**1. Introduction**

Following the Qinshui Basin, the Ordos Basin is another large gas field in China with proven reserves of more than 100 billion cubic meters. It is also the first demonstration area for the exploration and development of low- and medium-rank coalbed methane (CBM) in China [1,2]. The Carboniferous Permian coal seams in the Ordos Basin have undergone different degrees of subsidence, uplift, and denudation, resulting in different degrees of thermal evolution of coal seams in different regions [3–5]. The Baode block is located in the northern part of the eastern margin of the Ordos Basin. The *Ro,max* of coal ranges from 0.52% to 0.89%, belonging to low- and middle-rank bituminous coal. Some CBM wells in the Baode block have obtained industrial gas flow, showing a good prospect for CBM development [6,7].

Previous studies have made preliminary discussions on the formation conditions and genetic types of CBM in the eastern margin of the Ordos Basin, and pointed out that the shallow part is a mixture of secondary biogas and thermogenic gas, while the deep part is mainly composed of thermogenic gas [8,9]. However, there is a lack of a systematic understanding of the origin of CBM in Baode block. In addition to methane, low-rank coal reservoirs often contain a certain proportion of CO2 and N2, which can be used as important objects for studying the genesis of CBM [10].

**Citation:** Chen, H.; Tian, W.; Chen, Z.; Zhang, Q.; Tao, S. Genesis of Coalbed Methane and Its Storage and Seepage Space in Baode Block, Eastern Ordos Basin. *Energies* **2022**, *15*, 81. https:// doi.org/10.3390/en15010081

Academic Editors: Nikolaos Koukouzas and Reza Rezaee

Received: 23 October 2021 Accepted: 21 December 2021 Published: 23 December 2021

**Publisher's Note:** MDPI stays neutral with regard to jurisdictional claims in published maps and institutional affiliations.

**Copyright:** © 2021 by the authors. Licensee MDPI, Basel, Switzerland. This article is an open access article distributed under the terms and conditions of the Creative Commons Attribution (CC BY) license (https:// creativecommons.org/licenses/by/ 4.0/).

In the current study, based on proximate analysis, mean vitrinite reflectance ( *Ro*) measurements and maceral analyses, the material composition (including macerals, ash, moisture, volatile) of nine coal samples collected from Baode block were characterized. At the same time, isotopic testing of 54 gas samples collected from desorption tanks in different desorption periods was carried out to reveal the gas composition characteristics and gas genesis. Finally, based on high-pressure mercury injection, low-temperature liquid nitrogen, and X-ray CT experiments, the gas storage and seepage space were finely characterized, which provides a theoretical basis for further clarifying the direction of CBM exploration and development in the Baode block.

#### **2. Geologic Setting**

The Ordos Basin, a huge intra-cratonic basin, is located in North China and contains the second largest accumulation of coal resources in China [11,12] (Figure 1a). The basin is divided into seven structural units [13,14] (Figure 1b). The eastern margin of the Ordos Basin is a N–S striking and west-inclined monocline within the following three tectonic units: Weibei uplift in the north, Yimeng uplift in the south, and Jinxi fold in the middle [15–17] (Figure 1b). The Baode block is located in the northern part of the eastern margin of the Ordos Basin (Figure 1c). The formation is gentle, sloping westward at an angle of 1◦ to 5◦. The faults are rare and small in scale, and the faults are mainly in the northeast direction with a fault distance of 10–25 m.

**Figure 1.** (**a**) Location of the Ordos Basin. (**b**) Tectonic units of the Ordos Basin. (**c**) Division of eastern margin of Ordos Basin and the location of Baode block, with the location of Wells B1 and B2.

