Similarity Analysis in Scaling a Gas Hydrates Reservoir

Abstract

A complete set of scaling criteria for gas hydrate reservoir of five-spot well system case is derived from the 3D governing equations, involving the mass balance equation, the energy balance equation, the kinetic model, the endothermic model and the phase equilibrium model. In the scaling criteria, the key parameters of the experiment are the water/gas production rates, the water injection rate, and the production time. By using the scaling criteria, the experimental results can be enlarged to a field scale. Therefore, the experimental results and the scaling criteria could be used to evaluate the hydrate dissociation strategies and the gas production potential of the hydrate reservoir.

1. Introduction

Natural gas hydrates are solid, non-stoichiometric compounds of small molecules and water. They form when the constituents come into contact at low temperature and high pressure [1]. Gas hydrates were first discovered in laboratory studies circa 1800, but it was not until 1965 that it was first recognized that they are common in Nature, and that the age of some natural gas hydrate systems may be on the order of millions of years [2]. Although there has been no systematic effort to evaluate this resource and current estimates of the in-place amounts vary widely, the consensus is that the worldwide quantity of hydrocarbon gas hydrates is vast [2,3,4]. Kevenvolden [5] estimated that the global amount of hydrate-bound methane was on the order of 1.8 × 10¹⁶−2.1 × 10¹⁶ m³, which is twice the amount of carbon to be found in all known fossil fuels (coal, oil, and natural gas) on Earth.

To investigate natural gas hydrate production, it is important to establish a safe and efficient hydrate exploitation technology. More and more studies have focused on how to exploit natural gas hydrates in recent years. The research has carried out not only with one-dimensional reactors in laboratory conditions [6], but also with two-dimensional [7] and three-dimensional reactors [8]. The information obtained from these laboratory experiments is vast, but how to use this information in gas hydrate exploitation has become the next and more important problem.

In fact, the laboratory experiments on hydrate production are physical simulations of the hydrate exploitation. The physical simulation plays an important role in revealing the mechanism of the physical process and optimizing the development programs in the short term at a low cost. The principle of similarity or scaling law is crucial for physical simulations [9]. The scaling law has been widely used in the oil industry to preview the oil exploitation [10]. By using this method, the results from three-dimensional experiments can be enlarged and predicted the hydrate production in the field.

In this paper, a three-dimensional 5.8 L cubic pressure vessel (the Cubic Hydrate Simulator or (CHS) [11] has been developed for investigating the production of the gas hydrate. The gas production behavior of methane hydrate in the porous media using the thermal stimulation method with the five-spot well system is investigated in the CHS. The scaling criteria are first used for predicting the real-scale hydrate production behavior.

2. Experimental Section

2.1. Experimental Apparatus

Details of the CHS have been reported in our previous work [11,12]. The schematic of the CHS which has been used to investigate methane hydrate production by the huff and puff method [8] and the depressurization method [11] is shown in Figure 1. The experimental apparatus involves a high-pressure reactor, a water bath around the reactor, a back-pressure regulator, a gas and liquid injection equipment, a water/gas separator, a data acquisition system, and some measurement units. The high-pressure reactor (cubic inside, volume of 5.8 L, maximum pressure of 25 MPa) is the core component of the apparatus.

Figure 1. Schematic of three-dimensional experimental apparatus.

Figure 1. Schematic of three-dimensional experimental apparatus.

The distributions of the thermocouples (measure temperatures), electrodes (measure resistances), and production wellheads within the CHS are shown in Figure 2.

Figure 2. Distributions of temperature, resistance measuring points and production wellhead of each layer within the three-dimensional reactor.

Figure 2. Distributions of temperature, resistance measuring points and production wellhead of each layer within the three-dimensional reactor.

