Formation pressure and temperature simulation method based on thermoelastic stress sensitivity and application

Abstract

The invention belongs to the technical field of oil reservoir well testing analysis, and discloses a formation pressure and temperature simulation method based on thermoelastic stress sensibility and application. According to the method, a porosity model and a permeability model are established based on the thermoelastic stress sensibility, and meanwhile the temperature and pressure influence is taken as the precondition; an unstable seepage equation and a heat transfer equation are established, a seepage-heat transfer coupling model is obtained and solved by combining the above equations, and real-time simulation of formation pressure and temperature is achieved. The method is applied to inversion, and seepage parameters or thermodynamic parameters of the reservoir can be obtained. According to the method, the thermoelastic stress sensitivity is fully considered into the seepage flow-heat transfer coupling model, accurate simulation of the pressure distribution condition and the temperature distribution condition of the stratum is achieved, the real-time change rule of the porosity and the permeability of the stratum is reflected, and the method is suitable for forward modeling or inversion analysis of reservoir information.

Description

Technical Field

[0001] This invention belongs to the field of reservoir well test analysis technology, and relates to a formation pressure and temperature simulation method, specifically a formation pressure and temperature simulation method and its application based on thermoelastic stress sensitivity. Background Technology

[0002] Conventional well testing theories, when measuring well production, pressure, temperature, and their changes, often neglect variations in porosity and permeability, as well as the influence of temperature on seepage patterns. While this conventional theory is relatively accurate under normal temperature and pressure conditions, in reality, due to the thermoelastic stress sensitivity effect, temperature and pressure conditions also play a significant role in formation fluid flow. This is especially true for high-temperature, high-pressure oil reservoirs, where changes in temperature and pressure can easily cause substantial increases or decreases in porosity and permeability, leading to alterations in reservoir properties. In such cases, dynamically changing pressure and temperature data will affect porosity and permeability in real time, making it impossible for conventional well testing theories that ignore the thermoelastic stress sensitivity effect to obtain accurate porosity and permeability data, and consequently, inaccurate reservoir interpretation results.

[0003] Therefore, it is necessary to accurately simulate the pressure and temperature distribution of the formation in order to understand the real-time changes in formation porosity and permeability, and thus correctly invert and analyze reservoir information. Summary of the Invention

[0004] To address the shortcomings of existing technologies, this invention aims to provide a method for simulating formation pressure and temperature based on thermoelastic stress sensitivity. By considering thermoelastic stress sensitivity, a seepage-heat transfer coupled model is constructed and then solved to calculate formation pressure and temperature distribution data, thereby achieving real-time simulation of formation pressure and temperature distribution.

[0005] Another objective of this invention is to provide applications, apparatuses, and computer-readable storage media based on the above-described formation pressure and temperature simulation method.

[0006] To achieve the above objectives, the technical solution adopted by the present invention is as follows:

[0007] A method for simulating formation pressure and temperature based on thermoelastic stress sensitivity includes the following steps performed sequentially:

[0008] S1. Establish a seepage-heat transfer coupling model:

[0009] Based on thermoelastic stress sensitivity, a porosity model and a permeability model are established.

[0010] Based on the premise that temperature and pressure interact, an unsteady flow equation and a heat transfer equation are established.

[0011] By combining the porosity model, permeability model, unsteady flow equation, and heat transfer equation, a flow-heat transfer coupled model is obtained.

[0012] When considering the interaction between temperature and pressure, the following preconditions are assumed: the well production is constant, the fluid is a single-phase liquid, the flow follows Darcy's law, and the flow direction is one-dimensional radial; the gravity effect is ignored; the reservoir is of uniform thickness, isotropic, and has uniform thermal conductivity, and its thermal conductivity is not affected by pressure and temperature; the rock matrix and liquid water are in thermal equilibrium and maintain the same temperature; there is no heat transfer in the vertical direction of the reservoir.

