Biogenic Methane Accumulation and Production in the Jurassic Low-Rank Coal, Southwestern Ordos Basin

: Geological conditions are the key for coalbed methane (CBM) accumulation and production. However, the geological feature of CBM accumulation and production in the Jurassic of Ordos Basin lacks systematic and detailed evaluation, resulting in poor CBM production in this area. This study has determined the genetic types of gas according to geochemistry characteristics of the gas, the geological factors to control CBM accumulation and production performance were revealed, and a comprehensive method was established to evaluate favorable areas based on 32 sets of CBM well production data from Jurassic Yan’an Formation. The results show the coal macerals are rich in inertinite (41.13~91.12%), and the maximum reﬂectance of vitrinite ( R o,max ) in coal is 0.56~0.65%. According to gas compositions and carbon isotopes analysis, the δ 13 C(CH 4 ) is less than − 55‰, and the content of heavy hydrocarbon is less than 0.05%. The value of C 1 /(C 2 + C 3 ) is 6800~98,000, that is, the CBM is a typical biogenic gas of low-rank coal. The CBM accumulation model is the secondary biogenic on the gentle slope of the basin margin, in which gas content is closely related to buried depth and hydrodynamic environment, i.e., the high gas content areas are mainly located in the groundwater weak runoff zone at the burial depth of 450 m~650 m, especially in the syncline. Meanwhile, gas production mainly depends on the location of the structure. The high gas production areas of vertical wells were distributed on the gentle slope with high gas content between anticline and syncline, and the horizontal wells with good performance were located near the core of the syncline. According to the above analysis combined with the random forest model, the study area was divided into different production favorable areas, which will provide a scientiﬁc basis for the CBM production wells. the uplift and the south-north structures in the western margin of the basin, large-scale denudation of the coal-bearing rock series. The study area northeast inclined monoclinic structure, the coal seam belongs to the Jurassic coal shallow burial depth and low metamorphism degree ( R o,max < 0.65%). When the coal the shallow stratum ﬁssure recharged the coal the reproduction of bacteria. of organic mineralization


Introduction
China is a large country of coal production and energy consumption, the largescale and high-efficiency development of CBM can not only reduce mine gas accidents but also supplement the shortage of conventional natural gas [1,2]. Coalbed methane (CBM) is an important environment-friendly energy resource [3,4]. CBM includes biogenic gas and thermogenic gas, of which biogenic gas is generated dominantly by anaerobic bacteria and methanogens via coal biodegradation at low temperatures (<5 • C) [5][6][7]. Influenced by generation time and geological evolution, the biogas nowadays in coal reservoirs is secondary biogenic gas, which mainly is the reduction in carbon dioxide according to the gas component [8]. The resources of CBM are abundant in China, and commercial development for the middle-high rank CBM has achieved technological 2. Methodology

Data Acquisition and Processing
The coal samples in this paper were all collected from the No. 4 coal seam of the Middle Jurassic Yan'an Formation in the Dafosi minefield, Binchang mining area. The 10 coal samples were selected for the determination of maceral composition and the reflectance of vitrinite in coal according to the Chinese national standard GB/T 16773-2008, GB/T 8899-2013 and GB/T 6948-2008. The coal samples were ground to a particle size less than 1.0 mm air-dried base sample, made into pulverized coal slices, and then the samples were polished and carried out maceral composition determination. Meanwhile, the samples were repolished and dried in a drying oven at 30 • C~40 • C for 4 h before carrying out the reflectance of vitrinite in coal determination.
Carbon isotopic characteristics of CH 4 are important to the gas performance of coal reservoirs [42]. The gas samples came from the surface CBM wells, including multi-branch horizontal wells DFS-C02, DFS-05, DFS-06, DFS-09, and vertical wells DFS-C01, U-shaped well DFS-C03 and V-shaped well DFS-04. Wasson-7890A gas chromatograph was used for gas composition determination, and thermo MAT253 gas isotope mass spectrometer was employed in doing carbon isotope. Taking a certain volume of CBM sample with an airtight syringe and injecting it into the Trace GC ultra; the hydrocarbon components in the sample were separated by the meteorological chromatograph Trace GC ultra and converted into carbon dioxide in the oxidation unit GC combustion, and then the gas flow entered the isotope mass spectrometer MAT253 IRMS for the determination of carbon isotope components. Gas compositions and carbon isotopes are based on GB/T 13610-2003 and SY/T 5238-2008. The basic information of the test sample is shown in Table 1.