As seen in Figure 2, there are 25 × 3 thermocouples, one central vertical well, and four vertical wells in the four corners in the CHS. There are three layers, which divide the measuring points and the wellheads, named: Layer A, Layer B, and Layer C, respectively. In this work, the inlet for the heat injection is the V_I wellhead in the layer C along the centerline of the reactor, and the outlets for the gas and water production are the V₁–V₄ wellheads in the layer A.

2.2. Experimental Method

Detailed descriptions of the hydrate formation process have been introduced in previous studies [11,12]. The porous sediment used in this work is quartz sand with grain sizes of 300–450 µm. Approximately 923.6 mL of deionized water is injected to the CHS by the metering pump. The temperature of the water bath is set to a predetermined temperature for gas hydrate formation, which is 8.0 °C in the current research. A total of 19.9 mol of methane is then injected to pressurize the CHS to 20 MPa. Afterwards, hydrate formation starts, and the pressure in the CHS decreases. After 14 days, the final pressure decreases to 13.5 MPa. Before hydrate production, the initial hydrate/water/gas saturations (volume) are calculated as 38.5%, 2.2%, and 59.3%, respectively, using the model proposed by Linga et al. [13]. During the hydrate production, the temperature of the water bath is maintained at 8.0 °C, and the corresponding equilibrium pressure is calculated to be 5.7 MPa by the fugacity model proposed by Li et al. [14]. The temperature of deionized water is raised to the injection temperature (T_i = 130 °C) in the pre-heater. After preheating, the hot water is injected through the inlet valve with the hot water injection rate (q_i = 40 mL/min). The outlet valves of the wells open simultaneously, and then the gas production starts. The gas production pressure controlled by the back-pressure regulator keeps steady at 6.5 MPa. After more than 1 h hot water injection process, the rate of the gas production drops to approximately 0. We believe that no more hydrate decomposition in the CHS. Finally, the system is closed for more than 2 h, and then the system pressure starts to drop to atmosphere gradually. During these processes, the temperatures and pressures in the vessel, the gas production rate, the water injection/production rates are recorded at 10 s intervals.

3. Scaling Criteria

3.1. Mathematical Model

The 3D governing equations for hydrate dissociation in the porous sediments have been derived by combining the mass balance equation, the energy balance equation, the kinetic model, the endothermic model and the phase equilibrium model. Equations (1–3) are the mass balance equations for the gas phase, water phase, and hydrate phase:

$$\frac{\partial }{\partial x}(\frac{{\rho }_g{K}_g}{{\mu }_g}(\frac{\partial P_g}{\partial x}))+\frac{\partial }{\partial y}(\frac{{\rho }_g{K}_g}{{\mu }_g}(\frac{\partial P_g}{\partial y}))+\frac{\partial }{\partial z}(\frac{{\rho }_g{K}_g}{{\mu }_g}(\frac{\partial P_g}{\partial z}))+q_g+\stackrel{·}{m_g}=\frac{\partial }{\partial t}(\varphi {\rho }_g{s}_g)$$

(1)

$$\frac{\partial }{\partial x}(\frac{{\rho }_w{K}_w}{{\mu }_w}(\frac{\partial P_w}{\partial x}))+\frac{\partial }{\partial y}(\frac{{\rho }_w{K}_w}{{\mu }_w}(\frac{\partial P_w}{\partial y}))+\frac{\partial }{\partial z}(\frac{{\rho }_w{K}_w}{{\mu }_w}(\frac{\partial P_w}{\partial z}))+q_w+\stackrel{·}{m_w}=\frac{\partial }{\partial t}(\varphi {\rho }_w{s}_w)$$

(2)

