# A Fluid-Solid Coupling Mathematical Model of Methane Driven by Water in Porous Coal.

1. Introduction

At present, a mathematical model has been established to describe water-gas or water-oil two-phase driving processes in conventional porous medium reservoirs [10-12]. Of course, coal rock masses are also porous media. The water-driven-methane process in a coal rock mass also belongs to water-gas two-phase flow in porous media. However, the effect of methane adsorption and desorption in coal is significantly different from that of the water-driven-gas process in coal rock masses and conventional porous media. During the processes of water drainage, decreasing pressure, and desorption of coalbed methane, there is a stage of water-gas two-phase flow. A coupled fluid-solid mathematical model that considers the effects of methane adsorption and desorption has already been established to describe this stage, but it still cannot be directly used to describe the water-driven-methane process in coal because of the following reasons. (1) The coupled fluid-solid model of coalbed methane drainage is used to describe the process of water-methane two-phase flow with a decrease in the water pressure and adsorbed coalbed methane becoming free coalbed methane. However, a coupled fluid-solid model of methane driven by water is required to describe the process of driving out methane in coal by the injected water, which is injected into the coal. The boundary conditions of the above two processes are different. In addition, the injected water will also cause an increase in methane pressure, resulting in the transformation of free methane to adsorbed methane. (2) For the coupled fluid-solid mathematical models of coalbed methane drainage, some equations are only listed but not solved, and for the other equations, only the numerical solutions are offered. However, the reliability of these mathematical models has not been verified. Furthermore, these models primarily study the evolution regularities of reservoir permeability and methane production but rarely address the distribution regularities of water-methane two-phase saturation and of the pore pressure and its gradient [13-15].

To clarify the distribution regularities of water-methane two-phase saturation and the pore pressure and the mechanism of the pore pressure gradient in the water-driven-methane process, pure porous coal rock without fractures is selected in this study, thereby excluding the effects of fractured structures. Based on the elastic theory of porous media, the principle of effective stress, the principle of methane adsorption and desorption, and the principle of conservation of mass and Darcy's law, a coupled fluid-solid mathematical model of methane driven by water is established. This model considers the effect of coalbed methane adsorption and desorption, the deformation field of the coal rock mass, and the seepage field of water and methane. The reliability of the mathematical model is verified by physical experiments of artificially suppressed briquette coal. On the basis of the mathematical model, a further study is developed on the distribution regularities of water-methane two-phase saturation and the pore pressure and the mechanism of the pore pressure gradient. Scientific understanding is provided for the water-driven-methane process in the porous coal.

2. Conceptual Model

Porous coal rock (Figure 1(a)) is characterized by a pore structure of air pores and mold pores and similar structures (Figure 1(b)), which can provide space for free methane and adsorbed methane (Figure 1(c)) [16-18]. In a porous coal rock, there are many interconnected pores, which can be regarded as the migration channels of fluid [19, 20].

Before methane is driven by water, there are primarily methane and a small amount of bound water (Figure 1(c)) in the pores of coal rock. The pressure is regarded as the initial pore pressure. During the water-driven-methane process, pressure water will flow along the pore channel [21-24]. This breaks the original mechanical equilibrium in the coal sample, and the stress is redistributed again. The methane pressure will rise at a distance from the water injection position. The water drives the methane in the pore to move forward in the pore channel until the methane is expelled from the coal rock mass. At the same time, the pore space of methane is also occupied by water . The pore space occupied by water forms the water zone, but a certain amount of methane remains in the water zone. The pore space occupied by methane forms the gas zone, and there is also a small amount of bound water in the gas zone. According to the above process, a conceptual model of methane driven by water in porous coal rock (Figure 2) is constructed in this study.

3. Mathematical Model

3.1. Basic Assumptions. The mathematical model is established based on the following six basic assumptions:

(1) The water-methane two-phase flow is an immiscible system, and the solubility of methane in water is not considered in the model.

(2) The temperature in the seepage field is a constant, and the water, methane, and rock strata are in a state of thermal equilibrium.

(3) Methane is an ideal gas. The flow of water and methane in porous coal is both characterized by laminar flow and obeys Darcy's law.

(4) Porous coal rock is homogeneous and isotropic. Its solid skeletons and pores are compressible, and the deformation of porous coal rock is elastic and small.

(5) The influences of capillary pressure and gravity are considered in the mathematical model.

(6) Only the water-driven-methane effect is considered, and the water-displaced-methane effect is ignored.