Data Interpretation
In order to analyze the main controlling factors affecting CBM productivity, the grey correlation analysis method is introduced to quantitatively determine the correlation degree between each influencing factor and productivity, so as to objectively evaluate the influence degree of each geological factor on coalbed methane well productivity [39,43]. Grey correlation calculation is mainly divided into two processes, (1) correlation coefficient calculation, (2) calculation of correlation degree [44]. Random forest was used for favorable area evaluation and prediction. Random forest takes decision trees as the basic model to generate a series of differentiated decision tree models by building different training data sets and different feature spaces [45][46][47][48]. The random forest was constructed based on classification and regression trees in this paper. In the process of establishing each classification and regression tree, the splitting process of each node is completed by calculating the "purity" of the sample after the split. The classification and regression tree employ the gini coefficient to measure this so-called "purity", i.e., random forest uses the gini index to split the tree to complete the decision. The smaller the gini coefficient, the higher the purity of the sample and the better the effect of tree division. Assuming that the sample set T contains k categories, the Gini coefficient of the sample set can be expressed as [49]: where, p i is the probability that T contains class i. If T is divided into two subsets T 1 and T 2 , the divided gini coefficient can be expressed as: where, |*| represents the number of elements in the current sample set. The selection of CBM development prospect evaluation indicators vary in different areas. For low-rank coal development areas, the gas generation potential, storage performance and preservation conditions of the coal reservoir should be chosen. Through the analysis of the drilling and experimental data of the CBM wells, the main factors influencing the development potential and productivity of CBM, including resource conditions (gas content, ash, net coal seam thickness) and occurrence conditions (structural location, roof thickness), development conditions (permeability, reservoir pressure, burial depth) were selected as evaluation indicators. There are few faults in this area, mainly folds. In order to quantitatively study the influence of folds on the development of CBM, qualitative indicators (structural locations) are assigned and quantified separately. The flank is 0.8, the syncline is 1, and the anticline is 0.6.
In order to prevent the strong correlation between the factors, resulting in a decrease in the running rate of the evaluation model and over-fitting of the running results, the correlation between the factors needs to be tested. This paper adopts the Pearson correlation coefficient (PCC) to analyze the degree of correlation between the factors. The larger the value, the stronger the correlation of the factors. The calculation formula of the correlation coefficient between the evaluation factors is [50].
where, x i , y i is the variable values of X i and Y i , respectively, x and y are the average values of X i and Y i , respectively. When 0 ≤ |PCC| ≤ 0.4, it indicates that the factor is irrelevant or weakly correlated. When |PCC| > 0.6, it indicates that the factor is strongly correlated.

Geology Condition
The Binchang mining area is located in the Miaobin depression area on the northern margin of the Weibei flexure belt in the southern Ordos Basin, the surface is covered by loess formation, and the occurrence of Cretaceous strata exposed in the valley is relatively gentle [51]. The deep Jurassic hidden structure is generally a monoclinic structure with N 60 •~7 0 • E in strike and NW~NNW in the dip. A set of broad and gentle folds are developed on it, from south to north, Binxian anticline, Lujia-Xiaolingtai anticline, Mengcun syncline, Qilipu-Xipo anticline in order. According to the borehole, no fault structure is found in the area. The overall structure is a monoclinic structure inclined from southeast to northwest inherited from the Triassic basement, the stratum dip is gentle, on average 3~5 • . The stratigraphic division belongs to the Ordos areas, from bottom to top, it is the Hujiacun Formation of the Upper Triassic System (T 3h ), the Fuxian Formation of the Lower Jurassic System (J 1f ), the Middle Jurassic Yan'an Formation (J 2y ), Zhiluo Formation (J 2z ), Anding Formation (J 2a ), Lower Cretaceous Yijun Formation (K 1y ), Luohe Formation (K 1l ), Huachi Formation (K 1h ), Neogene and Quaternary strata, as shown in Figure 1. The overall structure of the study area is simple. As shown in Figure 2, the main structure is located on the southern flank of the Anhua syncline area to the north of the Binxian anticline. Due to the influence of synsedimentary structure, there are Anhua syncline, Qijia anticline, and Shijiadian syncline in order from north to south. The coal-  The overall structure of the study area is simple. As shown in Figure 2, the main structure is located on the southern flank of the Anhua syncline area to the north of the Binxian anticline. Due to the influence of synsedimentary structure, there are Anhua syncline, Qijia anticline, and Shijiadian syncline in order from north to south. The coalbearing stratum in the study area is the Jurassic Middle Yan'an Formation, with a total of six coal-bearing seams, of which No. 4 coal is a relatively stable and main mineable coal seam in the minefield, distributed throughout the minefield. The stratigraphic occurrence and structural morphology show that the strata above Jurassic in this area have not been subjected to strong tectonic extrusion and deformation. The structure is closely related to the coal system, the deposition distribution of coal seams and their thickness changes. The coal seam is thicker at the syncline axis and thinner at the anticline axis. This pattern is mainly related to synsedimentary tectonics, and also reflects the inheritance of later tectonics. The overall structure of the study area is simple. As shown in Figure 2, the main structure is located on the southern flank of the Anhua syncline area to the north of the Binxian anticline. Due to the influence of synsedimentary structure, there are Anhua syncline, Qijia anticline, and Shijiadian syncline in order from north to south. The coalbearing stratum in the study area is the Jurassic Middle Yan'an Formation, with a total of six coal-bearing seams, of which No. 4 coal is a relatively stable and main mineable coal seam in the minefield, distributed throughout the minefield. The stratigraphic occurrence and structural morphology show that the strata above Jurassic in this area have not been subjected to strong tectonic extrusion and deformation. The structure is closely related to the coal system, the deposition distribution of coal seams and their thickness changes. The coal seam is thicker at the syncline axis and thinner at the anticline axis. This pattern is mainly related to synsedimentary tectonics, and also reflects the inheritance of later tectonics.  CBM proved resources/reserves of the study area are 35.89 × 10 8 m 3 , which are 25.5 × 10 8 m 3 in the No. 4 coal reservoir, and the average resource abundance is 1.44 × 10 8 m 3 /km 2 . CBM gas production capacity is 5.2 × 10 4 m 3 /d, the average value of a single well can reach 1625 m 3 /d. Consequently, the development potential of CBM is significant. The basic data used in this study, such as gas content and gas production, coal burial depth, thickness, lithology of overburden, etc., were collected from 32 CBM wells as shown in Table 2. Generally speaking, under the same conditions, the greater the thickness of the coal seam, the greater the amount of gas generated. The escape of gas is dominated by diffusion, and the concentration difference between two points in space is the main driving force for its diffusion [52]. The thickness of the No. 4 coal seam is 0.3 m~20.5 m in the study area, statistical analysis has indicated that the gas content is positively correlated with the thickness of the coal seam as shown in Figure 3a. The thicker the coal seam, the longer the gas diffusion path between the roof and floor, and the greater the diffusion resistance, which is more conducive to gas accumulation.

