Gas-Oil Relative Permeability Ratio Correlation From Laboratory Data

Knopp, C.R.

doi:10.2118/963-pa

Cited by 9 publications

(4 citation statements)

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“…This observation is in disagreement with previous reports, ,,, in which immobile water saturation had no effect on gas/oil displacement and relative permeabilities. This discrepancy can be explained by the very low oil/gas IFT in our experiments.…”

Section: Resultscontrasting

confidence: 99%

“…This discrepancy can be explained by the very low oil/gas IFT in our experiments. Capillary pressure is a function of IFT, σ, as well as contact angle, θ, and pore radius, r , through the following equation: P cog = 2 σ og nobreak0em.25em⁡ cos nobreak0em.25em⁡ θ r For high oil/gas IFT systems, ,,, capillary forces (between oil and gas) would be high enough to prevent the gas entering into small pores. As a result, in a high oil/gas IFT system, in both cases with and without immobile water saturation, gas would not be able to enter those very small pores anyway and the amount of oil recovered by gas and k r would be unaffected by the presence or absence of immobile water saturation.…”

Section: Resultsmentioning

confidence: 99%

“…For high oil/gas IFT systems, 23,33,49,50 capillary forces (between oil and gas) would be high enough to prevent the gas entering into small pores. As a result, in a high oil/gas IFT system, in both cases with and without immobile water saturation, gas would not be able to enter those very small pores anyway and the amount of oil recovered by gas and k r would be unaffected by the presence or absence of immobile water saturation.…”

Section: Energy and Fuelsmentioning

confidence: 99%

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Recovery Mechanisms and Relative Permeability for Gas/Oil Systems at Near-Miscible Conditions: Effects of Immobile Water Saturation, Wettability, Hysteresis, and Permeability

Fatemi

Sohrabi

2013

Energy Fuels

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Near-miscible gas injection represents a number of processes of great importance to reservoir engineers, including hydrocarbon gas injection and CO 2 flood. Very little experimental data is available in the literature on displacements involving very low interfacial tension (IFT). In this paper, we present the results of a series of two-and three-phase gas injection (drainage) and oil injection (imbibition) core flood experiments for a gas/oil system at near-miscible (IFT = 0.04 mN m −1 ) conditions. Two different cores, a high-permeability (1000 mD) and a lower permeability (65 mD) core, were used in the experiments, and both water-and mixed-wet conditions were examined. The results show that, despite a very low gas/oil IFT, there is significant hysteresis between the imbibition and drainage oil and gas relative permeability (k r ) curves in the 65 mD core. Hysteresis was less for the 1000 mD core (in comparison to the 65 mD core), but it still could not be ignored. Near-miscible k r hysteresis was significant for both water-and mixed-wet systems. The presence of immobile water in the water-wet cores improved oil relative permeabilities but reduced gas relative permeabilities in both imbibition and drainage directions. As a result, oil recovery for gas injection experiments improved when the rock contained immobile water. Both oil and gas relative permeabilities reduced when the rock wettability was altered to mixed-wet from water-wet, and as a result, oil recovery by gas injection in the mixed-wet rock was less than that obtained under water-wet conditions. We offer explanations for these observations based on our understanding of the pore-scale interactions and mechanisms, the distribution of fluid phases, and their spreading behavior. The results help us better understand the impact of some of the important parameters pertinent to k r and its hysteresis, especially in very low IFT gas/oil systems and mixed-wet rocks. Understanding these effects and behavior is important for the improved prediction of the performance of gas injection and water-alternating-gas (WAG) injection in oil reservoirs.

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Section: Resultscontrasting

confidence: 99%

Section: Resultsmentioning

confidence: 99%

Section: Energy and Fuelsmentioning

confidence: 99%

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Recovery Mechanisms and Relative Permeability for Gas/Oil Systems at Near-Miscible Conditions: Effects of Immobile Water Saturation, Wettability, Hysteresis, and Permeability

Fatemi

Sohrabi

2013

Energy Fuels

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“…Because of different research methods and measures, there is a big difference in the impact of irreducible water saturation on critical condensate saturation. Knopp (1964), Delclaud and Rochon (1987), and Gravier et al (1986) held that irreducible water did not influence the flow of condensate. However, Danesh and Henderson (1988) suggested that irreducible water would decrease critical condensate saturation.…”

Section: Introductionmentioning

confidence: 99%

Experimental Research of Critical Condensate Saturation and Flow Characteristics of Gas Condensate Reservoir

Zan

et al. 2013

Petroleum Science and Technology

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The critical condensate saturation is a key parameter to reflect condensate flow capacity. The authors propose an experimental method to determine the critical condensate saturation and analyze the flow characteristics of gas condensate by coreflooding and chromatography. Using this method, they perform two sets of experiments with real-core of a gas condensate reservoir and a binary mixture fluid of methane and n-pentane under 84 ı C. Experimental results show that the critical condensate saturation is 3.04% and 4.66% when irreducible water saturation is 40% and 27%, respectively. The results also indicate porous media will raise the dew point pressure. The irreducible water and capillary number effect is conducive to the flow of condensate. Based on experimental researches, the authors theoretically analyze the distribution and mobilization characteristics of condensate. Although critical condensate saturation is low, it doesn't mean the condensate will be able to flow freely when it achieves the value, and condensate saturation will continue to increase. Compositional simulation is performed to demonstrate that the critical condensate saturation is low, which is important for the high effective development of a gas condensate reservoir.

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Numerical Determinationof Critical Condensate Saturation in Gas Condensate Reservoirs

Yi¹,

Li²,

Ji³

2017

Journal of Energy Resources Technology

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Critical condensate saturation, Scc, is a key parameter for the evaluation of well deliverability in gas condensate reservoirs. We propose a new method to determine Scc by performing three-phase flow simulations with three-dimensional (3D) pore network model. First, we establish a network model with random fractal methodology. Second, based on the condensation model in the literature of Li and Firoozabadi, we develop a modified condensation model to describe the condensation phenomenon of gas with connate water in the porous medium. The numerical model is verified by experimental measurements in the literature. Then, we investigate the influence of different factors on the critical condensate saturation, including micro pore structure (pore radius and fractal dimension), condensate gas/oil interfacial tension (IFT), and flow rate at different irreducible water saturation, Swi. The simulation results show that Scc decreases with increasing of average pore radius, but increases with increasing of fractal dimension. In the case of the same gas/oil interfacial tension, the higher the connate water saturation, the higher the critical condensate saturation. There is a critical gas/oil interfacial tension, below the critical value, the critical condensate saturation increases drastically with increasing of interfacial tension while it keeps almost unchanged when the interfacial tension is above the critical value. The critical condensate saturation decreases with increasing in the gas flow rate. High capillary number results in low critical condensate saturation. Reasonable increase in producing pressure drop can effectively improve the flow capacity of condensate oil.

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Gas-Oil Relative Permeability Ratio Correlation From Laboratory Data

Cited by 9 publications

References 0 publications

Recovery Mechanisms and Relative Permeability for Gas/Oil Systems at Near-Miscible Conditions: Effects of Immobile Water Saturation, Wettability, Hysteresis, and Permeability

Recovery Mechanisms and Relative Permeability for Gas/Oil Systems at Near-Miscible Conditions: Effects of Immobile Water Saturation, Wettability, Hysteresis, and Permeability

Experimental Research of Critical Condensate Saturation and Flow Characteristics of Gas Condensate Reservoir

Numerical Determinationof Critical Condensate Saturation in Gas Condensate Reservoirs

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