3.2. Basic Equations

3.2.1. The Equations of the Stress Field. The free coalbed methane and water in the coal can transfer fluid pressure. When methane is adsorbed on the surface of the coal, the surface tension of the coal decreases, resulting in the expansion of the volume. However, when the methane is desorbed from the coal surface, its volume shrinks. The above differences have prompted scholars to supplement the Terzaghi's effective pressure principle to adapt to the deformation of coal, which is rich in adsorbed coalbed methane. Based on the elastic theory of porous media, the constitutive equation of the coal body considering the effect of methane adsorption and desorption is as follows :

[mathematical expression not reproducible] (1)

in which

[mathematical expression not reproducible] (2)

where G is the shear modulus, E is the elastic modulus, v is Poisson's ratio, [[sigma].sub.kk] represents the components of the normal stress, p is the pore pressure, [alpha]([less than or equal to]1) is Biot's effective stress coefficient, K is the volume modulus of coal rock, [K.sub.s] is the volume modulus of a coal rock skeleton, [E.sub.s] is the elastic modulus of a coal rock skeleton, [[delta].sub.ij] is the Kronecker symbol (when i is equal to j, [[delta].sub.ij] is 1; when i is unequal to j, [[delta].sub.ij] is 0), [[epsilon].sub.s] is the adsorption strain of the methane, [[epsilon].sub.g] is the adsorption strain coefficient of the methane, [P.sub.L] is the Langmuir pressure constant, [V.sub.L] is the Langmuir volume constant, [S.sub.w] is the water saturation, [p.sub.w] is the pore pressure of water, [S.sub.g] is the methane saturation, and [p.sub.g] is the pore pressure of methane.

According to the theory of elastic mechanics, the relation between strain and displacement is

[[epsilon].sub.ij] = 1/2 ([u.sub.i,j] + [u.sub.j,i]). (3)

From the condition of static equilibrium, the following can be obtained:

[[sigma].sub.ij,j] + [f.sub.i] = 0 (4)

Substituting (1), (2), and (3) into (4), the modified Navier balance equation (5) with the displacement as the fundamentally unknown quantity and with the coupling term included can be obtained.

[Gu.sub.i,jj] + (G + [lambda])[u.sub.j,ji] - [[alpha].sub.p][p.sub.i] - K[[epsilon].sub.a,i] + [F.sub.i] = 0 (5)

where [u.sub.i] is the displacement along the i direction and [F.sub.i] is the volume force along the i direction (i = x, y, z).

3.2.2. Mass Conservation Equation. There are adsorbed methane and free methane in coal. The methane, which is initially adsorbed on the internal surface of matrix pores, becomes free-phase methane due to the reduction in pore pressure. On the contrary, with the increase in the pore pressure, the free-phase methane can become adsorbed methane.

The total methane can be calculated by

[m.sub.g] = [m.sub.y] + [m.sub.x], (6)

where [m.sub.y] is the free methane and [m.sub.y] is the adsorbed methane.

The free methane content [m.sub.y] can be calculated by the following:

[m.sub.y] = [[rho].sub.g][[phi].sub.nw], (7)

where [[rho].sub.g] is the density of methane and [[phi].sub.nw] is the porosity of coal rock.

By regarding the methane as an original gas, the relationship between its density and pressure can be expressed as follows:

[[rho].sub.g] = [beta][p.sub.g], (8)

where [p.sub.g] is the methane pressure (Pa), [beta] = [M.sub.g]/RT is the compression coefficient (kg/([m.sup.3] x Pa)), [M.sub.g] is the molecular weight of methane (kg/mol), R is the ideal gas constant (3.814kJ/(mol x K)), and T is the absolute temperature (K).

According to (8) and (9), the density of methane can be calculated by

[[rho].sub.g] = [p.sub.g]/[p.sub.0] [[rho].sub.0], (9)

where [p.sub.0] is the pressure under standard conditions (101325 Pa) and [[rho].sub.0] is the density of methane under standard conditions (0.717 kg/[m.sup.3]).

The adsorbed methane content [m.sub.x] satisfies the Langmuir formula, whose corresponding equation is

[m.sub.x] = ab[beta][p.sub.0][[rho].sub.c]/1 + [bp.sub.g] [p.sub.g], (10)

where a is the ultimate adsorption capacity of the methane ([m.sup.3]/kg), b is the adsorption equilibrium constant of the methane ([Pa.sup.-1]), and [[rho].sub.c] is the density of coal (kg/[m.sup.3]).

According to the principle of mass conservation, the mass continuity equation of a fluid is expressed as follows:

[partial derivative][m.sub.i]/[partial derivative]t + [nabla] x ([[rho].sub.i] x [u.sub.i]) = 0, (11)

[u.sub.i] = -[[lambda].sub.i]([nabla][[rho].sub.i] + [[rho].sub.i]g[nabla]D), (12)

where i represents w or g, where w is a water phase and g is a methane phase; [m.sub.i] is the mass of an i-phase fluid (kg/[m.sup.3]); [[rho].sub.i] is the mass of an i-phase fluid (kg/[m.sup.3]); [u.sub.i] is the average velocity of an i-phase fluid (m/s); K is the absolute permeability of the coal ([m.sup.2]); [[lambda].sub.i] - K [k.sub.r,i]/[[mu].sub.i] is the conductivity of an i-phase fluid; [k.sub.r,i] is the relative permeability of an i-phase fluid; [[mu].sub.i] is the dynamic viscosity of an i-phase fluid (Pa x s); and D is the height of the coordinate system (m).

