over a pressure range of 5−30 MPa and a constant temperature of 311 K. The present study provides a quantitative understanding on the effect of CO 2 solubility on density, specific volume, swelling, static structure, diffusion, and viscosity of CO 2 -saturated alkanes. According to results, CO 2 dissolution into alkanes, alkane-specific volume, and swelling are a direct function of pressure and alkane chain length. The densities of CO 2 -saturated alkanes increase with increasing pressure via an increase in mechanical compaction and/or increase in CO 2 mole fraction in solutions. As pressure increases, CO 2 mole fraction in solution increases and, consequently, the solution viscosity decreases. It was found that the swelling of CO 2 -saturated alkanes is due to the stretching of the alkane molecules rather than the change in their average separation distance. Furthermore, the CO 2 diffusion coefficient is closely related to the pressure and alkane chain length. The increase in the length of the alkane molecule chain leads to reduction in the CO 2 diffusion coefficient. Finally, according to the results, it is expected that the swelling oil recovery and CO 2 dissolution trapping mechanisms of CO 2 injection act much stronger for lighter crude oils than medium to heavy ones, while the viscosity reduction oil recovery mechanism is more dominant for medium to heavy oils than light ones. These findings are useful for fast screening oil reservoirs to identify the most suitable one for CO 2 enhanced oil recovery−storage applications.

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Section: Introductionmentioning

confidence: 99%

Molecular Dynamics Simulation of Transport and Structural Properties of CO₂–Alkanes

2021

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“… , In this regard, enhanced oil recovery using CO 2 has become one of the main applications of CCUS, providing safe sites to store CO 2 and an effective way to offset the costs of carbon capture. − CO 2 is widely used for the displacement of crude oil from formation, such as gas flooding, huff–puff, and water alternating gas processes. − However, the displacement efficiency of CO 2 flooding is too low because of the low viscosity of CO 2. In order to overcome this problem, CO 2 foam flooding is considered a great alternative . The viscosity of CO 2 foam is much higher than that of pure CO 2 gas, and along with the presence of a surfactant, it can effectively enhance oil recovery by reducing the interfacial tension between the oil and water .…”

Section: Introductionmentioning

confidence: 99%

“…9−11 However, the displacement efficiency of CO 2 flooding is too low because of the low viscosity of CO 2. 12 In order to overcome this problem, CO 2 foam flooding is considered a great alternative. 13 The viscosity of CO 2 foam is much higher than that of pure CO 2 gas, and along with the presence of a surfactant, it can effectively enhance oil recovery by reducing the interfacial tension between the oil and water.…”

Section: Introductionmentioning

confidence: 99%

Enhanced Oil Recovery Using Aqueous CO₂ Foam Stabilized by Particulate Matter from Coal Combustion

Zhou

Zhang

et al. 2020

Energy Fuels

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Carbon dioxide (CO2) foam flooding is a promising carbon capture, utilization, and storage technology that is often used for enhanced oil recovery (EOR). However, the instability of foam and low displacement efficiency restrict its efficient utilization. In this work, the microflow behavior and the EOR performance of aqueous CO2 foam stabilized by particulate matter (PM) from coal combustion were systematically studied using a micromodel with etched porous media. The results showed that, when a moderate camellia oleifera saponin (COS) concentration was used, the addition of PM could transfer the maximum foam volume to a higher temperature. Moreover, with the addition of PM, the half-life of CO2 foam drainage could be increased by ∼12 times at 75 °C. The disproportionation, coalescence, and film rupture of CO2 foams in the porous media slowed down in the presence of PM. At high water cut stage, the different types of microresidual oil, such as cluster, columnar, membrane, and blind-end, could effectively be activated and displaced by the PM/COS foam. During the flooding, the high stability of PM/COS foam in the presence of oil guaranteed the efficiency of the whole process. The solid-like foam film enhanced the plugging effect in the water channel. The rough surface of the PM/COS bubble with high interfacial viscoelasticity enhanced the scrubbing capacity of the bubble to residual oil. According to the sandpack flooding results, the recovery of oil increased by ∼40.85% due to the injection of PM/COS foam and subsequent water at 60 °C, which was about twice of the oil recovery obtained using pure surfactant foam.

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“…In recent decades, the energy needed to produce oil has become inadequate to achieve economically viable scales of production. For this purpose, to improve oil recovery, additional energy is required. − The most common secondary recovery techniques are the injection of gas and water. − Basically, gas is injected into the gas plug and water is injected into the production area to sweep the oil from the reservoir (Figure ). A pressure maintenance program may begin during the primary recovery stage, but it is an improved form or recovery.…”

Section: Introductionmentioning

confidence: 99%

Influence of the Clay Content and Type of Algerian Sandstone Rock Samples on Water–Oil Relative Permeabilities

et al. 2019

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The objective of this work is to study the effect of certain factors on oil−water relative permeability curves following a considerable drop in the production of certain oil wells at the Hassi Messaoud field in southern Algeria. In the present study, oil−water relative permeability experiments and irreducible water (S wi ) and residual oil (S or ) saturations have been investigated. The effect of the clay particle content in the samples (such as illite and kaolinite) on oil recovery is investigated. Indeed, other factors, such as injected pressure, wettability alteration, and petrophysical properties, of the reservoir rock interact with each other and, particularly, in the presence of injected Albian water. Results of the waterflooding experiments show that oil recovery (IOP) increases with increasing clay content, namely, kaolinite and illite type; this IOP is clearly higher for plugs containing more kaolinite than illite. The tested samples have water-wetting behavior, showing a decrease in S or and an increase in S wi , and are characterized by a strong presence of clays, 70% kaolinite and 30% illite, with a breakthrough from about 40 to 50%.

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Intermittent CO 2 and viscosity-reducing gas (VRG) injection for enhanced heavy oil recovery

Cited by 19 publications

References 31 publications

Molecular Dynamics Simulation of Transport and Structural Properties of CO₂–Alkanes

Molecular Dynamics Simulation of Transport and Structural Properties of CO₂–Alkanes

Enhanced Oil Recovery Using Aqueous CO₂ Foam Stabilized by Particulate Matter from Coal Combustion

Influence of the Clay Content and Type of Algerian Sandstone Rock Samples on Water–Oil Relative Permeabilities

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Intermittent CO 2 and viscosity-reducing gas (VRG) injection for enhanced heavy oil recovery

Cited by 19 publications

References 31 publications

Molecular Dynamics Simulation of Transport and Structural Properties of CO2–Alkanes

Molecular Dynamics Simulation of Transport and Structural Properties of CO2–Alkanes

Enhanced Oil Recovery Using Aqueous CO2 Foam Stabilized by Particulate Matter from Coal Combustion

Influence of the Clay Content and Type of Algerian Sandstone Rock Samples on Water–Oil Relative Permeabilities

Contact Info

Product

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Molecular Dynamics Simulation of Transport and Structural Properties of CO₂–Alkanes

Molecular Dynamics Simulation of Transport and Structural Properties of CO₂–Alkanes

Enhanced Oil Recovery Using Aqueous CO₂ Foam Stabilized by Particulate Matter from Coal Combustion