Experimental and numerical study of compositional two-phase displacements in layered porous media

Alhamdan, Mohammed R.; Cinar, Yildiray; Suiçmez, Vural Sander; Dindoruk, Birol

doi:10.1016/j.petrol.2012.09.009

Cited by 18 publications

(5 citation statements)

References 22 publications

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“…The oil RF of the entire system was very low, 27.64%. This finding is caused mainly by the heterogeneity of the reservoir and the fingering effect in the high permeability core, which results from differences in capillary resistance in different cores and leads to premature CO 2 BT . Hence, a large amount of CO 2 injected into the multilayer system flowed out through the CO 2 channel in the high-permeability core.…”

Section: Resultsmentioning

confidence: 99%

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO₂ and Water–Alternating-CO₂ (CO₂–WAG) Flooding at Miscible Pressures

et al. 2019

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Blockage in reservoirs caused by asphaltene deposits and inorganic interactions is a serious problem that may exacerbate the complexity of displacement characteristics in heterogeneous multilayer sandstone reservoirs and affect crude oil recovery performance during CO2 and CO2-WAG flooding. In this study, experiments of both CO2 and CO2-WAG flooding were carried out on the same multilayer systems under miscible conditions (70℃, 18 MPa). The two flooding methods were evaluated for oil production performance and reservoir damage. The experimental results indicate that, after CO2 flooding, the entire system has a low oil recovery factor (RF) of 27.6%, and oil is produced mainly from the high permeability layer (91.4%), whilst the residual oil remains predominantly in the medium and low permeability layers. The injection pressure of CO2-WAG flooding is high, but the timing of CO2 breakthrough (BT) is late, and the oil RF of the entire system reaches 44.5%. The contribution rate of oil production in medium and low permeability layers is improved to 3.8% and 17.1%, respectively. Furthermore, the permeability of the high permeability layer decreases by 16.8% after CO2 flooding, which is mainly due to asphaltene precipitation. However, after CO2-WAG flooding, the permeability of each layer is significantly reduced, namely by 29.4%, 16.8% and 6.9% respectively. Asphaltene precipitation is still the main factor, but permeability decline caused by CO2-brine-rock interactions cannot be ignored, especially in the high permeability layer (6.1%). Therefore, for multilayer reservoirs with high heterogeneity, CO2-WAG flooding provides the better oil displacement performance, but prevention and control measures for asphaltene precipitation are more necessary.

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Section: Resultsmentioning

confidence: 99%

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO₂ and Water–Alternating-CO₂ (CO₂–WAG) Flooding at Miscible Pressures

et al. 2019

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“…Dawe et al 1992;Huang et al 1995;Cinar et al 2006;Alhamdan et al 2012), and geologic CO 2 storage (e.g. Krevor et al 2011;Datta and Weitz 2013).…”

Section: Introductionmentioning

confidence: 99%

Capillary Heterogeneity Trapping and Crossflow in Layered Porous Media

et al. 2017

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We examine the effect of capillary and viscous forces on the displacement of one fluid by a second, immiscible fluid across and along parallel layers of contrasting porosity, and relative permeability, as well as previously explored contrasts in absolute permeability and capillary pressure. We consider displacements with wetting, intermediate-wetting and non-wetting injected phases. Flow is characterized using six independent dimensionless numbers and a dimensionless storage efficiency, which is numerically equivalent to the recovery efficiency. Results are directly applicable to geologic carbon storage and hydrocarbon production. We predict how the capillary-viscous force balance influences storage efficiency as a function of a small number of key dimensionless parameters, and provide a framework to support mechanistic interpretations of complex field or experimental data, and numerical model predictions, through the use of simple dimensionless models. When flow is directed across layers, we find that capillary heterogeneity traps the non-wetting phase, regardless of whether it is the injected or displaced phase. However, minimal trapping occurs when the injected phase is intermediate-wetting or when high-permeability layers contain a smaller moveable volume of fluid than low-permeability layers. A dimensionless capillary-to-viscous number defined using the layer thickness rather than the more commonly used system length is most relevant to predict capillary heterogeneity trapping. When flow is directed along layers, we show that, regardless of wettability, increasing capillary crossflow reduces the distance between the leading edges of the injected phase in each layer and increases storage efficiency. This may be counter-intuitive when the injected phase is non-wetting. Crossflow has a significant impact on storage efficiency only when high-permeability layers contain a smaller moveable volume of fluid than low-permeability layers. In that case, capillary heterogeneity traps the wetting phase, regardless of whether it is the injected or displaced phase. B Yacine Debbabi

