Natural gas hydrate exploitation parameter evolution numerical value determination method and device, electronic equipment and storage medium

Abstract

The invention discloses a natural gas hydrate exploitation parameter evolution numerical value determination method and device, electronic equipment and a storage medium. The method comprises the following steps: constructing temperature-pressure equations of a natural gas hydrate decomposition area and a natural gas hydrate non-decomposition area, and determining self-similarity solutions corresponding to the temperature-pressure equations; converting a self-similarity solution corresponding to the temperature-pressure equation according to a water-gas mass balance principle at the decomposition front edge to obtain a temperature-pressure conversion equation; at the decomposition front position, a decomposition front temperature-pressure equation is constructed according to natural gas hydrate phase equilibrium; carrying out iterative solution on the temperature-pressure conversion equation and the decomposition front temperature-pressure equation, and determining an influence factor influencing the decomposition of the natural gas hydrate; and constructing a natural gas hydrate yield prediction model according to the influence factors, and predicting the water and gas yield in the natural gas hydrate decomposition area according to the natural gas hydrate yield prediction model. By adopting the technical scheme of the embodiment of the invention, theoretical and technical support is provided for efficient exploitation of the natural gas hydrate.

Description

Technical Field

[0001] This invention relates to the field of natural gas hydrate resource development technology, and in particular to a method, apparatus, electronic device and storage medium for determining the evolution values ​​of natural gas hydrate extraction parameters. Background Technology

[0002] Natural gas hydrates are flammable, ice-like crystalline compounds with a cage-like structure formed from hydrocarbon gases and water. Natural gas hydrates are a highly compressible natural gas resource; 1m³ 3 Natural gas hydrates can be decomposed to obtain 160-180m 3 (Standard) natural gas. Natural gas hydrates are widely found in marine sediments and permafrost. It is estimated that the methane carbon content in natural gas hydrates worldwide reaches 1016 kg, therefore natural gas hydrates are recognized as a promising future energy source for the 21st century.

[0003] Natural gas hydrate extraction is generally based on altering the thermodynamic equilibrium of the three-phase system (water-hydrate-gas), with depressurization being the most common method. Depressurization disrupts the hydrate phase equilibrium by reducing bottom hole pressure, causing the hydrate to decompose and release natural gas. Field data and experimental studies both indicate that hydrate decomposition leads to changes in reservoir permeability, and the subsequent gas-water two-phase flow is a significant factor affecting the production capacity of depressurization extraction.

[0004] To address the hydrate decomposition problem, one approach uses classical phase transitions to describe the process, obtaining a self-similar solution for the pressure distribution; however, this model does not consider the impact of water release. Another approach proposes a model incorporating the effect of water release, considering the mass balance of gas and water at the decomposition front and assuming that the water produced during decomposition is static and does not affect gas flow. However, both models treat hydrate decomposition as an isothermal process, neglecting thermal effects. Other existing approaches consider temperature changes during hydrate decomposition, using conduction heat transfer equations to assess the temperature distribution within the hydrate layer, but only consider single-phase gas percolation. Summary of the Invention

[0005] This invention provides a method, apparatus, electronic device, and storage medium for determining the evolution of natural gas hydrate extraction parameters, in order to solve the problem in the prior art that only single-phase gas flow is considered and thermal effects are ignored during hydrate decomposition.

[0006] According to one aspect of the present invention, a method for determining the evolution of natural gas hydrate extraction parameters is provided, the method comprising:

[0007] A first temperature-pressure equation is constructed for the natural gas hydrate decomposition region and the undecomposition region, and the self-similar solution corresponding to the first temperature-pressure equation is determined; wherein, the first temperature-pressure equation includes a first pressure equation and a first temperature equation;

[0008] Based on the principle of water vapor mass balance at the decomposition front, the self-similar solution corresponding to the first temperature and pressure equation is transformed to obtain the second temperature and pressure equation;

[0009] Based on the phase equilibrium relationship of natural gas hydrates at the decomposition front, a third temperature-pressure equation is constructed;

[0010] By combining the second and third temperature-pressure equations and performing iterative solutions, the influencing factors affecting the decomposition of natural gas hydrates can be determined.

[0011] A natural gas hydrate production prediction model was constructed based on the aforementioned influencing factors, and the water and gas production in the natural gas hydrate decomposition zone was predicted based on the natural gas hydrate production prediction model.

[0012] According to another aspect of the present invention, a device for determining the evolution of natural gas hydrate extraction parameters is provided, the device comprising:

[0013] The self-similar solution determination module is used to construct the first temperature-pressure equations for the natural gas hydrate decomposition zone and the undecomposition zone, and to determine the self-similar solutions corresponding to the first temperature-pressure equations; wherein, the first temperature-pressure equations include a first pressure equation and a first temperature equation;

[0014] The self-similar solution conversion module is used to convert the self-similar solution corresponding to the first temperature and pressure equation based on the principle of water vapor mass balance at the decomposition front, so as to obtain the second temperature and pressure equation.

[0015] The phase equilibrium module is used to construct the third temperature and pressure equation based on the phase equilibrium relationship of natural gas hydrates at the decomposition front.

[0016] The influencing factor determination module is used to combine the second and third temperature and pressure equations for iterative solution to determine the influencing factors affecting the decomposition of natural gas hydrates.

[0017] The water gas production prediction module is used to construct a natural gas hydrate production prediction model based on the influencing factors, and to predict the water gas production in the natural gas hydrate decomposition zone based on the natural gas hydrate production prediction model.

