Method for determining wellbore pressure while tripping of high-temperature and high-pressure well

Abstract

A method for determining the wellbore pressure while tripping of a high-temperature and high-pressure well, relating to the technical field of petroleum and natural gas drilling. The method comprises: on the basis of a conservation of mass equation, a conservation of momentum equation, a conservation of energy equation, a micro-element length, an inclination angle at a grid node and parameter data, determining the wellbore pressure while tripping when temperature and pressure are comprehensively considered. The accuracy of wellbore pressure prediction can be improved.

Description

Method for determining wellbore pressure during tripping of high-temperature and high-pressure wells Technical Field

[0001] The present invention relates to the technical field of oil and natural gas drilling, and in particular to a method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well. Background Art

[0002] This section is intended to provide a background or context to the embodiments of the invention that are recited in the claims. No statement herein is admitted to be prior art by virtue of its inclusion in this section.

[0003] Deep formations are characterized by high temperatures and high pressures, and the safe density window for drilling fluids is narrow. With the increasing exploration and development of deep oil and gas resources, the demand for predicting wellbore pressure during tripping operations is becoming increasingly stringent. Accurately predicting wellbore pressure during tripping operations is of practical significance for ensuring drilling safety and improving operational efficiency.

[0004] Existing tripping wellbore pressure calculations fail to account for the interplay between wellbore temperature, pressure, and drilling fluid properties. For deep and ultra-deep wells, ignoring the effects of high temperature and pressure can lead to significant deviations in wellbore pressure predictions, causing wellbore pressure imbalances and leading to complications such as lost circulation and overflows. Existing methods for determining tripping wellbore pressure are inaccurate, posing significant safety risks to tripping operations.

[0005] Summary of the Invention

[0006] An embodiment of the present invention provides a method for determining wellbore pressure during tripping of a high-temperature and high-pressure well, which is used to improve the accuracy of wellbore pressure prediction, effectively meet the requirements for accurate regulation of wellbore pressure during tripping of a high-temperature and high-pressure well, and ensure safe and efficient tripping operations. The method includes:

[0007] Obtaining parameter data during the tripping operation; wherein the parameter data at least includes: inclination measurement data and preset well depth;

[0008] Divide the grid nodes according to the preset number of nodes and the preset well depth, and obtain the length of the microelement segment;

[0009] Determine the well inclination angle at the grid node based on the inclination survey data;

[0010] The tripping wellbore pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the length of the microelement segment, the wellbore inclination angle at the grid node, and parameter data.

[0011] An embodiment of the present invention further provides a device for determining wellbore pressure during tripping of a high-temperature and high-pressure well, which is used to improve the accuracy of wellbore pressure prediction, effectively meet the requirements for accurate regulation of wellbore pressure during tripping of a high-temperature and high-pressure well, and ensure safe and efficient tripping operations. The device includes:

[0012] The parameter acquisition module is used to obtain parameter data during the tripping operation; wherein the parameter data at least includes: inclination measurement data and preset well depth;

[0013] The first processing module is used to divide the grid nodes according to the preset number of nodes and the preset well depth, and obtain the length of the micro-element segment;

[0014] The second processing module is used to determine the well inclination angle at the grid node based on the inclination measurement data;

[0015] The third processing module is used to determine the tripping wellbore pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, infinitesimal segment length, well inclination angle at grid node, and parameter data.

[0016] An embodiment of the present invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the above-mentioned method for determining the wellbore pressure during tripping and drilling of a high-temperature and high-pressure well is implemented.

[0017] An embodiment of the present invention further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well is implemented.

[0018] An embodiment of the present invention further provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the above-mentioned method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well.

[0019] In an embodiment of the present invention, parameter data is obtained during the tripping operation; wherein the parameter data includes at least: inclination data and a preset well depth; grid nodes are divided according to the preset number of nodes and the preset well depth, and the length of the microelement segment is obtained; the well inclination angle at the grid node is determined based on the inclination data; and the tripping wellbore pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the microelement segment length, the well inclination angle at the grid node, and the parameter data. In this way, the effect of high temperature and high pressure on the properties of the drilling fluid is taken into account, the accuracy of the tripping wellbore pressure calculation is improved, the accuracy of the wellbore pressure prediction is improved, and the accurate regulation of the wellbore pressure during tripping of high temperature and high pressure wells is effectively met, ensuring safe and efficient tripping operations. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for the embodiments or the description of the prior art. Obviously, the 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 work. In the drawings:

[0021] FIG1 is a flow chart of a method for determining wellbore pressure during tripping of a high-temperature and high-pressure well provided in an embodiment of the present invention;

[0022] FIG2 is a flow chart of a method for dividing grid nodes and obtaining microelement segment lengths according to a preset number of nodes and a preset well depth, provided in an embodiment of the present invention;

[0023] FIG3 is a flow chart of a method for determining the tripping wellbore pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the length of the infinitesimal segment, the well inclination angle at the grid node, and parameter data, provided in an embodiment of the present invention;

[0024] FIG4 is a flow chart of a method for calculating drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at preset pressure and temperature values ​​provided in an embodiment of the present invention;

[0025] FIG5 is a schematic diagram of a device for determining wellbore pressure during tripping of a high-temperature and high-pressure well provided in an embodiment of the present invention;

[0026] FIG6 is a schematic diagram of a computer device provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0027] To make the purpose, technical solutions and advantages of the embodiments of the present invention more clear, the embodiments of the present invention are further described in detail below with reference to the accompanying drawings. Here, the exemplary embodiments of the present invention and their descriptions are used to explain the present invention, but are not intended to limit the present invention.

[0028] The acquisition, storage, use, and processing of data in this application's technical solution comply with relevant national laws and regulations.

[0029] The term "and / or" herein simply describes an association relationship, indicating that three relationships can exist. For example, A and / or B can represent the existence of A alone, the simultaneous existence of A and B, and the existence of B alone. In addition, the term "at least one" herein refers to any combination of at least two of any one or more of a plurality of items. For example, "at least one of A, B, and C" can represent any one or more elements selected from the set consisting of A, B, and C.

[0030] In the description of this specification, the terms "include", "including", "have", "contain", etc. are all open terms, which mean including but not limited to. The descriptions with reference to the terms "one embodiment", "a specific embodiment", "some embodiments", "for example", etc. mean that the specific features, structures or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present application. In this specification, the schematic expressions of the above terms do not necessarily refer to the same embodiment or example. Moreover, the specific features, structures or characteristics described can be combined in a suitable manner in any one or more embodiments or examples. The order of steps involved in each embodiment is used to schematically illustrate the implementation of the present application, and the order of steps therein is not limited and can be appropriately adjusted as needed.

