Methods and devices for determining drilling pressure during high-temperature and high-pressure well tripping

Abstract

This invention discloses a method and apparatus for determining the tripping and running-in pressure in high-temperature and high-pressure wells, relating to the field of oil and gas drilling technology. The method includes: acquiring parameter data during tripping and running-in operations; dividing the well into grid nodes and obtaining the length of micro-segments based on a preset number of nodes and a preset well depth; determining the well inclination angle at the grid nodes based on inclination measurement data; and determining the tripping and running-in pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at the grid nodes, and parameter data. This method considers the effects of high temperature and high pressure on drilling fluid properties, improves the accuracy of tripping and running-in pressure calculation, enhances the accuracy of wellbore pressure prediction, effectively meets the requirements for accurate control of tripping and running-in pressure in high-temperature and high-pressure wells, and ensures safe and efficient tripping and running-in operations. This invention can improve the accuracy of tripping and running-in pressure calculation and the accuracy of wellbore pressure prediction.

Description

Technical Field

[0001] This invention relates to the field of oil and gas drilling technology, and in particular to a method and apparatus for determining the drilling pressure during high-temperature and high-pressure well tripping. Background Technology

[0002] This section is intended to provide background or context for the embodiments of the invention set forth in the claims. The description herein is not an admission that it is prior art simply because it is included in this section.

[0003] Deep formations are characterized by high temperature and pressure, and narrow drilling fluid safety density windows. With increasing efforts in the exploration and development of deep oil and gas resources, the requirements for wellbore pressure prediction during tripping and running-in / out operations are becoming increasingly stringent. Accurate prediction of wellbore pressure during tripping and running-in / out is of practical significance for ensuring drilling safety and improving operational efficiency.

[0004] Existing methods for calculating tripping and running-in wellbore pressure do not consider the interaction between wellbore temperature, wellbore pressure, and drilling fluid properties. For deep and ultra-deep wells, neglecting the effects of high temperature and pressure can lead to significant deviations in wellbore pressure predictions, causing wellbore pressure imbalances and resulting in complex situations such as well leakage and overflow. The low accuracy of existing methods for determining tripping and running-in wellbore pressure also poses significant safety risks during drilling operations. Summary of the Invention

[0005] This invention provides a method for determining the tripping pressure in high-temperature, high-pressure wells, thereby improving the accuracy of wellbore pressure prediction, effectively meeting the requirements for accurate control of tripping pressure in high-temperature, high-pressure wells, and ensuring safe and efficient tripping operations. The method includes:

[0006] Acquire parameter data during the tripping and running-out operations; the parameter data shall include at least: inclination measurement data and preset well depth;

[0007] Based on the preset number of nodes and preset well depth, the grid nodes are divided, and the length of the micro-element segment is obtained;

[0008] Determine the well inclination angle at the grid node based on the inclination measurement data;

[0009] Based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at grid nodes, and parameter data, the tripping pressure under temperature-pressure coupling is determined.

[0010] This invention also provides a device for determining wellbore pressure during tripping in high-temperature and high-pressure wells, to improve the accuracy of wellbore pressure prediction, effectively meet the requirements for accurate control of wellbore pressure during tripping in high-temperature and high-pressure wells, and ensure safe and efficient tripping operations. The device includes:

[0011] The parameter acquisition module is used to acquire parameter data during the tripping and running-out operations; the parameter data includes at least: inclination measurement data and preset well depth;

[0012] The first processing module is used to divide the grid nodes and obtain the length of the micro-element segment according to the preset number of nodes and the preset well depth.

[0013] The second processing module is used to determine the well inclination angle at the grid node based on the inclination data;

[0014] The third processing module is used to determine the tripping pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at grid nodes, and parameter data.

[0015] This 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, it implements the above-described method for determining drilling pressure during high-temperature and high-pressure well tripping.

[0016] This invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for determining drilling pressure during high-temperature and high-pressure well tripping.

[0017] This invention also provides a computer program product, which includes a computer program that, when executed by a processor, implements the above-described method for determining drilling pressure during high-temperature and high-pressure well tripping.

