Effects of salinity and slug size in miscible CO2 water-alternating-gas core flooding experiments

Van, Si Le; Chon, Bo Hyun

doi:10.1016/j.jiec.2017.03.030

Cited by 25 publications

(3 citation statements)

References 28 publications

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“…Cost-effective and environmentally friendly techniques to enhance oil recovery from carbonates are therefore of broad scientific interest . CO 2 -assisted EOR techniques (e.g., miscible and immiscible continuous injection, , carbonate water flooding, huff and puff injection, , and water-alternating-CO 2 − ) have gained interests in scientific research and industry. This is largely because CO 2 -assisted EOR techniques can enhance oil recovery in a cost-effective and environmentally friendly way (e.g., decreasing the use of toxic chemicals and cutting back on the greenhouse gas emission released).…”

Section: Introductionmentioning

confidence: 99%

A pH-Resolved Wettability Alteration: Implications for CO₂-Assisted EOR in Carbonate Reservoirs

et al. 2017

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Wettability of an oil/brine/rock system is a critical petrophysical parameter, which governs subsurface multiphase flow behavior, thus hydrocarbon recovery. While the mechanisms of CO2-assisted enhanced oil recovery (EOR) techniques have been extensively investigated in carbonate reservoirs, few have been done to identify the controlling factor of CO2-induced wettability alteration, and fewer have looked beyond the implications for CO2-assisted EOR. We thus hypothesize that CO2-assisted EOR techniques cause a more hydrophilic system due to H+ adsorption on the interface of oil/brine and brine/carbonate as a result of CO2 dissolution. To test this hypothesis, we measured contact angles of two oils with different acid and base numbers in the presence of 1 M Na2SO4 at pH either 3 or 8. Moreover, we performed a geochemical study to identify the controlling factor of wettability alteration. Contact angle results support the hypothesis, showing that the oil/brine/rock system shifts toward more water-wet because of less bonds between oil/brine and brine/carbonate due to H+ adsorption on the interface of oil/brine and brine/carbonate. Our results also suggest that CO2-assisted EOR techniques likely shift relative permeability curves toward a lower residual oil saturation due to wettability alteration. We argue that geochemical reactions may need to be incorporated into a reservoir numerical model, thus better managing and predicting the performance of CO2-assisted EOR.

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Section: Introductionmentioning

confidence: 99%

A pH-Resolved Wettability Alteration: Implications for CO₂-Assisted EOR in Carbonate Reservoirs

et al. 2017

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“…The atmospheric concentration of CO 2 increased from a preindustrial level of 280 ppm to 380 ppm in 2005 and is predicated to reach 550 ppm by 2050 with a progressively faster rate. , Carbon capture, utilization, and storage technologies at commercial scale is an important approach in the global grand challenge presented by current CO 2 emissions. − CO 2 can be stored through injection into geological formations, mainly oil reservoirs, abandoned gas fields, and deep saline aquifers. − CO 2 injection into the depleted oil reservoirs (i.e., CO 2 -enhanced oil recovery) is the more common approach, which combines both CO 2 storage and oil recovery. − Currently, the majority of CO 2 storage/oil recovery projectsalso the largest CO 2 projects worldwideare in United States and Canada, allowing ∼370 billion tonnes of CO 2 storage potential and an additional ∼1300 billion barrels of oil recovery . CO 2 can be injected into the formation via various processes, depending on reservoir conditions and operational constraints, including continuous CO 2 injection (CO 2 flooding), , CO 2 huff-n-puff, − carbonated water injection, , and water-alternating-CO 2 injection. − In all of these cases, CO 2 interacts with the reservoir fluids and geology, with implications for storage, oil recovery, and associated environmental and economic performance. A range of mechanisms contribute to CO 2 -enhanced oil recovery including oil swelling, component extraction, interfacial tension reduction, and viscosity reduction. − …”

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confidence: 99%

Full Characterization of CO₂–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle

Sharbatian

Abedini

et al. 2018

Anal. Chem.