[0018] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0019] At least one processor; and

[0020] A memory communicatively connected to the at least one processor; wherein,

[0021] The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the method for determining the evolution of natural gas hydrate extraction parameters according to any embodiment of the present invention.

[0022] According to another aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions, the computer instructions being configured to cause a processor to execute and implement the method for determining the evolution values ​​of natural gas hydrate extraction parameters according to any embodiment of the present invention.

[0023] According to another aspect of the present invention, a computer program product is provided, the computer program product comprising a computer program that, when executed by a processor, implements the method for determining the evolution values ​​of natural gas hydrate extraction parameters as described in any embodiment of the present invention.

[0024] The technical solution of this invention constructs temperature-pressure equations for the decomposition zone and the undecomposition zone of natural gas hydrates, and determines the self-similar solutions corresponding to these equations. Based on the water-gas mass balance principle at the decomposition front, the self-similar solutions are transformed to obtain a temperature-pressure transformation equation. At the decomposition front, a temperature-pressure equation is constructed based on the phase equilibrium of natural gas hydrates. The temperature-pressure transformation equation and the temperature-pressure equation at the decomposition front are iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates. Based on these influencing factors, a natural gas hydrate production prediction model is constructed, and the water-gas production in the natural gas hydrate decomposition zone is predicted using this model. This solves the problem in existing technologies that only consider single-phase gas flow and ignore thermal effects during hydrate decomposition, achieving the beneficial effect of predicting water-gas production during depressurization extraction of natural gas hydrates, and providing theoretical and technical support for efficient extraction of natural gas hydrates.

[0025] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0026] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0027] Figure 1This is a flowchart of a method for determining the evolution of natural gas hydrate extraction parameters according to Embodiment 1 of the present invention;

[0028] Figure 2 This is a schematic diagram of a physical model of a natural gas hydrate reservoir provided in Embodiment 1 of the present invention;

[0029] Figure 3 This is a flowchart of a method for determining the evolution of natural gas hydrate extraction parameters according to Embodiment 2 of the present invention;

[0030] Figure 4 This is a schematic diagram of the curve showing the change of distance between the natural gas hydrate decomposition front and the wellbore over time, according to Embodiment 2 of the present invention.

[0031] Figure 5 This is a schematic diagram of the relationship between reservoir pressure and the distance the disintegration front moves, provided in Embodiment 2 of the present invention.

[0032] Figure 6 This is a schematic diagram of the relationship between natural gas reservoir temperature and decomposition front movement distance according to Embodiment 2 of the present invention;

[0033] Figure 7 This is a schematic diagram of the evolution curve of gas production over time according to Embodiment 2 of the present invention;

[0034] Figure 8 This is a schematic diagram of the evolution relationship between natural gas water production and time, according to Embodiment 2 of the present invention.

[0035] Figure 9 This is a schematic diagram of a device for determining the evolution values ​​of natural gas hydrate extraction parameters according to Embodiment 3 of the present invention;

[0036] Figure 10 This is a schematic diagram of the structure of an electronic device provided in Embodiment 4 of the present invention. Detailed Implementation

[0037] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0038] The acquisition, storage, use, and processing of data in the technical solution of this application all comply with relevant laws and regulations. It should be noted that the terms "first," "second," "target," and "original," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising," "etc.," and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that includes a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0039] Example 1

[0040] Figure 1 This is a flowchart illustrating a method for determining the evolution of natural gas hydrate extraction parameters according to Embodiment 1 of the present invention. This embodiment is applicable to situations where temperature, pressure, and production capacity around a natural gas hydrate depressurization well are predicted. This method can be executed by a device for determining the evolution of natural gas hydrate extraction parameters. This device can be implemented in hardware and / or software and can be configured in any electronic device with network communication capabilities. Figure 1 As shown, the method includes:

[0041] S110. Construct the first temperature-pressure equations for the natural gas hydrate decomposition zone and the undecomposed zone, and determine the self-similar solutions corresponding to the first temperature-pressure equations.

[0042] Among them, see Figure 2 Assume there is a large pressurized natural gas hydrate reservoir underground, with a reservoir pressure of p. e The reservoir temperature is T e Solid hydrates and natural gas exist in the porous layer. Under initial temperature and pressure, the hydrates are in a stable state. When the bottom-hole pressure p... G Decrease to a certain value p G <p D <p e T D For hydrates at decomposition temperature p DUnder the decomposition pressure, the phase equilibrium of hydrates around the well is disrupted, and they begin to decompose into natural gas and water. Over time, the hydrate decomposition process expands outward. Assuming that hydrate decomposition in porous media occurs within a narrow region, which can be considered a surface, the so-called decomposition front, this moving decomposition front divides the reservoir volume into two distinct regions: a near-wellbore zone where hydrates, water, and gas coexist; and a region farther from the wellbore where hydrates remain undecomposed, containing only solid hydrates and natural gas.

[0043] In this process, the pressure and temperature in the decomposition zone and the undecomposition zone gradually decrease. Due to the pressure gradient, natural gas and water move into the well, while the decomposition front moves in the opposite direction. The embodiments of the present invention make three assumptions about the decomposition of natural gas hydrate: (1) The pressure and temperature at any point on the decomposition front are the equilibrium pressure p of the natural gas hydrate decomposition. D and equilibrium temperature T D (2) The hydrate reservoir is assumed to be porous and contain natural gas. When the decomposition front moves towards the hydrate zone, heat must be provided to the front due to the endothermic nature of the hydrate decomposition process. At this time, heat conduction is negligible compared with heat convection. (3) The decomposition zone contains three phases: hydrate, natural gas and water. Among them, the gas and water phases are in flow. The absolute permeability, relative permeability of gas and water, gas saturation and water saturation of the decomposition zone all change with the hydrate saturation of the decomposition zone. Based on the above assumptions, a first temperature-pressure equation is constructed for the natural gas hydrate decomposition zone and the undecomposition zone, and the self-similar solution corresponding to the first temperature-pressure equation is determined. The first temperature-pressure equation includes a first pressure equation and a first temperature equation.

