Measurement of Three-Phase Relative Permeability With IFT Variation

Cinar, Yildiray; Orr, Franklin M.

doi:10.2118/89419-pa

Cited by 26 publications

(19 citation statements)

References 32 publications

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“…Cinar and Orr [], in a study of the effects of interfacial tension on three‐phase relative permeability in water‐wet bead packs, used a three‐liquid fluid system composed of hexadecane‐rich, n‐butanol‐rich, and water‐rich to represent the aqueous phase, the oil phase, and the gas phase, respectively. Three different compositions of the fluids, resulting in spreading coefficients of oil on water of −0.071, +0.362, and +0.011 mN/m, were selected for displacement experiments.…”

Section: Spreading Characteristics and Layer Flowmentioning

confidence: 99%

“…Cinar and Orr [] studied the effects of interfacial tension on three‐phase relative permeability using a quaternary liquid system composed of hexadecane, n‐butanol, water, and isopropanol. Isopropanol was added to the mixture of the components in order to vary interfacial tension.…”

Section: Effects Of Interfacial Tensionmentioning

confidence: 99%

“…Relative permeability of the n‐butanol‐rich oil phase as a function of IFT at determined saturation values [ Cinar and Orr , ].…”

Section: Effects Of Interfacial Tensionmentioning

confidence: 99%

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Three-phase flow in porous media: A review of experimental studies on relative permeability

Alizadeh

Piri

2014

Rev. Geophys.

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We present a detailed, synthesized review of experimental studies on three-phase relative permeability published since 1980. We provide comprehensive, yet highly focused, analysis of critical aspects of the field and their evolution over the last three decades. In particular, we review the effects of saturation history, wettability, spreading, and layer drainage on the measured flow properties. We also list all the processes, rock types, fluid systems, and measurement techniques in order to provide a clear map for future studies. Behavior of the measured three-phase relative permeabilities with respect to fluid saturations, saturation histories, wettability of rock samples, spreading characteristics, interfacial tensions, and other pertinent properties are carefully discussed. Studies that use a diverse set of experimental techniques and data analysis to deduce relative permeability are included. The experimental techniques that should be utilized to reduce uncertainty are also explored. We interpret the measured properties and outcomes of different studies and compare them to substantiate distinct trends at various saturation ranges and provide ideas for new studies. This is intended to distill a clear image of where the field stands and to allow composition of possible paths for future investigations. The areas of critical relevance that have not been investigated or require further studies are highlighted.

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Section: Spreading Characteristics and Layer Flowmentioning

confidence: 99%

Section: Effects Of Interfacial Tensionmentioning

confidence: 99%

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Three-phase flow in porous media: A review of experimental studies on relative permeability

Alizadeh

Piri

2014

Rev. Geophys.

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“…Therefore, the oil-gas relative permeability will be affected while the water relative permeability will not, as found experimentally by Cinar and Orr (2005). In processes like WAG, SWAG or SIMGAP where the main objective is to provide mobility control for gas, in some parts of the reservoir, oil will be displaced by gas while in other parts oil will be displaced by water and it may not be contacted by gas.…”

Section: Ift Dependent Relative Permeabilitymentioning

confidence: 91%

Impact of Relative Permeability Hysteresis, IFT dependent and Three Phase Models on the Performance of Gas Based EOR Processes

Masalmeh¹,

Wei

2010

All Days

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In this paper we report on a gas-injection based EOR study in heterogeneous carbonate reservoirs. The focus of the study is on modelling three phase flow, hysteresis and compositional effects on relative permeability for a reservoir with different scales of heterogeneity.For all gas-injection based EOR processes, numerical modelling requires proper understanding and presentation of phase behaviour, saturation functions and geological heterogeneity. In this study we performed a systematic analyses of the interplay between compositional effects, relative permeability hysteresis, interfacial tension dependent relative permeability and three phase relative permeability models for different gas based EOR schemes (e.g., WAG, SWAG, SIMGAP). The simulation runs were performed using 2D and 3D fine scale sector models. In order to extend the applicability of the results to a wide range of carbonate reservoirs, the study was performed using three different reservoir models with different permeability profiles and different initial water saturation distributions. To quantify the impact of phase behavior, the performance of different injection gases (methane, CO2 and acid gas) was compared. Finally, we also compared the impact different three phase relative permeability models on oil recovery.To the best of our knowledge, there is no commercial simulator which has implemented the combination of relative permeability hysteresis, IFT dependent and three phase models in compositional mode. Therefore, the study presented in this paper is the first in the literature which investigates the combination of all these effects on the performance of gas injection EOR schemes. The study shows that proper representation of relative permeability hysteresis, compositional effects and three phase models is essential in order to assess the performances of all gas based EOR processes. The study also shows that before embarking on very expensive laboratory work for EOR studies under three-phase flow, simulations should be used to help design the laboratory work in order to focus on the most important parameters that affect fluid flow and hydrocarbon recovery. The simulation work should be carried out using fine grid sector models.

