An effective approach to generate drainage representative capillary pressure and relative permeability curves in the framework of reservoir electrofacies

Kadkhodaie, Ali; Rezaee, Reza; Kadkhodaie, Rahim

doi:10.1016/j.petrol.2019.01.098

Cited by 21 publications

(2 citation statements)

References 11 publications

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“…There is a correlation between transverse relaxation time ( T 2 ) distribution and capillary pressure curve in the aspect of the pore structure. Therefore, many scholars have converted T 2 distribution into the capillary pressure curve and used the capillary pressure curve to predict relative permeability ( K r ). , Hosseinzadeh et al generated K r curves from mercury injection capillary pressure (MICP) data derived from NMR data based on the Corey model. These curves have effective application in carbonate reservoirs .…”

Section: Introductionmentioning

confidence: 99%

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Wei,

Xie,

Wang

et al. 2024

Energy Fuels

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The relative permeability (K r ) measurement of tight sandstones is challenging due to its low porosity, low permeability, and complex pore structure. Nuclear magnetic resonance (NMR) technology has the advantages of being fast, nondestructive, and noninvasive while also continuously evaluating tight reservoirs. Based on NMR technology, it is of great significance to establish an effective and reliable relative permeability prediction model to solve practical problems in oil fields. In this paper, a method for predicting gas−water relative permeability in tight sandstone reservoirs is proposed based on NMR transverse relaxation time (T 2 ) distribution. The gas−water relative permeability measurements are performed for tight sandstone reservoirs in the Central Sichuan Basin, China. On the basis of the analysis of the gas−water permeability features in the study area, the reservoir characteristics are clarified. Based on the NMR theories, two T 2 −K r prediction models (model 1 and optimal model 2) are derived and established, and the model performance is analyzed using experimental data and existing models (Purcell and Brooks-Corey). Finally, the optimal model is used to process NMR logging data, obtain continuous relative permeability curves, and perform a productivity prediction. The effectiveness and applicability of the method are verified using relative permeability experiments and the oil testing data. The proposed method can provide effective guidance for the prediction of relative permeability curves and productivity evaluation of tight sandstone reservoirs.

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Section: Introductionmentioning

confidence: 99%

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Wei,

Xie,

Wang

et al. 2024

Energy Fuels

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“…Two-phase or multiphase flow in oil and gas reservoirs is a very complex process. Relative permeability is adopted to characterize the seepage law of each phase at different saturations, which is a key parameter affecting the prediction of well-production dynamics and the distribution of the remaining oil and gas [1][2][3][4].…”

Section: Introductionmentioning

confidence: 99%

Effect of Displacement Pressure Gradient on Oil–Water Relative Permeability: Experiment, Correction Method, and Numerical Simulation

Wu,

Zhang,

Liu

et al. 2024

Processes

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Relative permeability is a fundamental parameter affecting reservoir development performance analysis. During the development of oil and gas fields, the displacement pressure gradient changes with time and space. This paper studies the effect of displacement pressure gradient on relative permeability. The oil–water relative permeability curves of a Bohai Oilfield under different displacement pressure gradients are obtained through experimental analysis. Based on the experimental data, a correction model of the permeability curve is established by regression of the Willhite model parameters. The correction model is introduced into the black oil numerical simulation, and the production performance and remaining oil are compared and analyzed. The results show that the displacement pressure gradient can have an obvious impact on the relative permeability curve. As the displacement pressure gradient increases, the two-phase span of the relative permeability curve increases, the oil displacement efficiency increases, and the water relative permeability increases. The relative permeability curves under different displacement pressure gradients can be accurately characterized by the Willhite model. The consideration of the displacement pressure gradient has an obvious impact on numerical simulation results. The conventional method of using a fixed relative permeability curve cannot truly reflect the production performance and the remaining oil distribution. This paper proposes a set of realization methods including obtaining laws from experiments, utilizing the empirical model to correct, and simulating to characterize reservoir changes.

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A New Insight into In Situ Capillary Pressure Curve: Upscaling Nuclear Magnetic Resonance Measurements Using Wavelet Analysis

Heidary¹

2022

Transp Porous Med

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An effective approach to generate drainage representative capillary pressure and relative permeability curves in the framework of reservoir electrofacies

Cited by 21 publications

References 11 publications

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Effect of Displacement Pressure Gradient on Oil–Water Relative Permeability: Experiment, Correction Method, and Numerical Simulation

A New Insight into In Situ Capillary Pressure Curve: Upscaling Nuclear Magnetic Resonance Measurements Using Wavelet Analysis

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An effective approach to generate drainage representative capillary pressure and relative permeability curves in the framework of reservoir electrofacies

Cited by 21 publications

References 11 publications

Nuclear Magnetic Resonance T2 Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Nuclear Magnetic Resonance T2 Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Effect of Displacement Pressure Gradient on Oil–Water Relative Permeability: Experiment, Correction Method, and Numerical Simulation

A New Insight into In Situ Capillary Pressure Curve: Upscaling Nuclear Magnetic Resonance Measurements Using Wavelet Analysis

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Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China

Nuclear Magnetic Resonance T₂ Distribution-Based Gas–Water Relative Permeability Prediction in Tight Sandstone Reservoirs: A Case Study on Central Sichuan Basin, China