Supercritical High-Pressure Methane Adsorption on the Lower Cambrian Shuijingtuo Shale in the Huangling Anticline Area, South China: Adsorption Behavior, Storage Characteristics, and Geological Implications

Shen, Wei; He, Sheng; Hu, Mingzeng; Yang, Wei; Guo, Xiaowen; Iglauer, Stefan; Zhai, Gangyi

doi:10.1021/acs.energyfuels.1c02702

Cited by 6 publications

(8 citation statements)

References 67 publications

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“…As shown in Figure 6, we obtained the pore-volume distributions for six samples by the Barrett−Joyner−Halenda (BJH) analysis. 57,58 The results show that the main pore-size distributions of the six samples range from 1 to 100 nm, and the pore-volume change rate decreases rapidly with the increasing pore size. As the pore size increases to 10 nm, the pore-volume change rate decreases below 0.001.…”

Section: Resultsmentioning

confidence: 99%

Effects of Microscopic Pore Structures on the Spontaneous Imbibition of Longmaxi Shale

Zhu

Lai

2022

Energy Fuels

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Spontaneous imbibition (SI) during the extended shut-in period effectively enhances the production performance of shale gas wells. This study presents an experimental work to evaluate the relationship between SI and microscopic pore structures and assess the dynamics of fluid distributions during imbibition for Longmaxi shale. We conducted imbibition tests on six samples collected from the Longmaxi Shale in Southern Sichuan Basin. Also, we conducted a series of experiments on these six samples to characterize microscopic pore-structure parameters. Correlation analysis indicates that porosity, reservoir quality index, permeability, and average pore radius are among the key pore-structure parameters impacting imbibition recovery of our shale samples. In this study, we also conducted nuclear magnetic resonance (NMR) tests to investigate the dynamics of water distribution during imbibition. The NMR results indicate that the micropores and microfractures in the samples are filled with water earlier compared with macropores and macrofractures. The findings may thus provide new insights into the SI after fracturing operations in shales.

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Section: Resultsmentioning

confidence: 99%

Effects of Microscopic Pore Structures on the Spontaneous Imbibition of Longmaxi Shale

Zhu

Lai

2022

Energy Fuels

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“…Based on free CH 4 density obtained from the NIST package [31] and the above calculated excess CH 4 adsorption amounts, the relationship between the buried depth and GIP was established and shown in Figure 8. It is worth noting that, here, the GIP calculation for the Shahezi and Yingcheng formations should be overestimated because the CH 4 adsorption isotherms were actually conducted under dry conditions [12][13][14]. The estimated GIP values of HS1-1 (1.388 m 3 /t) and S2-1 (3.307 m 3 /t) at sampling depth indicated favorable shale gas resources potential, especially in shales of the Yingcheng Formation.…”

Section: Evaluations Of Gip: Implications For Shale Gas Resourcesmentioning

confidence: 93%

“…The GIP calculation referred to the maximum amount of gas stored in shale reservoirs [12,13], which was the sum of the free gas content and adsorbed gas content [14]. The adsorbed gas amount was obtained based on excess adsorption data, while the free gas amount was calculated from the pore volume and free gas density under geological temperature and pressure [12,14]. The modified and simple equation was developed by Tian et al [14] to calculate GIP, as shown in Equation ( 4):…”

Section: Evaluations Of Gip: Implications For Shale Gas Resourcesmentioning

confidence: 99%

“…The adsorbed gas content was the highest in the five American shale formations, which accounted for 20-85% of the GIP [9]. Therefore, the GIP content and adsorbed gas ratio are critical parameters affecting potential shale gas resources, the evaluation of recoverable reserves, and the optimization of production strategies [10][11][12]. Usually, the adsorbed gas volumes were estimated by adsorption and desorption isotherms [13][14][15], while free gas was obtained from logging interpretation [16,17].…”

Section: Introductionmentioning

confidence: 99%

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Characterization of the Lower Cretaceous Shale in Lishu Fault Depression, Southeastern Songliao Basin: Implications for Shale Gas Resources Potential