Burial Depth and Structure
Burial depth is positively correlated with the reservoir pressure, and the larger reservoir pressure is conducive to the adsorption of gas. The migration distance of CBM to the surface with burial depth increases correspondingly, which is beneficial to the preservation of CBM. Therefore, the gas content generally increases with the increase in

Burial Depth and Structure
Burial depth is positively correlated with the reservoir pressure, and the larger reservoir pressure is conducive to the adsorption of gas. The migration distance of CBM to the surface with burial depth increases correspondingly, which is beneficial to the preservation of CBM. Therefore, the gas content generally increases with the increase in the burial depth of the coal seam. The burial depth of the No. 4 coal seam is 270 m~780 m from northeast to southwest. According to the analysis of the relationship between the burial depth and gas content, the area with gas content greater than 2 m 3 /t is mainly distributed in 400 m~650 m as shown in Figure 3b, the gas content is low when the burial depth is less than 400 m. The main reason is that the shallow burial depth is in the groundwater recharge zone, and the overburden is thin, so the CBM is easy to escape. The groundwater stagnant zone with a buried depth exceeding 650 m is not conducive to the reproduction of methanogens, gas generation capacity itself is low. At present, the burial depth of coal seam with high gas content is mainly 450~650 m.
The structure of the study area is dominated by broad and gentle folds. Folds mainly affect the gas content by controlling the thickness of coal and the flow of groundwater, i.e., "syncline rich gas, anticline poor gas". There is a significant difference at different locations on the anticline and syncline. Above the neutral surface of the anticline axis, the coal seam and roof develop tensile fissures, and the gas is easy to escape. The groundwater flows from the axis of the anticline to the flanks, taking away part of the gas, which is not conducive to the accumulation of CBM. However, the coal rock above the neutral plane of the syncline is subjected to compressive stress, which is conducive to the preservation of gas with high gas content. It can be seen from Figure 4 that the content of the gas is more obviously controlled by structure style. The area with the highest gas content is the Shijiadian syncline axis area; the gas content of the Qijia anticline axis is relatively low.

Hydrogeological Conditions
Hydrogeological conditions are an important factor affecting the occurrence of CBM [53,54], a positive relationship was found between gas content and basin hydrodynamics. As illustrated in Figure 5, it was found that the ions in the water of the Jurassic aquifer (Yan'an Formation and Zhiluo Formation) are mainly Cland Na + , the hydrochemical type is Cl − -Na + , and the mineralization range is 13,781 mg/L~16,490 mg/L ( Figure 6), which represents the water-bearing conditions of deepwater circulation and poor runoff, also provided favorable conditions for CBM accumulation. The main anions of the Cretaceous aquifers (Yijun Formation and Luohe Formation) are SO4 2− and HCO3 − , the main cations are Na + and Mg 2+ , and the hydrochemica types are SO4 2− •Cl --Na + , SO4 2− •(HCO 3-)-Na + •Mg 2+ , the mineralization range are 859 mg/L~5790 mg/L. The hydrochemica type of the Xiaozhanggou Formation is HCO 3− -Na + •Mg 2+ •Ca 2+ , and the mineralization is 274 mg/L~461 mg/L. The ions in the loose layer of the Quaternary system are HCO 3− , Na + , Mg 2+

Hydrogeological Conditions
Hydrogeological conditions are an important factor affecting the occurrence of CBM [53,54], a positive relationship was found between gas content and basin hydrodynamics. As illustrated in Figure 5, it was found that the ions in the water of the Jurassic aquifer (Yan'an Formation and Zhiluo Formation) are mainly Cl − and Na + , the hydrochemical type is Cl − -Na + , and the mineralization range is 13,781 mg/L~16,490 mg/L ( Figure 6), which represents the water-bearing conditions of deepwater circulation and poor runoff, also provided favorable conditions for CBM accumulation. The main anions of the Cretaceous aquifers (Yijun Formation and Luohe Formation) are SO 4 2− and HCO 3 − , the main cations are Na + and Mg 2+ , and the hydrochemica types are SO 4 2− •Cl − -Na + , SO 4 2− •(HCO 3− )-Na + •Mg 2+ , the mineralization range are 859 mg/L~5790 mg/L. The hydrochemica type of the Xiaozhanggou Formation is HCO 3− -Na + •Mg 2+ •Ca 2+ , and the mineralization is 274 mg/L~461 mg/L. The ions in the loose layer of the Quaternary system are HCO 3− , Na + , Mg 2+ mainly, the hydrochemical type is HCO 3− -Na + •Mg 2+ •Ca 2+ , the water quality is good, and the mineralization is between 271 mg/L~317 mg/L ( Figure 6). Low-rank coal located in the area of weak groundwater runoff, and low mineralization is conducive to secondary biogenic gas generation and hydrodynamic pressure-bearing sealing is conducive to the preservation of CBM.

