New approach for improved history matching while incorporating wettability variations in a sandstone reservoir—Field implementation

Zahoor, Muhammad Khurram; Derahman, Mohd. Nawi

doi:10.1016/j.petrol.2013.03.025

Cited by 8 publications

(3 citation statements)

References 23 publications

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“…The number of parameters can hinder the fluid flow and a displacement of one fluid by another in a reservoir. Such parameters involve wettability as of prime importance (Ahmed 2000;Zahoor & Derahman 2013;Zahoor et al 2011). Wettability, in turn also affects the relative permeability of displacing and displaced fluids, as shown in Figure 1.…”

Section: Fluid Displacement Systems In a Porous Mediummentioning

confidence: 99%

Comparative Analysis of Relative Permeability Models with Reference to Extreme Saturation Limit and Its Influence on Reservoir Performance Prediction

Zahoor¹

2015

JSM

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Section: Fluid Displacement Systems In a Porous Mediummentioning

confidence: 99%

Comparative Analysis of Relative Permeability Models with Reference to Extreme Saturation Limit and Its Influence on Reservoir Performance Prediction

Zahoor¹

2015

JSM

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“…Although lots of studies have confirmed that reservoir properties may alter during the process of high-volume water injection, the current commercial simulators fail to quantitatively describe the oil recovery changes with time-varying reservoir physical properties, − which cannot adapt to the actual demand of effective waterflooding for reservoir development at high water-cut stage and also increases the difficulty for history matching. , Therefore, it is urgent to carry out research on the simulation method that can characterize the effects of time-varying reservoir physical properties on the development of high water-cut reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Novel Method for Inverted Five-Spot Reservoir Simulation at High Water-Cut Stage Based on Time-Varying Relative Permeability Curves

et al. 2020

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After large-scale and long-term waterflooding, reservoir physical properties such as the pore throat structure and rock wettability may change. In this paper, the relative permeability curves under different water injection volumes through core-flood experiments were used to characterize the comprehensive changes of various reservoir physical properties at high water-cut stage. The novel concept of "water cross-surface flux" was proposed to characterize the cumulative flushing effect on the reservoir by injected water, and a novel method for inverted five-spot reservoir simulation at high water-cut stage based on time-varying relative permeability curves was established. From the relative permeability curves measured through two cores from the X oilfield under different water injection volumes (100, 500, 1000, 1500, and 2000 PV), it is found that with the increase of injected water volume, the two-phase co-flow zone becomes wider, the water permeability under residual oil saturation increases, and the residual oil saturation decreases. A waterflooding core model was established, simulated, and verified by the method proposed in this paper. It is found that using time-varying permeability curves for simulation, the highest oil recovery factor (61.58%) can be obtained with injected water volume up to 2000 PV, and the purpose of improved oil recovery (IOR) can be achieved by high water injection volume, but the increment is only approximately 10%. Besides, a waterflooding model of an inverted five-spot reservoir unit based on the X oilfield was also established, simulated, and analyzed. Simulation results have shown that no matter which set of core permeability curves measured from 100 to 2000 PV is directly used alone, the oil recovery factor will be simulated inaccurately. The findings of this study can help in better understanding the quantitative description of the oil recovery changes with time-varying reservoir physical properties in high water-cut reservoirs during waterflooding.

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“…Five factors that impact the polar adsorption and desorption should be considered, and these include the concentration of polar substances in crude oil and on rock surface [31], salinity and pH of injecting water and formation water [32,33], clay contents in rock [28], and flow rate of water through the pore [31]. Yet, an accurate description of wettability alternation model during long-term water flooding from injecting well or aquifer is lacking, which will lead to failure in history matching and unreliable forecasts using numerical simulation [34,35].…”

Section: Introductionmentioning

confidence: 99%

Modeling Wettability Variation during Long-Term Water Flooding

Cao

Sun

Zee

2015

Journal of Chemistry

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Surface property of rock affects oil recovery during water flooding. Oil-wet polar substances adsorbed on the surface of the rock will gradually be desorbed during water flooding, and original reservoir wettability will change towards water-wet, and the change will reduce the residual oil saturation and improve the oil displacement efficiency. However there is a lack of an accurate description of wettability alternation model during long-term water flooding and it will lead to difficulties in history match and unreliable forecasts using reservoir simulators. This paper summarizes the mechanism of wettability variation and characterizes the adsorption of polar substance during long-term water flooding from injecting water or aquifer and relates the residual oil saturation and relative permeability to the polar substance adsorbed on clay and pore volumes of flooding water. A mathematical model is presented to simulate the long-term water flooding and the model is validated with experimental results. The simulation results of long-term water flooding are also discussed.

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New approach for improved history matching while incorporating wettability variations in a sandstone reservoir—Field implementation

Cited by 8 publications

References 23 publications

Comparative Analysis of Relative Permeability Models with Reference to Extreme Saturation Limit and Its Influence on Reservoir Performance Prediction

Comparative Analysis of Relative Permeability Models with Reference to Extreme Saturation Limit and Its Influence on Reservoir Performance Prediction

Novel Method for Inverted Five-Spot Reservoir Simulation at High Water-Cut Stage Based on Time-Varying Relative Permeability Curves

Modeling Wettability Variation during Long-Term Water Flooding

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