By regarding the methane as a compressible fluid and the water as an incompressible fluid, with the union of (1), (2), (3), (4), (5), (6), (7), (8), (9), (10), (11), and (12), the mass continuity equation of the methane and water can be separately expressed as follows:

[mathematical expression not reproducible] (13)

For a further simplification, (13) can be separately expressed as follows:

[mathematical expression not reproducible] (14)

3.2.3. Level Set Transport Equation. The level set method, firstly proposed by Osher and Sethian, is a numerical method for solving the two-phase flowing equations including the surface tension phase. It can be utilized to simulate the water-driven-gas process. To understand the dynamic change characteristics of water and gas two-phase flow, the method has the advantages of convenience, visualization, and the like. The level set equation is written as follows :

[mathematical expression not reproducible] (15)

where [phi] is a contour line of the water-gas two-phase interface, [gamma] is the reinitialization parameter in the solution of the equation, u is the velocity of the fluid, [epsilon] is the thickness of the water-gas interface, and t is the time of water and gas flow.

To avoid the instability of the numerical calculation, the density and viscous property parameters of the fluid in the vicinity of the interface need to be smoothed. The smoothing method of the level set equation describes the changes in the density and dynamic viscosity in the process of water-gas two-phase flow with the level set function, and the corresponding equations are

[rho]([phi]) = [[rho].sub.g] + ([[rho].sub.w] - [[rho].sub.g]) [phi],

[mu]([phi]) = [[mu].sub.g] + ([[mu].sub.w] - [[mu].sub.g]) [phi], (16)

where [rho].sub.w] and [rho].sub.g] are the densities of water and gas (kg/[m.sup.3]), respectively, and [mu].sub.g] and [mu].sub.g] are the dynamic viscosities of water and methane (Pa x s), respectively.

3.2.4. Dynamic Model of Porosity and Permeability. Methane migration is determined by the porosity and permeability of coal rock, which are a bridge between the stress field and seepage field. Both of these key parameters are closely related to the stress and inherent material properties of coal rock.

Porous coal rock is porous media. Its porosity is influenced by the pore pressure and matrix expansion/contraction caused by methane adsorption/desorption. Considering the combined effect of the pore pressure and matrix expansion/ contraction, the dynamic model of porosity can be written as follows [26, 27]:

[phi] = 1/1 + S [[[phi].sub.0](1 + [S.sub.0]) + [alpha](S - [S.sub.0])], (17)

in which

S = [[epsilon].sub.v] + p/[K.sub.s] - [[epsilon].sub.a],

S = [[epsilon].sub.v0] + [p.sub.0]/[K.sub.s] - [[epsilon].sub.a0],

[[epsilon].sub.v] = [[epsilon].sub.x] + [[epsilon].sub.y] + [[epsilon].sub.z], (18)

where [phi] is the initial porosity of coal rock; [[epsilon].sub.v] is the volume strain of coal rock; [[epsilon].sub.x], [[epsilon].sub.y], and [[epsilon].sub.z] are the volume strain in the x, y, and z directions, respectively; [K.sub.s] is the volume modulus of the coal skeleton; and the index 0 is the initial value of the corresponding parameter.

The absolute permeability of porous media is also influenced by the in situ stress. The dynamic model of absolute permeability can be expressed as follows [28, 29]:

K = [K.sub.0]/1 + [[epsilon].sub.v] [[1 + [[epsilon].sub.v] - [DELTA]p(1 - [[phi].sub.0])/[K.sub.s]/[[phi].sub.0]].sup.3], (19)

where [K.sub.0] is the initial permeability of the porous media.

Capillary pressure curves are used by the Brooks and Corey-Burdine model to calculate the relative permeability of a fluid in porous media. Based on the Brooks and Corey-Burdine model, the relative permeabilities of water and methane in porous coal rock are a function of the water saturation. The corresponding expressions are as follows :

[mathematical expression not reproducible] (20)

where [k.sub.r,w0] is the relative permeability of the water phase endpoints, [k.sub.r,g0] is the relative permeability of the gas phase endpoint, [S.sub.r,w] is the residual saturation of the water phase, [S.sub.r,g] is the residual saturation of the gas phase, and [lambda] is a parameter that represents the pore structure characteristics of porous media.

When the parameter [lambda] of the Brooks and Corey-Burdine model is 1, the calculated relative permeability curves of water and methane are consistent with the results of the unsteady method experiment, as shown in Figure 3 .