[0013] The porosity model is as follows:

[0014]

[0015] Where: Φ is porosity; Φ0 is initial porosity; βs is the thermal expansion coefficient of the skeleton, ℃-1; ΔT is the temperature change, ℃; R is the modulation coefficient, which represents the degree to which the grid block is restricted by the surrounding blocks, 0≤R≤1; The initial skeleton volume is in cm³. The initial apparent volume is in cm³.

[0016] The penetration rate model is as follows:

[0017]

[0018] Where: k is permeability, m2; k0 is initial permeability, m2; β is thermal expansion coefficient, ℃-1; e is the base of the natural logarithm; α is permeability modulus, Pa-1; Cs is isothermal compressibility coefficient of rock, 1 / Pa; p is pressure, Pa; p0 is initial pressure, Pa; T is temperature, K; T0 is initial temperature, K;

[0019] The unsteady flow equation is obtained by setting the following conditions in the fluid mass conservation equation:

[0020] The inner boundary isobaric condition is:

[0021] The isobaric condition at the outer boundary is: p(r=r) e ) = p0;

[0022] The initial pressure condition is: p(t=0)=p0;

[0023] Where: π is a constant; r is the radial distance, m; rw is the wellbore radius, m; h is the reservoir thickness, m; ρ is the fluid density, kg / m3; μ is the viscosity, Pa·s; qsc is the wellhead flow rate, m3 / s; B is the volume coefficient, m3 / m3; V is the wellbore volume, m3; t is time, s;

[0024] The heat transfer equation is obtained by setting the following conditions in the rock-fluid heat balance equation:

[0025] The isothermal conditions at the inner boundary are:

[0026] The isothermal condition at the outer boundary is: T(r=r) e ) = T0;

[0027] The initial temperature condition is: T(t=0)=T0;

[0028] In the formula, λt is the thermal conductivity, w / (m·K); Cpw is the specific heat of the fluid, J / (kg·K); ε is the Joule-Thomson coefficient, K / Pa;

[0029] S2. Solve the seepage-heat transfer coupling model:

[0030] The seepage-heat transfer coupled model was discretized, and explicit matrix calculations were performed using numerical methods to obtain pressure, temperature, and fluid velocity data at each time point. Curves of temperature and pressure changes over time were generated to simulate changes in formation pressure and temperature.

[0031] As a limitation of the present invention, the fluid mass conservation equation is:

[0032]

[0033] In the formula, Ct is the overall compression coefficient, Pa⁻¹;

[0034] The rock fluid thermal balance equation is:

[0035]

[0036] In the formula, Cpw is the specific heat of the fluid, J / (kg·K); ρs is the density of the rock, kg / m3; Cps is the specific heat of the rock, J / (kg·K); βs is the isobaric thermal expansion coefficient of the rock, K-1; Cs is the isothermal compressibility coefficient of the rock, Pa-1; and is the gradient operator.

[0037] As another limitation of the present invention, the discretization process involves dividing the formation into several grid cells using the finite difference method, finite element method, or finite volume method. Within each grid cell, the unsteady flow equation and the heat transfer equation are discretized to form a set of equations.

[0038] As a further limitation of the present invention, the numerical method is an iterative method, a direct method, or a relaxation method.

[0039] This invention also provides an application of the above simulation method, which uses the curves of temperature and pressure changing over time for inversion to obtain the reservoir's seepage parameters or thermodynamic parameters.

[0040] The present invention also provides a formation pressure and temperature simulation device, which is an electronic device including a memory and a processor, wherein the memory stores executable instructions; the processor executes the executable instructions in the memory to implement the above-described formation pressure and temperature simulation method based on thermoelastic stress sensitivity.

[0041] The present invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for simulating formation pressure and temperature based on thermoelastic stress sensitivity.