Lithology of Overburden Stratum
The lithology, thickness, development of joints and fissures of the roof above coal reservoirs are closely related to the accumulation of CBM. There are three mechanisms for the sealing effect of the roof on CBM, pressure and capillary can prevent gas migration, and hydrocarbon concentration mainly restrains gas diffusion [55]. The proper thickness and good sealing of the roof make the coal seam have the potential to preserve higher gas content. The tighter the roof lithology is, the more beneficial it is for the accumulation of CBM. So, the greater the proportion of mudstone thickness in the Yan'an formation on the roof, the higher the gas content (Figure 7a). It is particularly emphasized that the thickness of mudstone within 10 m of the roof plays a more key role in the migration of CBM. As

Lithology of Overburden Stratum
The lithology, thickness, development of joints and fissures of the roof above coal reservoirs are closely related to the accumulation of CBM. There are three mechanisms for the sealing effect of the roof on CBM, pressure and capillary can prevent gas migration, and hydrocarbon concentration mainly restrains gas diffusion [55]. The proper thickness and good sealing of the roof make the coal seam have the potential to preserve higher gas content. The tighter the roof lithology is, the more beneficial it is for the accumulation of CBM. So, the greater the proportion of mudstone thickness in the Yan'an formation on the roof, the higher the gas content (Figure 7a). It is particularly emphasized that the thickness of mudstone within 10 m of the roof plays a more key role in the migration of CBM. As

Lithology of Overburden Stratum
The lithology, thickness, development of joints and fissures of the roof above coal reservoirs are closely related to the accumulation of CBM. There are three mechanisms for the sealing effect of the roof on CBM, pressure and capillary can prevent gas migration, and hydrocarbon concentration mainly restrains gas diffusion [55]. The proper thickness and good sealing of the roof make the coal seam have the potential to preserve higher gas content. The tighter the roof lithology is, the more beneficial it is for the accumulation of CBM. So, the greater the proportion of mudstone thickness in the Yan'an formation on the roof, the higher the gas content (Figure 7a). It is particularly emphasized that the thickness of mudstone within 10 m of the roof plays a more key role in the migration of CBM. As shown in Figure 7b, although the correlation between mudstone thickness within 10 m of the roof and gas content is not very significant if the immediate roof of the coal seam is mudstone, which is conducive to the accumulation of CBM.

Gas-Bearing Properties of Coal Reservoir
Gas content is a basic indicator of CBM storage performance and sufficient condition in the evaluation of CBM development prospects. Areas with high gas content are often favorable areas for CBM development. The gas content is mainly concentrated in 2 m 3 /t~10 m 3 /t, the gas production fluctuates in a wide range during the stable production stage ( Figure 8).

Gas-Bearing Properties of Coal Reservoir
Gas content is a basic indicator of CBM storage performance and sufficient condition in the evaluation of CBM development prospects. Areas with high gas content are often favorable areas for CBM development. The gas content is mainly concentrated in 2 m 3 /t~10 m 3 /t, the gas production fluctuates in a wide range during the stable production stage ( Figure 8).

Gas-Bearing Properties of Coal Reservoir
Gas content is a basic indicator of CBM storage performance and sufficient condition in the evaluation of CBM development prospects. Areas with high gas content are often favorable areas for CBM development. The gas content is mainly concentrated in 2 m 3 /t~10 m 3 /t, the gas production fluctuates in a wide range during the stable production stage (Figure 8). The burial depth of coal seams directly affects coal seam permeability, in situ stress, and reservoir pressure. The burial depth of coal seams is between 400 m~650 m. It can be seen from Figure 9a that when the depth is greater than 550 m, the tendency of gas

Burial Depth and Thickness of Coal Seam
The burial depth of coal seams directly affects coal seam permeability, in situ stress, and reservoir pressure. The burial depth of coal seams is between 400 m~650 m. It can be seen from Figure 9a that when the depth is greater than 550 m, the tendency of gas production to decrease with the increase in burial depth becomes more obvious. The thickness reflects the abundance of resources to a certain extent. The greater the thickness, the higher the resource abundance, and the gas production also increases. There is a positive correlation between the gas production and the thickness of the coal seam, especially with horizontal wells as shown in Figure 9b. positive correlation between the gas production and the thickness of the coal seam, especially with horizontal wells as shown in Figure 9b.

Permeability and Reservoir Pressure
Permeability and reservoir pressure play an important role in the development of CBM and restrict the desorption and migration of CBM. According to field data, the permeability of the No. 4 coal reservoir is 2 mD~20 mD, the reservoir pressure is 2 MPa~8 MPa, and the gas production has no obvious correlation with permeability and reservoir pressure ( Figure 10).

