Pore Structure Characterization and the Controlling Factors of the Bakken Formation

Liu, Yuming; Shen, Bo; Yang, Zhiqiang; Zhao, Peiqiang

doi:10.3390/en11112879

Cited by 22 publications

(20 citation statements)

References 40 publications

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“…The adsorbed methane content for this Bakken core is 0.3 mmol/g of rock at 1500 psi, which is below the reported range of CO2 adsorption isotherms 1.0 to 3.5 mmol/g [19]. LPGA results for the Bakken were between 1.75 and 3.25 cm 3 /g [20], which is less than the adsorption reported here (approximately 7 scm 3 /g) but the LPGA analysis was carried out with N2 at nearly 1500 psi less than the experimental conditions here.…”

Section: Resultsmentioning

confidence: 61%

Methane Isotherms and Magnetic Resonance Imaging in Shales

Dick¹,

Heagle

Veselinović³

et al. 2020

E3S Web Conf.

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Adsorption isotherms of light hydrocarbons on reservoir rocks are key data used to quantify the total gas content in reservoirs and isotherms are now being used to improve our understanding of the processes affecting subsurface gas flow associated with gas injection from Enhanced Oil Recovery techniques. This project combined elements of the traditional pressure-volume gas adsorption isotherm technique and an NMR-based adsorption isotherm approach to determine the adsorption isotherms of light hydrocarbons on to tight rocks from oil and gas reservoirs. The new approach allows isotherms to be derived from NMR data. First, a T2 distribution of the gas is determined over a range of gas pressures. Next, the volume of pore gas is estimated using the pore volume of the rock and the Van der Waals gas equation. The adsorbed gas content is then calculated by subtracting pore gas content from the total gas content. This is repeated for a range of gas pressures to determine the adsorption isotherm. This project used the NMR method described above and measured the gas pressure decay in the NMR cell. This combined approach includes the advantages of the NMR method but it also produces a pressure-time curve that can be used to identify when equilibrium is attained in low permeability rocks and can be used to compare adsorption kinetics of different gases. The advantages of our approach are that 1) the samples remain intact and the measurements provide information on the pore size distribution; 2) analyses can be carried out at reservoir pressures; 3) isotherms can be measured for any gas containing hydrogen atoms; and 4) the results can be used to examine the processes controlling gas flow through the rock. Future work to develop this technique will improve our quantification of the amount of pore gas in the cell, which will improve our partitioning between adsorbed gas and pore gas as well as allow for an improved analysis of the pressure response of the sample after degassing.

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Section: Resultsmentioning

confidence: 61%

Methane Isotherms and Magnetic Resonance Imaging in Shales

Dick¹,

Heagle

Veselinović³

et al. 2020

E3S Web Conf.

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“…Studies in the first category focus on the experimental approaches for the characterization of porous media. Through selecting 12 rock samples from the Bakken formation, Liu et al [1] conducted a set of experiments including X-ray diffraction analysis, total organic carbon analysis, vitrinite reflectance, and low-temperature nitrogen adsorption experiments to study pore structures and the main controlling factors in this formation. The Bakken formation has micro-, meso-, and macro-pores.…”

Section: Overview Of Work Presented In This Special Issuementioning

confidence: 99%

Emerging Advances in Petrophysics: Porous Media Characterization and Modeling of Multiphase Flow

et al. 2019

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With the ongoing exploration and development of oil and gas resources all around the world, applications of petrophysical methods in natural porous media have attracted great attention. This special issue collects a series of recent studies focused on the application of different petrophysical methods in reservoir characterization, especially for unconventional resources. Wide-ranging topics covered in the introduction include experimental studies, numerical modeling (fractal approach), and multiphase flow modeling/simulations.

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“…Removing the residual oil in shale samples via the Soxhlet (solvent) extraction can solve this problem in the analysis of LPGA [21][22][23]. However, published data on shale pore properties in the oil window are rarely obtained from solvent-extracted samples [24][25][26][27][28][29]. Therefore, there is an urgent need to restudy pore properties of shale in the oil window and their controlling factors, based on the solvent extraction.…”

Section: Introductionmentioning

confidence: 99%

“…The geological factors controlling pore properties are usually studied using the bivariate cross-plots and univariate regression analysis [23,25,30,31]. But in most cases, the correlation coefficients of pore properties with geological factors are very low (0.33-0.86) [23,25,30,31]. The reason is that the pore properties are controlled or affected by multiple factors in most cases.…”

Section: Introductionmentioning

confidence: 99%

Pore Properties of the Lacustrine Shale in the Upper Part of the Sha-4 Member of the Paleogene Shahejie Formation in the Dongying Depression in East China

et al. 2021

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Lacustrine shales hold a huge potential oil resource in China. Pore properties (pore volume, diameter, specific surface area, and fractal dimensions) and their relationships with geological factors (mineralogy, insoluble organic carbon, burial depth, and vitrinite reflectance) are critical for evaluating shale oil resource. However, the factors controlling pores for lacustrine shale oil remain unclear, as the relationships between pore properties of Soxhlet-extracted samples and geological factors have not been studied using multivariate analytical methods. In this paper, the samples from the lacustrine shale in the upper part of the Sha-4 Member of the Paleogene Shahejie Formation in the Dongying Depression were tested with a set of experiments including Soxhlet (solvent) extraction, X-ray diffraction mineral analysis, insoluble organic carbon, vitrinite reflectance, and low-pressure CO2 and N2 adsorption experiments. The micromesopore volume varies from 0.003 cm3/g to 0.045 cm3/g. The relationships of pore properties with geological factors were studied with partial least square regression analysis (PLSR analysis, a powerful multivariate regression analysis). The results of the PLSR analyses indicate that clay minerals and carbonates are two key factors affecting the pore properties of the lacustrine shale. Compared with marine shales, more clay minerals in the lacustrine shale make them become more important for controlling pores than organic matter. The PLSR results also illustrate that the shale with higher pore volume contains more clay minerals and fewer carbonates and thus is unfavorable for hydraulic fracturing. Therefore, the shale with high micromesopore volume may be unfavorable for shale oil production. The shale with the modest micromesopore volume (~0.036 cm3/g), relatively high content of brittle minerals (~71 wt%), and low clay mineral content (~29 wt%) is conducive to both oil storage and hydraulic fracturing for the development of the Es4U shale oil in the Dongying Depression in East China.

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Pore Structure Characterization and the Controlling Factors of the Bakken Formation

Cited by 22 publications

References 40 publications

Methane Isotherms and Magnetic Resonance Imaging in Shales

Methane Isotherms and Magnetic Resonance Imaging in Shales

Emerging Advances in Petrophysics: Porous Media Characterization and Modeling of Multiphase Flow

Pore Properties of the Lacustrine Shale in the Upper Part of the Sha-4 Member of the Paleogene Shahejie Formation in the Dongying Depression in East China

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