3.2.5. Capillary Equation. When the two immiscible fluids of water and gas flow into the pore channel, a meniscus-shaped interface between the water and methane is formed. The pressure on both sides of the interface is discontinuous. The difference in the pressure is called the capillary force, and the corresponding expression is

[p.sub.cgw] = [p.sub.g] - [p.sub.w], (21)

where [p.sub.cgw] is the capillary force, [p.sub.g] is the methane pressure, and [p.sub.w] is the water pressure.

3.2.6. Saturation Equation. In saturated porous media, the effective pores are all filled with water and gas. This process is described by the saturation equation:

[S.sub.g] + [S.sub.w] = 1. (22)

3.3. Geometric Model and Boundary Conditions. After water enters the coal rock from the borehole, it will drive the methane forward along the pore channels in the coal rock. The boundary and initial conditions corresponding to the physical model are as follows:

[mathematical expression not reproducible] (23)

4. Experimental Verification of the Model

4.1. Experiment of Methane Driven by Water in Porous Coal Rock

4.1.1. Experimental System. Based on the principle of methane displaced by water, a pseudo three-axial experimental system of water-methane displacement (Figure 4) is developed. This experimental system can simulate the process of displacing methane by water under the conditions of axial and confining pressures on a cylindrical coal sample with a diameter of 50 mm and a height of 100 mm. The experimental system comprises an axial and confining pressure loading system, a water injection system, a gas injection system, and displaced gas collection and measurement devices. The principle and real objective of the water-methane displacement device are shown in the blue rectangular dashed frame in Figure 4. The axial pressure is loaded by the hydraulic jack at the bottom of the water-methane displacement device, and the confining pressure is applied by injecting hydraulic oil into the annular space. The water pressure loading is controlled by a four-channel, electrohydraulic servo control system based on the MOOG valve. The pressure of the gas circuit system is adjusted using the pressure release valve at the outlet of the methane cylinders. The collection and volumetric measurement of the displaced methane are completed with the help of a geological exploration methane desorption instrument.

4.1.2. Preparation of the Briquette Coal. Briquette coal is formed from coal powder under the pressure provided by a rigid pressure testing machine, and the internal structure of the briquette coal is porous. To avoid the influence of discrete factors such as joints and fissures, the briquette coal can be an ideal porous coal. The preparation processes used for the briquette coal in this paper (Figure 5) are as follows. First, sieve out the coal powder with diameters of 0.3~0.45mm with a sifter (Figure 5(a)). Mix the coal powder and water to achieve a mass ratio of 10:1, and then put the coal-water mixture into the mold (Figure 5(b)). Exert a pressure of 100 MPa (Figure 5(b)) on the coal-water mixture with a rigid pressure testing machine. After ejection (Figure 5(c)), a briquette coal sample with a diameter of 50 mm and a height of 100 mm is produced (Figure 5(d)).

4.1.3. Experimental Process. The processes of the water-displaced-methane experiment are as follows. (1) Load the axial and confining pressures. An axial pressure of 2 MPa and a confining pressure of 1 MPa are simultaneously applied at loading rates of 0.2 MPa/s and 0.1 MPa/s, respectively. Then, maintain the axial pressure of 2 MPa and the confining pressure of 1 MPa for 5 minutes. (2) Vent the air. Open the intake and outlet valves and collect the gas at the outlet. When the methane concentration of the collected gas is close to 100%, it is believed that the air in the experimental system has been vented out. Then, close the outlet valve. (3) Achieve methane adsorption and desorption equilibrium. Open the cylinder and inlet valves and control the output pressure of the cylinder by adjusting the pressure-reducing valve. The coal sample finally arrives at a state of adsorption and desorption equilibrium, and the corresponding methane pressure is 0.5 MPa. (4) Drive the methane by water injection. Close the gas inlet valve, and open the gas outlet and water inlet valves. Maintain a water pressure of 0.7 MPa, and inject water into the coal sample. Collect the methane displaced by water until no further methane is released.

4.2. Calculation of the Mathematical Model

4.2.1. Geometrical Model. A cylindrical model with a diameter of 50 mm and a height of 100 mm (Figure 6(a)) is adopted in this numerical simulation. To facilitate the monitoring and analysis of the related parameters of the postprocessing model, the water-displaced-methane direction is flagged as the positive direction of the z-axis, along which nine monitoring points are separately distributed at the locations of 10 mm, 20 mm, 30 mm, 40 mm, 50 mm, 60 mm, 70 mm, 80 mm, and 90 mm from the top of the cylinder. At the same time, the axis of the cylinder is selected as the monitoring line. Water enters the coal sample from its top and drives the methane in the coal forward. The side of the cylinder is an impermeable boundary, the upper surface is the water inlet, and the lower surface is the methane outlet. In the water-displaced-methane process, the loading conditions of the axial and confining pressures are shown in Figure 6(b).

4.2.2. Determining the Parameters of the Numerical Simulation. The process of solving the equations using the COMSOL Multiphysics software is actually a recurrence of a physical process. The recurrence of a physical process needs to be built on the basis of a series of reasonable parameters.

