Steady-State Multi-Phase Relative Permeability Under Simultaneous Water and Gas Injection: Application on Different Rock Types

Moghadasi, Leili; Renna, D.; Bartošek, Martin; Maddinelli, G.

doi:10.2118/196697-ms

Cited by 3 publications

References 8 publications

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Sensitivity-based Parameter Calibration of Single- and Dual-continuum Coreflooding Simulation Models

et al. 2022

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Our study is keyed to the development of a viable framework for the stochastic characterization of coreflooding simulation models under two- and three-phase flow conditions taking place within a core sample in the presence of preferential flow of the kind that can be associated with the presence of a system of fractures. We do so considering various modeling strategies based on (spatially homogeneous or heterogeneous) single- and dual-continuum formulations of black-oil computational models and relying on a global sensitivity-driven stochastic parameter calibration. The latter is constrained through a set of data collected under a water alternating gas scenario implemented in laboratory-scale coreflooding experiments. We set up a collection of Monte Carlo (MC) numerical simulations while considering uncertainty encompassing (a) rock attributes (i.e., porosity and absolute permeability), as well as (b) fluid–fluid/ fluid–solid interactions, as reflected through characteristic parameters of relative permeability and capillary pressure formulations. Modern moment-based global sensitivity indices are evaluated on the basis of the MC model responses, with the aim of (i) quantifying sensitivity of the coreflooding simulation results to variations of the input uncertain model parameters and (ii) assessing the possibility of reducing the dimensionality of model parameter spaces. We then rest on a stochastic inverse modeling approach grounded on the acceptance–rejection sampling (ARS) algorithm to obtain probability distributions of the key model parameters (as identified through our global sensitivity analyses) conditional to the available experimental observations. The relative skill of the various candidate models to represent the system behavior is quantified upon relying on the deviance information criterion. Our findings reveal that amongst all tested models, a dual-continuum formulation provides the best performance considering the experimental observations available. Only a few of the parameters embedded in the dual-continuum formulation are identified as major elements significantly affecting the prediction (and associated uncertainty) of model outputs, petrophysical attributes and relative permeability model parameters having a stronger effect than parameters related to capillary pressure.

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Sensitivity-based Parameter Calibration of Single- and Dual-continuum Coreflooding Simulation Models

et al. 2022

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An Experimental Method for Measuring the Three-Phase Relative Permeability of Oil, Gas and Water By Nuclear Magnetic Resonance

Chang,

Song,

et al. 2023

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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The three-phase relative permeability of oil, gas, and water place a significant practical emphasis in the study and evolution of compact sandstone condensate gas traps. However, most investigations on itare relied on forecast patterns that make an effort to appraise it from the relative permeability of two phases. We have measured it of artificial dense sandstone core by online NMR tests. Firstly, the extracting of tight sandstone condensate gas reservoirs was mimicked using a steady-state flow toward, and crude oil, nitrogen and formation water were injected into tight sandstone simultaneously at room temperature according to the variation mechanism of reducing gas injection, and increasing water and oil injection. Secondly, the three-phase saturations were obtained by the different partition of oil-water phases in the 2D T1-T2 spectrum and the volume balance method. Finally, the relative permeability of three phases under various saturations was determined based on Darcy's formula. The findings indicated that in the 2D T1-T2 spectrum, the aqueous phase was mainly concentrated at the position where the T1/T2 ratio was 1, and the oil phase was mainly concentrated at the position where the T1/T2 ratio was greater than 1. Compared with the T2 spectrum, the T1 spectrum could effectively distinguish the oil and water phase, and their boundary was about 10 ms at the T1 relaxation time. The relative permeability of each phase exhibited a trend toward decreasing over time as gas injection decreased and water and oil injection increased. The relative permeability of the water phase dropped, albeit not as much as that of the oil-gas phases. The relative permeability curve of three phases was convex to the point where the oil saturation was equal to 1. As a result, the relative permeability of the gas-oil phases will be significantly impacted within the mining period of tight sandstone condensate gas accumulations when a little amount of condensate water arrives in the reservoir. Therefore, it is necessary to take measures to reasonably control the precipitation of water in condensate gas reservoir. In order to better understand the three-phase relative permeability, an innovative study has been conducted. And its results can more accurately predict and guide the production of condensate gas reservoirs.

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A Relative Permeability Model of Coal Based on Fractal Capillary Bundle Assumption

Shao,

Zhu,

Wang

et al. 2024

SPE Journal

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Summary As the pore and fracture structure of coal significantly influence gas-water relative permeability (GWRP), it is crucial to study the GWRP in coal reservoirs for optimizing gas production. This paper provided parameters such as pore size range and capillary bundle porosity by referring to existing mercury intrusion porosimetry (MIP) experiments. The effective porosity coefficient and gas-water phase critical pore size were introduced to improve the GWRP model for coal based on the assumption of fractal capillary bundle. The GWRP model depends on changes in phase saturation, maximum and minimum capillary tube pore diameters, porosity, capillary size distribution dimension Df, and fractal dimension of tortuosity Dt. It demonstrated that models for various coal samples from the southern Qinshui Basin exhibit good agreement with the GWRP experimental data. In addition, the improved GWRP model was used to simulate coalbed methane (CBM) production and water production. The findings suggested that as water and gas are continuously extracted, effective stress rises as reservoir pressure and water saturation decline, leading to a more even distribution of capillary diameter and an increase in capillary degree. Furthermore, the effect of structural parameters on CBM production was also discussed.

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Steady-State Multi-Phase Relative Permeability Under Simultaneous Water and Gas Injection: Application on Different Rock Types

Cited by 3 publications

References 8 publications

Sensitivity-based Parameter Calibration of Single- and Dual-continuum Coreflooding Simulation Models

Sensitivity-based Parameter Calibration of Single- and Dual-continuum Coreflooding Simulation Models

An Experimental Method for Measuring the Three-Phase Relative Permeability of Oil, Gas and Water By Nuclear Magnetic Resonance

A Relative Permeability Model of Coal Based on Fractal Capillary Bundle Assumption

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