Xie

2022

Energies

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Large thickness of shales over 180.0 m was developed in the source rocks of the Shahezi and Yingcheng formations in the Lishu Fault Depression. Moreover, the high amount of gas content and the total hydrocarbon value of gas logging in several boreholes illustrate that there is a great potential of shale gas resources in this region. Therefore, an integrated characterization of shales from the lower Cretaceous Shahezi and Yingcheng formations was provided to evaluate shale gas resources potential. The measurement results illustrated that the organic-rich shale samples with kerogen type Ⅱ during high to over thermal maturity had a higher content of brittle minerals (>50%) and clay mineral dominated by illite. The shales had a total porosity of 3.11–4.70%, a permeability of 1.24 × 10−3–1.52 × 10−3 μm2, and possessed pore types including dissolution pores, inter-layer pores of clay minerals, micro-fractures, intra-granular pores, and organic pores, which were dominated by micropores and mesopores (0.5–1.7 nm, 2.2–34.3 nm) with a significant contribution from OM and clay minerals. According to the N2 adsorption isotherms, the pore volume was comprised primarily of mesopores with mean widths of 4.314–6.989 nm, while the surface area was comprised primarily of micropores with widths in ranges of 0.5–0.8 nm and 1.0–1.7 nm. Thus, the shales have a suitable porosity and permeability, indicating that fine storage capacity and favorable gas flow capacity occur in the Shahezi and Yingcheng formations, which exhibit a good reservoir quality and excellent exploration potential since the considerable thickness of shales could form a closed reservoir and served as cap rocks for in situ gas generation and accumulation. Especially, according to the measured CH4 excess adsorption amount and the calculated maximum absolute adsorption capacities of CH4 based on the Langmuir adsorption model, the estimated GIP values (1.388–3.307 m3/t) of the shales happened to be in a sampling depth under geological hydrostatic pressure and temperature conditions. This means that the shale storage capacity and high gas content from well site desorption completely met the standard of industrial exploitation when synthetically considering the GIP model. As a consequence, shales in the Shahezi and Yingcheng formations in the Lishu Fault Depression could be potential targets for shale gas exploration.

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“…Excess adsorption isotherms were fitted by the supercritical Dubinin–Radushkevich (SDR) model, and the adsorbed gas density can be obtained. The calculations of the absolute amount of methane adsorption were described by Wei et al…”

Section: Samples’ Geological Background and Methodologymentioning

confidence: 99%

Organic Mesopore and Micropore Structures and Their Effects on Methane Adsorption in Marine Organic-Rich Shales

Guo

Zhao

et al. 2023

Energy Fuels

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Organic pores in organic-rich shale reservoirs can provide major pore space for adsorbed and free gas storage. In this study, the organic micropore and mesopore structures in organic-rich shale reservoirs and their influence on gas adsorption are investigated by comparing CO 2 , N 2 , and methane adsorption isotherms for organic matter-combusted and non-combusted organic-rich shale samples taken from the Wufeng− Longmaxi Formation in the Sichuan Basin. Experimental results show that organic pores in organic-rich shales from the Wufeng−Longmaxi Formation in Sichuan Basin are mainly smaller than 15 nm in diameters. Volumes of organic micropores and mesopores are mainly distributed in the diameter size ranges of 0.3−0.9 and 2−8 nm, respectively. Specific surface areas of organic micropores and mesopores are mainly distributed in the diameter size ranges of 0.3−0.7 and 2−4 nm, respectively. Organic pores dominate in the organic-rich shales from the Wufeng−Longmaxi Formation, contributing 49−77% and 50−84% of the entire micropore and mesopore volumes and specific surface areas, respectively. Organic micropores contribute 42− 84% and 44−85% of the entire micropore volume and specific surface area, respectively, and organic mesopores contribute 48−84% and 59−89% of the entire mesopore volume and specific surface area, respectively. Organic pores are dominant pore spaces for adsorbed methane in organic-rich shale reservoirs and contribute 75−87% of the total amount of adsorbed methane in shales from the Wufeng−Longmaxi Formation. Outcomes of this study demonstrate that organic matter combustion is a useful method for evaluating organic pores in organic-rich shales mainly according to following lines of evidence: (1) after combustion, samples have low volumes and specific surface areas for micropores and mesopores as well as extremely low contents of adsorbed methane. This suggests that combustion does not result in the generation of <15 nm inorganic micropores and mesopores in clay minerals to provide pore space for adsorbed methane. (2) The total organic carbon content (TOC) positively correlates with the organic pore volume and specific areas as well as the absolute amount of methane adsorption, suggesting that organic pores determined in this study are mainly controlled by TOC values and combustion caused the removal of organic micropores and mesopores.

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Supercritical High-Pressure Methane Adsorption on the Lower Cambrian Shuijingtuo Shale in the Huangling Anticline Area, South China: Adsorption Behavior, Storage Characteristics, and Geological Implications

Cited by 6 publications

References 67 publications

Effects of Microscopic Pore Structures on the Spontaneous Imbibition of Longmaxi Shale

Effects of Microscopic Pore Structures on the Spontaneous Imbibition of Longmaxi Shale

Characterization of the Lower Cretaceous Shale in Lishu Fault Depression, Southeastern Songliao Basin: Implications for Shale Gas Resources Potential

Organic Mesopore and Micropore Structures and Their Effects on Methane Adsorption in Marine Organic-Rich Shales

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