[0042] By adopting the above-described technical solution, the beneficial effects achieved by this invention compared to the prior art are as follows:

[0043] (1) The formation pressure and temperature simulation method based on thermoelastic stress sensitivity of the present invention, on the basis of the original seepage theory and thermodynamic theory, takes into more comprehensive consideration the influencing factors, takes into account the real-time influence of temperature and pressure changes on formation porosity and permeability, and establishes a seepage-heat transfer coupling model. Solving the equations of this model can accurately simulate the pressure distribution and temperature distribution of the formation, thereby intuitively showing the real-time change law of formation porosity and permeability. By fitting the obtained change law diagram (i.e., pressure and temperature change simulation diagram, formation pressure distribution diagram and formation temperature distribution diagram) with historical temperature and pressure data, the reservoir information can be correctly inverted and analyzed, and the evaluation of seepage parameters and thermodynamic parameters can be realized to guide oil well development and production.

[0044] (2) The formation pressure and temperature simulation method based on thermoelastic stress sensitivity of the present invention can be used to draw pressure and temperature simulation diagrams, formation pressure distribution maps, and formation temperature distribution maps, which facilitates intuitive analysis and understanding of seepage and heat transfer processes in the formation. Moreover, the method has a small amount of computation and requires fewer hardware resources and equipment. Attached Figure Description

[0045] The present invention will now be described in further detail with reference to the accompanying drawings and specific embodiments.

[0046] Figure 1 This is a schematic diagram simulating pressure and temperature changes in Embodiment 1 of the present invention;

[0047] Figure 2 This is a formation pressure distribution diagram in Embodiment 1 of the present invention;

[0048] Figure 3 This is a formation temperature distribution map in Embodiment 1 of the present invention;

[0049] Figure 4 This is a pressure fitting curve diagram from Embodiment 5 of the present invention;

[0050] Figure 5 This is a temperature fitting curve diagram from Embodiment 5 of the present invention. Detailed Implementation

[0051] The present invention will be further described in detail below with reference to specific embodiments and accompanying drawings. It should be understood that the described embodiments are only used to explain the present invention and do not limit the present invention.

[0052] Example 1: A method for simulating formation pressure and temperature based on thermoelastic stress sensitivity

[0053] This embodiment interprets a well test. By using a formation pressure and temperature simulation method based on thermoelastic stress sensitivity, it obtains a schematic diagram of the pressure and temperature changes in the formation, a formation pressure distribution map, and a formation temperature distribution map, thereby achieving real-time simulation or prediction of the formation pressure and temperature of the well test.

[0054] The specific method includes the following steps:

[0055] S0. Given the basic data, seepage parameters and thermodynamic parameters of the well test, as shown in Tables 1-3.

[0056] Table 1 Basic Data Table

[0057] Parameter name unit numerical values Time t s <![CDATA[1.8×10 5 ]]> Wellhead flow rate qsc <![CDATA[m 3 / s]]> <![CDATA[2.315×10 -4 ]]> <![CDATA[Wellbore radius r w > m 0.09 reservoir thickness h m 9.144 <![CDATA[Initial porosity Φ0]]> - 0.1 Volume index B <![CDATA[m 3 / m 3 ]]> 1.0 Crude oil viscosity μ mPa·s 1.0 <![CDATA[Initial fluid density ρ0]]> <![CDATA[kg / m 3 ]]> 1000 <![CDATA[Rock density ρ s > <![CDATA[kg / m 3 ]]> 2000 <![CDATA[Isothermal compressibility coefficient C of rock s > <![CDATA[Pa -1 ]]> <![CDATA[1×10 -10 ]]> <![CDATA[Isothermal compressibility coefficient C of fluid w > <![CDATA[Pa -1 ]]> <![CDATA[1×10 -10 ]]> <![CDATA[Isobaric thermal expansion coefficient β of rock s > <![CDATA[K -1 ]]> <![CDATA[1×10 -6 ]]> <![CDATA[Isobaric thermal expansion coefficient β of fluid w > <![CDATA[K -1 ]]> <![CDATA[1×10 -6 ]]> <![CDATA[Specific heat of rock C ps > J / (kg·K) 1000 <![CDATA[Specific heat capacity C of fluid pw > J / (kg·K) 4000 Joule-Thomson coefficient ε K / Pa <![CDATA[1×10 -8 ]]> <![CDATA[Initial pressure p0]]> MPa 60 <![CDATA[Initial temperature T0]]> ℃ 100 <![CDATA[Boundary radius r e > m 1524