[0044] Among them, a self-similar solution can refer to a special solution of the first thermo-pressure equation, such that the solution of the first thermo-pressure equation remains unchanged through appropriate scaling transformation.

[0045] S120. Based on the principle of water-gas mass balance at the decomposition front, the self-similar solution corresponding to the first temperature-pressure equation is transformed to obtain the second temperature-pressure equation.

[0046] The decomposition front can refer to the location used to distinguish between the decomposition zone and the undecomposition zone. At the decomposition front, natural gas hydrates decompose to separate the natural gas hydrates in the reservoir into water and natural gas.

[0047] The water-gas mass balance principle includes the conservation of gas mass and the conservation of water mass. Specifically, the amount of gas released from the decomposition of natural gas hydrates equals the increase in free gas, and the amount of water produced from the decomposition of natural gas hydrates equals the increase in liquid water (or ice). Using this water-gas mass balance principle, the self-similar solution corresponding to the first temperature-pressure equation is transformed to obtain the second temperature-pressure equation, which is then used to determine the influencing factors.

[0048] S130. Based on the phase equilibrium relationship of natural gas hydrates at the decomposition front, a third temperature and pressure equation is constructed.

[0049] The phase equilibrium relationship of natural gas hydrate can refer to a pre-constructed assumption, that is, assuming that the pressure and temperature at any point on the decomposition front are the equilibrium pressure and equilibrium temperature of natural gas hydrate decomposition.

[0050] At the decomposition front, a third temperature-pressure equation is constructed based on the phase equilibrium relationship of natural gas hydrates, which can be expressed as:

[0051] log 10 p D =a(T D -T0)+b(T D -T0) 2 +c

[0052] Where T0 is the reference temperature, which can be taken as 273.15 K in this embodiment of the invention; a, b, and c are empirical constants related to the hydrate composition, which can be taken as 0.0342 / K and 0.0005 / K respectively in this embodiment of the invention. 2 And 6.4804. The values ​​of T0, a, b, and c are not specifically limited in the embodiments of the present invention.

[0053] S140, combined with the second and third temperature and pressure equations, is used for iterative solution to determine the influencing factors affecting the decomposition of natural gas hydrates.

[0054] The influencing factors can refer to indicators affecting the decomposition of natural gas hydrates, including but not limited to decomposition pressure, decomposition temperature, and decomposition front shift parameters. The influencing factors affecting the decomposition of natural gas hydrates can be determined by iteratively solving the second and third temperature-pressure equations.

[0055] S150. Construct a natural gas hydrate production prediction model based on the aforementioned influencing factors, and predict the water and gas production in the natural gas hydrate decomposition zone based on the aforementioned natural gas hydrate production prediction model.

[0056] The natural gas hydrate production prediction model includes a water production prediction model and a gas production prediction model. By solving the natural gas hydrate production prediction model based on the determined influencing factors, the water and gas production within the natural gas hydrate decomposition zone can be predicted.

[0057] This invention provides a method for numerically determining the evolution of natural gas hydrate extraction parameters. It involves constructing a first temperature-pressure equation for the natural gas hydrate decomposition zone and the undecomposition zone, and determining the self-similar solution corresponding to the first temperature-pressure equation. Based on the water-gas mass balance principle at the decomposition front, the self-similar solution corresponding to the first temperature-pressure equation is transformed to obtain a second temperature-pressure equation. Based on the phase equilibrium relationship of natural gas hydrate at the decomposition front, a third temperature-pressure equation is constructed. The second and third temperature-pressure equations are combined and iteratively solved to determine the influencing factors affecting natural gas hydrate decomposition. Based on these influencing factors, a natural gas hydrate production prediction model is constructed, and the water-gas production in the natural gas hydrate decomposition zone is predicted using this model. By employing the technical solution of this invention, a natural gas hydrate water-gas production prediction model is constructed. By obtaining the evolution law of the influencing factors of the hydrate reservoir, water-gas production is predicted, providing theoretical and technical support for the efficient extraction of natural gas hydrates.

[0058] Example 2

[0059] Figure 3 This is a flowchart illustrating a method for determining the evolution of natural gas hydrate extraction parameters according to Embodiment 2 of the present invention. This embodiment further optimizes the aforementioned embodiments, and can be combined with various optional schemes from one or more of the above embodiments. For example... Figure 3 As shown, the method includes:

[0060] S310. Construct the first temperature-pressure equations for the natural gas hydrate decomposition zone and the undecomposed zone, and determine the self-similar solutions corresponding to the first temperature-pressure equations.

[0061] In this embodiment of the invention, first temperature-pressure equations are constructed for the natural gas hydrate decomposition zone and the undecomposition zone, respectively, and the self-similar solutions of the first temperature-pressure equations are solved.

[0062] As an optional but non-limiting implementation, the construction of the first temperature-pressure equation for the natural gas hydrate decomposition zone and the undecomposition zone, and the determination of the self-similar solution corresponding to the first temperature-pressure equation, includes, but is not limited to, steps A1-A3:

[0063] Step A1: Construct the first pressure equations for the natural gas hydrate decomposition zone and the undecomposition zone.

