Combining Mercury Intrusion and Nuclear Magnetic Resonance Measurements Using Percolation Theory

Daigle, Hugh; Johnson, Andrew C.

doi:10.1007/s11242-015-0619-1

Cited by 129 publications

(72 citation statements)

References 25 publications

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“…In the laboratory NMR tests (water‐saturated porous media), the diffusion and bulk relaxation times (order of seconds) are much longer than the surface relaxation (order of milliseconds) . Therefore, surface relaxation ( T 2 S ) becomes the most critical mechanism affecting the NMR relaxation …”

Section: Samples and Methodsmentioning

confidence: 99%

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Effect of pore structure on oil‐bearing property in the third member of Paleogene Funing Formation in Subei Basin, East China

Liu

Xie

Shu

et al. 2020

Energy Science & Engineering

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Mercury injection capillary pressure (MICP) tests, nuclear magnetic resonance (NMR), (fluorescence) thin section, X-ray diffraction (XRD), and scanning electron microscope (SEM) analyses were used to describe the size and distribution of entire pore-throat structures in the sandstones of the E 1 f 3 (the third member of Paleogene Funing Formation) in the Subei Basin. The lithologies of E 1 f 3 in the Subei Basin are mainly dark-gray, very fine-grained sandstones and siltstones, interbedded with dark mudstones. The pore systems predominantly feature secondary intergranular and intragranular dissolution pores, micropores coexisting with minor amounts of intergranular pores, and microfractures. The high threshold pressure and bulk volume of irreducible fluids values and the significant variation in the NMR and MICP parameters indicate that the E 1 f 3 reservoirs are characterized by complex and heterogeneous microscopic pore structures. Microscopic pore-throat parameters are linked with macroscopic properties through the reservoir quality index (RQI). The NMR T 2 (transverse time relaxation) spectrum is unimodal or bimodal but with weak right peaks, indicating the rarity of large intergranular pores. However, large-scale pore throats, though only account for a minor part of the total pore volume, significantly contribute to the total permeability. The abundance of small-scale pore-throat systems (short T 2 components) results in high irreducible water content. Therefore, the oil saturation in E 1 f 3 sandstones is low, and the pore structure, especially the number of micropores, determines the oil-bearing property. Oil primarily occurs in the intragranular dissolution pores with minor amounts occurring in the large intergranular pores. Most of the micropores are bound by capillary water. The sandstones with chlorite clay minerals tend to be oil-wet and have high oil-bearing potential, while the abundance of detrital clay or illite contributes to a low oil-bearing grade. The combination of core and microscopic observations and the MICP and NMR analyses have allowed the determination of the pore structure characteristics and their coupling effects on oil-bearing property. |

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Section: Samples and Methodsmentioning

confidence: 99%

“…The T 2 value can be linked to pore size (Equation )

\frac{1}{T_{2}} = \frac{1}{T_{2 normalS}} = ρ \frac{S}{V} = ρ \frac{a}{r},

in which ρ is the surface relaxivity (μm/ms) to convert the NMR T 2 to the pore‐size distribution, S (μm 2 ) and V (μm 3 ) are the pore surface area and pore volume, respectively, and a is the pore shape constant …”

Section: Samples and Methodsmentioning

confidence: 99%

Effect of pore structure on oil‐bearing property in the third member of Paleogene Funing Formation in Subei Basin, East China

Liu

Xie

Shu

et al. 2020

Energy Science & Engineering

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“…For brine‐saturated rock samples, diffusion relaxation is minimized if small echo spacing is used (Daigle et al, ), yielding a negligible diffusion term in equation . For brine, the magnetization decay is sufficiently smaller than the surface relaxation rate in a porous media (Daigle & Johnson, ; Kleinberg & Horsfield, ); T 2 is dominated by T 2surface and can be simplified as

\frac{1}{T_{2}} \approx ρ \frac{S}{V_{p}} .

…”

Section: Methodsmentioning

confidence: 99%

Low‐Field Nuclear Magnetic Resonance Characterization of Carbonate and Sandstone Reservoirs From Rock Spring Uplift of Wyoming

et al. 2018

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Laboratory measurements including gas (N2) porosity and permeability, time‐domain nuclear magnetic resonance, thin section, and scanning electron microscopy analysis were conducted to obtain petrographical and petrophysical descriptions of the Weber Sandstone and Madison Limestone at the Rock Spring Uplift, a potential carbon dioxide storage site in Southwestern Wyoming. The relationships between pore structures, such as pore geometry, pore‐size distribution, pore network, and porosity/permeability are investigated. First, using thin sections combined with scanning electron microscopy for pore structures description, all samples are described in detail from the geological, petrographysical, and diagenetic viewpoint. Results show that within the Madison Limestone, pore types include intercrystalline, vuggy, moldic, or mixed (combination of all other pore types). Both moldic and vuggy pore types are associated with samples of high porosity and permeability. Nuclear magnetic resonance relaxation time distributions show either bimodal or multimodal distributions. Large relaxation time components are associated with samples with large pores, whereas small components are dominated by small pores. The T2 geometric mean correlates well with gas permeability. Additionally, short‐time diffusion coefficients (D) were measured by pulsed field gradient method using a series of gradient strengths. We found that diffusion coefficient distributions correlate with the corresponding T2 distributions for macropores. By comparing the dominant peak position of T2 distributions and their corresponding diffusion coefficient distributions, we predicted the surface relaxivity of different rock types. We found that surface relaxivities of Weber Sandstone samples can be well predicted, while for Madison Limestone samples, surface relaxivities are overestimated due to diffusive pore coupling effect.

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“…If the pore structure of interest is highly heterogeneous, the calculated CPC may have an unacceptable error due to the unrepresentative pore structure. Additionally, direct numerical simulations on the reconstructed 3-D pore network models is a multistep process, including training experimental images, extracting pore or solid parameters, and building models, as well as numerical computation with a strong computer performance caused by the complex nature of porous media (Daigle & Johnson, 2016;Ferrari et al, 2015;Okabe & Blunt, 2004;Øren & Bakke, 2002;Shikhov & Arns, 2015;Wang & Pan, 2009). Thus, the numerical approach is not sufficiently economical for obtaining the CPC.…”

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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Combining Mercury Intrusion and Nuclear Magnetic Resonance Measurements Using Percolation Theory

Cited by 129 publications

References 25 publications

Effect of pore structure on oil‐bearing property in the third member of Paleogene Funing Formation in Subei Basin, East China

Effect of pore structure on oil‐bearing property in the third member of Paleogene Funing Formation in Subei Basin, East China

Low‐Field Nuclear Magnetic Resonance Characterization of Carbonate and Sandstone Reservoirs From Rock Spring Uplift of Wyoming

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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