Structure Conditions
It was found that the fractures in the fold flanks are moderately developed, and the permeability of coal reservoirs as well. In the process of gas production, although it receives recharge from the anticline, underground water flows to the syncline core to make it easier for depressurization and gas migration. Therefore, the gas content of the fold flank and the permeability of the coal reservoir reach a suitable match, and the stable gas production of the CBM well is generally better. The Anhua syncline, Qijia anticline and Shijiadian syncline are developed in the study area. As shown in Figure 11, the gas production is closely related to the structure position, but the difference between different well types is obvious. The vertical wells DFS-128 and DFS-C04 are located in the gentle slope between the fold flanks, which average gas production were 3256.75 m 3 /d and

Permeability and Reservoir Pressure
Permeability and reservoir pressure play an important role in the development of CBM and restrict the desorption and migration of CBM. According to field data, the permeability of the No. 4 coal reservoir is 2 mD~20 mD, the reservoir pressure is 2 MPa~8 MPa, and the gas production has no obvious correlation with permeability and reservoir pressure ( Figure 10). positive correlation between the gas production and the thickness of the coal seam, especially with horizontal wells as shown in Figure 9b.

Permeability and Reservoir Pressure
Permeability and reservoir pressure play an important role in the development of CBM and restrict the desorption and migration of CBM. According to field data, the permeability of the No. 4 coal reservoir is 2 mD~20 mD, the reservoir pressure is 2 MPa~8 MPa, and the gas production has no obvious correlation with permeability and reservoir pressure ( Figure 10).

Structure Conditions
It was found that the fractures in the fold flanks are moderately developed, and the permeability of coal reservoirs as well. In the process of gas production, although it receives recharge from the anticline, underground water flows to the syncline core to make it easier for depressurization and gas migration. Therefore, the gas content of the fold flank and the permeability of the coal reservoir reach a suitable match, and the stable gas production of the CBM well is generally better. The Anhua syncline, Qijia anticline and Shijiadian syncline are developed in the study area. As shown in Figure 11, the gas production is closely related to the structure position, but the difference between different well types is obvious. The vertical wells DFS-128 and DFS-C04 are located in the gentle slope between the fold flanks, which average gas production were 3256.75 m 3 /d and 3145.28 m 3 /d, respectively, in the stable production stage. However, the gas production of

Structure Conditions
It was found that the fractures in the fold flanks are moderately developed, and the permeability of coal reservoirs as well. In the process of gas production, although it receives recharge from the anticline, underground water flows to the syncline core to make it easier for depressurization and gas migration. Therefore, the gas content of the fold flank and the permeability of the coal reservoir reach a suitable match, and the stable gas production of the CBM well is generally better. The Anhua syncline, Qijia anticline and Shijiadian syncline are developed in the study area. As shown in Figure 11, the gas production is closely related to the structure position, but the difference between different well types is obvious. The vertical wells DFS-128 and DFS-C04 are located in the gentle slope between the fold flanks, which average gas production were 3256.75 m 3 /d and 3145.28 m 3 /d, respectively, in the stable production stage. However, the gas production of vertical wells was poor near the syncline axis. Horizontal wells DFS-C02, DFS-M124, and DFS-05 are located near the Shijiadian syncline axis. The average gas production in the stable production stage is about 11,270.97 m 3 /d, 3759.98 m 3 /d, and 10,600.96 m 3 /d. Therefore, it can be summarized that the high production area of horizontal wells is between the syncline core and the vertical wells are between the fold flanks. stable production stage is about 11,270.97 m 3 /d, 3759.98 m 3 /d, and 10,600.96 m 3 /d. Therefore, it can be summarized that the high production area of horizontal wells is between the syncline core and the vertical wells are between the fold flanks. Figure 11. The relationship between gas production and structure.

Coal Sample Characteristics
The maximum vitrinite reflectance (Ro,max) of the coals is 0.56~0.65%. The coal macerals are mainly inertinite (41.13~91.12%), followed by vitrinite (6.93~49.3%), and the content of liptinite is the lowest (<9.52%) as shown in Table 3. Statistical analysis of the data found that the vitrinite is positively correlated with the gas content, and the fitting result R 2 value is 0.73, while the inertinite is negatively correlated (Figure 12), which is also consistent with the results of previous studies [51].

Coal Sample Characteristics
The maximum vitrinite reflectance (R o,max ) of the coals is 0.56~0.65%. The coal macerals are mainly inertinite (41.13~91.12%), followed by vitrinite (6.93~49.3%), and the content of liptinite is the lowest (<9.52%) as shown in Table 3. Statistical analysis of the data found that the vitrinite is positively correlated with the gas content, and the fitting result R 2 value is 0.73, while the inertinite is negatively correlated (Figure 12), which is also consistent with the results of previous studies [51].

Geochemistry Characteristic of the Gas
The gas compositions (Table 4) show that the gas compositions include CH4, CO2, N2, a small amount of O2 and a trace of C2H6. The content of CH4 is 68.35~97.95%, and C2H6 is 0.001~0.028%. The geochemical characteristics of carbon isotope determined that the C1/(C2 + C3) are 6800~98,000. The dry and wet index C1/C1-5 of the hydrocarbon composition is 0.99991. The non-hydrocarbon compositions are mainly N2, the content is 1.256~29.75%, and the content of CO2 is 0.24~2.375%, with an average of 1.16%. The results of the isotope test showed that the δ 13 C(CH4) was −87.2~−68.9‰, with an average of −78.75‰, and the δ 13 C(CO2) was between −41.693‰ and −7.0650‰, with an average of −20.43‰.