[0064] Step A2: Based on the thermal convection effect of the natural gas hydrate reservoir fluid, construct the first temperature equation for the decomposition zone and the undecomposition zone of the natural gas hydrate.

[0065] Step A3: Based on the boundary conditions and initial conditions, determine the self-similar solutions corresponding to the first pressure equation and the first temperature equation, respectively.

[0066] Specifically, for the hydrate decomposition region, according to the mass conservation equation, the first pressure equation for the gas-water two-phase system is as follows:

[0067]

[0068] Where, φ1=(1-S H -S w )φ (3)

[0069] The undecomposed zone contains only free methane gas; similarly, the pressure expression for the undecomposed zone can be obtained as follows:

[0070]

[0071] Where, φ2=(1-S w0 -S H0 )φ(5)

[0072] In the above formulas, φ1 and φ2 represent the porosity of the decomposed and undecomposed regions, respectively; μ g and μ w K represents the viscosity of gas and water, respectively; K1 is the absolute permeability of the decomposition zone, and K2 is the initial absolute permeability of the reservoir; k rg1 k rg2 These represent the relative gas permeability in the decomposition and non-decomposition zones, respectively; k rw1 k represents the relative permeability of the water in the decomposition zone. rg0 The initial relative permeability of the reservoir gas; p1 and p2 represent the pressures in the decomposition and non-decomposition zones, respectively; S H S represents the original hydrate saturation of the reservoir. w S represents the water saturation level in the decomposition zone. w0 S represents the original water saturation of the reservoir. H0 This represents the initial hydrate saturation of the reservoir.

[0073] Based on the model assumptions, when natural gas is present in the hydrate reservoir, thermal conduction is much less than convective heat transfer. Therefore, this model only considers the thermal convection effect of the fluid and ignores the thermal conduction effect, resulting in the following first temperature equations for the decomposition and non-decomposition zones of the hydrate reservoir:

[0074]

[0075] Where T1 and T2 are the temperatures of the decomposition zone and the non-decomposition zone, respectively; c v δ is the isochoric heat capacity of the gas; c1 and c2 are the combined specific heat capacities of the decomposition and non-decomposition regions, respectively; δ is the throttling coefficient; and η is the gas adiabatic coefficient.

[0076] In the above formula,

[0077] c1=φ(S w cw +S g c g +S H c H )+(1-φ)c r

[0078] c2=φ(S w0 c w +S g0 c g +S H0 c H )+(1-φ)c r

[0079] μ1=S w μ w +(1-S w )μ g

[0080] μ2=S w0 μ w +(1-S w0 )μ g (8)

[0081] Among them, c w c g c H c r S represents the specific heat capacity of water, gas, hydrate, and reservoir rock, respectively; g S represents the gas saturation in the decomposition zone. g0 This represents the original gas saturation of the reservoir.

[0082] The auxiliary equation is: S g +S w +S H =1(9)

[0083] The initial and boundary conditions are as follows:

[0084] p1(0,t)=p G

[0085] p2(x,0)=p2(∞,t)=p e (10)

[0086] p1(l(t),t)=p2(l(t),t)=p D (T D (11)

[0087] T2(x,0)=T2(∞,t)=T e (12)

[0088] T1(l(t),t)=T2(l(t),t)=TD (13)

[0089] Where, p G p is the bottom hole pressure; e T represents the initial pressure of the reservoir. e p is the initial temperature of the reservoir. D To resolve the leading-edge pressure, T D To decompose the leading edge temperature, based on the model assumptions, p D and T D t represents the equilibrium pressure and temperature for the decomposition of methane hydrate; l(t) is the distance from the decomposition front to the bottom of the well.

[0090] Formula (10) represents the pressure (i.e., bottom hole pressure) at a location 0 m away from the wellbore under any time condition. G Under the initial conditions, the initial pressure at any location in the reservoir is the original reservoir pressure p. e At an infinite distance from the wellbore, the pressure at any given time is the original reservoir pressure p. e In formula (11), l represents the distance between the decomposition front and the wellbore, which is the pressure at the decomposition front at any given time, which is the equilibrium pressure of the hydrate phase, p. D Formula (12) represents that at the initial moment, and at infinite distance from the wellbore, the temperature of the undecomposed zone is the original reservoir temperature T. e Formula (13) represents that at the hydrate decomposition front, both the temperature of the decomposition zone and the temperature of the undecomposed zone are the hydrate phase equilibrium temperature T. D .

[0091] The pressure is approximated using constant bottom hole pressure and constant reservoir pressure methods, as follows:

[0092]

[0093] Equations (1), (2), and (4) are linearized as follows:

[0094]

[0095] In this context, the subscripts i = g and w represent the gas phase and the aqueous phase, respectively.

[0096]

[0097] From the boundary condition relations (10)-(13), we can obtain the self-similar solutions of equations (15) and (16):

[0098]

[0099] in,

[0100]

[0101] In the above formulas, γ represents a constant representing the movement of the decomposition leading edge, which requires iterative solution. The error function and complementary error function are defined as follows:

[0102]

[0103] Similarly, the self-similar solutions of equations (6) and (7) can be obtained:

[0104]

[0105] in,

[0106]

[0107]

[0108] S320. Based on the principle of water-gas mass balance at the decomposition front, the self-similar solution corresponding to the temperature-pressure equation is transformed to obtain the temperature-pressure transformation equation.

[0109] The self-similar solution corresponding to the first temperature-pressure equation is transformed based on the principle of water-gas mass balance at the decomposition front to obtain the second temperature-pressure equation.