Only in this way can the solution of the equations converge and the recurrence of the physical process succeed. To ensure that the numerical simulation is similar to the real physical experiment, the real physical parameters of the experimental briquette coal sample are used in the numerical calculation to the farthest extent possible. The relevant parameters used in this numerical simulation are shown in Table 1.

4.3. Comparisons of the Experiment and Numerical Calculation Results. The methane driven by water is mainly free methane in the coal. The free methane includes the original free methane (black line in Figure 7) and the desorbed methane from the adsorbed methane (magenta line in Figure 7). When pressure water enters the pores of the coal, the free methane in the pores will be driven forward along the seepage direction of the pressure water. As more water enters the pores, additional methane is driven by the water. It can be seen from Figure 7 that, during the initial 20 min, the collected methane volume of the water-displaced-methane experiment is significantly higher than the value calculated by the mathematical model; however, from 20 min to 60 min, the collected methane volumes of the experiment and numerical calculation gradually converge. In an hour, the collected methane volume of the water-displaced-methane experiment is 1.4 percent higher than that of the numerical calculation. This is because after water enters the coal, both the free methane in the pores and the free methane from the adsorbed methane displaced by water are driven out at the same time. Although only a small volume of the methane is displaced by water, its existence is confirmed by the experiment [1, 32-35]. Currently, the methane displaced by water cannot be quantitatively calculated by the mathematical formula. In this paper, the mathematical model also lacks a quantitative expression of the methane volume. This is the reason for the subtle difference between the experimental and calculation results. Overall, the results indicate that the mathematical model of the methane driven by water is basically reliable and can be used to predict the methane volume in the water-driven-methane process.

5. The Regularities of Methane Driven by Water

5.1. Space-Time Distribution Regularities of the Water-Methane Two-Phase Saturation

5.1.1. Visualization of the Space-Time Distribution of the Water-Methane Two-Phase Saturation along the Driving Direction. In the water-driven-methane process, the dynamic processes of the spatial distributions of water and methane saturations can be shown clearly by a saturation cloud image. The spatial distributions of the water and methane saturations at the four moments of 1 min, 5 min, 10 min, and 30 min are shown in Figure 8. The following can be seen from Figure 8. (1) When water enters the pores, the methane cannot be expelled completely, and there is residual methane in the pores of the coal rock. The residual methane saturation is set as 0.2 in the numerical simulation, so the maximum water saturation is 0.8. When the water saturation of the coal sample reaches 0.8, it is believed that the pores in this area have been saturated with water. (2) There is bound water in the coal sample. With the existence of bound water, the pores in the coal rock cannot be completely filled with methane. Therefore, the saturation of bound water in the coal sample is set as 0.05, and the maximum methane saturation is 0.95.

The results shown in Figure 8 are in agreement with the preset parameters of the mathematical model, which indicates indirectly the feasibility and reliability of the mathematical model. With the help of the COMSOL Multiphysics software, the visualization of the water-driven-methane behaviours can be realized. This contributes to the semiqualitative and semiquantitative research on the visualization of the space-time distribution of water-methane two-phase saturation.

5.1.2. Space-Time Distribution of the Water-Methane Two-Phase Saturation on the Axial Monitoring Line along the Driving Direction. When the pressure water is injected into the coal sample, more and more space is occupied by water. Meanwhile, the methane at that point is driven forward by water, resulting in a decrease in the space occupied by methane. Because the sum of the water and methane saturation at any space point is 1, the change regularities of the water and methane saturations at any point in space are opposite to one another. In other words, the water saturation is greater and the methane saturation is smaller, which is closer to the water inlet end. It can be seen from Figure 9. (1) In the same position, the water saturation increases with an increase in time (e.g., the water saturation at the 20 mm position increases from 0.05 to 0.65 within 30 minutes), but the methane saturation decreases over time (e.g., the methane saturation at the 20 mm position decreases from 0.95 to 0.35 within 30 minutes). Meanwhile, the increase rate of the water saturation decreases gradually, and the decrease rate of the methane saturation decreases gradually as well. The increase rate of the spatial distribution of the water saturation in 1~5 min is larger than that in 10~30 min. (2) At the same time, the water saturation along the driving direction is continuously decreasing within the change interval from 0.05 to 0.8, and the methane saturation shows a continuous increase within the change interval from 0.2 to 0.95. (3) Over time, the curve of the water saturation changes from a lower concave curve to a straight line, and the curve of the methane saturation changes from an upper convex curve to a straight line. It is shown that with the continuous water-driven-methane process, the water saturation along the driving direction shows a linear increase and the methane saturation shows a linear decrease.