[0031] Research has revealed that deep formations exhibit significant high-temperature and high-pressure characteristics, resulting in a narrow window of safe drilling fluid density. With the increasing exploration and development of deep oil and gas resources, the demand for predicting wellbore pressure during tripping operations is becoming increasingly stringent. Accurately predicting wellbore pressure during tripping operations is of practical significance for ensuring drilling safety and improving operational efficiency.

[0032] Existing tripping wellbore pressure calculations fail to account for the interplay between wellbore temperature, pressure, and drilling fluid properties. For deep and ultra-deep wells, ignoring the effects of high temperature and pressure can lead to significant deviations in wellbore pressure predictions, causing wellbore pressure imbalances and leading to complications such as lost circulation and overflows. Existing methods for determining tripping wellbore pressure are inaccurate, posing significant safety risks to tripping operations.

[0033] In response to the above research, as shown in FIG1 , an embodiment of the present invention provides a method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well, comprising:

[0034] S101: Acquire parameter data during the tripping operation; wherein the parameter data at least includes: inclination measurement data and a preset well depth;

[0035] S102: Divide the grid nodes according to the preset number of nodes and the preset well depth, and obtain the length of the micro-element segment;

[0036] S103: determining the well inclination angle at the grid node according to the inclination survey data;

[0037] S104: Determine the tripping wellbore pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the length of the microelement segment, the wellbore inclination angle at the grid node, and parameter data.

[0038] In an embodiment of the present invention, parameter data is obtained during the tripping operation; wherein the parameter data includes at least inclination data and a preset well depth; grid nodes are divided according to the preset number of nodes and the preset well depth, and the length of the microelement segment is obtained; the well inclination angle at the grid node is determined based on the inclination data; and the tripping wellbore pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the microelement segment length, the well inclination angle at the grid node, and the parameter data. In this way, the effect of high temperature and high pressure on the properties of the drilling fluid is taken into account, the accuracy of the tripping wellbore pressure calculation is improved, the accuracy of the wellbore pressure prediction is improved, and the accurate regulation of the wellbore pressure during tripping of high temperature and high pressure wells is effectively met, ensuring safe and efficient tripping operations.

[0039] The method for determining the wellbore pressure during tripping of the above-mentioned high-temperature and high-pressure well is described in detail below.

[0040] Regarding the above S102, as shown in FIG2, a flowchart of a method for dividing grid nodes according to a preset number of nodes and a preset well depth, and obtaining the length of a microelement segment is provided in an embodiment of the present invention, including:

[0041] S201: According to the preset number of nodes and the total well depth, the grid nodes are divided using an equal spacing or a variable spacing method to obtain an initial grid node matrix.

[0042] In one embodiment of the present invention, when equal-interval division is adopted, the average well depth between adjacent preset grid nodes is first calculated based on the preset number of nodes and the total well depth, and then the initial grid node matrix is ​​obtained based on the average well depth of each preset grid node.

[0043] For example, if the well depth is 3000m and the number of preset nodes is 5, the average well depth of adjacent preset grid nodes is 600, and the initial grid node matrix is ​​[600, 1200, 1800, 2400, 3000].

[0044] In another embodiment of the present invention, when variable spacing division is adopted, the variable spacing interval is set in advance according to the preset number of nodes and the total well depth. For example, the spacing can be set to increase or decrease, and then the initial grid node matrix is ​​obtained according to the preset variable spacing interval, the preset number of nodes, and the total well depth.

[0045] For example, if the well depth is 3000m, the number of preset nodes is 5, and the spacing between adjacent preset grid nodes is preset to increase, the initial grid node matrix is ​​[600, 1000, 1600, 2400, 3000].

[0046] S202: Add the preset well depth to the initial grid node matrix to obtain a final divided grid node matrix; wherein each element value in the grid node matrix represents the well depth corresponding to a grid node.

[0047] The preset well depths include, for example, the well depth at the casing shoe, the well depth at the drill string diameter change point, and the well depth at the abnormal formation pressure point.

[0048] Specifically, according to the well depth of the preset point and the well depth of the preset grid node, the well depth of the preset point is added to the initial grid node matrix to obtain the final divided grid node matrix; wherein each element value in the grid node matrix represents the well depth corresponding to a grid node.

[0049] For example, the initial grid node matrix is ​​[600, 1000, 1600, 2400, 3000], and the preset well depths include: 700m at the casing shoe, 1050m at the drill string diameter change, and 2600m at the abnormal formation pressure. The final divided grid node matrix is ​​[600, 700, 1000, 1050, 1600, 2400, 2600, 3000].

[0050] S203: Determine the length of the microelement segment according to the preset number of nodes and the total well depth.

[0051] In one embodiment of the present invention, the well depth between preset grid nodes is determined according to the total well depth and the number of preset nodes, and the well depth between the preset grid nodes is used as the microelement length.

[0052] With respect to the above S103, determining the well inclination angle at the grid node according to the inclination measurement data, for example, includes: calculating the well inclination angle at the grid node according to the inclination measurement data using a linear interpolation method.

[0053] In one embodiment of the present invention, the inclination survey data includes, for example, the well depth and inclination angle at the inclination survey points above the grid nodes, and the well depth and inclination angle at the inclination survey points below the grid nodes.

[0054] Specifically, the well inclination angle at the grid node is calculated using the linear interpolation method based on the inclination survey data, including: using the well depth and well inclination angle at the inclination survey point above the grid node, and the well depth and well inclination angle at the inclination survey point below the grid node, to calculate the well inclination angle at the grid node:

[0055] Where θ is the well inclination angle at the grid node; D m is the well depth at the grid node; θ1 is the well inclination angle at the inclination measurement point above the grid node; D m,1 is the well depth at the inclination measurement point above the grid node; θ2 is the well inclination angle at the inclination measurement point below the grid node; D m,2 is the well depth at the inclination survey point below the grid node.

[0056] For the above S104, the parameter data also includes, for example: the total heat transfer coefficient of the cement sheath, casing and annular fluid, the total heat transfer coefficient of the drill pipe and the fluid in the pipe, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, test temperature value, test pressure value, annular drilling fluid flow rate, inclination data, drilling fluid density at test temperature value and test pressure value, drilling fluid yield stress at test temperature value and test pressure value, drilling fluid plastic viscosity at test temperature value and test pressure value, drilling fluid specific heat capacity at test temperature value and test pressure value, inlet drilling fluid temperature, formation specific heat capacity, formation thermal conductivity at test temperature value and test pressure value, surface formation temperature, geothermal gradient and total well depth, preset point well depth, inlet drilling fluid temperature, drilling fluid flow rate, and annular cross-sectional area. FIG3 is a flowchart of a method for determining the tripping wellbore pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the length of the infinitesimal segment, the well inclination angle at the grid node, and parameter data, provided by an embodiment of the present invention. The method includes: for each grid node, executing the following process:

[0057] S301: Calculate the drilling fluid density at the preset pressure value and preset temperature value, the drilling fluid yield stress at the preset pressure value and preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and preset temperature value, the drilling fluid specific heat capacity at the preset pressure value and preset temperature value, and the formation thermal conductivity at the preset pressure value and preset temperature value based on the preset pressure value and preset temperature value of the grid node.