In the Baode block, the main coal-bearing sequences occur in the Upper Carboniferous Taiyuan Formation (C3t) and the Lower Permian Shanxi Formation (P1s) (Figure 2). The C3t is in integrated contact with the underlying strata, with a thickness of 50–90 m. It is mainly composed of black-gray mudstone, gray-white medium sandstone, gray coarse

sandstone, and coal seam. A layer of bioclastic limestone is locally developed in the lower part, and the bottom is gray-white thick layered medium coarse sandstone and gravelly coarse sandstone. It is a set of interactive marine coal bearing deposits (Figure 2). The P1s is 60–90 m thick. It is mainly composed of gray fine sandstone, black-gray black, sandy mudstone, and coal seam. The bottom of P1s is gray-white coarse-grained quartz sandstone. The formation is a set of meandering river and delta plain swamp facies deposits (Figure 2). No. 4 + 5 coal seam in P1s and No. 8 + 9 coal seam in C3t are continuous and thick. They are the main coal seams in the Baode block and the target seam for CBM development, occurring at a depth of 400–1200 m, with a thickness ranging from 1.16 m to 20.21 m. The lithology of the roof and floor of No. 4 + 5 and No. 8 + 9 coal seams is dominated by mudstone, locally sandy mudstone. The thickness of the roof of the No. 4 + 5 coal seam is 4.3–13.9 m, and the thickness of the floor is 2.4–6.7 m, while those of the 8 + 9 coal seam are 2.8–6.8 m and 2.0–18.6 m, respectively.

**Figure 2.** Lower Permian stratigraphic column in the Baode block.

#### **3. Samples and Analytical Procedures**

#### *3.1. Coal and Gas Samples*

Eleven coal samples were collected from Wells B1 and B2 (Figure 1c) in the Baode block, and the burial depths of the main coal seams in these two wells are 501.40–547.20 m and 1011.40–1068.30 m, respectively. Among them, four samples were collected form No. 4 + 5 coal seam, and seven of them were collected form No. 8 + 9 coal seam. Part of the sample was carefully packed and then immediately sent to the laboratory for experiments, and another part of the sample was immediately put into different desorption tanks to collect the desorption gas. A total of 54 gas samples were collected from eleven desorption tanks in different desorption periods for gas composition and isotopes analysis.

#### *3.2. Material Composition*

Nine of the collected coal samples were analyzed for proximate analysis on an airdried basis following the Chinese national standard GB/T 212-2008 [18]. According to ISO 7404.3-1994 [19] and ISO 7404.5-1994 [20], mean vitrinite reflectance (*Ro*) measurements and maceral analyses (500 points) were performed on the same polished section of the coal samples using a Leitz MPV-3 photometer microscope. Nonlinear error: max. ±1 low significance bit. A/D conversion accuracy: ±1 low significance bit, less than 2‰.

#### *3.3. Pore-Size Distribution*

Based on the material composition analysis results, six samples were selected to analyze the characteristic pore-size distributions by using mercury intrusion porosimetry (MIP), low-temperature nitrogen adsorption (LTNA) and X-ray CT. Diameters of pores detected by LTNA range from 2 to 300 nm, and those accessed by MIP are in the diameter of 30– > 1000 nm. Thus, the adsorption pores (<10<sup>2</sup> nm) [21] can be determined by LTNA, while the seepage pores (>10<sup>2</sup> nm) [21] can be well characterized by MIP. MIP was carried out according to the national standard, SY/T 5346-2005 [22], by using Micromeritics Auto Pore IV 9500 instrument. Before the LTNA experiments, all samples were crushed and sieved to a size of 0.18–0.25 mm (60–80 mesh) (dried for 48 h), and then tested using a Micromeritics ASAP2020 instrument at 77K. The X-ray CT was carried out by using U.S. ACTIS-250/320PK/225FFI industrial CT system. The spatial resolution is close to 50 μm in the process of X-ray CT measurement, and therefore large pores and microfractures can be identified in the coal core plug. The specific experimental procedures and image processing methods were presented in detail by Tao et al. (2019) [23].