[0018] In this embodiment of the invention, parameter data during the tripping and tripping operation is acquired. This parameter data includes at least: inclination measurement data and a preset well depth; grid nodes are defined based on the preset number of nodes and the preset well depth, and the length of each micro-segment is obtained; the inclination angle at each grid node is determined based on the inclination measurement data; and the tripping and tripping wellbore pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, wellbore inclination angle at each grid node, and the parameter data. This approach considers the effects of high temperature and high pressure on the drilling fluid properties, improves the accuracy of tripping and tripping wellbore pressure calculation, enhances the accuracy of wellbore pressure prediction, effectively meets the requirements for accurate control of tripping and tripping wellbore pressure in high-temperature and high-pressure wells, and ensures safe and efficient tripping and tripping operations. Attached Figure Description

[0019] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. 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 effort. In the drawings:

[0020] Figure 1 This is a flowchart of a method for determining drilling pressure during high-temperature and high-pressure well tripping, provided in an embodiment of the present invention.

[0021] Figure 2 This is a flowchart of a method for dividing grid nodes and obtaining the length of micro-element segments based on a preset number of nodes and a preset well depth, provided in an embodiment of the present invention.

[0022] Figure 3 This is a flowchart of a method for determining the tripping pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at grid nodes, and parameter data, provided in an embodiment of the present invention.

[0023] Figure 4 This is a flowchart illustrating a method for determining drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity under preset pressure and temperature values, as provided in an embodiment of the present invention.

[0024] Figure 5 This is a schematic diagram of a high-temperature and high-pressure well tripping and drilling pressure determination device provided in an embodiment of the present invention;

[0025] Figure 6 This is a schematic diagram of a computer device provided in an embodiment of the present invention. Detailed Implementation

[0026] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings. Here, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but are not intended to limit the present invention.

[0027] The acquisition, storage, use, and processing of data in this application all comply with the relevant provisions of national laws and regulations.

[0028] In this document, the term "and / or" merely describes a relationship, indicating that three relationships can exist. For example, A and / or B can represent three cases: A alone, A and B simultaneously, and B alone. Furthermore, the term "at least one" in this document means any combination of at least two of any one or more elements. For example, including at least one of A, B, and C can mean including any one or more elements selected from the set consisting of A, B, and C.

[0029] In the description of this specification, the terms "comprising," "including," "having," and "containing" are open-ended terms, meaning that they include but are not limited to. The terms "an embodiment," "a specific embodiment," "some embodiments," and "for example," etc., refer to specific features, structures, or characteristics described in connection with that embodiment or example that are included in at least one embodiment or example of this application. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, or characteristics described can be combined in any suitable manner in one or more embodiments or examples. The order of steps involved in the various embodiments is used to illustrate the implementation of this application, and the order of steps is not limited and can be adjusted appropriately as needed.

[0030] Studies have revealed that deep formations are characterized by high temperature and pressure, and narrow drilling fluid safety density windows. With increasing efforts in the exploration and development of deep oil and gas resources, the requirements for wellbore pressure prediction during tripping operations are becoming increasingly stringent. Accurate prediction of wellbore pressure during tripping is of practical significance for ensuring drilling safety and improving operational efficiency.

[0031] Existing methods for calculating tripping and running-in wellbore pressure do not consider the interaction between wellbore temperature, wellbore pressure, and drilling fluid properties. For deep and ultra-deep wells, neglecting the effects of high temperature and pressure can lead to significant deviations in wellbore pressure predictions, causing wellbore pressure imbalances and resulting in complex situations such as well leakage and overflow. The low accuracy of existing methods for determining tripping and running-in wellbore pressure also poses significant safety risks during drilling operations.

[0032] Regarding the above research, such as Figure 1 As shown, this embodiment of the invention provides a method for determining the drilling pressure during tripping in high-temperature and high-pressure wells, including:

[0033] S101: Acquire parameter data during the tripping in and out of the well; the parameter data shall include at least: directional measurement data and preset well depth;

[0034] S102: Based on the preset number of nodes and the preset well depth, divide the grid into nodes and obtain the length of the micro-element segment;

[0035] S103: Determine the well inclination angle at the grid node based on the inclination data;

[0036] S104: Determine the tripping pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at grid nodes, and parameter data.