[0058] As shown in FIG4 , the calculation of the drilling fluid density at a preset pressure value and a preset temperature value, the drilling fluid yield stress at a preset pressure value and a preset temperature value, the drilling fluid plastic viscosity at a preset pressure value and a preset temperature value, the drilling fluid specific heat capacity at a preset pressure value and a preset temperature value, and the formation thermal conductivity at a preset pressure value and a preset temperature value includes:

[0059] S401: Calculate the drilling fluid density at the preset temperature value and the preset pressure value according to the test temperature value, the test pressure value, the drilling fluid density at the test temperature value and the test pressure value, the preset temperature, and the preset pressure.

[0060] In one embodiment of the present invention, the drilling fluid density at the preset temperature value and the preset pressure value is calculated based on the test temperature value, the test pressure value, the drilling fluid density at the test temperature value and the test pressure value, the preset temperature, and the preset pressure, including:

[0061] The following formula is used to calculate the drilling fluid density at the preset temperature and pressure values ​​based on the test temperature, test pressure, drilling fluid density at the test temperature and test pressure values, preset temperature, and preset pressure: ρ = ρ0 + [A1(T-T0) + A2(P-P0)]

[0062] Wherein, ρ is the drilling fluid density at the preset temperature and pressure values, ρ0 is the drilling fluid density at the test temperature and pressure values, T0 is the test temperature value, P0 is the test pressure value, T is the preset temperature value, P is the preset pressure value, and A1 and A2 are drilling fluid characteristic parameters.

[0063] Specifically, the drilling fluid characteristic parameters are constant values ​​determined historically based on the drilling fluid characteristics. In one embodiment of the present invention, A1 = -0.71603, A2 = 4.12172 × 10 -7 .

[0064] S402: Calculating the yield stress of the drilling fluid at a preset temperature value and a preset pressure value according to the test temperature value, the test pressure value, and the yield stress of the drilling fluid at the test temperature value and the test pressure value.

[0065] In one embodiment of the present invention, the yield stress of the drilling fluid at a preset temperature value and a preset pressure value is calculated based on the test temperature value, the test pressure value, and the yield stress of the drilling fluid at the test temperature value and the test pressure value, including:

[0066] The following formula is used to calculate the yield stress of the drilling fluid at the preset temperature and pressure values ​​based on the test temperature, test pressure, and yield stress of the drilling fluid at the test temperature and test pressure values:

[0067] Among them, τ y is the yield stress of the drilling fluid at the preset temperature and pressure, τ y,0 is the yield stress of the drilling fluid under the test temperature and test pressure values, and α1, β1, γ1, δ1, and ε1 are the characteristic parameters of the drilling fluid.

[0068] In one embodiment of the present invention, α1 = -1.01229 × 10 -2 , β1=-1.03560×10 -4 ,γ1=5.08647×10 -3 ,δ1=-5.92252×10 -5 ,ε1=1.28569×10 -4 .

[0069] S403: Calculating the plastic viscosity of the drilling fluid at the preset temperature value and the preset pressure value according to the preset test temperature value, the test pressure value, and the plastic viscosity of the drilling fluid at the test temperature value and the test pressure value.

[0070] In one embodiment of the present invention, the plastic viscosity of the drilling fluid at the preset temperature value and the preset pressure value is calculated based on the preset test temperature value, the test pressure value, and the plastic viscosity of the drilling fluid at the test temperature value and the test pressure value, including:

[0071] The plastic viscosity of the drilling fluid at the preset temperature and pressure values ​​is calculated using the following formula based on the preset test temperature, test pressure, and the plastic viscosity of the drilling fluid at the test temperature and test pressure values:

[0072] Among them, μ p is the plastic viscosity of the drilling fluid at the preset temperature and pressure, μ p,0 is the plastic viscosity of the drilling fluid at the test temperature and test pressure values, and α2, β2, γ2, δ2, and ε2 are the characteristic parameters of the drilling fluid.

[0073] In one embodiment of the present invention, α2 = -3.26140 × 10 -2 , β2=2.38849×10 -4 ,γ2=1.98767×10 -2 ,δ2=4.75823×10 -5 ,ε2=-2.44399×10 -4 .

[0074] S404: Calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​according to the preset temperature value.

[0075] In one embodiment of the present invention, calculating the specific heat capacity of the drilling fluid at the preset temperature and pressure according to the preset temperature includes:

[0076] The following formula is used to calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​according to the preset temperature value: fl =a+bT+cT -2

[0077] Among them, c fl is the specific heat capacity of the drilling fluid at the preset temperature T, and a, b, and c are the characteristic parameters of the drilling fluid.

[0078] In one embodiment of the present invention, a=4114.83672, b=1.12275, and c=-14.55477.

[0079] S405: Calculate the thermal conductivity of the formation at the preset temperature value according to the preset temperature value.

[0080] In one embodiment of the present invention, calculating the formation thermal conductivity at the preset temperature value according to the preset temperature value includes:

[0081] The following formula is used to calculate the thermal conductivity of the formation at the preset temperature value: k e =k e,0 (1+βT)

[0082] Among them, k e is the thermal conductivity of the formation at the preset temperature T, k e,0 is the thermal conductivity of the formation at 0℃, and β3 is the formation characteristic parameter.

[0083] Specifically, the formation characteristic parameter is a constant value determined historically based on formation characteristics.

[0084] S302: Calculate the calculated temperature value of the grid node based on the energy conservation equation, the specific heat capacity of the drilling fluid at a preset pressure value and a preset temperature value, the thermal conductivity of the formation at a preset pressure value and a preset temperature value, the total heat transfer coefficient of the cement sheath, casing, and annulus fluid, the total heat transfer coefficient of the drill pipe and the fluid in the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the inner radius of the drill pipe, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth.

