Comparison of permeability models using mercury injection capillary pressure data on carbonate rock samples

Nooruddin, Hasan A.; Hossain, Mohammed Kamal; Al-Yousef, Hasan Y.; Okasha, Taha

doi:10.1016/j.petrol.2014.06.032

Cited by 89 publications

(45 citation statements)

References 25 publications

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“…We selected these samples because it is well documented that carbonates exhibit multiple sizes and distribution of pores within the pore systems and include large degrees of microporosity. [42][43][44][45][46] This poses a challenge when analyzing and quantifying porosity using techniques such as image analysis from petrographic thin sections ( Fig. 3).…”

Section: Methodsmentioning

confidence: 99%

Pore system characterization of Cambrian‐Ordovician carbonates using a new mercury porosimetry‐based petrofacies classification system: application to carbon sequestration reservoirs

2018

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To better understand injection and post‐injection flow processes and the entrapment of supercritical CO2 during geological carbon sequestration in a carbonate reservoir, the pore system was analyzed in 66 Cambrian‐Ordovician carbonate samples from several locations in the midwestern USA. This work employed standard microphotography from thin sections, helium porosimetry for porosity and permeability, and mercury injection capillary pressure analysis, aiming to understand which elements of the pore system dominantly control the overall flow and CO2 storage potential in the subsurface. In particular, mercury injection capillary pressure analysis has been fundamental in understanding several petrophysical properties of rocks, including porosity, permeability, and the pore‐size distribution of the samples under study. This work analyzes mercury injection capillary pressure data and proposes a petrophysical subdivision of the samples into four petrofacies, based on values of porosity, permeability, and capillary entry pressure. This system aims to predict the portions of the studied carbonate sequence that are more likely to have a higher potential for injectivity and storage, and to better understand how porosity, permeability, capillary entry pressure, and pore size all play a role in ensuring both buoyant and capillary trapping mechanisms to secure the injected supercritical CO2. Results from this investigation suggest that in these Cambrian‐Ordovician carbonate reservoirs, pore size inversely correlates with capillary entry pressure, and that permeability does not always have a direct relationship with pore size but rather relates to the overall interconnectivity of the complex pore system. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Methodsmentioning

confidence: 99%

Pore system characterization of Cambrian‐Ordovician carbonates using a new mercury porosimetry‐based petrofacies classification system: application to carbon sequestration reservoirs

2018

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“…Permeability is one of the most important parameters for reservoir characterization and productivity prediction. There are many well established theoretical and empirical methods to predict the permeability combining conventional MICP parameters and the fractal dimension [ Swanson , ; Katz and Thompson , ; Hunt , ; Hunt and Gee , ; Yu and Liu , ; Glover et al ., ; Yang and Aplin , ; Xu and Yu , ; Abojafer , ; Othman et al ., ; Zinovik and Poulikakos , ; Latief and Fauzi , ; Rezaee et al ., ; Gao and Hu , ; Buiting and Clerke , ; Nooruddin et al ., ; Lala , ; Cai et al ., ; Miao et al ., ].…”

Section: Algorithm and Applicationmentioning

confidence: 99%

An improvement of the fractal theory and its application in pore structure evaluation and permeability estimation

Fan

Deng

et al. 2016

JGR Solid Earth

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We present an improved fractal model for pore structure evaluation and permeability estimation based on the high pressure mercury porosimetry data. An accumulative fractal equation is introduced to characterize the piecewise nature of the capillary pressure and the mercury saturation. The iterative truncated singular value decomposition algorithm is developed to solve the accumulative fractal equation and obtain the fractal dimension distributions. Furthermore, the fractal dimension distributions and relevant parameters are used to characterize the pore structure and permeability. The results demonstrate that the proposed model provides better characterization of the mercury injection capillary pressure than conventional monofractal theory. In addition, there is a direct relationship between the pore structure types and the fractal dimension spectrums. What is more, the permeability is strongly correlated with the geometric and the arithmetic mean values of fractal dimensions, and the permeability estimated using these new fractal dimension parameters achieve excellent result. The improved model and solution give a fresh perspective of the conventional monofractal theory, which may be applied in many geological and geophysical fields.