[0110] As an optional but non-limiting implementation, the transformation of the self-similar solution corresponding to the first temperature-pressure equation based on the water-gas mass balance principle at the decomposition front to obtain the second temperature-pressure equation includes, but is not limited to, steps B1-B2:

[0111] Step B1: Based on the principle of gas mass balance at the decomposition leading edge, the self-similar solution corresponding to the first pressure equation is transformed to obtain the second pressure equation at the decomposition leading edge; wherein, the decomposition leading edge movement parameter is determined based on the second pressure equation.

[0112] Step B2: Based on the principle of water vapor mass balance at the decomposition front, the self-similar solution corresponding to the first temperature equation is transformed to obtain the second temperature equation at the decomposition front.

[0113] The mass balance equation for the gas at the decomposition front is as follows:

[0114]

[0115] In the above formulas, ρ1 and ρ2 are the densities of methane gas in the decomposition and non-decomposition regions, respectively; ρ H ε is the density of the methane hydrate; v1 and v2 are the methane gas velocities in the decomposition and undecomposition zones, respectively.

[0116] At the decomposition leading edge

[0117]

[0118] Where z is the compressibility factor of methane gas, and ρ0 is the density of methane gas under standard conditions (pressure p0, temperature T0).

[0119] Substituting equation (32) into equation (31), we get:

[0120]

[0121] The mass balance equation for water is:

[0122] ρ w φ1S w =(1-ε)ρ H φ2S H (34)

[0123] Where, ρ w This is the density of water.

[0124] Substituting equations (18) and (19) into equation (33) yields the equation that determines the constant γ:

[0125]

[0126] Furthermore, at the decomposition leading edge, λ2 = α2, and equation (25) becomes:

[0127]

[0128] S330. Based on the phase equilibrium relationship of natural gas hydrates at the decomposition front, a third temperature and pressure equation is constructed.

[0129] At the decomposition front, according to the phase equilibrium of natural gas hydrate, T D With p D The relationship can be represented as:

[0130] log 10 p D =a(T D -T0)+b(T D -T0) 2 +c (30)

[0131] In the formula, T0 is the reference temperature, which is taken as 273.15 K in this model; a, b, and c are empirical constants related to the hydrate composition, which are taken as 0.0342 / K and 0.0005 / K in this model, respectively. 2 And 6.4804.

[0132] S340. Construct a permeability model for the decomposition zone; the permeability model includes an absolute permeability model and a relative permeability model; based on the hydrate saturation of the decomposition zone and the pre-obtained gas saturation and water saturation, solve the permeability model to determine the absolute permeability and relative permeability of the reservoir in the decomposition zone.

[0133] The hydrate decomposition zone is a three-phase flow region consisting of gas, water, and hydrate. As the hydrate decomposes, the absolute permeability of the decomposition zone gradually increases, and the relative permeability of gas and water also changes continuously. The empirical formula for the change in absolute permeability with hydrate saturation is as follows:

[0134]

[0135] In the above formula, K0 is the absolute permeability of the reservoir when the hydrate saturation is equal to 0; N is the permeability reduction index, and the value of N is 5 in this model.

[0136] The formula for the relative permeability of air and water is as follows:

[0137]

[0138] in,

[0139]

[0140] In the formula, m = 0.45, S wr =0.3, S gr =0.05, k rw0 =0.5, k rg0 =1.0. The above value is not specifically limited in the embodiments of the present invention, and can be determined according to the actual situation.

[0141] S350, combined with the second and third temperature and pressure equations, were iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates.

[0142] In this application, the decomposition pressure, decomposition temperature, and decomposition front movement parameters that affect the decomposition of natural gas hydrates are determined by iteratively solving the second and third temperature-pressure equations.

[0143] As an optional but non-limiting implementation, the combined second and third temperature-pressure equations are iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates, including but not limited to steps C1-C2:

[0144] Step C1: Obtain the attribute information of the natural gas hydrate reservoir; the attribute information includes the initial temperature, bottom hole pressure, hydrate saturation in the decomposition zone, and the predetermined absolute permeability and relative permeability of the decomposition zone reservoir.

[0145] Step C2: Based on the natural gas hydrate reservoir property information, the second and third temperature-pressure equations are combined and iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates; wherein, the influencing factors include decomposition pressure, decomposition temperature, and decomposition front movement parameters.

[0146] In the decomposition region, a hydrate saturation S is given. H By combining formulas (9) and (34), the corresponding gas saturation S can be calculated. g and water saturation S w Furthermore, the absolute permeability and relative permeability of gas and water in the reservoir under different hydrate saturation levels can be calculated. By solving the nonlinear equation set (30), (35), and (37) using an iterative scheme, the influence factor T affecting the decomposition of natural gas hydrate under different time and space conditions can be obtained. D p D and γ value.

[0147] S360. Construct a natural gas hydrate production prediction model based on the aforementioned influencing factors, and predict the water and gas production in the natural gas hydrate decomposition zone based on the aforementioned natural gas hydrate production prediction model.

[0148] Among them, a water-gas production prediction model for natural gas hydrates was constructed to predict the water-gas production in the decomposition zone well.

[0149] As an optional but non-limiting implementation, the step of constructing a natural gas hydrate production prediction model based on the influencing factors, and predicting the water and gas production in the natural gas hydrate decomposition zone based on the natural gas hydrate production prediction model, includes, but is not limited to, steps D1-D3:

[0150] Step D1: Determine the absolute and relative permeability of the reservoir in the decomposition zone, and identify the influencing factors affecting the decomposition of natural gas hydrates.