[0085] In one embodiment of the present invention, a calculated temperature value of a grid node is calculated based on an energy conservation equation, a drilling fluid specific heat capacity at a preset pressure value and a preset temperature value, a formation thermal conductivity at a preset pressure value and a preset temperature value, a total heat transfer coefficient of the cement sheath, casing, and annular fluid, a total heat transfer coefficient of the drill pipe and the fluid in the pipe, a dimensionless temperature, a drilling fluid mass flow rate, a wellbore radius, an inner radius of the drill pipe, an inlet drilling fluid temperature, a surface formation temperature, a geothermal gradient, and a total well depth. The calculation includes: using the energy conservation equation, the drilling fluid specific heat capacity at a preset pressure value and a preset temperature value, and the formation thermal conductivity at a preset pressure value and a preset temperature value to obtain the following calculated temperature value calculation formula; and determining the calculated temperature value based on the total heat transfer coefficient of the cement sheath, casing, and annular fluid, the total heat transfer coefficient of the drill pipe and the fluid in the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the inner radius of the drill pipe, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth using the following calculated temperature value calculation formula:

[0086] Among them, T cal To calculate the temperature value, the boundary condition is T t | z＝0 =T ti , Tti is the inlet drilling fluid temperature, T es is the surface formation temperature, g G is the geothermal gradient, L is the total well depth c fl is the specific heat capacity of the drilling fluid at the preset pressure and temperature, k e is the formation thermal conductivity under the test temperature and pressure, U a is the total heat transfer coefficient among cement sheath, casing and annulus fluid, U t is the total heat transfer coefficient between the drill pipe and the fluid in the pipe, T D is the dimensionless temperature, w is the drilling fluid mass flow rate, r w is the wellbore radius, r t is the inner radius of the drill pipe, and π is the pi.

[0087] Specifically, the energy conservation equation of drilling fluid is:

[0088] Among them, T cal To calculate the temperature value (℃), T t is the drilling fluid temperature in the pipe (℃), T ei is the formation temperature (℃), c fl is the specific heat capacity of drilling fluid at the preset pressure and temperature (J / (kg·℃)), c e is the formation specific heat capacity (J / (kg·℃)), k e is the formation thermal conductivity (W / (m·℃)) at the test temperature and pressure values, U a is the total heat transfer coefficient among cement sheath, casing and annulus fluid (W / (m 2 ℃)), U t is the total heat transfer coefficient between the drill pipe and the fluid in the pipe (W / (m 2 ℃)), T D is the dimensionless temperature, t D is the dimensionless cycle time, t is the cycle time (h), w is the drilling fluid mass flow rate (kg / s), ρ e is the formation density (kg / m 3 ), z is the well depth (m), r w is the wellbore radius (m), r t is the inner radius of the drill pipe (m), and π is the pi.

[0089] According to the boundary conditions of the above energy conservation equation: T t | z＝0 =T ti , Perform analysis to obtain the above temperature calculation formula.

[0090] S303: Determine a temperature error value according to a preset temperature value and a calculated temperature value.

[0091] In one embodiment of the present invention, the temperature error value is determined using the following formula based on the preset temperature value and the calculated temperature value:

[0092] Among them, T cal To calculate the temperature value, T ass is the preset temperature value, and m1 is the temperature error value.

[0093] S304: When the temperature error value is less than the first error threshold, the calculated pressure value of the grid node is calculated based on the mass conservation equation, the momentum conservation equation, the drilling fluid density at the preset temperature value and the preset pressure value, the drilling fluid yield stress at the preset pressure value and the preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and the preset temperature value, the annular drilling fluid flow rate, the annular cross-sectional area, the well inclination angle at the grid node, and the microelement segment length.

[0094] In one embodiment of the present invention, a calculated pressure value of a grid node is calculated based on a mass conservation equation and a momentum conservation equation, a drilling fluid density at a preset temperature and a preset pressure value, a drilling fluid yield stress at a preset pressure and a preset temperature value, a drilling fluid plastic viscosity at a preset pressure and a preset temperature value, an annular drilling fluid flow rate, an annular cross-sectional area, a well deviation angle at a grid node, and a microelement segment length. The calculation includes: a fluctuating pressure per unit length of the annular drilling fluid obtained based on the drilling fluid density at a preset temperature and a preset pressure value, the drilling fluid yield stress at a preset pressure and a preset temperature value, and the drilling fluid plastic viscosity at a preset pressure and a preset temperature value; the following calculated pressure value calculation formula is obtained based on the mass conservation equation and the momentum conservation equation; and the calculated pressure value is determined using the following calculated pressure value calculation formula based on the drilling fluid density at a preset temperature and a preset pressure value, the annular drilling fluid flow rate, the annular cross-sectional area, the well deviation angle at a grid node, and the microelement segment length:

[0095] Among them, P cal To calculate the pressure value, i represents the i-th grid node, ρ is the drilling fluid density at the preset temperature and pressure, V a is the annular drilling fluid velocity, A a is the annular cross-sectional area (m 2 ), P a To calculate the pressure value, P Surge,a is the fluctuating pressure per unit length of the annular drilling fluid, g is the acceleration of gravity, θ is the well inclination angle at the grid node, and Δz is the length of the microelement segment.

[0096] Specifically, the mass conservation equation for drilling fluid flow is:

[0097] Where ρ is the drilling fluid density (kg / m 3 ), V a is the annular drilling fluid velocity (m / s), A a is the annular cross-sectional area (m 2 ), z is the well depth (m)

[0098] The momentum conservation equation for drilling fluid flow is:

[0099] Among them, P cal To calculate the pressure value (Pa), P Surge,a is the fluctuating pressure per unit length of the annular drilling fluid (Pa / m), g is the acceleration due to gravity (9.81m / s 2 ), θ is the well inclination angle (°).

[0100] The above mass conservation equation and momentum conservation equation are discretely solved using the finite difference method to obtain the calculation formula for the pressure value:

[0101] In addition, the fluctuating pressure per unit length of the annular drilling fluid obtained based on the drilling fluid density at a preset temperature value and a preset pressure value, the drilling fluid yield stress at a preset pressure value and a preset temperature value, and the drilling fluid plastic viscosity at a preset pressure value and a preset temperature value, for example, includes:

[0102] (1) Fluid flow state judgment

[0103] When Re a >Re a,c When Re a ≤Re a,c When , the annular flow is laminar.

[0104] Among them: Re a is the annular fluid Reynolds number, D w is the inner diameter of the wellbore (m), D d,o is the outer diameter of the drill pipe (m), ρ is the density of the drilling fluid at the preset pressure and temperature (kg / m 3 ), μ p is the plastic viscosity of the drilling fluid at the preset pressure and temperature (Pa·s).

[0105] Among them: Re a,c is the critical Reynolds number of the annular fluid, τ y is the yield stress of drilling fluid at preset pressure and temperature (Pa), τ wis the yield stress of drilling fluid on the outer wall of drill pipe (Pa), and He is the Hedstrom number.

[0106] (2) Calculation of laminar flow pressure fluctuation (Re a ≤Re a,c )

[0107] Where: P Surge,a is the fluctuating pressure per unit length of the annular drilling fluid (Pa / m).

[0108] (3) Calculation of turbulent fluctuation pressure (Re a >Re a,c )

[0109] S305: Determine a pressure error value according to the preset pressure value and the calculated pressure value.

[0110] In one embodiment of the present invention, the pressure error value is determined using the following formula based on the preset pressure value and the calculated pressure value:

[0111] Among them, P cal To calculate the pressure value, P ass is the preset pressure value, and m2 is the pressure error value.