(3)

where x, y, z are the coordinates; ø is the porosity; K_g and K_w are the permeabilities of the gas and water, respectively; P_g and P_w are pressures of the water and gas, respectively; µ_g and µ_w are the viscosities of gas and water, respectively; ρ_g, ρ_w and ρ_h are the densities of gas, water, and hydrate, respectively; s_g, s_w, and s_h are the saturations of gas, water, and hydrate, respectively; ${\dot{m}}_g$, ${\dot{m}}_w$, and ${\dot{m}}_h$ are the masses of gas, water, and hydrate formation or dissociation; q_g and q_w are the boundary changes of gas and water, which can be expressed as follows:

$$q_g=\frac{\pi {\rho }_g{K}_g(P_{gp}-P_g)}{2{\mu }_g\ln r_{eo}/r_o}\delta (x-x_p)\delta (y-y_p)$$

(4)

$$q_w=\frac{{\rho }_w{q}_I}{4H}\delta (x-x_I)\delta (y-y_I)+\frac{\pi {\rho }_w{K}_w(P_{wp}-P_w)}{2{\mu }_w\ln r_{eo}/r_o}\delta (x-x_p)\delta (y-y_p)$$

(5)

where x_p and y_p are the coordinates of the production well, respectively; x_I, y_I are the coordinates of the injection well, respectively; P_gp and P_wp are the production pressures of gas and water, respectively; r₀ is the well radius; r_e0 is the effective radius of well; q_I is the rate of the water injection, H is the thickness of the hydrate reservoir. The power-law model [15] Equation (6) is used to describe the local absolute permeability:

$$\frac{K}{K_0}=\frac{{\varphi }_e}{{\varphi }_0}{\left(\frac{{\varphi }_e(1-{\varphi }_0)}{{\varphi }_0(1-{\varphi }_e)}\right)}^{2\beta }$$

(6)

where K is the local absolute permeability; ø₀ is the total porosity; K₀ is the maximum absolute permeability corresponding to ø₀; ø_e is the effective porosity defined as ø_e = ø₀ (1−S_h); β is the index parameter.

The three-phase saturation relation is expressed as follows:

S_w + S_g + S_k = 1

(7)

The energy balance equation is written as:

$$\begin{array}{l}\frac{\partial }{\partial t}((\varphi ({\rho }_w{s}_w{h}_w+{\rho }_g{s}_g{h}_g+{\rho }_h{s}_h{h}_h)+{\rho }_r{h}_r(1-\varphi ))T)=\nabla .[({\rho }_w{h}_w\frac{k_w}{{\mu }_w}\nabla p_w+{\rho }_g{h}_g\frac{k_g}{{\mu }_g}\nabla p_g)T]\\ +\nabla .((\varphi s_w{\lambda }_w+\varphi s_g{\lambda }_g+\varphi s_h{\lambda }_h+(1-\varphi ){\lambda }_r)\nabla T)-{\dot{m}}_h\Delta H+h_w{T}_I\frac{{\rho }_w{q}_I}{4H}\delta (x-x_I)\delta (y-y_I)\end{array}$$

(8)

where h_g, h_w, h_h and h_r are the specific heats of gas, water, hydrate, and rock, respectively; λ_g, λ_w, λ_h, and λ_r are conductivity coefficients of gas, water, hydrate, and rock, respectively; T is the temperature; T_I is the temperature of the injected water; t is the time; ∆H is the enthalpy change of hydrate decomposition and can be expressed as follows [16]:

ΔH = −132.638 T + 446.12 × 10³

(9)

According to the dissociation reaction of hydrate, we can obtain the following equations:

$$\frac{{\dot{m}}_g}{{\dot{m}}_h}=\frac{M_g}{N_h{M}_w+M_g}$$

(10)

$$\frac{{\dot{m}}_w}{{\dot{m}}_g}=\frac{N_h{M}_w}{M_g}$$

(11)

where M_w and M_g are the molecular weight of the water and gas, respectively; N_h is the coefficient of dissociation reaction.