Geochemistry Characteristic of the Gas
The gas compositions (Table 4) show that the gas compositions include CH 4 , CO 2 , N 2 , a small amount of O 2 and a trace of C 2 H 6 . The content of CH 4 is 68.35~97.95%, and C 2 H 6 is 0.001~0.028%. The geochemical characteristics of carbon isotope determined that the C 1 /(C 2 + C 3 ) are 6800~98,000. The dry and wet index C 1 /C 1-5 of the hydrocarbon composition is 0.99991. The non-hydrocarbon compositions are mainly N 2 , the content is 1.256~29.75%, and the content of CO 2 is 0.24~2.375%, with an average of 1.16%. The results of the isotope test showed that the δ 13 C(CH 4 ) was −87.2~−68.9‰, with an average of −78.75‰, and the δ 13 C(CO 2 ) was between −41.693‰ and −7.0650‰, with an average of −20.43‰. The δ 13 C 1 is less than −55‰, and the content of heavy hydrocarbon is less than 0.05%. By comparing δ 13 CH 4 with C 1 /(C 2 + C 3 ), and the methane-genesis identification chart [57], it can be determined that the gas is a biogenic gas (Figure 13). The N 2 is 1.256~29.75%, with an average of 16.17%. There is an obvious linear negative correlation between the content of N 2 and CH 4 (Figure 14), indicating that the coal seam was exposed to the surface or connected with surface water, N 2 in the atmosphere seeped into the coal seam with the water flow, resulting in the high N 2 content. The CO 2 content is 0.24~2.375% and the value of δ 13 C (CO 2 ) is between −36.693‰ and −7.0650‰, it belongs to CO 2 of organic origin. The δ 13 C1 is less than −55‰, and the content of heavy hydrocarbon is less than 0.05% By comparing δ 13 CH4 with C1/(C2 + C3), and the methane-genesis identification chart [57] it can be determined that the gas is a biogenic gas ( Figure 13). The N2 is 1.256~29.75%, with an average of 16.17%. There is an obvious linear negative correlation between the content of N2 and CH4 (Figure 14), indicating that the coal seam was exposed to the surface or connected with surface water, N2 in the atmosphere seeped into the coal seam with the water flow, resulting in the high N2 content. The CO2 content is 0.24~2.375% and the value of δ 13 C (CO2) is between −36.693‰ and −7.0650‰, it belongs to CO2 of organic origin.  The maximum vitrinite reflectance (Ro,max) has indicated that the coal of the study area was a low metamorphism degree. The coal seam was at the end of the primary biogenic gas and has not yet entered the thermal genetic stage of massive methane generation, which provided favorable material conditions for the generation of secondary biogenic gas. Based on the above comprehensive analysis, CBM was the typical secondary biogenic gas. The δ 13 C1 is less than −55‰, and the content of heavy hydrocarbon is less than 0.05% By comparing δ 13 CH4 with C1/(C2 + C3), and the methane-genesis identification chart [57] it can be determined that the gas is a biogenic gas (Figure 13). The N2 is 1.256~29.75%, with an average of 16.17%. There is an obvious linear negative correlation between the content of N2 and CH4 (Figure 14), indicating that the coal seam was exposed to the surface or connected with surface water, N2 in the atmosphere seeped into the coal seam with the water flow, resulting in the high N2 content. The CO2 content is 0.24~2.375% and the value of δ 13 C (CO2) is between −36.693‰ and −7.0650‰, it belongs to CO2 of organic origin.  The maximum vitrinite reflectance (Ro,max) has indicated that the coal of the study area was a low metamorphism degree. The coal seam was at the end of the primary biogenic gas and has not yet entered the thermal genetic stage of massive methane generation, which provided favorable material conditions for the generation of secondary biogenic gas. Based on the above comprehensive analysis, CBM was the typical secondary biogenic gas. The maximum vitrinite reflectance (R o,max ) has indicated that the coal of the study area was a low metamorphism degree. The coal seam was at the end of the primary biogenic gas and has not yet entered the thermal genetic stage of massive methane generation, which provided favorable material conditions for the generation of secondary biogenic gas. Based on the above comprehensive analysis, CBM was the typical secondary biogenic gas.

Geological Model of CBM Accumulation
In the geological evolution process of coal reservoirs, tectonic evolution plays a key role in gas generation through stratum subsidence and thermal evolution. Wang et al. [58] proposed the feature of the later tectonic of the Ordos coal-forming basin is the symbiosis of the western thrust, the southern uplift and the fault depression. Near south-north thrust nappe structures developed in the western margin of the basin, leading to exposure and large-scale denudation of the Jurassic coal-bearing rock series. The study area is a northeast inclined monoclinic structure, the coal seam belongs to the Jurassic coal seam with shallow burial depth and low metamorphism degree (R o,max < 0.65%). When the coal seam was raised to the shallow area, the stratum fissure developed and atmospheric precipitation and surface runoff directly recharged the coal reservoir, which provided suitable geological environmental conditions for the reproduction of bacteria. Under the action of the methane bacteria, the organic matter turned into methane under physical and chemical. It was found that the relatively enriched area of CBM was mainly concentrated in the weak runoff zone of the basin margin slope with a burial depth of 450 m~650 m. The weak runoff zone has weak groundwater activity, which is conducive to the preservation of CBM reservoirs. The deep stagnant zone (>650 m) is insufficient to recharge the coal seams and the water mineralization is high, which is not conducive to the reproduction of methane bacteria and gas generation. According to the analysis results of 4.1 and 4.2, CBM was the secondary biogenic gas of low-rank coal. Based on the above comprehensive analysis, the CBM accumulation model is the secondary biogenic gas accumulation on the gentle slope of the basin margin ( Figure 15). of the western thrust, the southern uplift and the fault depression. Near south-north thrust nappe structures developed in the western margin of the basin, leading to exposure and large-scale denudation of the Jurassic coal-bearing rock series. The study area is a northeast inclined monoclinic structure, the coal seam belongs to the Jurassic coal seam with shallow burial depth and low metamorphism degree (Ro,max < 0.65%). When the coal seam was raised to the shallow area, the stratum fissure developed and atmospheric precipitation and surface runoff directly recharged the coal reservoir, which provided suitable geological environmental conditions for the reproduction of bacteria. Under the action of the methane bacteria, the organic matter turned into methane under physical and chemical. It was found that the relatively enriched area of CBM was mainly concentrated in the weak runoff zone of the basin margin slope with a burial depth of 450 m~650 m. The weak runoff zone has weak groundwater activity, which is conducive to the preservation of CBM reservoirs. The deep stagnant zone (> 650 m) is insufficient to recharge the coal seams and the water mineralization is high, which is not conducive to the reproduction of methane bacteria and gas generation. According to the analysis results of 4.1 and 4.2, CBM was the secondary biogenic gas of low-rank coal. Based on the above comprehensive analysis, the CBM accumulation model is the secondary biogenic gas accumulation on the gentle slope of the basin margin ( Figure 15).