[0112] S306: When the pressure error value is less than the second error threshold, the calculated temperature value is determined as the actual pressure value of the grid node, and the process ends.

[0113] S307: When the pressure error value is not less than the second error threshold, the calculated pressure value is used as the preset pressure value, and the process returns to S304.

[0114] S308: When the temperature error value is not less than the first error threshold, return to 301.

[0115] The present invention also provides an apparatus for determining wellbore pressure during tripping of a high-temperature, high-pressure well, as described in the following embodiments. Because the principles underlying the apparatus are similar to those of the method for determining wellbore pressure during tripping of a high-temperature, high-pressure well, the implementation of the apparatus can be referenced to the implementation of the method for determining wellbore pressure during tripping of a high-temperature, high-pressure well, and any repetitive details will not be repeated.

[0116] FIG5 is a schematic diagram of a device for determining wellbore pressure during tripping of a high-temperature and high-pressure well according to an embodiment of the present invention, comprising:

[0117] The parameter acquisition module 501 is used to acquire parameter data during the tripping operation; wherein the parameter data at least includes: inclination measurement data and preset well depth;

[0118] The first processing module 502 is used to divide the grid nodes according to the preset number of nodes and the preset well depth, and obtain the length of the micro-element segment;

[0119] The second processing module 503 is used to determine the well inclination angle at the grid node according to the inclination measurement data;

[0120] The third processing module 504 is used to determine the tripping wellbore pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the length of the infinitesimal segment, the well inclination angle at the grid node, and parameter data.

[0121] In a possible implementation, the first processing module is specifically configured to divide the grid nodes into equal spacing or variable spacing according to a preset number of nodes and a total well depth, to obtain an initial grid node matrix;

[0122] The preset well depth is added to the initial grid node matrix to obtain the final divided grid node matrix; wherein each element value in the grid node matrix represents the well depth corresponding to a grid node;

[0123] The length of the microelement segment is determined based on the preset number of nodes and the total well depth.

[0124] In a possible implementation, the second processing module is specifically configured to calculate the well inclination angle at the grid node using a linear interpolation method based on the inclination survey data.

[0125] In a possible implementation, the inclination survey data includes: the well depth and well inclination angle at the inclination survey point above the grid node, and the well depth and well inclination angle at the inclination survey point below the grid node;

[0126] The second processing module is specifically configured to calculate the well inclination angle at the grid node using the well depth and well inclination angle at the inclination measurement point above the grid node, and the well depth and well inclination angle at the inclination measurement point below the grid node using the following formula:

[0127] Where θ is the well inclination angle at the grid node; D m is the well depth at the grid node; θ1 is the well inclination angle at the inclination measurement point above the grid node; D m,1 is the well depth at the inclination measurement point above the grid node; θ2 is the well inclination angle at the inclination measurement point below the grid node; D m,2 is the well depth at the inclination survey point below the grid node.

[0128] In a possible embodiment, the parameter data further includes: a total heat transfer coefficient between the cement sheath, the casing, and the annular fluid, a total heat transfer coefficient between the drill pipe and the fluid in the pipe, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, test temperature value, test pressure value, annular drilling fluid flow rate, inclination data, drilling fluid density at test temperature value and test pressure value, drilling fluid yield stress at test temperature value and test pressure value, drilling fluid plastic viscosity at test temperature value and test pressure value, drilling fluid specific heat capacity at test temperature value and test pressure value, inlet drilling fluid temperature, formation specific heat capacity, formation thermal conductivity at test temperature value and test pressure value, surface formation temperature, geothermal gradient and total well depth, preset point well depth, inlet drilling fluid temperature, drilling fluid flow rate, and annular cross-sectional area;

[0129] The third processing module is specifically configured to execute the following process for each grid node:

[0130] Calculate, based on the preset pressure value, preset temperature value, and parameter data of the grid nodes, the drilling fluid density at the preset pressure value and preset temperature value, the drilling fluid yield stress at the preset pressure value and preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and preset temperature value, the drilling fluid specific heat capacity at the preset pressure value and preset temperature value, and the formation thermal conductivity at the preset pressure value and preset temperature value;

[0131] Calculate the calculated temperature value of the grid node based on the energy conservation equation, the specific heat capacity of the drilling fluid at a preset pressure value and a preset temperature value, the thermal conductivity of the formation at a preset pressure value and a preset temperature value, the total heat transfer coefficient of the cement sheath, the casing, and the annulus fluid, the total heat transfer coefficient of the drill pipe and the fluid in the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the inner radius of the drill pipe, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth;

[0132] Determine a temperature error value according to a preset temperature value and a calculated temperature value;

[0133] When the temperature error value is less than the first error threshold, the calculated pressure value of the grid node is calculated according to the mass conservation equation and the momentum conservation equation, the drilling fluid density at the preset temperature value and the preset pressure value, the drilling fluid yield stress at the preset pressure value and the preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and the preset temperature value, the annular drilling fluid flow rate, the annular cross-sectional area, the well inclination angle at the grid node, and the microelement segment length;

[0134] Determine a pressure error value based on a preset pressure value and a calculated pressure value;

[0135] When the pressure error value is less than a second error threshold, determining the calculated temperature value as the actual pressure value of the grid node;

[0136] When the pressure error value is not less than the second error threshold, using the calculated pressure value as the preset pressure value, and returning to the step of calculating the calculated pressure value of the grid node according to the mass conservation equation, the momentum conservation equation, the preset temperature value, and the drilling fluid density at the preset pressure value;

[0137] When the temperature error value is not less than the first error threshold, the step of calculating, based on the preset pressure value, preset temperature value, and parameter data of the grid node, the drilling fluid density at the preset pressure value and preset temperature value, the drilling fluid yield stress at the preset pressure value and preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and preset temperature value, the drilling fluid specific heat capacity at the preset pressure value and preset temperature value, and the formation thermal conductivity at the preset pressure value and preset temperature value is returned to.

[0138] In one possible implementation, the third processing module is specifically configured to calculate the drilling fluid density at a preset temperature value and a preset pressure value based on the test temperature value, the test pressure value, the drilling fluid density at the test temperature value and the test pressure value, the preset temperature, and the preset pressure;

[0139] Calculating the yield stress of the drilling fluid at a preset temperature and a preset pressure value according to the test temperature, the test pressure, and the yield stress of the drilling fluid at the test temperature and the test pressure;

[0140] Calculating the plastic viscosity of the drilling fluid at the preset temperature and the preset pressure according to the preset test temperature, the test pressure, and the plastic viscosity of the drilling fluid at the test temperature and the test pressure;

[0141] Calculating the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​according to the preset temperature value;

[0142] According to the preset temperature value, the thermal conductivity of the formation at the preset temperature value is calculated.