The Kim-Bishnoi model is adopted to evaluate the local mass rate of gas production by hydrate dissociation as follows [17]:

(12)

where f and f_eq are the local gas fugacity and the equilibrium gas fugacity which are usually replaced by local gas pressure P_g and P_eq; k_d is the dissociation constant; A_s is the specific surface area of porous media bearing gas hydrate, which is calculated as follows:

$$A_s={({\varphi }_e^3/2K)}^{0.5}$$

(13)

The gas hydrate equilibrium equation can be calculated as [18]:

$${\log }_{10}{P}_{eq}=a(T_{eq}-T_0)+b{(T_{eq}-T_0)}^2+c$$

(14)

where T_eq is the equilibrium temperature of gas hydrate; P_eq is the equilibrium pressure of gas hydrate; T₀ is 273.15 K; a, b, c are constant.

Initial conditions are given as:

$$s_h{|}_{t=0}=s_{hi} s_{wi}{|}_{t=0}=s_{wi} T{|}_{t=0}=T_i P{|}_{t=0}=P_i$$

(15)

Boundary conditions are:

$$P_l=P_{gp} T=T_{gp} \frac{\partial P_l}{\partial i}=0 l=g,w,h i =x,y,z$$

(16)

3.2. Calculation

We introduce the dimensionless independent variables:

$$x_D=\frac{x}{L} y_D=\frac{y}{W} z_D=\frac{z}{H} t_D=\frac{t}{t_0}=\frac{{\dot{m}}_{h}t}{s_{hi}{\varphi }_0{\rho }_h}=\frac{p_{gp}t{k}_d}{s_{hi}{\varphi }_0{\rho }_h}\sqrt{\frac{{\varphi }_0^3}{2K_0}}$$

(17)

in which the x_D, y_D, z_D, and t_D are the dimensionless coordinates and dimensionless time, respectively; L, W, and H are the length, width, and thickness of the hydrate reservoir, respectively; S_hi is the initial saturation of hydrate.

According to the calculation with the governing equations, energy equations, and the initial and boundary conditions, we get a complete set of scaling criteria of hydrate production including 36 dimensionless parameters as follows [19]:

$${\pi }_1=\frac{K_g}{K_{rwg}} {\pi }_2=\frac{K_w}{K_{rgw}} {\pi }_3=\frac{K}{K_0} {\pi }_4=\frac{L}{W} {\pi }_5=\frac{H}{L} {\pi }_6=\frac{x_p}{L} {\pi }_7=\frac{y_p}{W} {\pi }_8=\frac{x_I}{L} {\pi }_9=\frac{y_I}{W} {\pi }_{10}=\frac{r_{eo}}{L} {\pi }_{11}=\frac{r_o}{L} {\pi }_{12}=\frac{{\rho }_h}{{\rho }_g} {\pi }_{13}=\frac{{\rho }_r}{{\rho }_g} {\pi }_{14}=\frac{{\rho }_w}{{\rho }_h} {\pi }_{15}=\frac{{\lambda }_g}{{\lambda }_w} {\pi }_{16}=\frac{{\lambda }_h}{{\lambda }_w} {\pi }_{17}=\frac{{\lambda }_r}{{\lambda }_w} {\pi }_{18}=\frac{h_g}{h_w} {\pi }_{19}=\frac{h_h}{h_w} {\pi }_{20}=\frac{h_r}{h_w} {\pi }_{21}=\frac{\Delta H}{h_w{T}_{gp}} {\pi }_{22}=\frac{P_{eq}}{P_{gp}} {\pi }_{23}=\frac{P_i}{P_{gp}} {\pi }_{24}=\frac{T_i}{T_{gp}} {\pi }_{25}=\frac{T_I}{T_{gp}} {\pi }_{26}=\frac{s_{gi}-s_{rg}}{\Delta s} {\pi }_{27}=s_{hi} {\pi }_{28}=s_{rg} {\pi }_{29}=s_{rw} {\pi }_{30}={\varphi }_0 {\pi }_{31}=\frac{K_{rgw}/{\mu }_w}{K_{rwg}/{\mu }_g} {\pi }_{32}=\frac{{\rho }_g{K}_0{K}_{rwg}}{L^2{\mu }_g{k}_d}\sqrt{\frac{2K_0}{{\varphi }_0^3}} {\pi }_{33}=\frac{{\lambda }_h}{L^2{P}_{gp}{k}_d{h}_h}\sqrt{\frac{2K_0}{{\varphi }_0^3}} {\pi }_{34}=\frac{\sigma \cos \theta }{P_{gp}}\sqrt{\frac{{\varphi }_0}{K_0}} {\pi }_{35}=\frac{{\rho }_{w0}{q}_I}{HWL{k}_d{P}_{gp}}\sqrt{\frac{2K_0}{{\varphi }_0^3}} {\pi }_{36}=\frac{{\rho }_{g}gL}{p_{gp}}$$