Thus, the characteristics of seepage pores (>10<sup>2</sup> nm) were measured by MIP, and then the characteristics of adsorption pores (<10<sup>2</sup> nm) were measured by LTNA. Finally, the three-dimensional models of samples' adsorption pores and percolation pores were constructed by X-ray CT experiment.

#### *3.4. Gas Composition and Isotopes*

A total of 54 gas samples were collected from eleven desorption tanks to analyze the gas composition by using an Agilent 7890B gas chromatograph, according to the Chinese national standard GB/T 13610-2014 [24]. Afterward, δ13C values of CH4 and CO2, and δD values of CH4 of 54 gas samples were determined on a Finnigan MAT 253 mass spectrometer. The δ13C and δD values were calibrated with respect to the VPDB and VSMOW standards, and the standard deviations were ±(0.1‰~0.3‰) and ±(1‰~2‰), respectively.

#### **4. Results and Discussion**

#### *4.1. Basic Information of Coals*

As shown in Table 1, the Baode coal samples have ash yields ranging from 4.96% to 7.31%, whereas they have relatively high moisture contents (18.6–26.56%) and volatile yields (25.95–30.32%). Higher volatile content means lower coal metamorphism, with *Ro* of 0.62–0.76%. The vitrinite content is the highest (41.5–84.8%, mean 69.3%), followed by inertinite (8.7–54.4%, mean 22.8%) and liptinite (0.5–17.0%, mean 7.9%). Macerals in the Baode coal samples include: cutinite, microsporinite, desmocollinite, fusinite, semifusinite, resinite, and liptodetrinite. The cutinite is usually distributed in strips, and the microsporinite is distributed in parallel planes in a worm-like shape (Figure 3).

**Table 1.** Results of the proximate and maceral analyses.


Notes: Mad = moisture content; Aad = ash yield; Vad = volatile yield; ad = air dried basis.

**Figure 3.** Characteristic macerals from Baode coals, polished section, reflected fluorescence and reflected plane-polarized light (last two pictures). Cu: cutinite; MiS: microsporinite; DC: desmocollinite; F: fusinite; Sf: Semifusinite; Py: Pyrite; V: Vitrinite; Cl: clay; Re: resinite; LD: liptodetrinite.

#### *4.2. CBM Composition and Origin*

4.2.1. Compositional Characteristics of CBM

As shown in Table 2, the gas in No. 4 + 5 and No. 8 + 9 coal seams are dominated by CH4, with a volume fraction ranging from 80.9% to 94.7% (mean 88.32%). The volume fraction of N2 varies between 0.6–15.9% (mean 4.95%), and the N2 content in No. 4 + 5 coal seam is higher than that in No. 8 + 9 coal seam. Meanwhile, as the depth increases, the N2 content decreases relatively, which shows that the gas composition of shallow CBM is affected by mixing with atmospheric air [25,26]. Figure 4 indicates that the N2 volume fraction and CH4 volume fraction in the two sets of coal seams are negatively correlated. The main difference between 8 + 9 coal seam (a) and8+9 coal seam (b) is the different proportions of N2 and CH4. Different proportions can characterize the source of coal seam gas. The proportion of gas in No. 8 + 9 coal seam (a) is the same as that in No. 4 + 5 coal seam. The CO2 content increases with increasing burial depth of No. 8 + 9 coal seam. This phenomenon is related to the action of CO2-reducing bacteria in the shallow part which decreases with depth [27].

**Table 2.** CBM composition of the collected gas samples from eleven desorption tanks in different desorption periods.


**Figure 4.** Relationship between N2 volume fraction and CH4 volume fraction.

4.2.2. Genetic Types of CH4 and CO2

CBM is divided into biogenic gas and thermogenic gas, and the thermogenic gas is further subdivided into early thermogenic wet gas and late thermogenic dry gas [28]. To some extent, different gas concentrations in CBM reflect the genesis of CBM which can be identified by gas composition.