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“…Bardon and Longeron (1980). Cinar et al (2004) and Cinar and Orr (2005) measured relative permeabilities for two sets of three-phase systems analogue to gas-oil-water in water-wet and strongly oil-wet media, for "gas" injection processes in which the IFT between "gas" and "oil" was varied. They reported increasing "gas" and "oil" relative permeabilities with decreasing IFT in both media, but almost constant and decreasing "water" relative permeabilities in water-wet and oil media respectively.…”

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confidence: 99%

The Mechanism of Oil Recovery by Water-Alternating-Gas Injection at Near-Miscible Conditions in Mixed Wet Systems

Sorbie

Dijke

2010

Proceedings of SPE Improved Oil Recovery Symposium

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The modelling of WAG processes at the pore scale in the "near-miscible" regime is still not fully understood, where "nearmiscible" implies at low gas/oil interfacial tension (IFT, go  ) near the transition from immiscible to miscible conditions.Micromodel experiments under near-miscible conditions have been performed previously at Heriot-Watt U. (HWU) and results from these show clear differences from the immiscible flooding cycles. In particular, there is significant oil production through "thick" films after the breakthrough of the gas finger and, in repeated gas floods, the gas finger tends to re-establish rather than to redistribute the phases as in the immiscible floods. Here, we address some of the major issues in modelling nearmiscible WAG and a new mechanism is proposed based on the interfacial physics of the process. At near-miscible conditions, mass transfer between phases occurs and the oil and gas hydrocarbon phases approach each other in properties, which leads to both the swelling and extraction of oil. The importance of both viscous and gravity forces may increase and it is also thought that water blocking (shielding) leads to bypassing of oil, indicating that gas-water and oilwater capillary forces remain important. The flow of oil through "thick" films and layers becomes more important, possibly as a result of a "wetting transition" or gas-oil contact angle change.To explain these processes, a consistent model is proposed for the IFT and contact angles (which must also change) as the three-phase system goes from immiscible to near-miscible conditions. A linear model is assumed for the variation of the gaswater and gas-oil IFTs, gw  and ow  , as functions of the gas-oil IFT, go  , consistent with measurements. Along with some further linear assumptions on the solid-fluid IFTs, expressions are presented for the varying (cosines of) gas-water and oilwater contact angles, cos gw  and cos ow  . Surprisingly, cos go  is predicted to be constant down to fully miscible conditions ( go  = 0). Indeed, accurate measurements of the two-phase cos go  , confirm this trend, but only down to a finite value of go  , below which the values of cos go  rapidly increases to 1 ( 0 go   ). This behaviour has been incorporated in our model.The consequences of the various IFT and contact angle models are then worked through, using our previously developed theory of film and layer formation for three-phase configurations in angular pores. We demonstrate how the formation of these thick conducting layers is affected as the system goes from immiscible to miscible conditions. By incorporating the more realistic behaviour with cos go  approaching 1 as the system goes miscible, much thicker and more conductive oil layers are predicted, very like those observed in the HWU micromodel experiments. This may not be the only explanation for the changes in oil recovery and WAG flooding behaviour in near-miscible systems, but we believe that it is an important and novel component of the mechanism. Additionally, it is s...

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Measurement of Three-Phase Relative Permeability With IFT Variation

Cited by 26 publications

References 32 publications

Three-phase flow in porous media: A review of experimental studies on relative permeability

Three-phase flow in porous media: A review of experimental studies on relative permeability

Impact of Relative Permeability Hysteresis, IFT dependent and Three Phase Models on the Performance of Gas Based EOR Processes

The Mechanism of Oil Recovery by Water-Alternating-Gas Injection at Near-Miscible Conditions in Mixed Wet Systems

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