(18)

where K_rwg is the effective permeability of the gas with the irreducible water; K_rgw is the effective permeability of the water with the residual gas; s_rg and s_rw are the saturations of the residual gas and residual water, respectively.

The physical meaning of each parameter is as follows:

• π₁ and π₂ are the dimensionless permeabilities of water and gas, respectively;
• π₃ is the dimensionless absolutely permeability;
• π₄–π₁₁ are the similarities of geometry, well position, and well radius, respectively;
• π₁₂–π₁₄ are the density ratios of hydrate to gas, rock to gas, and water to hydrate, respectively;
• π₁₅–π₁₇ are the conductivity coefficient ratios of gas to water, hydrate to water, and rock to water, respectively;
• π₁₈–π₂₀ are the specific heat ratios of gas to water, hydrate to water, and rock to water, respectively;
• π₂₁ is the dimensionless dissociation heat of hydrate;
• π₂₂ and π₂₃ are the ratios of hydrate equilibrium pressure to gas production pressure, and initial gas pressure to gas production pressure, respectively;
• π₂₄ is the dimensionless temperature in the hydrate reservoir;
• π₂₅ is the dimensionless injection temperature;
• π₂₆ is the dimensionless initial gas saturation;
• π₂₇ is the initial hydrate saturation;
• π₂₈ and π₂₉ are the saturation of residual gas and residual water, respectively;
• π₃₀ is the total porosity;
• π₃₁ is the mobility ratio of the water in residual gas and the gas in residual water;
• π₃₂ is the amount ratio of gas flow per unite area to gas production per unite area in hydrate sediment;
• π₃₃ is the ratio of conduction heat to hydrate dissociation heat per unite time;
• π₃₄ is the ratio of capillary force to gas production pressure;
• π₃₅ is the amount ratio of water flow per unite area to water production per unite area in hydrate sediment;
• π₃₆ is the dimensionless gravity.

4. Results and Discussion

4.1. Production Process

Figure 3 shows the cumulative volumes of the produced gas/water and the injected water during the hydrate dissociation. As seen in Figure 3, during the hydrate production process, hot water (4000 mL) with the temperature of 130 °C at 40 mL/min is injected into the CHS. The total time of gas production is 100 min. Obviously, during the thermal injection process, the gas production rate is relatively high during the first 60 min, approximately 2 L/min. It is contributed to that the injected heat quickly diffuses in the hydrate reservoir, mainly dissociating the hydrate in this region. After that, the gas production rate gradually decreases with time because the hydrate around the central well has been completely decomposed and the hydrate in the production-well region is gradually decomposed, however, the heat loss on the boundary of the reactor which leaves less capability to progress to the surroundings and to decompose hydrate. The final cumulative volume of the produced gas is 152.5 L. The water production rate during the first 5 minutes is quite low. After that, the water production rate gradually increases and stabilizes at a certain rate which is equal to the water injection rate. It is attributed to that there are a lot of pores in the reservoir in the CHS before the beginning of the experiment, thus, some of the injected water remains in the CHS during the term. After this period, the pores are filled by the injected water gradually, and finally, the amount of the water injected is nearly identical to that of the water produced during the remaining experimental process.