As shown in Table 3, the value of δ13C (CH4) in No. 4 + 5 coal seam varies between −55.6‰ and −47.7‰, with an average of −52.5‰, and the value of that in No. 8 + 9 coal seam varies between −62.3‰ and −50.4‰, with an average of −54.5‰. The δ13C (CH4) values of the two coal seams are within the range of national δ13C (CH4) observation values of CBM (from −73.7‰ to −24.9‰) [29], belonging to light carbon isotopes. The value of δ13D (CH4) in No. 4 + 5 coal seam ranges from −256.2‰ to −241.6‰, with an average of −249.4‰, and the value of that in No. 8 + 9 coal seam ranges from −261.8‰ to −247.6‰, with an average of −252.8‰. At shallower than 550 m, the average value of δ13C (CH4) is less than −55‰, indicating that biogenic gas is the main source. With the increase in burial depth (about 1000 m in Table 3), the average value of δ13C (CH4) is around −50‰, indicating that thermogenic gas is dominant. Figure 5 also shows that No. 4 + 5 and No. 8 + 9 coal seams both have biogenic gas and thermogenic gas [30].

**Figure 5.** Genetic type discrimination map of CBM. (C1 stands for CH4) (modified from [31]).


**Table 3.** Carbon and hydrogen stable isotope compositions and CDMI values of gas samples from eleven desorption tanks in different desorption periods.

CO2 in CBM is mainly generated in the low maturity evolution stage of organic matter, which is generated through the chemical reaction of oxygen-containing groups such as decarboxylation and carbonyl in coal molecules [31]. Previous studies have shown that the value of δ13C in organic CO2 is generally −39‰~−8‰, where the value of δ13C (CO2) produced by humic organic matter is generally −25‰~−5‰; while the value of δ13C (CO2) produced by thermal degradation of organic matter is −28‰~−10‰, and the value of δ13C (CO2) transformed by microbial reduction is more important, reaching 18‰. In the study area, the δ13C (CO2) value in No. 4 + 5 coal seam is between −10.5‰ and −0.6‰, and that in No. 8 + 9 coal seam is between −11.3‰ and −7.6‰ (Table 3), which conforms to the carbon isotope characteristics of organic (biological) genetic gas. Among them, some samples have higher δ13C (CO2) values due to microbial transformation. The burial depth also affects the δ13C (CO2) values. The burial depth of No. 4 + 5 coal seam and No. 8 + 9 coal seam in the same well is similar, but that of the same coal seam in different wells (such as No. 4 + 5 coal seam in wells B1 and B2) is quite different. Therefore, the δ13C (CO2) values of samples are separated in two groups in Figure 5.

According to the component data of CBM, the CO2–CH4 coefficient of each sample is calculated by:

$$\text{CDMI} = \frac{\text{CO}\_2}{\text{CO}\_2 + \text{CH}\_4} \times 100\%$$

The CDMI value and the δ13C (CO2) are used to draw the relationship diagram reflecting the genetic types of CO2 (Figure 6). No. 4 + 5 and No. 8 + 9 coal seams both contain CO2 generated by coal pyrolysis, which belongs to organic genetic gas [28], while shallow CO2 is greatly affected by the action of microorganisms and belongs to biogenic gas. In the stagnant CBM system, the water-soluble consumption of CO2 produced by coalification (including associated gas during microbial methane production and thermal degradation gas of coal-forming material) is not complete [32], resulting in high CO2 concentration in gas components, and increases with the increase of burial depth.