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Carbon capture, storage, and utilization technologies target a reduction in net CO emissions to mitigate greenhouse gas effects. The largest such projects worldwide involve storing CO through enhanced oil recovery-a technologically and economically feasible approach that combines both storage and oil recovery. Successful implementation relies on detailed measurements of CO-oil properties at relevant reservoir conditions (P = 2.0-13.0 MPa and T = 23 and 50 °C). In this paper, we demonstrate a microfluidic method to quantify the comprehensive suite of mutual properties of a CO and crude oil mixture including solubility, diffusivity, extraction pressure, minimum miscibility pressure (MMP), and contact angle. The time-lapse oil swelling/extraction in response to CO exposure under stepwise increasing pressure was quantified via fluorescence microscopy, using the inherent fluorescence property of the oil. The CO solubilities and diffusion coefficients were determined from the swelling process with measurements in strong agreement with previous results. The CO-oil MMP was determined from the subsequent oil extraction process with measurements within 5% of previous values. In addition, the oil-CO-silicon contact angle was measured throughout the process, with contact angle increasing with pressure. In contrast with conventional methods, which require days and ∼500 mL of fluid sample, the approach here provides a comprehensive suite of measurements, 100-fold faster with less than 1 μL of sample, and an opportunity to better inform large-scale CO projects.

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“…The volume ratio of water slug and CO 2 slug is 1:1, the volume of the slug is 0.4 PV. According to the comprehensive assessment, these injection parameters are considered to be optimal for the effect of oil displacement and injection capacity, commonly used in oilfields [31][32][33]. When the inlet pressure remained stable during CO 2 injection in the three consecutive flooding cycles and the total flooding time was over 150 h, the core-flooding was completed.…”

Section: Core-floodingmentioning

confidence: 99%

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Wang

Yang

Han³

et al. 2019

Energies

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The petrophysical properties of ultra-low permeability sandstone reservoirs near the injection wells change significantly after CO2 injection for enhanced oil recovery (EOR) and CO2 storage, and different CO2 displacement methods have different effects on these changes. In order to provide the basis for selecting a reasonable displacement method to reduce the damage to these high water cut reservoirs near the injection wells during CO2 injection, CO2-formation water alternate (CO2-WAG) flooding and CO2 flooding experiments were carried out on the fully saturated formation water cores of reservoirs with similar physical properties at in-situ reservoir conditions (78 °, 18 MPa), the similarities and differences of the changes in physical properties of the cores before and after flooding were compared and analyzed. The measurement results of the permeability, porosity, nuclear magnetic resonance (NMR) transversal relaxation time (T2) spectrum and scanning electron microscopy (SEM) of the cores show that the decrease of core permeability after CO2 flooding is smaller than that after CO2-WAG flooding, with almost unchanged porosity in both cores. The proportion of large pores decreases while the proportion of medium pores increases, the proportion of small pores remains almost unchanged, the distribution of pore size of the cores concentrates in the middle. The changes in range and amplitude of the pore size distribution in the core after CO2 flooding are less than those after CO2-WAG flooding. After flooding experiments, clay mineral, clastic fines and salt crystals adhere to some large pores or accumulate at throats, blocking the pores. The changes in core physical properties are the results of mineral dissolution and fines migration, and the differences in these changes under the two displacement methods are caused by the differences in three aspects: the degree of CO2-brine-rock interaction, the radius range of pores where fine migration occurs, the power of fine migration.

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Effects of salinity and slug size in miscible CO2 water-alternating-gas core flooding experiments

Cited by 25 publications

References 28 publications

A pH-Resolved Wettability Alteration: Implications for CO₂-Assisted EOR in Carbonate Reservoirs

A pH-Resolved Wettability Alteration: Implications for CO₂-Assisted EOR in Carbonate Reservoirs

Full Characterization of CO₂–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

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Effects of salinity and slug size in miscible CO2 water-alternating-gas core flooding experiments

Cited by 25 publications

References 28 publications

A pH-Resolved Wettability Alteration: Implications for CO2-Assisted EOR in Carbonate Reservoirs

A pH-Resolved Wettability Alteration: Implications for CO2-Assisted EOR in Carbonate Reservoirs

Full Characterization of CO2–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

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Product

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A pH-Resolved Wettability Alteration: Implications for CO₂-Assisted EOR in Carbonate Reservoirs

A pH-Resolved Wettability Alteration: Implications for CO₂-Assisted EOR in Carbonate Reservoirs

Full Characterization of CO₂–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle