Lower Cretaceous gas shales in northeastern British Columbia, Part I: geological controls on methane sorption capacity

Chalmers, Gareth R.L.; Bustin, R. Marc

doi:10.2113/gscpgbull.56.1.1

Cited by 527 publications

(329 citation statements)

References 26 publications

Supporting

Mentioning

295

Contrasting

Unclassified

Order By: Relevance

“…7 shows the micropore surface area (S mic ) for eight shale samples ranges from 4.97 m 2 /g to 17.94 m 2 /g, which has also a strong positive correlation with the TOC content (R 2 =0.8962). These agree well with previous results from gas shales in North American basins (Chalmers and Bustin, 2008;Ross and Bustin, 2009) and Lower Silurian and Lower Cambrian shales in southwestern China (Tian et al, 2013. They both suggest that organic matters provide important spaces for micropores development in the Lower Silurian shale, which has also been reported in other shales (Milliken et al, 2013;Tian et al, 2013Tian et al, , 2015.…”

Section: Isotherms Of Co 2 Adsorptionsupporting

confidence: 92%

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Chen

Jiang

Liu

et al. 2017

Adv. Geo-Energ. Res.

View full text Add to dashboard Cite

The pores in shales are mainly of nanometer-scale, and their pore size distribution is very important for shale gas storage and adsorption capacity, especially micropores having widths less than 2 nm, which contribute to the main occurrence space for gas adsorption. This study is focused on the organic-rich Lower Silurian black shale from four wells in the Upper Yangtze Platform, and their total organic carbon (TOC), mineralogical composition and micropore characterization were investigated. Low pressure CO2 adsorption measurement was conducted at 273.15 K in the relative pressure range of 0.0001-0.03, and the micropore structure was characterized by Dubinin-Radushkevich (DR) equation and density functional theory (DFT) method and then the relationship between micropore structure and shale gas adsorption capacity was discussed. The results indicated that (1) The Lower Silurian shale have high TOC content in the range of 0.92-4.96%, high quartz content in the range of 30.6-69.5%, and high clays content in the range of 24.1-51.2%. The TOC content shows a strong positive relationship with the quartz content which suggests that the quartz is mainly biogenic in origin. (2) The micropore volume varies from 0.12 cm 3 /100 g to 0.44 cm 3 /100 g and micropore surface area varies from 4.97 m 2 /g to 17.94 m 2 /g. Both of them increase with increasing TOC content, indicating TOC is the key factor to control the micropore structure of the Lower Silurian shale. (3) Low pressure CO2 adsorption measurement provides the most suitable detection range (0.3-1.5 nm) and has high reliability and accuracy for micropore structure characterization. (4) The TOC content is the key factor to control gas adsorption capacity of the Lower Silurian shale in the Upper Yangtze Platform.

show abstract

Section: Isotherms Of Co 2 Adsorptionsupporting

confidence: 92%

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Chen

Jiang

Liu

et al. 2017

Adv. Geo-Energ. Res.

View full text Add to dashboard Cite

show abstract

“…The Langmuir parameters (V L and P L ), which were obtained from the least-squares fit of methane adsorption isotherms, are listed in Table 3, with values ranging from 2.37 cm 3 /g to 5.55 cm 3 /g and 2.6105 MPa to 6.1741 MPa, respectively. According to previous studies [9][10][11]40,45,[48][49][50][51], the Langmuir methane adsorption volume of organic-rich shale is controlled by a number of interior and external factors, including the shale matrix (heterogeneous mixture of organic and inorganic) and reservoir's temperature and pressure. In particular, organic matter with a microporous structure is the dominant factor that controls the methane adsorption capacity of organic-rich shales.…”

Section: Methane Adsorption Kineticsmentioning

confidence: 99%

Methane Adsorption Rate and Diffusion Characteristics in Marine Shale Samples from Yangtze Platform, South China

et al. 2017

View full text Add to dashboard Cite

Knowledge of the gas adsorption rate and diffusion characteristics in shale are very important to evaluate the gas transport properties. However, research on methane adsorption rate characteristics and diffusion behavior in shale is not well established. In this study, high-pressure methane adsorption isotherms and methane adsorption rate data from four marine shale samples were obtained by recording the pressure changes against time at 1-s intervals for 12 pressure steps. Seven pressure steps were selected for modelling, and three pressure steps of low (~0.4 MPa), medium (~4.0 MPa), and high (~7.0 MPa) were selected for display. According to the results of study, the methane adsorption under low pressure attained equilibrium much more quickly than that under medium and high pressure, and the adsorption rate behavior varied between different pressure steps. By fitting the diffusion models to the methane adsorption rate data, the unipore diffusion model based upon unimodal pore size distribution failed to describe the methane adsorption rate, while the bidisperse diffusion model could reasonably describe most of the experimental adsorption rate data, with the exception of sample YY2-1 at high pressure steps. This phenomenon may be related to the restricted assumption on pore size distribution and linear adsorption isotherm. The diffusion parameters α and β/α obtained from the bidisperse model indicated that both macro-and micropore diffusion controlled the methane adsorption rate in shale samples, as well as the relative importance and influence of micropore diffusion and adsorption to adsorption rate and total adsorption increased with increasing pressure. This made the inflection points, or two-stage process, at higher pressure steps not as evident as at low pressure steps, and the adsorption rate curves became less steep with increasing pressure. This conclusion was also supported by the decreasing difference values with increasing pressures between macro-and micropore diffusivities obtained using the bidisperse model, which is roughly from 10 −3 to 10 0 , and 10 −3 to 10 −1 , respectively. Additionally, an evident negative correlation between macropore diffusivities and pressure lower than 3-4 MPa was observed, while the micropore diffusivities only showed a gentle decreasing trend with pressure. A mirror image relationship between the variation in the value of macropore diffusivity and adsorption isotherms was observed, indicating the negative correlation between surface coverage and gas diffusivity. The negative correlation of methane diffusivity with pressure and surface coverage may be related to the increasing degree of pore blockage and the decreasing concentration gradient of methane adsorption. Finally, due to the significant deviation between the unipore model and experimental adsorption rate data, a new estimation method based upon the bidisperse model is proposed here.

show abstract

“…A gas shale reservoir is characterized by abundant pores having sizes in a range of several to several hundreds of nanometers [1][2][3][4][5][6][7][8]. Pores are subdivided into micropores (pore width <2 nm), mesopores (pore width between 2-50 nm) and macropores (pore width >50 nm) according to the classification of International Union of Pure and Applied Chemistry (IUPAC) [9].…”

Section: Introductionmentioning

confidence: 99%

“…Pores are subdivided into micropores (pore width <2 nm), mesopores (pore width between 2-50 nm) and macropores (pore width >50 nm) according to the classification of International Union of Pure and Applied Chemistry (IUPAC) [9]. It has been found that a considerable part of gas occurs in an adsorbed state within micro-and mesopores of gas shales [3,4,[10][11][12]. Elucidating the complex pore networks in gas shales has become a strategic subject because many studies have shown that shale pore structure is one of the most important factors controlling gas capacity [1][2][3][4][10][11][12].…”

Section: Introductionmentioning

confidence: 99%

Evolution of nanoporosity in organic-rich shales during thermal maturation

Chen

Xiao

2014

Fuel

348

186

View full text Add to dashboard Cite

Lower Cretaceous gas shales in northeastern British Columbia, Part I: geological controls on methane sorption capacity

Cited by 527 publications

References 26 publications

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Methane Adsorption Rate and Diffusion Characteristics in Marine Shale Samples from Yangtze Platform, South China

Evolution of nanoporosity in organic-rich shales during thermal maturation

Contact Info

Product

Resources

About