[0151] Step D2: Construct a natural gas hydrate production prediction model based on the influencing factors, absolute permeability, and relative permeability; wherein, the natural gas hydrate production prediction model includes a gas production prediction model and a water production prediction model.

[0152] Step D3: Based on the natural gas hydrate production prediction model, predict the water and gas production of the wells in the natural gas hydrate decomposition zone.

[0153] The influencing factors, absolute permeability, and relative permeability of the decomposition zone reservoir were determined, and a natural gas hydrate production prediction model was constructed. In the model, the decomposition pressure and temperature depend only on the bottom hole pressure, reservoir temperature, and pressure. Therefore, the constructed production prediction model per unit length of the production well can be expressed as:

[0154]

[0155] The water production prediction model per unit length of a production well can be expressed as:

[0156]

[0157] Specifically, the water and gas production of production wells within the natural gas hydrate decomposition zone is predicted using the aforementioned natural gas hydrate production prediction model. Wherein, Q... g Q represents the gas production per unit length of a production well. w Characterizes the water production per unit length of a well.

[0158] As an optional but non-limiting implementation, the method also includes, but is not limited to, steps E1-E3:

[0159] Step E1: Based on the natural gas hydrate reservoir property information, iteratively solve the temperature-pressure conversion equation and the decomposition front temperature-pressure equation to determine the distance between the hydrate decomposition front and the wellbore.

[0160] Step E2: Determine the target relationship curve based on the distance between the hydrate decomposition front and the wellbore; wherein, the target relationship curve includes the curve of the target distance changing with time under different conditions, the relationship curve between reservoir pressure and target distance, and the relationship curve between reservoir temperature and target distance, and the target distance refers to the distance between the hydrate decomposition front and the wellbore.

[0161] Step E3: Based on the target relationship curve, determine the evolution relationship curve of natural gas hydrate water gas production over time.

[0162] In one optional embodiment of the present invention, the temperature-pressure conversion equation and the temperature-pressure equation of the decomposition front are solved iteratively to determine the distance between the hydrate decomposition front and the wellbore. Using the distance between the hydrate decomposition front and the wellbore, curves showing the change of the hydrate decomposition front over time under different conditions, as well as curves showing the relationship between reservoir pressure, reservoir temperature, and the distance the decomposition front moves, are further obtained. Finally, curves showing the evolution of gas-water production over time are plotted.

[0163] Specifically, the basic parameters of the natural gas hydrate reservoir are given as shown in Table 1.

[0164] Table 1. Natural Gas Hydrate Reservoir Parameters

[0165]

[0166] Based on a given reservoir temperature T e (15℃), bottom hole pressure p G(10MPa) and hydrate saturation S in the hydrate decomposition zone H (0.5), by iteratively solving the system of equations (30), (35) and (37), the hydrate decomposition temperature T is obtained. D Decomposition pressure p D The values ​​of γ and l, representing the movement of the hydrate decomposition front, are shown in Table 2.

[0167] Table 2 Iterative Solution Values

[0168]

[0169] Based on the data in Table 2, further information can be obtained as follows: Figure 4 The curves showing the distance between the hydrate decomposition front and the wellbore under different conditions as a function of time are shown; and as shown in the figure... Figure 5-6 The curves showing the relationship between reservoir pressure and target distance, and the curves showing the relationship between reservoir temperature and target distance, where the target distance refers to the distance between the hydrate decomposition front and the wellbore; finally, the following plots are shown... Figure 7-8 The curves showing the evolution of gas and water production over time are shown.

[0170] This invention provides a numerical method for determining the evolution of natural gas hydrate extraction parameters. By establishing a two-phase gas-water production model for hydrate depressurization extraction, and considering the changes in hydrate saturation and gas-water permeability in the decomposition zone, a set of approximately self-similar solutions is used to obtain the variations in pressure, temperature, and flow rate in the reservoir. This method iteratively solves a set of coupled algebraic equations relating the decomposition front location and the equilibrium temperature and pressure at the decomposition front as a function of time. Ultimately, it obtains numerical results on the evolution of hydrate reservoir pressure, temperature distribution, front location, and natural gas / water production over time, providing theoretical and technical support for the efficient extraction of natural gas hydrates.

[0171] Example 3

[0172] Figure 9 This is a schematic diagram of a device for determining the evolution of natural gas hydrate extraction parameters according to Embodiment 3 of the present invention. Figure 9 As shown, the device includes:

[0173] The self-similar solution determination module 910 is used to construct the first temperature-pressure equations for the natural gas hydrate decomposition zone and the undecomposition zone, and to determine the self-similar solutions corresponding to the first temperature-pressure equations; wherein, the first temperature-pressure equations include a first pressure equation and a first temperature equation.

[0174] The self-similar solution conversion module 920 is used to convert the self-similar solution corresponding to the first temperature and pressure equation based on the water-gas mass balance principle at the decomposition front to obtain the second temperature and pressure equation.

[0175] Phase equilibrium module 930 is used to construct the temperature and pressure equation of the decomposition front based on the phase equilibrium relationship of natural gas hydrate at the decomposition front;

[0176] The influencing factor determination module 940 is used to combine the second temperature and pressure equation and the third temperature and pressure equation for iterative solution to determine the influencing factors affecting the decomposition of natural gas hydrates.

[0177] The water gas production prediction module 950 is used to construct a natural gas hydrate production prediction model based on the influencing factors, and to predict the water gas production in the natural gas hydrate decomposition zone based on the natural gas hydrate production prediction model.