[0037] In this embodiment of the invention, parameter data during the tripping and tripping operation is acquired. This parameter data includes at least: inclination measurement data and a preset well depth. Based on the preset number of nodes and the preset well depth, grid nodes are divided, and the length of the micro-segment is obtained. The inclination angle at the grid node is determined based on the inclination measurement data. Based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at the grid node, and parameter data, the tripping and tripping wellbore pressure under temperature-pressure coupling is determined. This approach considers the effects of high temperature and high pressure on the drilling fluid properties, improves the accuracy of tripping and tripping wellbore pressure calculation, enhances the accuracy of wellbore pressure prediction, effectively meets the requirements for accurate control of tripping and tripping wellbore pressure in high-temperature and high-pressure wells, and ensures safe and efficient tripping and tripping operations.

[0038] The method for determining the drilling pressure during the tripping of high-temperature and high-pressure wells is explained in detail below.

[0039] Regarding the above S102, such as Figure 2 The diagram shows a flowchart of a method for dividing a grid into nodes and obtaining the length of a micro-element segment based on a preset number of nodes and a preset well depth, according to an embodiment of the present invention. The method includes:

[0040] S201: Based on the preset number of nodes and the total well depth, divide the grid nodes using equal or variable spacing methods to obtain the initial grid node matrix.

[0041] In one embodiment of the present invention, when using equal-spacing division, 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.

[0042] For example, if the well depth is 3000m and the preset number of nodes is 5, then the average well depth of adjacent preset grid nodes is 600m, and the initial grid node matrix is ​​[600, 1200, 1800, 2400, 3000].

[0043] In another embodiment of the present invention, when using variable spacing partitioning, the interval of variable spacing 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. 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.

[0044] For example, if the well depth is 3000m, the preset number of nodes is 5, and the spacing between adjacent preset grid nodes is set to increase, then the initial grid node matrix is ​​[600, 1000, 1600, 2400, 3000].

[0045] S202: Add the preset well depth to the initial grid node matrix to obtain the final divided grid node matrix; where each element value in the grid node matrix represents the well depth corresponding to a grid node.

[0046] Among them, the preset well depths include, for example, the well depth at the casing shoe, the well depth at the drill string diameter change, and the well depth at the abnormal formation pressure.

[0047] Specifically, based on the preset well depth and the preset grid node depth, the preset well depth is added to the initial grid node matrix to obtain the final divided grid node matrix; where each element value in the grid node matrix represents the well depth corresponding to a grid node.

[0048] For example, if 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, then the final grid node matrix is ​​obtained as [600, 700, 1000, 1050, 1600, 2400, 2600, 3000].

[0049] S203: Determine the length of the micro-segment based on the preset number of nodes and the total well depth.

[0050] In one embodiment of the present invention, the well depth between preset grid nodes is determined based on the total well depth and the preset number of nodes, and the well depth between preset grid nodes is used as the micro-segment length.

[0051] For the above S103, determining the well inclination angle at the grid node based on the inclination data includes, for example, calculating the well inclination angle at the grid node using linear interpolation based on the inclination data.

[0052] In one embodiment of the present invention, the inclination data includes, for example, the well depth and inclination angle at inclination points above the grid nodes, and the well depth and inclination angle at inclination points below the grid nodes.

[0053] Specifically, based on the inclination data, the inclination angle at the grid nodes is calculated using linear interpolation, including: calculating the well depth and inclination angle at the inclination points above the grid nodes, and the well depth and inclination angle at the inclination points below the grid nodes, using the following formulas:

[0054]

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

[0056] For the aforementioned S104, the parameter data also includes, for example: the total heat transfer coefficient between the cement sheath, casing, and annular fluid; the total heat transfer coefficient between the drill pipe and the fluid inside the pipe; dimensionless temperature; drilling fluid mass flow rate; wellbore radius; drill pipe inner radius; test temperature value; test pressure value; annular drilling fluid velocity; directional drilling data; drilling fluid density at test temperature and test pressure values; drilling fluid yield stress at test temperature and test pressure values; drilling fluid plastic viscosity at test temperature and test pressure values; drilling fluid specific heat capacity at test temperature and test pressure values; inlet drilling fluid temperature; formation specific heat capacity; formation thermal conductivity at test temperature and test pressure values; surface formation temperature; geothermal gradient and total well depth; preset well depth; inlet drilling fluid temperature; drilling fluid velocity; and annular cross-sectional area. Figure 3 The diagram shows a flowchart of a method for determining the tripping 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 nodes, and parameter data, according to an embodiment of the present invention. The method includes: for each grid node, performing the following process:

[0057] S301: Based on the preset pressure value, preset temperature value, and parameter data of the grid nodes, calculate the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure value and preset temperature value.