Figure 3. Cumulative volumes of produced gas/water and injected water during hydrate dissociation with thermal stimulation method.

Figure 3. Cumulative volumes of produced gas/water and injected water during hydrate dissociation with thermal stimulation method.

Figure 4 shows the three-dimensional temperature distributions in the experiment with the thermal stimulation method. In this work, the temperature of the injected water is 130 °C, while the temperature deceases to about 60 °C when it reaches the wellhead, due to the heat loss on the pipeline. Panels a−d in Figure 4 are the temperature distributions corresponding to time points of 0 min, 25 min, 50 min, and 100 min, respectively. At the beginning of the injection Figure 4a, the temperature at all points within the system remains almost same and is close to the environmental temperature. At the 25 min of the experiment Figure 4b, the temperature in the injection-well region has increased and the heat has diffused to the surroundings. At the 50 min Figure 4c, the temperature of the central continues to rise, which indicates that the heat continuously diffuses outward. At the end of the hot water injection Figure 4d, the temperatures in production-well regions increase because the heat is almost entirely diffused in the system.

Figure 4. Three-dimensional spatial temperature distributions during the hydrate dissociation with thermal stimulation method. (a) 0 min; (b) 25 min; (c) 50 min; (d) 100 min.

Figure 4. Three-dimensional spatial temperature distributions during the hydrate dissociation with thermal stimulation method. (a) 0 min; (b) 25 min; (c) 50 min; (d) 100 min.

4.2. Similar Model

According to the scaling criteria derived in Section 3, the governing equations contain the both of small scale phenomena and large scale transport. The former is independent of the scale and the latter depends on the scale. Therefore, the experiment results from the thermal stimulation method in the CHS can be enlarged to a field scale by using the scaling criteria. However, it is difficult or even impossible to achieve an experimental model which is completely similar to the prototype, attributing to the conflict between the two different dimensionless parameters. Therefore, we have to ignore some of the dimensionless parameters in actual modeling. According to the sensitivity analysis by Liu et al. [19], the effect of physical parameters on hydrate dissociation can be quantified by a sensitivity factor, which means the variance in hydrate production caused by slightly changing dimensionless parameters. The higher sensitivity factor indicates that the parameter is more important.

As the sensitivity analysis, the important parameters are summarized as the initial temperature T_i, equilibrium pressure P_eq, maximal porosity ø₀, initial pressure p_i, hydrate density ρ_h, and initial hydrate saturation s_hi. According to the scaling criteria, these parameters should keep the same in either the model or the prototype.

Furthermore, according to the calculation from the dimensionless parameters π₃₂, π₃₅, and the non-dimensional time t_D, some important physical parameters (K₀, q_I, and t) ratio existing between the model and the prototype can be obtained. The detail calculation is shown as follows:

Firstly, the size ratio between the model and prototype is set as a, which means a = L_m/L_f = H_m/H_f = W_m/W_f.

Secondly, as the scaling criteria, the dimensionless parameters π₃₂ for the model and prototype are same, which can be expressed as:

$${\left(\frac{{\rho }_g{K}_0{K}_{rwg}}{L^2{\mu }_g{k}_d}\sqrt{\frac{2K_0}{{\varphi }_0^3}}\right)}_m={\left(\frac{{\rho }_g{K}_0{K}_{rwg}}{L^2{\mu }_g{k}_d}\sqrt{\frac{2K_0}{{\varphi }_0^3}}\right)}_f$$

(19)

Thus, the permeability ratio can be obtained as:

$${\left(\sqrt{\frac{K_0^3}{{\varphi }_0^3}}\right)}_m/{\left(\sqrt{\frac{K_0^3}{{\varphi }_0^3}}\right)}_f={\left(L_m/L_f\right)}^2=a^2$$

(20)

which is:

$$\frac{{(K_0)}_m}{{(K_0)}_f}=a^{\frac{4}{3}}$$

(21)

Subsequently, by above method, the injection rate ratio and the time ratio can be obtained as:

$$\frac{{(q_I)}_m}{{(q_I)}_f}=a^{\frac{7}{3}} \frac{{(t)}_m}{{(t)}_f}=a^{\frac{2}{3}}$$

(22)

The key physical parameters ratios for hydrate production have given above.