**Figure 6.** Relationship between δ13C (CO2) and CDMI.

*4.3. Characterization of Gas Storage and Seepage Space*

4.3.1. Characteristics of Seepage Pores

The experimental data of mercury injection are shown in Table 4, and the mercury injection curves are shown in Figure 7. The pores contained in the coal samples are mainly micropores and transition pores, and the development of mesopores and macropores is less. The average proportion of pores in each pore size class is 56.61%, 28.22%, 5.10%, and 10.07%, respectively. Mercury injection curves can be divided into three types. Type 1 contains samples BD-1 and BD-3. At pressures lower than 10 MPa, the amount of mercury injected increased rapidly; at pressures greater than 10 MPa, the amount of mercury injected increased slowly, indicating that micropores are more developed. The mercury intrusion curve and the extrusion curve basically overlap, indicating that the mercury removal efficiency is high and the pore connectivity is good. Type 2 contains BD-5 and BD-6. At pressures below 10 MPa, the amount of mercury injected increased slowly, and at pressures greater than 10 MPa, the amount of mercury increased rapidly, indicating that the pore structure is dominated by micropores. The large offset between the mercury injection curve and the mercury extrusion curve shows the low mercury removal efficiency and poor pore connectivity. The Type 3 mercury injection curve of BD-2 and BD-9 has a three-stage structure. At pressures less than 2 MPa, the mercury injection curve rises linearly; at pressures between 2 MPa and 10 MPa, the mercury injection rate gradually slows down; at pressures greater than 10 MPa, the mercury injection rate increases again, indicating

BD-9

 8 + 9 that compared

**Table**

developed

**4.**

 5.29  with the first two types of curves, mesopores

 in samples BD-2 and BD-9.

 Mercury injection typical samples **Sample No. Coal Seam No. Porosity (%) Pore Volume Percentage (%) Micropore (<10 nm) Transition Pores (10–10<sup>2</sup> nm) Mesopore (102–103 nm) Macropore (>10<sup>3</sup> nm)** BD-1 4 + 5 5.07 64.09 26.41 2.46 7.04 BD-2 4 + 5 5.39 61.15 22.19 3.99 12.67 BD-3 8 + 9 5.42 62.24 26.58 3.35 7.83 BD-5 8 + 9 6.89 54.89 31.38 4.65 9.08 BD-6 8 + 9 6.09 47.91 32.87 9.61 9.60

data

 49.38

of

 29.89

in

the

Baode

 and

block.

 6.54 macropores

 are more

 14.19

**Figure 7.** Mercury injection curves of typical samples in the study area.

Overall, the seepage pores (>10<sup>2</sup> nm) are poorly developed in Baode coal samples. Compared with No. 4 + 5 coal samples, No. 8 + 9 coal samples have a relatively small hysteresis and good pore connectivity. At the same time, the proportion of mesopores and macropores is relatively high, which is conducive to gas migration (Table 4).

#### 4.3.2. Characteristics of Adsorption Pores

Low-temperature liquid nitrogen adsorption experiments are often used to finely characterize the adsorption pores (<10<sup>2</sup> nm) of coal samples [33,34]. As shown in Table 5, the BET specific surface area (SSA) is 1.41–5.14 m2/g, and the total pore volume of BJH is 0.0063–0.0166 mL/g. The average pore diameter (APD) ranges from 11.50 nm to 19.86 nm, and the proportion of transition pores is the largest.


**Table 5.** Nitrogen adsorption data of typical samples in the study area.

Notes: BJH TPV = Total pore volume; APD = Average pore diameter; BET SSA = Specific surface area.

Based on the adsorption/desorption curve of the nitrogen adsorption experiment, scholars use the hysteresis loop to classify the pore morphology in coal [35–37]. As can be seen in Figure 8, the pore morphology of the samples is divided into two types. Type 1 contains samples of BD-1 and BD-2 collected from No. 4 + 5 coal samples, which has an obvious hysteresis loop located at the relative pressure of 0.5–1, indicating that ink bottle pores are well-developed in No. 4 + 5 coal samples. Type 2 contains samples BD-3, BD-5, BD-6, and BD-9, which belong to the No. 8 + 9 coal samples. There is no hysteresis loop or an obvious hysteresis loop, which means that the inflection point of desorption curve is not obvious, thus the adsorption and desorption curves are roughly parallel, indicating that the samples mainly develop an airtight pore closed at one end.