[0058] like Figure 4 As shown, the calculation includes the following parameters: 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.

[0059] S401: Calculate the drilling fluid density at the preset temperature and preset pressure values ​​based on the test temperature value, test pressure value, drilling fluid density at the test temperature and test pressure values, preset temperature, and preset pressure.

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

[0061] The drilling fluid density at the preset temperature and preset pressure values ​​is calculated using the following formula based on the test temperature and test pressure values, the drilling fluid density at the test temperature and test pressure values, the preset temperature, and the preset pressure:

[0062] ρ=ρ0+[A1(T-T0)+A2(P-P0)]

[0063] Where ρ is the drilling fluid density at preset temperature and preset pressure values, ρ0 is the drilling fluid density at test temperature and test 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.

[0064] Specifically, the drilling fluid characteristic parameters are constant values ​​determined historically based on drilling fluid characteristics. In one embodiment of the present invention, A1 = -0.71603, A2 = 4.12172 × 10 -7 .

[0065] S402: Calculate the yield stress of the drilling fluid at preset temperature and preset pressure values ​​based on the test temperature, test pressure, and the yield stress of the drilling fluid at the test temperature and test pressure values.

[0066] In one embodiment of the present invention, the yield stress of the drilling fluid at a preset temperature and a preset pressure is calculated based on the test temperature value, the test pressure value, and the yield stress of the drilling fluid at the test temperature and the test pressure value, including:

[0067] The following formula is used to calculate the yield stress of the drilling fluid at preset temperature and pressure values ​​based on the test temperature, test pressure, and test pressure values:

[0068]

[0069] Where, τ y τ is the yield stress of the drilling fluid at preset temperature and pressure values. y,0 The yield stress of the drilling fluid is determined by the test temperature and test pressure values, where α1, β1, γ1, δ1, and ε1 are drilling fluid characteristic parameters.

[0070] In one embodiment of the present invention, α1 = -1.01229 × 10 -2 β1=-1.03560×10 -4γ1=5.08647×10 -3 δ1=-5.92252×10 -5 ε1=1.28569×10 -4 .

[0071] S403: Calculate the plastic viscosity of the drilling fluid at the preset temperature and pressure values ​​based on the preset test temperature, test pressure, and plastic viscosity of the drilling fluid at the preset temperature and test pressure values.

[0072] In one embodiment of the present invention, the calculation of the plastic viscosity of the drilling fluid at a preset temperature and a preset pressure value, based on the preset test temperature value, a test pressure value, and the plastic viscosity of the drilling fluid at the test temperature and test pressure values, includes:

[0073] The following formula is used to calculate the plastic viscosity of the drilling fluid at preset test temperature and pressure values, based on the plastic viscosity of the drilling fluid at the preset test temperature and pressure values:

[0074]

[0075] Where, μ p The plastic viscosity (μ) of the drilling fluid at preset temperature and pressure values. p,0 The plastic viscosity of the drilling fluid is measured at the test temperature and test pressure values. α2, β2, γ2, δ2, and ε2 are characteristic parameters of the drilling fluid.

[0076] 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 .

[0077] S404: Calculate the specific heat capacity of drilling fluid at preset temperature and preset pressure values ​​based on preset temperature values.

[0078] In one embodiment of the present invention, calculating the specific heat capacity of drilling fluid at a preset temperature and a preset pressure value based on a preset temperature value includes:

[0079] The specific heat capacity of the drilling fluid at a preset temperature and a preset pressure is calculated using the following formula:

[0080] c fl = a + bT + cT -2

[0081] Among them, cfl denoted as the specific heat capacity of the drilling fluid at a preset temperature value T, where a, b, and c are characteristic parameters of the drilling fluid.

[0082] In one embodiment of the present invention, a = 4114.83672, b = 1.12275, and c = -14.55477.

[0083] S405: Calculate the thermal conductivity of the formation at the preset temperature value.

