The Investigation on the Key Hydrocarbons of Crude Oil Swelling via Supercritical CO<sub>2</sub>

Han, Haishui; Shi, Li; Chen, Xinglong; Zhang, Ke; Yu, Hongwei; Ji, Zemin

doi:10.1002/9781119363804.ch7

Cited by 2 publications

(1 citation statement)

References 15 publications

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“…Low-salinity waterflooding is one such process that causes wettability modification and leads to higher oil recovery [28]; several mechanisms have been proposed to explain the effect, although there has been no consensus [29][30][31][32][33][34]. Wettability modification will also occur in rock-oil-CO 2 systems [35], due to the fact that CO 2 reduces the viscosity of crude oil [36] and leads to asphaltene precipitation [37,38] during the oil-CO 2 interaction. Thus, wettability should be expected to evolve during subsurface engineering endeavors involving perturbations of pore fluid composition, rather than being a simple fixed parameter for a given reservoir rock type.…”

Section: Variability and Evolution Of Wettability During Ccus/eor In mentioning

confidence: 99%

Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wettability

et al. 2019

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The efficiency of carbon utilization and storage within the Pennsylvanian Morrow B sandstone, Farnsworth Unit, Texas, is dependent on three-phase oil, brine, and CO2 flow behavior, as well as spatial distributions of reservoir properties and wettability. We show that end member two-phase flow properties, with binary pairs of oil–brine and oil–CO2, are directly dependent on heterogeneity derived from diagenetic processes, and evolve progressively with exposure to CO2 and changing wettability. Morrow B sandstone lithofacies exhibit a range of diagenetic processes, which produce variations in pore types and structures, quantified at the core plug scale using X-ray micro computed tomography imaging and optical petrography. Permeability and porosity relationships in the reservoir permit the classification of sedimentologic and diagenetic heterogeneity into five distinct hydraulic flow units, with characteristic pore types including: macroporosity with little to no clay filling intergranular pores; microporous authigenic clay-dominated regions in which intergranular porosity is filled with clay; and carbonate–cement dominated regions with little intergranular porosity. Steady-state oil–brine and oil–CO2 co-injection experiments using reservoir-extracted oil and brine show that differences in relative permeability persist between flow unit core plugs with near-constant porosity, attributable to contrasts in and the spatial arrangement of diagenetic pore types. Core plugs “aged” by exposure to reservoir oil over time exhibit wettability closer to suspected in situ reservoir conditions, compared to “cleaned” core plugs. Together with contact angle measurements, these results suggest that reservoir wettability is transient and modified quickly by oil recovery and carbon storage operations. Reservoir simulation results for enhanced oil recovery, using a five-spot pattern and water-alternating-with-gas injection history at Farnsworth, compare models for cumulative oil and water production using both a single relative permeability determined from history matching, and flow unit-dependent relative permeability determined from experiments herein. Both match cumulative oil production of the field to a satisfactory degree but underestimate historical cumulative water production. Differences in modeled versus observed water production are interpreted in terms of evolving wettability, which we argue is due to the increasing presence of fast paths (flow pathways with connected higher permeability) as the reservoir becomes increasingly water-wet. The control of such fast-paths is thus critical for efficient carbon storage and sweep efficiency for CO2-enhanced oil recovery in heterogeneous reservoirs.

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Section: Variability and Evolution Of Wettability During Ccus/eor In mentioning

confidence: 99%

Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wettability

et al. 2019

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Wettability of rock/CO2/brine and rock/oil/CO2-enriched-brine systems:Critical parametric analysis and future outlook

Arif

Abu-Khamsin

Iglauer

2019

Advances in Colloid and Interface Science

174

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The Investigation on the Key Hydrocarbons of Crude Oil Swelling via Supercritical CO₂

Cited by 2 publications

References 15 publications

Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wettability

Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wettability

Wettability of rock/CO2/brine and rock/oil/CO2-enriched-brine systems:Critical parametric analysis and future outlook

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The Investigation on the Key Hydrocarbons of Crude Oil Swelling via Supercritical CO2

Cited by 2 publications

References 15 publications

Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wettability

Carbon Storage and Enhanced Oil Recovery in Pennsylvanian Morrow Formation Clastic Reservoirs: Controls on Oil–Brine and Oil–CO2 Relative Permeability from Diagenetic Heterogeneity and Evolving Wettability

Wettability of rock/CO2/brine and rock/oil/CO2-enriched-brine systems:Critical parametric analysis and future outlook

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The Investigation on the Key Hydrocarbons of Crude Oil Swelling via Supercritical CO₂