[0058] Table 2 Seepage Parameters

[0059]

[0060]

[0061] Table 3. Thermodynamic Parameters

[0062] Parameter name unit numerical values <![CDATA[Thermal conductivity λ t > w / (m·K) 3.0 Modulation coefficient R - 0.9

[0063] S1. Establish a seepage-heat transfer coupling model:

[0064] S11. Based on thermoelastic stress sensitivity, establish a porosity model:

[0065] Considering the expansion of pores and matrix caused by temperature, which in turn leads to changes in permeability, porosity is defined as follows:

[0066]

[0067] The apparent volume and the skeletal volume can be expressed as:

[0068]

[0069] V s =V s0 (1+ε s (3)

[0070] The volumetric strain within the rock can be expressed as:

[0071] ε v =R(3βΔT) (4)

[0072] Assuming that solid particles can expand freely in all directions, the volumetric strain of the solid particles can be expressed as:

[0073] ε s =3β s ΔT (5)

[0074] Assuming the coefficient of thermal expansion is equal to the coefficient of thermal expansion of the skeleton, β = βs, and combining equations (1) to (5), the expression based on the porosity model can be obtained as follows:

[0075]

[0076] in,

[0077] In the formula:

[0078] Φ represents porosity;

[0079] Φ0 is the initial porosity;

[0080] Vp is the pore volume, cm3; V b Vs represents the apparent volume, in cm³; Vs represents the skeletal volume, in cm³. The initial skeleton volume is in cm³. The initial apparent volume is in cm³.

[0081] εv and εs are the volumetric strain and skeleton volumetric strain, respectively;

[0082] R is the modulation coefficient, which represents the degree to which a grid block is constrained by its surrounding blocks; 0 ≤ R ≤ 1.

[0083] β is the coefficient of thermal expansion, in °C⁻¹; βs is the coefficient of thermal expansion of the skeleton, in °C⁻¹. 1 ;

[0084] ΔT represents the temperature change, in °C.

[0085] S12. Based on thermoelastic stress sensitivity, establish a permeability model:

[0086] The equation of state for porosity considering the effect of temperature is:

[0087]

[0088] The expression for stress-sensitive permeability is:

[0089]

[0090] In the formula:

[0091] α is the permeability modulus, Pa⁻¹;

[0092] p0 is the initial pressure, in Pa;

[0093] p represents pressure, expressed in Pa.

[0094] k0 is the initial permeability, m2;

[0095] k is the permeability, in m2;

[0096] Cs is the isothermal compressibility coefficient of the rock, 1 / Pa.

[0097] Combining equations (6) and (8), we obtain the permeability model expression as follows:

[0098]

[0099] S13. Based on the premise of the interaction between temperature and pressure, establish the unsteady flow equation and the heat transfer equation; combine the porosity model, permeability model, unsteady flow equation, and heat transfer equation to obtain the flow-heat transfer coupled model, as follows:

[0100] S131. Based on the premise that temperature and pressure interact, make the following model assumptions:

[0101] Considering the mutual influence of temperature and pressure; assuming constant production in vertical wells, the fluid is a single-phase liquid, the flow follows Darcy's law, and the flow direction is one-dimensional radial; neglecting the effect of gravity; the reservoir is of uniform thickness, isotropic, and has uniform thermal conductivity, and its thermal conductivity is not affected by pressure and temperature; the rock matrix and liquid water are in thermal equilibrium and maintain the same temperature; there is no heat transfer in the vertical direction of the reservoir.

[0102] S132. Establish the equations for unsteady seepage:

[0103] The fluid mass conservation equation is expressed as:

[0104]

[0105] The isobaric conditions for the inner and outer boundaries are as follows:

[0106]

[0107] p(r=r e )=p0 (12)

[0108] in:

[0109]

[0110] The initial pressure conditions are:

[0111] p(t=0)=p0 (13)

[0112] In the formula:

[0113] B is the volume coefficient, m 3 / m 3 ;

[0114] Cs is the isothermal compressibility coefficient of the rock, Pa. -1 Cw is the isothermal compressibility coefficient of the fluid, Pa -1 Ct is the overall compression coefficient, Pa -1 ;

[0115] h is the reservoir thickness, in meters;

[0116] k is the permeability, m 2 ;

[0117] p is the pressure, Pa; p0 is the initial pressure, Pa;

[0118] qsc is the wellhead flow rate, in meters. 3 / s;

[0119] r is the radial distance, in meters; rw is the wellbore radius, in meters; re is the boundary radius, in meters.