[0178] Optional, self-similar solution determination module, specifically used for:

[0179] Construct the first pressure equations for the natural gas hydrate decomposition zone and the undecomposed zone;

[0180] Based on the thermal convection effect of natural gas hydrate reservoir fluids, the first temperature equations for the decomposition and non-decomposition zones of natural gas hydrates are constructed.

[0181] Based on the boundary conditions and initial conditions, the self-similar solutions corresponding to the first pressure equation and the first temperature equation are determined respectively.

[0182] Optional, self-similar solution conversion module, specifically used for:

[0183] Based on the gas mass balance principle at the decomposition leading edge, the self-similar solution corresponding to the first pressure equation is transformed to obtain the second pressure equation at the decomposition leading edge; wherein, the decomposition leading edge movement parameter is determined based on the second pressure equation.

[0184] Based on the principle of water vapor mass balance at the decomposition front, the self-similar solution corresponding to the first temperature equation is transformed to obtain the second temperature equation at the decomposition front.

[0185] Optionally, before iteratively solving the second and third temperature-pressure equations to determine the influencing factors affecting the decomposition of natural gas hydrates, the device further includes a permeability model construction module, specifically used for:

[0186] Construct a permeability model for the decomposition zone; the permeability model includes an absolute permeability model and a relative permeability model;

[0187] Based on the hydrate saturation in the decomposition zone, as well as the pre-obtained gas saturation and water saturation, the permeability model is solved to determine the absolute and relative permeability of the reservoir in the decomposition zone.

[0188] Optional, the impact factor determination module, specifically used for:

[0189] Obtain natural gas hydrate reservoir attribute information; the attribute information includes initial temperature, bottom hole pressure, hydrate saturation in the decomposition zone, and predetermined absolute and relative permeability of the decomposition zone reservoir;

[0190] Based on the natural gas hydrate reservoir property information, the second and third temperature-pressure equations are combined and iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates; wherein, the influencing factors include decomposition pressure, decomposition temperature, and decomposition front movement parameters.

[0191] Optional, a water vapor production prediction module, specifically used for:

[0192] Determine the absolute and relative permeability of the reservoir in the decomposition zone, and identify the influencing factors affecting the decomposition of natural gas hydrates;

[0193] A natural gas hydrate production prediction model is constructed based on the aforementioned influencing factors, absolute permeability, and relative permeability; wherein, the natural gas hydrate production prediction model includes a gas production prediction model and a water production prediction model;

[0194] Based on the natural gas hydrate production prediction model, the water and gas production of wells in the natural gas hydrate decomposition zone is predicted.

[0195] Optionally, the device further includes a relationship curve construction module, specifically used for:

[0196] Based on the natural gas hydrate reservoir property information, the distance between the hydrate decomposition front and the wellbore is determined by iteratively solving the second and third temperature and pressure equations.

[0197] Based on the distance between the hydrate decomposition front and the wellbore, a target relationship curve is determined; wherein, the target relationship curve includes the curve of target distance changing with time under different conditions, the relationship curve between reservoir pressure and target distance, and the relationship curve between reservoir temperature and target distance, and the target distance refers to the distance between the hydrate decomposition front and the wellbore;

[0198] Based on the target relationship curve, the evolution relationship curve of natural gas hydrate water gas production over time is determined.

[0199] The device for determining the evolution value of natural gas hydrate mining parameters provided in this embodiment of the invention can execute the method for determining the evolution value of natural gas hydrate mining parameters provided in any of the above embodiments of the invention. It has the corresponding functions and beneficial effects of executing the method for determining the evolution value of natural gas hydrate mining parameters. For details, please refer to the relevant operations of the method for determining the evolution value of natural gas hydrate mining parameters in the foregoing embodiments.

[0200] Example 4

[0201] Figure 10 A schematic diagram of an electronic device 10 that can be used to implement embodiments of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0202] like Figure 10 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 may also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0203] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0204] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, central processing unit (CPU), graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, digital signal processors (DSPs), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as the numerical determination method for the evolution of natural gas hydrate extraction parameters.

[0205] In particular, according to embodiments of the present invention, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, embodiments of the present invention include a computer program product comprising a computer program carried on a non-transitory computer-readable medium, the computer program containing program code for performing the methods shown in the flowcharts. In such embodiments, the computer program can be downloaded and installed from a network via communication unit 19, or installed from storage unit 18, or installed from ROM 12. When the computer program is executed by processor 11, it performs the functions defined in the methods of the embodiments of the present invention.

[0206] In some embodiments, the method for determining the evolution of natural gas hydrate extraction parameters can be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the method for determining the evolution of natural gas hydrate extraction parameters described above can be performed. Alternatively, in other embodiments, processor 11 can be configured to perform the method for determining the evolution of natural gas hydrate extraction parameters by any other suitable means (e.g., by means of firmware).

[0207] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), system-on-a-chip (SoCs), complex programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transferring data and instructions to the storage system, the at least one input device, and the at least one output device.