5.1.3. Space-Time Distribution of the Water-Methane Two-Phase Saturation at the Axial Monitoring Points along the Driving Direction. It can be seen from Figure 10 and Table 2 that the space-time distribution regularities of the water saturation are as follows. (1) For the same point in space, the water saturation first presents a nearly linear increase to a certain value and then remains stable. This is because, over time, water continues to flow into the coal sample, resulting in a continuous increase in the water saturation. However, the pore space at this point is limited. When the pore space is completely occupied by water, the water saturation at that point gradually becomes saturated and reaches a stable value. (2) The increased values of the water saturation at 10 m at 0~5 min, 5~10 min, and 10~15 min are, respectively, 0.653, 0.02, and 0.002, which indicates that the increase in the rate of water saturation gradually reduces over time. The changes in the water saturation at the 50 m and 90 m positions follow the same regularities as that at the 10 m position.

It can be seen from Figure 10 that the space-time regularities of the methane saturation are as follows. (1) For the same point in space, the methane saturation first presents a nearly linear decrease to a certain value and then remains stable. This is because, over time, pressure water enters the coal sample, drives the methane out from the coal sample, and occupies the pore space of the methane. However, the total pore space of the coal has a certain value. With an increase in the water entering the coal sample, the pore space occupied by water gradually increases and the pore space occupied by methane gradually decreases. When the pore space occupied by water in the coal sample tends to be stable, the pore space occupied by the methane will eventually stabilize. (2) The decreasing values of the methane saturation at the 10 m position at 0~5 min, 5~10 min, and 10~15 min are 0.653, 0.02, and 0.002, respectively. This indicates that, over time, the decreasing rate of methane saturation gradually reduces. The changes in the methane saturation at the 50 m and 90 m positions follow the same regularities as that at the 10 m position. (3) At the same time, the methane saturation is lower, which is closer to the water inlet. This is because the water injection volume at a specific time is certain. The closer to the water inlet, the greater the pore space occupied by water and the lower the pore space occupied by methane.

5.2. Space-Time Distribution Regularities of the Pore Pressure

5.2.1. Space-Time Distribution of the Pore Pressure along the Driving Direction. The following can be seen from Figure 11. (1) The initial pore pressure in the coal sample is 0.5 MPa. However, in the water-driven-methane process, the pore pressure in the coal sample is no longer 0.5 MPa. This indicates that, in the water-driven-methane process, the pore pressure in the coal sample is redistributed. Compared with the initial pore pressure of 0.5 MPa, the maximum pore pressure after redistribution is 0.7 MPa and the minimum pore pressure after redistribution is 0.1 MPa. This shows that there is only a range of increasing zones of pore pressure caused by the transmission of water pressure. (2) Using the initial pore pressure of 0.5 MPa as the dividing line, the coal sample can be divided into an increasing zone and a decreasing zone of pore pressure, as shown by the dotted lines with arrows in Figure 11. Over time, the increasing zone of pore pressure gradually decreases, but the decreasing zone of pore pressure gradually increases. (3) As the water-driven-methane process continues, the pore pressure along the driving direction gradually decreases. This is because the water pressure at the inlet is 0.7 MPa and the atmospheric pressure at the outlet is 0.1 MPa. The pore pressure in the coal is continuous from 0.7 MPa to 0.1 MPa, as shown in the cloud image of the pore pressure in Figure 11. (4) For the same point in space, the methane pressure in the coal sample gradually decreases over time. This is because the free methane in the coal sample is driven by water, resulting in a decrease in the free methane content and the methane pressure in the coal sample.

By combining the space-time distribution regularities of the pore pressure with the space-time distribution regularities of the water-methane two-phase saturation, it is concluded that the methane saturation in the decreasing zone of pore pressure is greater than that in the increasing zone of pore pressure. That is, the free methane content in the decreasing zone of pore pressure is greater than that in the increasing zone of pore pressure. This is because, in the increasing zone of pore pressure, some free methane is driven to the decreasing zone of pore pressure and some free methane is converted into adsorption methane. The free methane in the decreasing zone of pore pressure includes the free methane driven by water from the increasing zone of pore pressure, the original free methane in the region, and the free methane desorbed from the adsorbed methane.

5.2.2. Space-Time Distribution of the Pore Pressure on the Axial Line along the Driving Direction. The following can be seen from Figure 12 and Table 3. (1) The initial pore pressure in the coal sample is 0.5 MPa, and thus the initial pore pressure at each space point in the coal sample is 0.5 MPa. When the pressure water enters the coal sample, the free methane in the pores is driven forward and the pore pressure along the driving direction is redistributed. Therefore, the pore pressures at 10 mm, 20 mm, 30 mm, 40 mm, and 50 mm are all greater than the initial pore pressure, indicating that these points in space are located in the increasing zone of pore pressure. However, the pore pressures at 60 mm, 70 mm, 80 mm, and 90 mm are less than the initial pore pressure, indicating that these points in space are located in the decreasing zone of pore pressure. That is, the increasing zone of pore pressure is distributed closer to the water inlet end, and the decreasing zone of pore pressure is distributed closer to the methane outlet end. This is because the water inlet end is closer to a high-pressure source of 0.7 MPa, and the methane outlet end is closer to a low-pressure source of 0.1 MPa. (2) Over time, the pore pressure in the increasing zone first increases and then decreases, but the pore pressure in the decreasing zone decreases continuously. (3) At the beginning of the water-driven-methane process, the change (increase or decrease) rate of the pore pressure decreases from both ends to the middle of the coal sample. This is because the two ends of the coal sample are close to a high- or low-pressure source, which creates a pressure difference from the initial pore pressure. At the beginning of the water-driven-methane process, to realize the continuous distribution of the pore pressure in the coal sample, it is necessary to overcome this pressure difference in order to realize the connection and transition of the pore pressure in the coal sample.