[0120] t represents time, in seconds;

[0121] T represents temperature, in K.

[0122] T0 is the initial temperature, in K;

[0123] v is the flow velocity, m / s; V is the wellbore volume, m³ / s. 3 ;

[0124] βs is the isobaric thermal expansion coefficient of rock, K -1 βw is the isobaric thermal expansion coefficient of the fluid, K -1 ;

[0125] Φ represents porosity; Φ0 represents initial porosity;

[0126] μ is the viscosity, Pa·s;

[0127] ρ is the fluid density, kg / m³ 3 ρ0 is the initial density of the fluid, kg / m³ 3 ;

[0128] ▽ represents the gradient operator.

[0129] S133. Establish the system of heat transfer equations:

[0130] The rock fluid heat balance equation is:

[0131]

[0132] The isothermal condition at the inner boundary is as follows:

[0133]

[0134] The isothermal conditions at the outer boundary are:

[0135] T(r=r e )=T0 (16)

[0136] The initial temperature conditions are:

[0137] T(t=0)=T0 (17)

[0138] In the formula:

[0139] Cps is the specific heat of rock, J / (kg·K); Cpw is the specific heat of fluid, J / (kg·K);

[0140] H is the specific enthalpy, J / kg; Hs is the specific enthalpy of rock, J / kg;

[0141] U is the specific internal energy, J / kg; Us is the specific internal energy of the rock, J / kg;

[0142] βt is the overall thermal expansion coefficient, K -1 ;

[0143] ε is the Joule-Thomson coefficient, K / Pa;

[0144] λt is the thermal conductivity, W / (m·K);

[0145] ρs is the density of the rock, kg / m³ 3 .

[0146] The equations (6), (9), (10), and (17) of the porosity model are combined to form the equation set of the seepage-heat transfer coupled model.

[0147] S2. Solving the seepage-heat transfer coupled model:

[0148] Discretize the equations of the seepage-heat transfer coupled model: Divide the formation into several grid cells using the finite difference method. Within each grid cell, discretize the equations of unsteady seepage and heat transfer to form a set of equations.

[0149] An iterative method (numerical method) is used to explicitly solve the discrete equation system using matrix methods. Through iterative calculation, the specific parameter values ​​of pressure, temperature, and fluid velocity at any time within each grid cell are obtained, generating curves of temperature and pressure changing over time, as shown in the figure. Figure 1 A schematic diagram simulating pressure and temperature changes is drawn as follows: Figure 2 and Figure 3 The system generates formation pressure and temperature distribution maps, enabling real-time and accurate simulations of formation pressure and temperature changes. Figure 2 It reflects the distribution of formation pressure at different times. Figure 3 This reflects the temperature distribution at different times. The schematic diagrams and distribution maps obtained in this embodiment can be used to intuitively analyze and understand the seepage and heat transfer processes in the formation, and can provide real-time information on the formation fluid flow. They can also intuitively reflect the formation pressure and temperature corresponding to the seepage and thermodynamic parameters in this embodiment.

[0150] In other implementations, numerical methods, such as direct methods or relaxation methods, can solve the discrete system of equations.

[0151] In other implementations, using the finite element method or the finite volume method to divide the strata into several grid cells can yield good calculation results.

[0152] Example 2: An apparatus for simulating formation pressure and temperature based on thermoelastic stress sensitivity.

[0153] This embodiment is an electronic device based on a method for simulating formation pressure and temperature based on thermoelastic stress sensitivity, including a memory and a processor.

[0154] The memory stores executable instructions; the processor runs the executable instructions in the memory to implement the formation pressure and temperature simulation method based on thermoelastic stress sensitivity of Embodiment 1.