[0208] Computer programs used to implement the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0209] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0210] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0211] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0212] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0213] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0214] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for numerically determining the evolution of natural gas hydrate extraction parameters, characterized in that, The method includes: A first temperature-pressure equation is constructed for the natural gas hydrate decomposition region and the undecomposition region, and the self-similar solution corresponding to the first temperature-pressure equation is determined; wherein, the first temperature-pressure equation includes a first pressure equation and a first temperature equation; Based on the principle of water vapor mass balance at the decomposition front, the self-similar solution corresponding to the first temperature and pressure equation is transformed to obtain the second temperature and pressure equation; Based on the phase equilibrium relationship of natural gas hydrates at the decomposition front, a third temperature-pressure equation is constructed; By combining the second and third temperature-pressure equations and performing iterative solutions, the influencing factors affecting the decomposition of natural gas hydrates can be determined. A natural gas hydrate production prediction model was constructed based on the aforementioned influencing factors, and the water and gas production in the natural gas hydrate decomposition zone was predicted based on the natural gas hydrate production prediction model.

2. The method according to claim 1, characterized in that, The construction of the first temperature-pressure equation for the natural gas hydrate decomposition region and the undecomposition region, and the determination of the self-similar solution corresponding to the first temperature-pressure equation, includes: Construct the first pressure equations for the natural gas hydrate decomposition zone and the undecomposed zone; Based on the thermal convection effect of natural gas hydrate reservoir fluids, the first temperature equations for the decomposition and non-decomposition zones of natural gas hydrates are constructed. Based on the boundary conditions and initial conditions, the self-similar solutions corresponding to the first pressure equation and the first temperature equation are determined respectively.

3. The method according to claim 1, characterized in that, The self-similar solution corresponding to the first temperature-pressure equation is transformed based on the water-gas mass balance principle at the decomposition front to obtain the second temperature-pressure equation, including: Based on the gas mass balance principle at the decomposition leading edge, the self-similar solution corresponding to the first pressure equation is transformed to obtain the second pressure equation at the decomposition leading edge; wherein, the decomposition leading edge movement parameter is determined based on the second pressure equation. Based on the principle of water vapor mass balance at the decomposition front, the self-similar solution corresponding to the first temperature equation is transformed to obtain the second temperature equation at the decomposition front.

4. The method according to claim 1, characterized in that, Before iteratively solving the second and third temperature-pressure equations to determine the influencing factors affecting the decomposition of natural gas hydrates, the method further includes: Construct a permeability model for the decomposition zone; the permeability model includes an absolute permeability model and a relative permeability model; Based on the hydrate saturation in the decomposition zone, as well as the pre-obtained gas saturation and water saturation, the permeability model is solved to determine the absolute and relative permeability of the reservoir in the decomposition zone.

5. The method according to claim 1, characterized in that, The combined second and third temperature-pressure equations are iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates, including: Obtain natural gas hydrate reservoir attribute information; the attribute information includes initial temperature, bottom hole pressure, hydrate saturation in the decomposition zone, and predetermined absolute and relative permeability of the decomposition zone reservoir; Based on the natural gas hydrate reservoir property information, the second and third temperature-pressure equations are combined and iteratively solved to determine the influencing factors affecting the decomposition of natural gas hydrates; wherein, the influencing factors include decomposition pressure, decomposition temperature, and decomposition front movement parameters.

6. The method according to claim 1, characterized in that, The step of constructing a natural gas hydrate production prediction model based on the aforementioned influencing factors, and predicting the water and gas production in the natural gas hydrate decomposition zone based on the natural gas hydrate production prediction model, includes: Determine the absolute and relative permeability of the reservoir in the decomposition zone, and identify the influencing factors affecting the decomposition of natural gas hydrates; A natural gas hydrate production prediction model is constructed based on the aforementioned influencing factors, absolute permeability, and relative permeability; wherein, the natural gas hydrate production prediction model includes a gas production prediction model and a water production prediction model; Based on the natural gas hydrate production prediction model, the water and gas production of wells in the natural gas hydrate decomposition zone is predicted.

7. The method according to any one of claims 1-6, characterized in that, The method further includes: Based on the natural gas hydrate reservoir property information, the distance between the hydrate decomposition front and the wellbore is determined by iteratively solving the second and third temperature and pressure equations. Based on the distance between the hydrate decomposition front and the wellbore, a target relationship curve is determined; wherein, the target relationship curve includes the curve of target distance changing with time under different conditions, the relationship curve between reservoir pressure and target distance, and the relationship curve between reservoir temperature and target distance, and the target distance refers to the distance between the hydrate decomposition front and the wellbore; Based on the target relationship curve, the evolution relationship curve of natural gas hydrate water gas production over time is determined.

8. A device for determining the numerical evolution of natural gas hydrate extraction parameters, characterized in that, The device includes: The self-similar solution determination module is used to construct the first temperature-pressure equations for the natural gas hydrate decomposition zone and the undecomposition zone, and to determine the self-similar solutions corresponding to the first temperature-pressure equations; wherein, the first temperature-pressure equations include a first pressure equation and a first temperature equation; The self-similar solution conversion module is used to convert the self-similar solution corresponding to the first temperature and pressure equation based on the principle of water vapor mass balance at the decomposition front, so as to obtain the second temperature and pressure equation. The phase equilibrium module is used to construct the third temperature and pressure equation based on the phase equilibrium relationship of natural gas hydrates at the decomposition front. The influencing factor determination module is used to combine the second and third temperature and pressure equations for iterative solution to determine the influencing factors affecting the decomposition of natural gas hydrates. The water gas production prediction module is used to construct a natural gas hydrate production prediction model based on the influencing factors, and to predict the water gas production in the natural gas hydrate decomposition zone based on the natural gas hydrate production prediction model.

9. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, the computer program being executed by the at least one processor to enable the at least one processor to perform the method for determining the evolution of natural gas hydrate extraction parameters according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that are used to cause a processor to execute the method for determining the evolution of natural gas hydrate extraction parameters according to any one of claims 1-7.

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