Anisotropic rate-dependent saturation functions for compositional simulation of sandstone composites

Boon, Maartje; Matthäi, Stephan; Shao, Q. T.; Youssef, AbdAllah A.; Mishra, Achyut; Benson, Sally M.

doi:10.1016/j.petrol.2021.109934

Cited by 14 publications

(4 citation statements)

References 43 publications

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“…The analysis methodology is applied to field data collected from the CRC-3 well at the Otway International Research Facility, Victoria, Australia (e.g., Mishra et al 2020). Detailed air mini-permeameter measurements collected on split core nearly every 10 cm, along the injection interval of the Paaratte formations parasequence 1 (several coarsening-downward sedimentation cycles buried in the Otway basin underneath shale formations, Boon et al 2022) show orders of magnitudes variations in the permeability (Fig. 3).…”

Section: Resultsmentioning

confidence: 99%

“…Comparatively, little work is conducted on continuum-scale heterogeneity (e.g., Sedaghat et al 2017). One of the traditional approaches that is still attractive is classifying continuumscale heterogeneity in terms of combinations of rock types at the sub-core scale (Boon et al 2022). studied laminated composites while Lohne et al (2006) modelled fine-scale heterogeneity as a checkerboard structure.…”

Section: Introductionmentioning

confidence: 99%

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Upscaled Dynamic Relative Permeability for Unstable CO2 Flow in Stratified Porous Media

Youssef

Matthäi

2022

Transp Porous Med

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In geologic porous media, layering is ubiquitous on all length scales ranging from sub-mm compositional laminations to km-thick formations. The current study presents a general framework for estimating the two-phase viscous limit dynamic relative permeability $$(k_{r} )$$ ( k r ) for non-communicating stratified sedimentary rocks. The approach is a two-stage upscaling taking into account the influence of nested heterogeneity at intra- and inter-layer scales. Sub-layer heterogeneities, promoting microflow instabilities in individual layers, are modelled by tuning input relative permeability parameters based on the viscosity contrast between fluids. Macroscopic flow instability at the domain scale is tackled by a new analytical solution for the saturation distribution in stratified media considering the complexities of frontal advance theory. For each layer, three flow stages are considered, each with its unique time-dependent behaviour. The overall solution is presented as a set of equations derived by overlapping of the solutions in different layers. The upscaled dynamic $$k_{r}$$ k r is figured out by history matching. The practicality of the method is demonstrated in application to measurements collected from the Otway International Research Facility, Victoria, Australia. The results show the significant impact of layer separation on the upscaled endpoint saturations in addition to required modifications on the current $$k_{r}$$ k r formulas. A comparison with conventionally modelled steady-state sweep highlights the inadequacy of steady-state upscaling for viscous limit flows. The applicability of the method to estimate $$k_{r}$$ k r from the unsteady-state lab experiments conducted on heterogeneous cores is also discussed.

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Upscaled Dynamic Relative Permeability for Unstable CO2 Flow in Stratified Porous Media

Youssef

Matthäi

2022

Transp Porous Med

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“…Sandstone is composed of grains, matrix, cements and pores, and it is an important carrier of underground hydrocarbon and the geological sequestration of carbon dioxide (Pettijohn et al ., 2012; Boon et al ., 2021). In recent years, many researchers have conducted chemical diagenesis evaluations and investigated the diagenetic paths of sandstone reservoirs during burial.…”

Section: Introductionmentioning

confidence: 99%

Influence of the grain shape and packing texture on the primary porosity of sandstone: Insights from a numerical simulation

et al. 2023

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Sandstone is an important carrier of underground hydrocarbon and the geological sequestration of carbon dioxide. Primary porosity is an important parameter used to predict reservoir quality, and it is influenced by the grain shape, grain‐size distribution and grain packing texture. However, few studies have focused on deriving multivariate equations of the grain size, grain‐size distribution and grain packing texture to predict the primary porosity of sandstone. The natural sedimentary process of sandstones was designed and simulated using a discrete element method. The results confirmed that the primary porosity is influenced by roundness, flatness, elongation, grain‐size distribution and grain packing texture; of the attributes, the mean grain size contributes less to the primary porosity of sandstone. Based on 193 simulated sandstone samples with a one‐component grain packing texture, a mathematical model considering roundness, flatness, elongation, grain packing texture and grain‐size distribution was proposed. The maximum, mean absolute and root mean square errors were 0.71, 0.26 and 0.32, respectively. The correlation coefficient between the simulated results and mathematical predicted results was 0.94. Furthermore, the primary porosity was positively correlated with the kurtosis of the grain‐size distribution in sandstone with the same grain shape but different kurtosis. The primary porosity was found to be independent of the mean grain size and mainly affected by the grain packing texture. Moreover, the primary porosity prediction model for sandstones with different grain‐size distribution curves based on the grain packing texture, which was proposed by the author in a previous study, was verified, and the correlation coefficient between the simulated results and predicted results was >0.92. The new mathematical model proposed in this study is a useful supplement for key parameter acquisition in the previous primary porosity prediction model of sandstone with different grain‐size distribution curves and grain packing texture. A mathematical model considering roundness, flatness, elongation, grain packing texture and grain‐size distribution is of great significance for reservoir quality prediction and conducting a quantitative evaluation of the diagenesis.

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“…Of potential geological targets, deep saline aquifers are of great importance because they are prevalent in sedimentary basins and have promising storage capacity. However, the spatial heterogeneity in geological formations, as well as high contrast between fluids when storing CO2 in saline aquifers, pose challenges on understanding and simulating such unstable processes [2][3][4][5][6][7][8][9].…”

Section: Introductionmentioning

confidence: 99%

Simulation of CO2 Storage using a Parameterization Method for Essential Trapping Physics: FluidFlower Benchmark Study

Wang¹,

Vuik²,

Hajibeygi³

2023

Preprint

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An efficient compositional framework is developed for simulation of CO2 storage in saline aquifers during a full-cycle injection, migration and post-migration processes. Essential trapping mechanisms, including structural, dissolution, and residual trapping, which operate at different time scales are accurately captured in the presented unified framework. In particular, a parameterization method is proposed to efficiently describe the relevant physical processes. The proposed framework is validated by comparing the dynamics of gravity-induced convective transport with that reported in the literature. Results show good agreement for both the characteristics of descending fingers and the associated dissolution rate. The developed simulator is then applied to study the FluidFlower benchmark model. An experimental setup with heterogeneous geological layers is discretized into

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Anisotropic rate-dependent saturation functions for compositional simulation of sandstone composites

Cited by 14 publications

References 43 publications

Upscaled Dynamic Relative Permeability for Unstable CO2 Flow in Stratified Porous Media

Upscaled Dynamic Relative Permeability for Unstable CO2 Flow in Stratified Porous Media

Influence of the grain shape and packing texture on the primary porosity of sandstone: Insights from a numerical simulation

Simulation of CO2 Storage using a Parameterization Method for Essential Trapping Physics: FluidFlower Benchmark Study

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