[0155] This memory is used to store non-transitory computer-readable instructions. Specifically, the memory may include one or more computer program products, which may include various forms of computer-readable storage media, such as volatile memory and / or non-volatile memory. The volatile memory may, for example, include random access memory (RAM) and / or cache memory. The non-volatile memory may, for example, include read-only memory (ROM), hard disk, flash memory, etc.

[0156] The processor may be a central processing unit (CPU) or other form of processing unit with data processing capabilities and / or instruction execution capabilities, and may control other components in the electronic device to perform desired functions. In one embodiment disclosed in this application, the processor is used to execute computer-readable instructions stored in the memory.

[0157] Those skilled in the art will understand that, in order to solve the technical problem of how to achieve a good user experience, this embodiment may also include well-known structures such as communication buses and interfaces, and these well-known structures should also be included within the protection scope of this disclosure.

[0158] Example 3: A computer-readable storage medium

[0159] This embodiment provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the formation pressure and temperature simulation method based on thermoelastic stress sensitivity in Embodiment 1.

[0160] The computer-readable storage medium stores non-transitory computer-readable instructions thereon. When the non-transitory computer-readable instructions are executed by a processor, all or part of the steps of the methods of the foregoing embodiments are performed.

[0161] The aforementioned computer-readable storage media include, but are not limited to: optical storage media (e.g., CD-ROM and DVD), magneto-optical storage media (e.g., MO), magnetic storage media (e.g., magnetic tape or portable hard drive), media with built-in rewritable non-volatile memory (e.g., memory card), and media with built-in ROM (e.g., ROM cartridge).

[0162] Example 4: Application of a formation pressure and temperature simulation method based on thermoelastic stress sensitivity

[0163] The pressure and temperature change simulation diagram obtained in Example 1 was used for inversion, and the reservoir's seepage parameters and thermodynamic parameters were consistent with those in Tables 2 and 3.

[0164] This embodiment demonstrates that the method of the present invention can accurately invert and analyze reservoir information by fitting the obtained change pattern diagrams (i.e., pressure and temperature change simulation diagrams, formation pressure distribution diagrams, and formation temperature distribution diagrams) with historical data, thereby guiding oil well development and production.

[0165] Example 5: Application of a formation pressure and temperature simulation method based on thermoelastic stress sensitivity

[0166] Historical pressure and temperature data obtained from actual well tests in a certain work area were used as measured data. Given initial seepage and thermodynamic parameters, these were substituted into the seepage-heat transfer coupled model equations to obtain corresponding simulated data. The seepage and thermodynamic parameters were repeatedly adjusted until the simulated data and measured data achieved a certain degree of overlap. Figure 4 , Figure 5 As shown, the seepage parameters and thermodynamic parameters obtained at this time are the inversion results, as shown in Tables 4 and 5.

[0167] Table 4. Results of seepage parameter inversion

[0168] Parameter name unit numerical values Penetration rate k <![CDATA[μm 2 ]]> 0.0064 Permeability modulus α <![CDATA[MPa -1 ]]> 0.01

[0169] Table 5 Results of thermodynamic parameter inversion

[0170] Parameter name unit numerical values Thermal conductivity λt w / (m·K) 1.2 Modulation coefficient R - 0.99

[0171] This embodiment demonstrates that the method of the present invention can be used to invert seepage and thermodynamic parameters based on measured pressure and temperature data from well tests, so as to analyze reservoir information and guide oil well development and production.

[0172] It should be noted that the above description is merely a preferred embodiment of the present invention and is not intended to limit the present invention. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art can still modify the technical solutions described in the above embodiments or make equivalent substitutions for some of the technical features. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the claims of the present invention.