6. Conclusions

(1) Based on the conceptual model of methane driven by water in porous coal rock, with the effect of methane adsorption and desorption considered, a fluid-solid coupling mathematical model of methane driven by water is established in this paper. The accuracy and reliability of the mathematical model have been verified by the results of the water-driven-methane experiment in a briquette coal sample.

(2) With the help of the COMSOL Multiphysics software, visualization of the space-time distribution of water-methane two-phase saturation can be realized. The curve of the water saturation over time changes from a lower concave curve to a straight line, while the curve of the methane saturation with time changes from an upper convex curve to a straight line. Meanwhile, both of the increase rate of the water saturation and the decrease rate of the methane saturation gradually reduce over time.

(3) In the water-driven-methane process, the pore pressure of the coal sample is redistributed. The maximum pore pressure is the water pressure at the side of the water inlet, and the minimum pore pressure is the atmospheric pressure at the side of the methane outlet. The pore pressure decreases along the driving direction. Using the initial pore pressure as the dividing line, the coal sample can be divided into an increasing zone and a decreasing zone of pore pressure. The increasing zone of pore pressure is close to the side of the water inlet, and the decreasing zone of pore pressure is close to the methane outlet. The increasing zone of pore pressure gradually decreases, and the decreasing zone of pore pressure gradually increases. Over time, the pore pressure in the increasing zone of pore pressure first increases and then decreases, and the pore pressure in the decreasing zone of pore pressure continuously decreases. The change (increase or decrease) rate of the pore pressure in the coal sample gradually decreases from both ends towards the middle of the coal sample.

(4) The pore pressure gradient decreases first and then increases along the driving direction. The decreasing zone of the pore pressure gradient is located in the increasing zone of pore pressure, and the increasing zone of the pore pressure gradient is located in the decreasing zone of pore pressure. In the water-driven-methane process, the distribution of the pore pressure gradient is influenced by the difference between the initial pore pressure and the atmospheric pressure at the side of the methane outlet and the difference between the water pressure at the side of the water inlet and the initial pore pressure. When the pressure difference between the first two is greater than that between the latter two, the pore pressure gradient at the side of the methane outlet is greater than that at the side of the water inlet. Over time, the pore pressure gradient at the side of the water inlet increases, and its rate of increase decreases. The pore pressure gradient at the side of the methane outlet decreases, and its rate of decrease also decreases. The rate of increase in the pore pressure gradient at the side of the water inlet is greater than the rate of decrease in the pore pressure gradient at the side of the methane outlet.

Data Availability

The data used to support the findings of this study are available from the corresponding author upon request.

https://doi.org/10.1155/2018/7049830

Conflicts of Interest

The authors declare that they have no conflicts of interest.

Acknowledgments

The financial support for this work, provided by the National Key Research and Development Program of China (no. 2017YFC0603001), the National Science Fund for Excellent Young Scholars (no. 51522406), and the Fundamental Research Funds for the Central Universities (China University of Mining and Technology) (no. 2015XKZD04), is gratefully acknowledged.

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Bingxiang Huang and Weiyong Lu (iD)

State Key Laboratory of Coal Resources and Safe Mining, China University of Mining and Technology, Xuzhou, Jiangsu 221116, China

Correspondence should be addressed to Weiyong Lu; 489698551@qq.com

Received 30 April 2018; Revised 14 July 2018; Accepted 25 July 2018; Published 16 September 2018

Caption: Figure 1: Methane distribution in porous coal.

Caption: Figure 2: Conceptual model of methane driven by water in porous coal rock.

Caption: Figure 3: The permeability of water and methane in porous coal rock.

Caption: Figure 4: Experimental system of methane displacement by water.

Caption: Figure 5: Preparation process of the briquette coal samples.

Caption: Figure 6: Schematic diagram of the geometric model (a) and imposed constraints (b).

Caption: Figure 7: Change in the methane volume over time.

Caption: Figure 8: Space-time distribution of the water-methane two-phase saturation.

Caption: Figure 9: Space-time distribution curve of the water-methane two-phase saturation along the driving direction.