**Figure 8.** Typical nitrogen adsorption and desorption curve of coal samples in Baode block.

As shown in Figure 9, all samples have pores with a diameter of 1–100 nm, and micropores with a pore diameter of less than 10 nm are less developed, and there is a peak around 40–50 nm. The contribution of SSA is dominated by 1–10 nm micropores. The

difference is that the 1–3 nm pores of the No. 4 + 5 coal samples have a grea<sup>t</sup> contribution, while the 3–10 nm pores of the No. 8 + 9 coal samples have a grea<sup>t</sup> contribution. Compared with No. 8 + 9 coal samples, No. 4 + 5 coal samples have developed more adsorbed pores such as ink bottle pores, so the SSA is relatively large, which is conducive to the adsorption of CBM but not conducive to desorption.

**Figure 9.** Relationship between pore diameter, SSA, and pore volume of typical coal samples in Baode block.

The BET model, FHH model, and thermodynamic model are often used to calculate the fractal dimension of micropores of coal [38,39]. In this paper, the FHH model is used to calculate the fractal dimension based on nitrogen adsorption data;

$$\ln(V/V\_0) = A \ln\left(\ln P/P\_0\right) + C$$

where *V* is the volume of gas molecules adsorbed at equilibrium pressure; *V*0 is the volume of gas adsorbed by the monolayer; *P*0 is the saturated vapor pressure of gas adsorption; *A* is the slope of the double logarithm curve of ln*V* and ln(ln(*P*0/*P*)); *C* is a constant.

In the process of liquid nitrogen adsorption, micropores are filled first, and then monolayer adsorption occurs, followed by multi-molecular layer adsorption. When the relationship between the relative pressure and pore diameter conforms to the Kelvin equation, capillary condensation occurs [40]. Therefore, taking the relative pressure as the boundary of 0.5 [40], the fractal dimensions D1 and D2 can be calculated respectively (Table 6). The fractal dimension D should meet 2 ≤ D ≤ 3, in which the larger the fractal dimension, the rougher the coal surface and the stronger the adsorption capacity [41,42].


**Table 6.** Fractal dimension of typical samples in the study area.

As shown in Figure 10, the fractal dimension D1 has no obvious correlation with the SSA and APD. The fractal dimension D1 reflects the porosity of the sample with a relative pressure of 0~0.5, which cannot characterize all the pore characteristics of the sample. The fractal dimension D2 is positively correlated with the SSA and negatively correlated with the APD, which indicates that the larger the SSA, the smaller the average pore size, and the higher the overall micropore proportion of the sample. It indicates that the more developed the micropore, the stronger the adsorption capacity of coal. As the value of D2 increases, the pore structure becomes more complex, and the adsorption capacity of coal becomes stronger.

**Figure 10.** (**a**) Relationship between fractal dimension and SSA; (**b**) Relationship between fractal dimension and APD.

#### 4.3.3. Three-Dimensional Model of Storage and Seepage Space

In order to intuitively obtain the distribution characteristics of pores and fractures, the samples are selected for X-ray CT imaging tests (Table 7). The results show that the porosity of the selected coal samples varies from 0.76% to 4.39%, with an average of 2.38%. However, the proportion of connected pores is extremely low (0–35.04%), resulting in an extremely low connected porosity of 0–1.21%. There is a negative correlation between the porosity and the mineral content. Sample BD-3 has the lowest porosity, because most of the fractures inside the sample are filled with minerals (Figure 11).

**Figure 11.** Two-dimensional slices of mineral filling fractures in sample BD-3 ((**a**) is the first slice and (**b**) is the 45th slice; white means the fractures are filled with minerals).