Claims

1. A method for simulating formation pressure and temperature based on thermoelastic stress sensitivity, characterized in that, This includes the following steps performed sequentially: S1. Establish a seepage-heat transfer coupling model: Based on thermoelastic stress sensitivity, a porosity model and a permeability model are established. Based on the premise that temperature and pressure interact, an unsteady flow equation and a heat transfer equation are established. By combining the porosity model, permeability model, unsteady flow equation, and heat transfer equation, a flow-heat transfer coupled model is obtained. The porosity model is as follows: Where: Φ is porosity; Φ0 is initial porosity; βs is the thermal expansion coefficient of the skeleton, ℃-1; ΔT is the temperature change, ℃; R is the modulation coefficient, which represents the degree to which the grid block is restricted by the surrounding blocks, 0≤R≤1; The initial skeleton volume is in cm³. The initial apparent volume is in cm³. The penetration rate model is as follows: Where: k is permeability, m2; k0 is initial permeability, m2; β is thermal expansion coefficient, ℃-1; e is the base of the natural logarithm; α is permeability modulus, Pa-1; Cs is isothermal compressibility coefficient of rock, 1 / Pa; p is pressure, Pa; p0 is initial pressure, Pa; T is temperature, K; T0 is initial temperature, K; The unsteady flow equation is obtained by setting the following conditions in the fluid mass conservation equation: The inner boundary isobaric condition is: The isobaric condition at the outer boundary is: p(r=r) e ) = p0; The initial pressure condition is: p(t=0)=p0; Where: π is a constant; r is the radial distance, m; rw is the wellbore radius, m; h is the reservoir thickness, m; ρ is the fluid density, kg / m3; μ is the viscosity, Pa·s; qsc is the wellhead flow rate, m3 / s; B is the volume coefficient, m3 / m3; V is the wellbore volume, m3; t is time, s; The heat transfer equation is obtained by setting the following conditions in the rock-fluid heat balance equation: The isothermal conditions at the inner boundary are: The isothermal condition at the outer boundary is: T(r=r) e ) = T0; The initial temperature condition is: T(t=0)=T0; In the formula, λt is the thermal conductivity, w / (m·K); Cpw is the specific heat of the fluid, J / (kg·K); ε is the Joule-Thomson coefficient, K / Pa; S2. Solve the seepage-heat transfer coupling model: The seepage-heat transfer coupled model was discretized, and explicit matrix calculations were performed using numerical methods to obtain pressure, temperature, and fluid velocity data at each time point. Curves of temperature and pressure changes over time were generated to simulate changes in formation pressure and temperature.

2. The method for simulating formation pressure and temperature based on thermoelastic stress sensitivity according to claim 1, characterized in that, The fluid mass conservation equation is: In the formula, Ct is the overall compression coefficient, Pa⁻¹; The rock fluid thermal balance equation is: In the formula, Cpw is the specific heat of the fluid, J / (kg·K); ρs is the density of the rock, kg / m3; Cps is the specific heat of the rock, J / (kg·K); βs is the isobaric thermal expansion coefficient of the rock, K-1; Cs is the isothermal compressibility coefficient of the rock, Pa-1; and is the gradient operator.

3. A method for simulating formation pressure and temperature based on thermoelastic stress sensitivity according to claim 1 or 2, characterized in that, Discretization involves dividing the seepage-heat transfer coupled model into several grid cells using the finite difference method, finite element method, or finite volume method. Within each grid cell, the unsteady seepage equation and heat transfer equation are discretized to form a set of equations.

4. The formation pressure and temperature simulation method based on thermoelastic stress sensitivity according to claim 3, characterized in that, The numerical method is an iterative method, a direct method, or a relaxation method.

5. An application of a formation pressure and temperature simulation method based on thermoelastic stress sensitivity, characterized in that, The temperature and pressure curves as a function of time according to any one of claims 1 to 4 are used for inversion to obtain the reservoir's permeation parameters or thermodynamic parameters.

6. A formation pressure and temperature simulation device, characterized in that, An electronic device includes a memory and a processor, wherein the memory stores executable instructions; the processor executes the executable instructions in the memory to implement the formation pressure and temperature simulation method based on thermoelastic stress sensitivity as described in any one of claims 1 to 4.

7. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the formation pressure and temperature simulation method based on thermoelastic stress sensitivity as described in any one of claims 1 to 4.

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