[0143] In one possible implementation, the third processing module is specifically configured to calculate the drilling fluid density using the following formula: ρ = ρ0 + [A1(T-T0) + A2(P-P0)]

[0144] Wherein, ρ is the drilling fluid density at the preset temperature and pressure values, ρ0 is the drilling fluid density at the test temperature and pressure values, T0 is the test temperature value, P0 is the test pressure value, T is the preset temperature value, P is the preset pressure value, and A1 and A2 are drilling fluid characteristic parameters.

[0145] In a possible implementation, the third processing module is specifically configured to calculate the drilling fluid yield stress using the following formula:

[0146] Among them, τ yis the yield stress of the drilling fluid at the preset temperature and pressure, τ y,0 is the yield stress of the drilling fluid under the test temperature and test pressure values, and α1, β1, γ1, δ1, and ε1 are the characteristic parameters of the drilling fluid.

[0147] In one possible implementation, the third processing module is specifically configured to calculate the plastic viscosity of the drilling fluid at a preset temperature value and a preset pressure value based on the preset test temperature value, the test pressure value, and the plastic viscosity of the drilling fluid at the test temperature value and the test pressure value using the following formula:

[0148] Among them, μ p is the plastic viscosity of the drilling fluid at the preset temperature and pressure, μ p,0 is the plastic viscosity of the drilling fluid at the test temperature and test pressure values, and α2, β2, γ2, δ2, and ε2 are the characteristic parameters of the drilling fluid.

[0149] In a possible implementation, the third processing module is specifically configured to calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​according to the preset temperature value using the following formula: fl =a+bT+cT -2

[0150] Among them, c fl is the specific heat capacity of the drilling fluid at the preset temperature T, and a, b, and c are the characteristic parameters of the drilling fluid.

[0151] In a possible implementation, the third processing module is specifically configured to calculate the formation thermal conductivity at the preset temperature value using the following formula according to the preset temperature value: k e =k e,0 (1+βT)

[0152] Among them, k e is the thermal conductivity of the formation at the preset temperature T, k e,0 is the thermal conductivity of the formation at 0℃, and β3 is the formation characteristic parameter.

[0153] In one possible embodiment, the third processing module is specifically configured to use the energy conservation equation, the specific heat capacity of the drilling fluid at a preset pressure value and a preset temperature value, and the thermal conductivity of the formation at a preset pressure value and a preset temperature value to obtain the following calculated temperature value calculation formula, and determine the calculated temperature value using the following calculated temperature value calculation formula based on the total heat transfer coefficient between the cement sheath, the casing, and the annular fluid, the total heat transfer coefficient between the drill pipe and the fluid in the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the inner radius of the drill pipe, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth:

[0154] Among them, T cal To calculate the temperature value, the boundary condition is T t | z＝0 =T ti , T ti is the inlet drilling fluid temperature, T es is the surface formation temperature, g G is the geothermal gradient, L is the total well depth, c fl is the specific heat capacity of the drilling fluid at the preset pressure and temperature, k e is the formation thermal conductivity under the test temperature and pressure, U a is the total heat transfer coefficient among cement sheath, casing and annulus fluid, U t is the total heat transfer coefficient between the drill pipe and the fluid in the pipe, T D is the dimensionless temperature, w is the drilling fluid mass flow rate, r w is the wellbore radius, r t is the inner radius of the drill pipe, and π is the pi.

[0155] In a possible implementation, the third processing module is specifically configured to determine the temperature error value using the following formula according to the preset temperature value and the calculated temperature value:

[0156] Among them, T cal To calculate the temperature value, T ass is the preset temperature value, and m1 is the temperature error value.

[0157] In one possible embodiment, the third processing module is specifically configured to obtain the fluctuating pressure per unit length of the annular drilling fluid based on the drilling fluid density at a preset temperature and a preset pressure, the drilling fluid yield stress at a preset pressure and a preset temperature, and the drilling fluid plastic viscosity at a preset pressure and a preset temperature; obtain the following calculated pressure value calculation formula based on the mass conservation equation and the momentum conservation equation; and determine the calculated pressure value using the following calculated pressure value calculation formula based on the drilling fluid density at the preset temperature and the preset pressure, the annular drilling fluid flow rate, the annular cross-sectional area, the well inclination angle at the grid node, and the microelement segment length:

[0158] Among them, P cal To calculate the pressure value, i represents the i-th grid node, ρ is the drilling fluid density at the preset temperature and pressure, V a is the annular drilling fluid velocity, A a is the annular cross-sectional area (m 2 ), P a To calculate the pressure value, P Surge,ais the fluctuating pressure per unit length of the annular drilling fluid, g is the acceleration of gravity, θ is the well inclination angle at the grid node, and Δz is the length of the microelement segment.

[0159] In a possible implementation, the third processing module is specifically configured to determine the pressure error value using the following formula according to the preset pressure value and the calculated pressure value:

[0160] Among them, P cal To calculate the pressure value, P ass is the preset pressure value, and m2 is the pressure error value.

[0161] Based on the aforementioned inventive concept, as shown in FIG6 , the present invention further proposes a computer device 600, comprising a memory 610, a processor 620, and a computer program 630 stored on the memory 610 and executable on the processor 620. When the processor 620 executes the computer program 630, the aforementioned method for determining the wellbore pressure during drilling of a high-temperature and high-pressure well is implemented.

[0162] An embodiment of the present invention further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well is implemented.

[0163] An embodiment of the present invention further provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the above-mentioned method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well.

[0164] In an embodiment of the present invention, parameter data is acquired during the tripping operation; the parameter data includes at least inclination data and a preset well depth; grid nodes are divided based on the preset number of nodes and the preset well depth, and the length of the microelement segment is obtained; the well inclination angle at the grid node is determined based on the inclination data; and the tripping wellbore pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, and energy conservation equation, the microelement segment length, the well inclination angle at the grid node, and the parameter data. This method takes into account the effects of high temperature and high pressure on drilling fluid properties, improves the accuracy of tripping wellbore pressure calculations, and improves the accuracy of wellbore pressure predictions, effectively meeting the requirements for accurate control of wellbore pressure during tripping in high-temperature and high-pressure wells, and ensuring safe and efficient tripping operations.

[0165] It will be understood by those skilled in the art that embodiments of the present invention may be provided as methods, systems, or computer program products. Thus, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware. Furthermore, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to magnetic disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0166] The present invention is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of processes and / or boxes in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device produce a device for implementing the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0167] These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce a product including an instruction device that implements the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0168] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, so that the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0169] The specific embodiments described above further illustrate the objectives, technical solutions and beneficial effects of the present invention in detail. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present invention should be included in the scope of protection of the present invention.