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“…The heterogeneity and anisotropy of pore structures are involved in the CPC; thus, the CPC has been applied to a wide range of natural or synthetic porous media, such as shale, tight sandstone, carbonate rock, packing bed, coal rock, cement slurry, and fine sediment containing natural gas hydrate (Cai et al, ; Lei & Santamarina, ; Sang et al, ; Voigt et al, ; Wyrzykowski et al, ). From the equivalent hydraulic size distribution of the pore‐throat (SDPT) given by the CPC, many critical pore structure parameters, such as the threshold pressure and radius, the maximum displacement pressure P d and its corresponding maximum pore‐throat radius r max , the average pore‐throat radius r mean , the irreducible water saturation S wir , the structural coefficient T , and the pore‐throat radius at any saturation (e.g., r 15 , r 25 , r 50 ), can be directly determined (Nooruddin et al, ). Recently, Nishiyama and Yokoyama () reported that the critical radius from the CPC is the radius of the largest sphere that can move freely in porous media.…”

Section: Introductionmentioning

confidence: 99%

“…In this regard, the CPC may be applied to the migration of solutes in groundwater. Thus, the CPC has been used to successfully evaluate many macroscopic petrophysical properties for formation estimation and reservoir simulation, such as permeability (Nooruddin et al, 2014;Rashid et al, 2015;Rezaee et al, 2012), electrical conductivity and cementation factors (Katz & Thompson, 1987;Shahsenov & Orujov, 2018), and even relative permeability curves (Li & Horne, 2006).…”

Section: Introductionmentioning

confidence: 99%

Capillary Pressure Curve Determination Based on a 2‐D Cross‐Section Analysis Via Fractal Geometry: A Bridge Between 2‐D and 3‐D Pore Structure of Porous Media

Chen

Yao

Luo³

et al. 2019

JGR Solid Earth

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Pore structure is a crucial attribute in characterizing fluid flow through porous media. However, direct experimental measurements or numerical reconstructions are commonly expensive and not environmentally friendly, with great uncertainty caused by the complex nature of porous media. In this study, we demonstrate that one special bridge function, which is a function of the apparent length and tortuosity fractal dimension, can characterize the relationship of pore structures between two dimensions (2‐D) and three dimensions (3‐D), and it can serve as a conversion bridge of the radius to determine the capillary pressure curve (CPC). We compare estimations by the proposed method with experimental results obtained by mercury intrusion porosimetry in six typical natural sandstones with varying porosities and permeabilities. The result shows that cross sections of the global pore structure, such as thin section, electronic probe, and microcomputed tomography slices, give a reliable estimation of the CPC using the bridge function in porous media with a medium porosity. However, in unconventional porous media with a relatively low porosity (~10%) or extra high porosity (~30%), due to the empirical nature of the equation widely used to calculate the tortuosity fractal dimension, the necessary modification is necessary to obtain the CPC when applying the bridge function in such porous media. This insight can significantly simplify the procedure for obtaining the petrophysical properties of a porous medium, which may shed light on the inherent differences and correlations between the 2‐D and 3‐D pore structures of porous media.

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Comparison of permeability models using mercury injection capillary pressure data on carbonate rock samples

Cited by 89 publications

References 25 publications

Pore system characterization of Cambrian‐Ordovician carbonates using a new mercury porosimetry‐based petrofacies classification system: application to carbon sequestration reservoirs

Pore system characterization of Cambrian‐Ordovician carbonates using a new mercury porosimetry‐based petrofacies classification system: application to carbon sequestration reservoirs

An improvement of the fractal theory and its application in pore structure evaluation and permeability estimation

Capillary Pressure Curve Determination Based on a 2‐D Cross‐Section Analysis Via Fractal Geometry: A Bridge Between 2‐D and 3‐D Pore Structure of Porous Media

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