During the hydrate production process, the most important parameters are the water/gas production rates, the water injection rate, and the production time. Table 1 lists the results of the key parameters obtained from the experiment in the CHS. By using the scaling criteria, the results can be enlarged to a field scale. In this work, the size of the hydrate reservoir in CHS is enlarged 100 times to the size of 18 m × 18 m × 18 m. Therefore, the size ratio a is 100. And the injection rate ratio and the time ratio can be calculated as 46,377.7 and 21.54 by the Equation 22. The results of the scaling model also are shown in Table 1.

Table 1. Parameters of the CHS and the corresponding scaling model.

Parameters	L/m	H/m	W/m	qI /m3s−1	r0/m	Sh
CHS	0.18	0.18	0.18	6.7 × 10−7	2 × 10−3	0.310
Scaling model	18	18	18	3.1 × 10−2	1 × 10−1	0.310
Parameters	TI/°C	ø 0	Pgp/MPa	g/ms−2	t/min	Q/m3
CHS	130	0.46	6.5	9.8	100	0.152
Scaling model	130	0.46	6.5	9.8	2154	1.52 × 105

Table 1. Parameters of the CHS and the corresponding scaling model.

Parameters	L/m	H/m	W/m	qI /m3s−1	r0/m	Sh
CHS	0.18	0.18	0.18	6.7 × 10−7	2 × 10−3	0.310
Scaling model	18	18	18	3.1 × 10−2	1 × 10−1	0.310
Parameters	TI/°C	ø 0	Pgp/MPa	g/ms−2	t/min	Q/m3
CHS	130	0.46	6.5	9.8	100	0.152
Scaling model	130	0.46	6.5	9.8	2154	1.52 × 105

As indicated in Table 1, during the experiment with thermal stimulation method in the CHS, the heat injection lasts 100 min at the rate of 40 mL/min, leading to a total injection amount of 4000 mL and the final cumulative volume of the produced gas of 152.5 L. The size of the hydrate reservoir in the CHS is enlarged 100 times. The results show that hot water of 130 °C is injected into the hydrate reservoir with a field scale (18 m × 18 m × 18 m) with the rate of 3.1 × 10⁻² m³/s for 2154 min, leading to the final cumulative volume of the produced gas of 1.52 × 10⁵ m³, which means that the final cumulative volume of the produced gas is enlarged 10⁶ times. The experimental results and the scaling criteria could be used to evaluate the hydrate dissociation strategies and the gas production potential of the hydrate reservoir.

5. Conclusions

In this paper, the CHS, a three-dimensional 5.8 L cubic pressure vessel, has been developed for investigating the gas production of hydrate reservoir. The gas production behavior of methane hydrate in the porous media is investigated in the CHS using the thermal stimulation method. The scaling criteria are firstly used in the hydrate production experiments for predicting the real-scale hydrate production behavior.

In the scaling criteria, the key parameters of the experiment are the water/gas production rates, the water injection rate, and the production time. These parameters can be enlarged to a field scale by using the criteria. The data obtained from the experiment with thermal stimulation method in the CHS (injecting hot water of 130 °C at 40 mL/min for 100 min, the final cumulative volume of the produced gas is 152.5 L) are enlarged 100 times by the scaling criteria. The results show that the hot water of 130 °C is injected at 3.1 × 10⁻² m³/s for 2154 min in the enlarged hydrate reservoir, and the final cumulative volume of the produced gas is 1.52 × 10⁵ m³.