Near-Critical Gas/Condensate Relative Permeability of Carbonates

Calisgan, Huseyin; Demiral, Birol; Akın, Serhat

doi:10.2118/99710-ms

Cited by 4 publications

(1 citation statement)

References 20 publications

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“…Gas-condensate systems are represented by liquid-liquid fluids which have been used rarely in gas-condensate experimental studies in the literature (Boom et al, 1996;Blom et al, 1997;Calisgan et al, 2006). Finally, production simulation was used to test the implications of the results.…”

Section: Methodsmentioning

confidence: 99%

Gas Condensate Flow Behaviour Within Tight Reservoirs

Al-Harrasi¹,

Grattoni

Fisher

et al. 2013

All Days

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Tight gas-condensate reservoirs contain large reserves, but can be extremely costly to develop. Understanding the fundamental controls on the fluid flow behaviour of tight gas and gas-condensate reservoirs has the potential to result in more cost-effective reservoir development and help increase the world's producible reserves. The principal objective of the paper is to improve understanding of multiphase flow within tight gas-condensate reservoirs. In order to achieve this objective a series of pore-to-core scale experiments under controlled conditions were performed, followed by numerical simulation. Three methodologies were used in this study: First, pore-scale experiments in glass micromodels with liquid-liquid systems were performed to improve understanding of the phase separation and flow mechanisms at pore level. Second, coreflood experiments were performed while in-situ saturation was monitored using an X-ray CT-scanner. A newly developed liquidliquid system was used in these experiments. Flow through tight gas sandstones allowed the determination of relative permeabilities as well as determining their dependence on absolute permeability and capillary number. Third, production simulation modelling has been conducted to investigate the implications of the results.The micromodel experiments have proved extremely useful for characterizing the flow behaviour of condensate systems. The results showed that the flow mechanisms and phases' distributions were affected largely by interfacial tension, pore structure and wettability. The experimental results showed the dependence of gas-condensate relative permeabilities of tight rocks on absolute permeability and capillary number. The incorporation of the results into production simulation modelling has shown an increase of gas production up to 70% for tight gas-condensate reservoirs when capillary number effects were included.The modelling has shown that the high velocity phenomena near the production well must be taken into account for tight gascondensate reservoirs. Therefore, the current practice of modelling these reservoirs using immiscible relative permeabilities should be immediately reviewed to avoid costly and ineffective reservoir development plans.

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Section: Methodsmentioning

confidence: 99%

Gas Condensate Flow Behaviour Within Tight Reservoirs

Al-Harrasi¹,

Grattoni

Fisher

et al. 2013

All Days

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The Effect of Interfacial Tension on Two-phase Relative Permeability: A Review

Jamaloei

2015

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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A Comparative Study of the Effect of Gas/Oil IFT Variation on Two- and Three-Phase Relative Permeability and the Performance of WAG Injection at Laboratory Scale

et al. 2016

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Gas/oil interfacial tension (IFT) is one of the most important parameters that impact the performance of gas injection in an oil reservoir. The choice or design of the composition of the gas injected for EOR is usually affected by the gas/oil IFT. In conventional reservoir simulation, IFT does not explicitly appear in the equations of flow and therefore its effect must be captured by the shape and values of relative permeability curves. A few studies have been previously reported for IFT effect on two-phase flow but very little have been done to investigate gas/oil IFT effect under three-phase flow conditions. The objective of this study is, firstly, to investigate the impact of gas/oil IFT reduction on two- and three-phase relative permeabilities using coreflood experiments. Secondly, to investigate the effect of changing gas/oil IFT value (immiscible and near-miscible) on the performance of WAG injections and residual oil saturation reduction at laboratory scale. Two- and three-phase (WAG) coreflood experiments have been performed on water-wet and mixed-wet cores at three different gas/oil IFT conditions. These experiments were conducted on Clashach sandstone cores with a permeability of 65 and 1000 mD. The two- and three-phase relative permeabilities were estimated from the results of the coreflood experiments using our in-house software (3RPSim) and were compared with each other on the basis of their gas/oil IFT values. Moreover, the impact of gas/oil IFT reduction on the performance of gas and WAG injection and in particular on the reduction of residual oil saturation was investigated. The results of our studies were also compared with the existing literature on the laboratory investigation of WAG injection. The results show that in two-phase gas/oil systems, the relative permeability of non-wetting phase is more affected by a reduction in the gas/oil IFT compared of the relative permeability of the wetting phase. Comparing the curvature of the gas and oil relative permeability curves shows that although the curvature decreases by a reduction in gas/oil IFT but it is still far away from straight line even at ultra-low IFT values. In three-phase flow system, reduction of gas/oil IFT affects the relative permeabilities of all the three phases (gas, oil and water). The results show that at high gas/oil IFT or immiscible WAG injection, the most reduction in residual oil saturation is achieved in the first injection cycle and further WAG cycles do not result in a significant additional reduction in oil saturation. On the contrary, at low gas/oil IFT or near-miscible WAG injection, the residual oil saturation keeps decreasing as the number of WAG cycles increases. Moreover, the reduction in residual oil saturation was more effective when the immiscible WAG experiments started with gas injection (secondary WAG).

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Near-Critical Gas/Condensate Relative Permeability of Carbonates

Cited by 4 publications

References 20 publications

Gas Condensate Flow Behaviour Within Tight Reservoirs

Gas Condensate Flow Behaviour Within Tight Reservoirs

The Effect of Interfacial Tension on Two-phase Relative Permeability: A Review

A Comparative Study of the Effect of Gas/Oil IFT Variation on Two- and Three-Phase Relative Permeability and the Performance of WAG Injection at Laboratory Scale

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