Geological Factors Evaluation of CBM Production
As mentioned before, the main controlling factors of CBM production capacity include gas content, burial depth, coal thickness, structural, hydrological conditions, permeability, and reservoir pressure. Daily gas production is a key indicator reflecting production capacity, the average daily gas production at the stable production stage is considered as the dependent variable and other related factors as independent variables. The main control factors of gas production capacity were analyzed by the gray correlation. The calculation process of correlation degree refers to the literature [44,59,60]. The lithology of the No. 4 coal seam roof is all sandy mudstone or carbonaceous mudstone, and the difference in lithology is small. Therefore, the factors that can affect the CBM production capacity (gas production) include coal thickness, permeability, gas content, reservoir pressure, ash, roof thickness and burial depth. According to the results of the correlation degree, it can be seen that the main control factors of the productivity between vertical wells and horizontal wells are quite different, as shown in Table 5. Table 5. Grey correlation quantitative evaluation of controlling factors of CBM production.

Vertical Well
Horizontal Well

Geological Factors Evaluation of CBM Production
As mentioned before, the main controlling factors of CBM production capacity include gas content, burial depth, coal thickness, structural, hydrological conditions, permeability, and reservoir pressure. Daily gas production is a key indicator reflecting production capacity, the average daily gas production at the stable production stage is considered as the dependent variable and other related factors as independent variables. The main control factors of gas production capacity were analyzed by the gray correlation. The calculation process of correlation degree refers to the literature [44,59,60]. The lithology of the No. 4 coal seam roof is all sandy mudstone or carbonaceous mudstone, and the difference in lithology is small. Therefore, the factors that can affect the CBM production capacity (gas production) include coal thickness, permeability, gas content, reservoir pressure, ash, roof thickness and burial depth. According to the results of the correlation degree, it can be seen that the main control factors of the productivity between vertical wells and horizontal wells are quite different, as shown in Table 5. The study area as a whole is a monoclinic structure dipping from northeast to southwest. Except for DFS114 and DFS-C01 located in the eastern part of the minefield, the rests were distributed in the central area of the minefield. In terms of gas production, there are 19 production wells above 1000 m 3 /d, in which horizontal wells DFS-C02 and DFS-05 have gas production rates of more than 10,000 m 3 /d. High production vertical wells (>3000 m 3 /d) include DFS-128 and DFS -C04.
Through the connected well profile of the high production well in the Dafosi minefield, DFS-128(V)-DFS-C04(V)-DFS-C02/-05(H)-DFS-M168(H) showed that the vertical wells DFS-128 and DFS-C04 were mainly distributed on the flanks of the anticline, while horizontal wells DFS-C02, DFS-05 and DFS-M168 were located near the core of the Shijiadian syncline, and the gas content of the high production wells are basically more than 4 m 3 /t ( Figure 16). The well positions of different well types have obvious differences, the high production area of vertical wells is located at the folding flank, and horizontal wells are located at the syncline axis. The roof mudstone and weak underground water sealing effect are conducive to forming the high gas content in the fold flank. Under the action of tensile stress, the fractures above the neutral of the fold are more developed and the permeability is good, which is conducive to rapid depressurization of the reservoir and gas production by drainage, e.g., the gas production of well DFS-128 during the stable production period is more than 3200 m 3 /d. The thickness (12 m~20 m) and burial depth (500 m~600 m) of the coal seam at the syncline axis of Shijiadian are large. The hydrodynamic environment is a weak runoff zone. Due to the long horizontal section of the horizontal well, the influencing range in the coal seam is relatively wide. Good drainage and depressurization effect, high gas production, e.g., the gas production of DFS-C02 well during steady production period is about 11,000 m 3 /d. Of course, apart from geological factors, drilling and production technologies, fracturing technologies and drainage systems all have a significant impact on gas production, but we will not discuss them here.  The study area as a whole is a monoclinic structure dipping from northeast to southwest. Except for DFS114 and DFS-C01 located in the eastern part of the minefield, the rests were distributed in the central area of the minefield. In terms of gas production, there are 19 production wells above 1000 m 3 /d, in which horizontal wells DFS-C02 and DFS-05 have gas production rates of more than 10,000 m 3 /d. High production vertical wells (>3000 m 3 /d) include DFS-128 and DFS -C04.
Through the connected well profile of the high production well in the Dafosi minefield, DFS-128(V)-DFS-C04(V)-DFS-C02/-05(H)-DFS-M168(H) showed that the vertical wells DFS-128 and DFS-C04 were mainly distributed on the flanks of the anticline, while horizontal wells DFS-C02, DFS-05 and DFS-M168 were located near the core of the Shijiadian syncline, and the gas content of the high production wells are basically more than 4 m 3 /t ( Figure 16). The well positions of different well types have obvious differences, the high production area of vertical wells is located at the folding flank, and horizontal wells are located at the syncline axis. The roof mudstone and weak underground water sealing effect are conducive to forming the high gas content in the fold flank. Under the action of tensile stress, the fractures above the neutral of the fold are more developed and the permeability is good, which is conducive to rapid depressurization of the reservoir and gas production by drainage, e.g., the gas production of well DFS-128 during the stable production period is more than 3200 m 3 /d. The thickness (12 m~20 m) and burial depth (500 m~600 m) of the coal seam at the syncline axis of Shijiadian are large. The hydrodynamic environment is a weak runoff zone. Due to the long horizontal section of the horizontal well, the influencing range in the coal seam is relatively wide. Good drainage and depressurization effect, high gas production, e.g., the gas production of DFS-C02 well during steady production period is about 11,000 m 3 /d. Of course, apart from geological factors, drilling and production technologies, fracturing technologies and drainage systems all have a significant impact on gas production, but we will not discuss them here. Figure 16. High-production model of CBM. Figure 16. High-production model of CBM.