Caption: Figure 10: Space-time distribution curve of the water-methane two-phase saturation at the axial monitoring points along the driving direction.

Caption: Figure 11: Space-time curve and cloud image of the pore pressure on the axial monitoring line along the driving direction.

Caption: Figure 12: Space-time distribution curves of the pore pressure at the axial monitoring points along the driving direction.

Caption: Figure 13: Space-time distribution of the pore pressure gradient along the driving direction.
```Table 1: Parameters of the numerical simulation.

Symbol                    Physical significance               Value

E                    Elastic modulus of the coal rock          2713
[E.sub.s]          Elastic modulus of the coal skeleton        8469
v                    Poisson's ratio of the coal rock          0.32
[[phi].sub.0]                Initial porosity                  0.09
[[mu]sub.nw]         Dynamic viscosity of the methane       1.84e - 5
[[mu].sub.w]          Dynamic viscosity of the water        1.01e - 3
[[rho].sub.s]          Density of the coal skeleton            1470
[[rho].sub.w]                Density of water                  1000
[K.sub.0]         Absolute permeability of the coal rock     2e - 17
a                 Langmuir ultimate adsorption capacity       0.036
of the methane
constant of the methane
[S.sub.r,w]               Bound water saturation               0.2
[S.sub.r,g]            Residual methane saturation             0.1
[k.sub.r,w0]          Relative permeability of the             0.83
water endpoint
[k.sub.r,g0]          Relative permeability of the              1
methane endpoint
[p.sub.g0]                   Outlet pressure                   0.1
[p.sub.0]                 Initial pore pressure                0.5

Symbol               Unit

E                     MPa
[E.sub.s]             MPa
v                      1
[[phi].sub.0]          1
[[mu]sub.nw]        Pa x s
[[mu].sub.w]        Pa x s
[[rho].sub.s]    kg/[m.sup.3]
[[rho].sub.w]    kg/[m.sup.3]
[K.sub.0]          [m.sup.2]
a                [m.sup.3]/kg
b                     MPa
[S.sub.r,w]            1
[S.sub.r,g]            1
[k.sub.r,w0]           1
[k.sub.r,g0]           1
[p.sub.g0]            MPa
[p.sub.0]             MPa

Table 2: Space-time distribution of the water-methane two-phase
saturation at the axial monitoring points.

Monitoring point (mm)

10                 50
Time        Saturation         Saturation
(min)    Water   Methane    Water   Methane

0        0.05      0.95     0.05      0.95
5        0.703    0.297     0.350    0.650
10       0.723    0.277     0.419    0.581
15       0.725    0.275     0.424    0.576

Monitoring
point (mm)

90
Time       Saturation
(min)    Water   Methane

0        0.05      0.95
5        0.101    0.899
10       0.123    0.877
15       0.125    0.875

Table 3: Space-time distribution of the pore pressure at
the axial monitoring points.

Monitoring point (mm)

Time        10          20          30          40          50
(min)      Pore        Pore        Pore        Pore        Pore
pressure    pressure    pressure    pressure    pressure
(MPa)       (MPa)       (MPa)       (MPa)       (MPa)

0          0.500       0.500       0.500       0.500       0.500
5          0.648       0.604       0.569       0.542       0.519
10         0.656       0.617       0.582       0.548       0.517
15         0.656       0.616       0.578       0.543       0.509
20         0.654       0.613       0.575       0.539       0.504

Monitoring point (mm)

Time        60          70          80          90
(min)      Pore        Pore        Pore        Pore
pressure    pressure    pressure    pressure
(MPa)       (MPa)       (MPa)       (MPa)

0          0.500       0.500       0.500       0.500
5          0.493       0.462       0.413       0.325
10         0.483       0.441       0.383       0.294
15         0.474       0.430       0.371       0.284
20         0.468       0.424       0.365       0.278

Table 4: Space-time distribution of the pore pressure gradient
at the axial monitoring points.

Monitoring point (mm)

Time          0            10            20            30
(min)       Pore          Pore          Pore          Pore
pressure      pressure      pressure      pressure
(MPa/m)       (MPa/m)       (MPa/m)       (MPa/m)

10          4.623         4.119         3.720         3.422
20          4.806         4.325         3.966         3.704
30          4.947         4.460         4.091         3.817

Monitoring point (mm)

Time         40            50            60            70
(min)       Pore          Pore          Pore          Pore
pressure      pressure      pressure      pressure
(MPa/m)       (MPa/m)       (MPa/m)       (MPa/m)

10          3.225         3.135         3.719         4.893
20          3.526         3.423         3.930         5.049
30          3.622         3.497         3.981         5.071

Monitoring point (mm)

Time         80            90            100
(min)       Pore          Pore          Pore
pressure      pressure      pressure
(MPa/m)       (MPa/m)       (MPa/m)

10          6.946        11.455        41.869
20          6.944        10.963        36.354
30          6.899        10.751        34.594
```
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