**Table 7.** X-ray CT imaging test results of typical samples.

After three-dimensional reconstruction, the distribution of the coal matrix, pores, fractures, and minerals in coal samples can be more easily displayed (Figure 12). The distribution direction of minerals is similar to the direction of densely developed pores, especially in samples BD-3 and BD-6, and the distribution of pores and fractures is extremely uneven. Meanwhile, although some samples have relatively high porosity, such as BD-9, due to the extremely low proportion of connected pores, the connected porosity is still very low. On the contrary, if the mineral content in coal is small and distributed in a dispersed state, the proportion of connected pores will be high, and the connected porosity will be high, which is conducive to gas flow, such as sample BD-5. Therefore, it is not the measured porosity that plays a key role in the development of CBM, but it depends on the connectivity of the pore and fracture system.

**Figure 12.** (**a**) Three-dimensional reconstruction image of coal samples (gray: matrix, blue: pores and fractures, orange: mineral). (**b**) Three-dimensional image of connected and isolated pores and fractures (blue: connected pores and fractures, red: isolated pores and fractures). (**c**) Threedimensional image of minerals.

## **5. Conclusions**

(1) Gases disrobed from No. 4 + 5 and No. 8 + 9 coal seams in Baode block are dominated by CH4, followed by N2 and CO2. Under the influence of air mixing, the N2 content decreases with the increase of burial depth. Meanwhile, the CO2 content increases with increasing burial depth of No. 8 + 9 coal seam, which related to the action of CO2-reducing bacteria in the shallow part.

(2) The δ13C (CO2) value in No. 4 + 5 coal seam is between −10.5‰ and −0.6‰, and that in No. 8 + 9 coal seam is between −11.3‰ and −7.6‰. No. 4 + 5 and No. 8 + 9 coal seams both have biogenic gas and thermogenic methane. Meanwhile, No. 4 + 5 and No. 8 + 9 coal seams both contain CO2 generated by thermal maturation of coal (thermogenic gas), while shallow CO2 is likely to result from the action of microorganisms (microbial gas). With the increase of burial depth, the content of CO2 increases.

(3) The seepage pores (>10<sup>2</sup> nm) are poorly developed in the Baode coal samples. Samples collected from No. 4 + 5 coal seams have developed more sorption pores such as ink bottle pores, so the SSA is relatively large, which is conducive to the adsorption of CBM. The mercury intrusion and extrusion curves of samples from No. 8 + 9 coal seams exhibit a relatively low degree of hysteresis (Hg retention), indicating good pore connectivity. At the same time, the proportion of mesopores and macropores is relatively high, which is conducive to gas migration.

(4) The porosity of the coal samples is inversely related to the mineral content and the occurrence of the mineral. If the mineral content in coal is small and distributed in a dispersed state, the proportion of connected pores will be high, and the connected porosity will be high, which is conducive to gas flow.

**Author Contributions:** Conceptualization, H.C. and W.T.; methodology, H.C.; software, Z.C.; validation, H.C., W.T. and Q.Z.; formal analysis, S.T.; investigation, S.T.; resources, W.T.; data curation, W.T.; writing—original draft preparation, H.C.; writing—review and editing, W.T.; visualization, Z.C.; supervision, Q.Z.; project administration, H.C.; funding acquisition, W.T. All authors have read and agreed to the published version of the manuscript.

**Funding:** This research was funded by [the National Natural Science Foundation Project] gran<sup>t</sup> number [No. 41772132, 41502157, 41530314], [the Key Project of the National Science & Technology] gran<sup>t</sup> number [No. 2016ZX05043-001], [the Fundamental Research Funds for the Central Universities] gran<sup>t</sup> number [No. 2652019095] and The APC was funded by [the National Natural Science Foundation Project]. Key Technologies R&D Programme of PetroChina Company Limited (2019E-25).

**Institutional Review Board Statement:** Not applicable.

**Informed Consent Statement:** Not applicable.

**Data Availability Statement:** Not applicable.

**Conflicts of Interest:** The authors declare no conflict of interest.