Claims

1. A method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well, characterized in that: include: Obtaining parameter data during the tripping operation; wherein the parameter data at least includes: inclination measurement data and well depth at a preset point; According to the preset number of nodes and the preset well depth, the grid nodes are divided and the length of the microelement segment is obtained; Determine the well inclination angle at the grid node according to the inclination survey data; The tripping wellbore pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, energy conservation equation, microelement segment length, well inclination angle at grid nodes, and parameter data.

2. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 1, characterized in that: According to the preset number of nodes and the preset well depth, the grid nodes are divided and the length of the microelement segment is obtained, including: According to the preset number of nodes and the total well depth, the grid nodes are divided by equal spacing or variable spacing to obtain an initial grid node matrix; The well depth of the preset point is added to the initial grid node matrix to obtain the final divided grid node matrix; wherein each element value in the grid node matrix represents the well depth corresponding to a grid node; The length of the microelement segment is determined based on the preset number of nodes and the total well depth.

3. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 1, characterized in that: Preset point well depth, including: The well depth at the casing shoe, the well depth at the drill string diameter change point, and the well depth at the abnormal formation pressure.

4. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 1, characterized in that: Determine the well inclination angle at the grid node based on the inclination survey data, including: Based on the inclination data, the linear interpolation method is used to calculate the well inclination angle at the grid node.

5. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 3, characterized in that: The inclination survey data include: the well depth and well inclination angle at the inclination survey point above the grid node, and the well depth and well inclination angle at the inclination survey point below the grid node; According to the inclination data, the linear interpolation method is used to calculate the well inclination angle at the grid node, including: The well depth and well inclination angle at the inclination point above the grid node, and the well depth and well inclination angle at the inclination point below the grid node are calculated using the following formula: Where θ is the well inclination angle at the grid node; D m is the well depth at the grid node; θ1 is the measured value above the grid node Well inclination angle at the inclination point; D m,1 is the well depth at the inclination point above the grid node; θ2 is the well inclination angle at the inclination point below the grid node; D m,2 It is the well depth at the inclinometer point below the grid node.

6. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 1, characterized in that: The parameter data also include: the total heat transfer coefficient of cement sheath, casing and annular fluid, the total heat transfer coefficient of drill pipe and fluid in the pipe, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, test temperature value, test pressure value, annular drilling fluid flow rate, inclination data, drilling fluid density at test temperature value and test pressure value, drilling fluid yield stress at test temperature value and test pressure value, drilling fluid plastic viscosity at test temperature value and test pressure value, drilling fluid specific heat capacity at test temperature value and test pressure value, inlet drilling fluid temperature, formation specific heat capacity, formation thermal conductivity at test temperature value and test pressure value, surface formation temperature, geothermal gradient and total well depth, preset point well depth, inlet drilling fluid temperature, drilling fluid flow rate, annular cross-sectional area; According to the mass conservation equation, momentum conservation equation, energy conservation equation, microelement length, well inclination angle at grid node, and parameter data, the tripping wellbore pressure under temperature-pressure coupling is determined, including: For each grid node, perform the following process: According to the preset pressure value, preset temperature value and parameter data of the grid node, the drilling fluid density at the preset pressure value and preset temperature value, the drilling fluid yield stress at the preset pressure value and preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and preset temperature value, the drilling fluid specific heat capacity at the preset pressure value and preset temperature value and the formation thermal conductivity at the preset pressure value and preset temperature value are calculated; Calculate the calculated temperature value of the grid node according to the energy conservation equation, the specific heat capacity of the drilling fluid at a preset pressure value and a preset temperature value, the thermal conductivity of the formation at a preset pressure value and a preset temperature value, the total heat transfer coefficient of the cement sheath, the casing and the annulus fluid, the total heat transfer coefficient of the drill pipe and the fluid in the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the inner radius of the drill pipe, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth; Determine the temperature error value according to the preset temperature value and the calculated temperature value; When the temperature error value is less than the first error threshold, the calculated pressure value of the grid node is calculated according to the mass conservation equation, the momentum conservation equation, the drilling fluid density at the preset temperature value and the preset pressure value, the drilling fluid yield stress at the preset pressure value and the preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and the preset temperature value, the annular drilling fluid flow rate, the annular cross-sectional area, the well inclination angle at the grid node, and the microelement segment length; Determine a pressure error value according to a preset pressure value and a calculated pressure value; When the pressure error value is less than a second error threshold, determining the calculated temperature value as the actual pressure value of the grid node; When the pressure error value is not less than the second error threshold, the calculated pressure value is used as the preset pressure value, and the drilling fluid density under the mass conservation equation, momentum conservation equation, preset temperature value and preset pressure value is returned. Steps for calculating pressure values ​​of grid nodes; When the temperature error value is not less than the first error threshold, return to the step of calculating the drilling fluid density at the preset pressure value and the preset temperature value, the drilling fluid yield stress at the preset pressure value and the preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and the preset temperature value, the drilling fluid specific heat capacity at the preset pressure value and the preset temperature value, and the formation thermal conductivity at the preset pressure value and the preset temperature value according to the preset pressure value, the preset temperature value and the preset temperature value of the grid node.

7. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 6, characterized in that: Calculating the drilling fluid density at a preset pressure value and a preset temperature value, the drilling fluid yield stress at a preset pressure value and a preset temperature value, the drilling fluid plastic viscosity at a preset pressure value and a preset temperature value, the drilling fluid specific heat capacity at a preset pressure value and a preset temperature value, and the formation thermal conductivity at a preset pressure value and a preset temperature value, including: Calculate the density of the drilling fluid at the preset temperature value and the preset pressure value according to the test temperature value, the test pressure value, the density of the drilling fluid at the test temperature value and the test pressure value, the preset temperature, and the preset pressure; Calculate the yield stress of the drilling fluid at a preset temperature value and a preset pressure value according to the test temperature value, the test pressure value, and the yield stress of the drilling fluid at the test temperature value and the test pressure value; Calculating the plastic viscosity of the drilling fluid at the preset temperature value and the preset pressure value according to the preset test temperature value, the test pressure value, and the plastic viscosity of the drilling fluid at the test temperature value and the test pressure value; According to the preset temperature value, calculating the specific heat capacity of the drilling fluid at the preset temperature value and the preset pressure value; According to the preset temperature value, the thermal conductivity of the formation at the preset temperature value is calculated.

8. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 7, characterized in that: According to the test temperature value, the test pressure value, the drilling fluid density at the test temperature value and the test pressure value, the preset temperature, and the preset pressure, the drilling fluid density at the preset temperature value and the preset pressure value is calculated, including: The following formula is used to calculate the drilling fluid density at the preset temperature value and the preset pressure value based on the test temperature value, the test pressure value, the drilling fluid density at the test temperature value and the test pressure value, the preset temperature, and the preset pressure: ρ=ρ0+[A1(T-T0)+A2(P-P0)] Among them, ρ is the drilling fluid density at the preset temperature value and the preset pressure value, ρ0 is the drilling fluid density at the test temperature value and the test pressure value, T0 is the test temperature value, P0 is the test pressure value, T is the preset temperature value, P is the preset pressure value, and A1 and A2 are drilling fluid characteristic parameters.

9. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 7, characterized in that: According to the test temperature value, the test pressure value, and the yield stress of the drilling fluid under the test temperature value and the test pressure value, the yield stress of the drilling fluid under the preset temperature value and the preset pressure value is calculated, including: The following formula is used to calculate the yield stress of the drilling fluid at the preset temperature value and the preset pressure value based on the test temperature value, the test pressure value, and the yield stress of the drilling fluid at the test temperature value and the test pressure value: Among them, τ y is the yield stress of the drilling fluid at the preset temperature and pressure, τ y,0 is the yield stress of drilling fluid under test temperature and test pressure, and α1, β1, γ1, δ1, and ε1 are the characteristic parameters of drilling fluid.

10. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 7, characterized in that: According to the preset test temperature value, the test pressure value, and the plastic viscosity of the drilling fluid at the test temperature value and the test pressure value, the plastic viscosity of the drilling fluid at the preset temperature value and the preset pressure value is calculated, including: The following formula is used to calculate the plastic viscosity of the drilling fluid at the preset temperature value and the preset pressure value according to the preset test temperature value, the test pressure value, and the plastic viscosity of the drilling fluid at the test temperature value and the test pressure value: Among them, μ p is the plastic viscosity of the drilling fluid at the preset temperature and pressure, μ p,0 is the plastic viscosity of the drilling fluid at the test temperature and test pressure values, and α2, β2, γ2, δ2, and ε2 are the characteristic parameters of the drilling fluid.

11. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 7, characterized in that: According to the preset temperature value, the specific heat capacity of the drilling fluid at the preset temperature value and the preset pressure value is calculated, including: The following formula is used to calculate the specific heat capacity of the drilling fluid at the preset temperature value and the preset pressure value according to the preset temperature value: c fl =a+bT+cT -2 Among them, c fl is the specific heat capacity of the drilling fluid at the preset temperature value T, and a, b, c are the characteristic parameters of the drilling fluid.

12. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 7, characterized in that: According to the preset temperature value, the formation thermal conductivity under the preset temperature value is calculated, including: The following formula is used to calculate the formation thermal conductivity at the preset temperature value according to the preset temperature value: k e =k e,0 (1+βT) Among them, k e is the thermal conductivity of the formation at the preset temperature T, k e,0 is the thermal conductivity of the formation at 0℃, and β3 is the formation characteristic parameter.

13. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 6, characterized in that: According to the energy conservation equation, the specific heat capacity of the drilling fluid at the preset pressure value and the preset temperature value, the thermal conductivity of the formation at the preset pressure value and the preset temperature value, the total heat transfer coefficient of the cement sheath, the casing and the annulus fluid, the total heat transfer coefficient of the drill pipe and the fluid in the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the inner radius of the drill pipe, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth, the calculated temperature value of the grid node is calculated, including: Using the energy conservation equation, the preset pressure value and the specific heat capacity of the drilling fluid at the preset temperature value, the preset pressure value and the preset temperature value, the The following temperature calculation formula is obtained based on the total heat transfer coefficient between cement sheath, casing and annulus fluid, the total heat transfer coefficient between drill pipe and fluid in the pipe, dimensionless temperature, drilling fluid mass flow rate, borehole radius, drill pipe inner radius, inlet drilling fluid temperature, surface formation temperature, geothermal gradient, and total well depth: Among them, T cal To calculate the temperature value, the boundary condition is T t | z＝0 =T ti , T ti is the inlet drilling fluid temperature, T es is the surface temperature, g G is the geothermal gradient, L is the total well depth, c fl is the specific heat capacity of the drilling fluid at the preset pressure and temperature, k e is the formation thermal conductivity at the test temperature and pressure, U a is the total heat transfer coefficient between cement sheath, casing and annulus fluid, U t is the total heat transfer coefficient between the drill pipe and the fluid in the pipe, T D is the dimensionless temperature, w is the drilling fluid mass flow rate, r w is the wellbore radius, r t is the inner radius of the drill pipe, and π is the pi.

14. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 6, characterized in that: The temperature error value is determined according to the preset temperature value and the calculated temperature value, including: The temperature error value is determined by the following formula based on the preset temperature value and the calculated temperature value: Among them, T cal To calculate the temperature value, T ass is the preset temperature value, and m1 is the temperature error value.

15. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 6, characterized in that: According to the mass conservation equation and momentum conservation equation, the drilling fluid density at the preset temperature value and the preset pressure value, the drilling fluid yield stress at the preset pressure value and the preset temperature value, the drilling fluid plastic viscosity at the preset pressure value and the preset temperature value, the annular drilling fluid flow rate, the annular cross-sectional area, the well inclination angle at the grid node, and the microelement segment length, the calculated pressure value of the grid node is calculated, including: Fluctuating pressure per unit length of the annular drilling fluid obtained according to the drilling fluid density at a preset temperature value and a preset pressure value, the drilling fluid yield stress at a preset pressure value and a preset temperature value, and the drilling fluid plastic viscosity at a preset pressure value and a preset temperature value; According to the mass conservation equation and momentum conservation equation, the following calculation formula for the calculated pressure value is obtained. According to the drilling fluid density, annular drilling fluid velocity, annular cross-sectional area, well inclination angle at the grid node, and micro-element length at the preset temperature and preset pressure values, the calculated pressure value is determined using the following calculation formula for the calculated pressure value: Among them, P cal To calculate the pressure value, i represents the i-th grid node, ρ is the drilling fluid density at the preset temperature and pressure, V a is the annular drilling fluid velocity, A a is the cross-sectional area of ​​the annulus, P a To calculate the pressure value, P Surge,a is the fluctuating pressure per unit length of the annular drilling fluid, g is the gravitational acceleration, θ is the well inclination angle at the grid node, and Δz is the length of the microelement segment.

16. The method for determining the wellbore pressure during tripping of a high-temperature and high-pressure well according to claim 6, characterized in that: The pressure error value is determined according to the preset pressure value and the calculated pressure value, including: The pressure error value is determined based on the preset pressure value and the calculated pressure value using the following formula: Among them, P cal To calculate the pressure value, P ass is the preset pressure value, and m2 is the pressure error value.

17. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the method according to any one of claims 1 to 16 is implemented.

18. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the method according to any one of claims 1 to 16 is implemented.

19. A computer program product, characterized in that The computer program product comprises a computer program, and when the computer program is executed by a processor, the method according to any one of claims 1 to 16 is implemented.

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