The Favorable Areas for CBM High Production
It can be seen in Table 6, that the absolute value of the correlation coefficient between all factors was less than 0.4, and the correlation coefficient of the structure position was also close to 0.4. Therefore, the factors can be considered independent of each other. The gas production of CBM wells is quite different, the classification standard of high production and low production is the daily gas production in the stable production stage. If it is higher than 1500 m 3 /d, it is regarded as high production, less than 1500 m 3 /d is the low production. The attribute data of 12 high production wells and the same number of nonhigh production wells are randomly selected as the training sample set, and the remaining five high production wells and the rest of the non-high production well points form a test sample set. Based on MATLAB, the random forest model training sample set is used for learning, and the learned model is used in the test sample. The prediction rate of the model is 70%. Therefore, the model is considered reliable and can be used to evaluate the whole area in the next step. Subsequently, the attribute database of the study area was brought into the trained model, and the susceptibility index of high production CBM wells based on the random forest model was obtained, and the interval is [0, 0.948]. The natural discontinuity method was used to classify its susceptibility levels into three categories, which are the unfavorable area [0.03, 0.386], generally the favorable area [0.386, 0.51], and the extremely favorable area [0.51, 0.948], the predicted result of the generated favorable area of CBM is shown in Figure 17. It can be seen in Table 6, that the absolute value of the correlation coefficient between all factors was less than 0.4, and the correlation coefficient of the structure position was also close to 0.4. Therefore, the factors can be considered independent of each other. The gas production of CBM wells is quite different, the classification standard of high production and low production is the daily gas production in the stable production stage. If it is higher than 1500 m 3 /d, it is regarded as high production, less than 1500 m 3 /d is the low production. The attribute data of 12 high production wells and the same number of nonhigh production wells are randomly selected as the training sample set, and the remaining five high production wells and the rest of the non-high production well points form a test sample set. Based on MATLAB, the random forest model training sample set is used for learning, and the learned model is used in the test sample. The prediction rate of the model is 70%. Therefore, the model is considered reliable and can be used to evaluate the whole area in the next step. Subsequently, the attribute database of the study area was brought into the trained model, and the susceptibility index of high production CBM wells based on the random forest model was obtained, and the interval is [0, 0.948]. The natural discontinuity method was used to classify its susceptibility levels into three categories, which are the unfavorable area [0.03, 0.386], generally the favorable area [0.386, 0.51], and the extremely favorable area [0.51, 0.948], the predicted result of the generated favorable area of CBM is shown in Figure 17.

Conclusions
(1) The maximum reflectance of vitrinite (R o,max ) in coal are 0.56~0.65%. The result of gas compositions and carbon isotopes analysis shows that CBM is typical biogenic gas of low-rank coal.
(2) The gas content is closely related to buried depth and hydrodynamic environment, i.e., the high gas content areas are mainly located in the groundwater weak runoff zone at the burial depth of 450 m~650 m, especially in the syncline. The CBM accumulation model is the secondary biogenic on the gentle slope of the basin margin.
(3) The productivity of CBM wells is closely related to the structural location, but vertical wells gas production performance is different from horizontal wells. The high gas production area of vertical wells is distributed on the gentle slope with high gas content between anticline and syncline, the horizontal wells with good performance are located near the core of the syncline.
(4) According to the random forest model, the study area is divided into three areas, which are the unfavorable area, the generally favorable area, and the extremely favorable area. The predicted results will provide the scientific basis for the CBM production wells.
(5) The CBM development of low-rank coal in Western China is still in the early stage. The study area is relatively small, and the number of samples is few. It is suggested that future research should be based on more production data. In addition, mining technology is an indispensable aspect of the research on CBM development, and the evaluation of geological factors should be combined with mining technology.