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“…According to the field production data and predicted results, the results obtained using the multilayer system correspond more to actual values. This finding is mainly caused by the heterogeneity of the reservoir and the fingering effect in the high-permeability layer . Therefore, using the multilayer system has a practical guiding significance for the field.…”

Section: Results and Discussionmentioning

confidence: 99%

Oil Recovery Performance and CO₂ Storage Potential of CO₂ Water-Alternating-Gas Injection after Continuous CO₂ Injection in a Multilayer Formation

Yang

et al. 2016

Energy Fuels

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In this study, oil recovery performance and carbon dioxide (CO 2 ) storage potential of a CO 2 water-alternating-gas (CO 2 -WAG) injection after continuous CO 2 injection process for multilayer formation were experimentally determined under immiscible and miscible conditions. First, a slim-tube apparatus was used to measure the minimum miscibility pressure (MMP) of a CO 2 −crude oil system (MMP = 22.79 MPa), which was applied as a guide for follow-on investigations. Afterward, the CO 2 -WAG injection after the continuous CO 2 injection for a triple-layer system, horizontally placed and parallel-connected, was conducted to evaluate the capacity of enhanced oil recovery and CO 2 storage potential of the multilayer formation at different operating pressures and a reservoir temperature of 98 °C. Results revealed that the oil recovery of the entire system was determined by the recovery of a layer with the highest permeability, which was more than 90% of the entire system recovery provided by the highest permeability layer in the continuous CO 2 injection. The ensuing CO 2 -WAG injection could further enhance the oil recovery of the system after the continuous CO 2 injection. The contribution of the recovery produced by the highest permeability from 90 to 98.3% could also be reduced for the entire system recovery. The oil recovery factor of the multilayer system increased as the operating pressure increased (i.e., from 33.01% of the system at P op = 15 MPa to 39.42% of the system at P op = 25 MPa). From a view of CO 2 storage potential, the ensuing CO 2 -WAG injection at immiscible and miscible conditions could also double the amount of stored CO 2 after the continuous CO 2 injection for the multilayer system. More than 75−80% of stored CO 2 for the multilayer system was contributed by the highest permeability layer at the end of the CO 2 -WAG the CO 2 -WAG injection after the continuous CO 2 injection process under immiscible and miscible conditions. Therefore, for a multilayer formation, such as the Jilin oilfield, the layer with medium and low permeability should be further developed after CO 2 -WAG injection.

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Experimental and numerical study of compositional two-phase displacements in layered porous media

Cited by 18 publications

References 22 publications

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO₂ and Water–Alternating-CO₂ (CO₂–WAG) Flooding at Miscible Pressures

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO₂ and Water–Alternating-CO₂ (CO₂–WAG) Flooding at Miscible Pressures

Capillary Heterogeneity Trapping and Crossflow in Layered Porous Media

Oil Recovery Performance and CO₂ Storage Potential of CO₂ Water-Alternating-Gas Injection after Continuous CO₂ Injection in a Multilayer Formation

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Experimental and numerical study of compositional two-phase displacements in layered porous media

Cited by 18 publications

References 22 publications

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO2 and Water–Alternating-CO2 (CO2–WAG) Flooding at Miscible Pressures

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO2 and Water–Alternating-CO2 (CO2–WAG) Flooding at Miscible Pressures

Capillary Heterogeneity Trapping and Crossflow in Layered Porous Media

Oil Recovery Performance and CO2 Storage Potential of CO2 Water-Alternating-Gas Injection after Continuous CO2 Injection in a Multilayer Formation

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Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO₂ and Water–Alternating-CO₂ (CO₂–WAG) Flooding at Miscible Pressures

Experimental Investigation of Oil Recovery Performance and Permeability Damage in Multilayer Reservoirs after CO₂ and Water–Alternating-CO₂ (CO₂–WAG) Flooding at Miscible Pressures

Oil Recovery Performance and CO₂ Storage Potential of CO₂ Water-Alternating-Gas Injection after Continuous CO₂ Injection in a Multilayer Formation