[0084] In one embodiment of the present invention, calculating the thermal conductivity of the formation at a preset temperature value includes:

[0085] The thermal conductivity of the formation at a preset temperature is calculated using the following formula:

[0086] k e =k e,0 (1+βT)

[0087] Where, k e k is the thermal conductivity of the formation at a preset temperature value T. e,0 β is the thermal conductivity of the formation at 0℃, and β3 is a formation characteristic parameter.

[0088] Specifically, the stratigraphic characteristic parameters are constant values ​​determined historically based on stratigraphic characteristics.

[0089] S302: Based on the energy conservation equation, the specific heat capacity of drilling fluid under preset pressure and temperature values, the thermal conductivity of formation under preset pressure and temperature values, the total heat transfer coefficient of cement sheath, casing and annulus fluid, the total heat transfer coefficient of drill pipe and pipe fluid, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, inlet drilling fluid temperature, surface formation temperature, geothermal gradient, and total well depth, calculate the calculated temperature value of the grid nodes.

[0090] In one embodiment of the present invention, the calculated temperature value of the grid node is calculated based on the energy conservation equation, the specific heat capacity of the drilling fluid under preset pressure and temperature values, the formation thermal conductivity under preset pressure and temperature values, 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 inside the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the drill pipe inner radius, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth. This includes: using the energy conservation equation, the specific heat capacity of the drilling fluid under preset pressure and temperature values, and the formation thermal conductivity under preset pressure and temperature values, obtaining the following calculated temperature value calculation formula; and determining the calculated temperature value using the following calculated temperature value calculation formula 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 inside the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the drill pipe inner radius, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth.

[0091]

[0092] Among them, T cal To calculate the temperature value, the boundary condition is T. t | z＝0 =T ti , T ti T represents the inlet drilling fluid temperature. es For surface strata temperature, g G The geothermal gradient is L, and the total well depth is L. c fl k is the specific heat capacity of the drilling fluid at preset pressure and temperature values. e To test the formation thermal conductivity at the required temperature and pressure, U a U is the overall heat transfer coefficient between the cement ring, the casing, and the annular fluid. t T is the overall heat transfer coefficient between the drill pipe and the fluid inside the pipe. D Let w be the dimensionless temperature, w be the drilling fluid mass flow rate, and r be the drilling fluid mass flow rate. w r is the wellbore radius. t Let π be the inner radius of the drill pipe, and π be the value of pi.

[0093] Specifically, the energy conservation equation for drilling fluid is:

[0094]

[0095] Among them, T cal To calculate the temperature value (°C), T t T represents the drilling fluid temperature inside the pipe (°C). ei C represents the formation temperature (°C). flThe specific heat capacity of the drilling fluid (J / (kg·℃)) at preset pressure and temperature values, c e The specific heat capacity of the formation (J / (kg·℃)), k e To test the formation thermal conductivity (W / (m·℃)) at the test temperature and test pressure values, U a The overall heat transfer coefficient between the cement ring, the casing, and the annular fluid (W / (m²)) 2 ·℃), U t The overall heat transfer coefficient between the drill pipe and the fluid inside the pipe (W / (m)) 2 ·℃), T D For dimensionless temperature, t D The dimensionless cycle time is given by t (h), w is the drilling fluid mass flow rate (kg / s), and ρ is the circulatory flow rate. e Formation density (kg / m³) 3 ), z is the well depth (m), r w r is the wellbore radius (m). t Let π be the inner radius of the drill pipe (m), and π be the value of pi.

[0096] According to the boundary conditions of the above energy conservation equation: T t | z＝0 =R ti , After analysis, the above formula for calculating the temperature value is obtained.

[0097] S303: Determine the temperature error value based on the preset temperature value and the calculated temperature value.

[0098] In one embodiment of the present invention, the temperature error value is determined using the following formula based on a preset temperature value and a calculated temperature value:

[0099]

[0100] Among them, R cal To calculate the temperature value, T ass m1 is the preset temperature value, and m2 is the temperature error value.

[0101] S304: When the temperature error value is less than the first error threshold, calculate the calculated pressure value of the grid node based on the mass conservation equation, the momentum conservation equation, the drilling fluid density at the preset temperature and preset pressure values, the drilling fluid yield stress at the preset pressure and preset temperature values, the drilling fluid plastic viscosity at the preset pressure and preset temperature values, the annular drilling fluid velocity, the annular cross-sectional area, the well inclination angle at the grid node, and the length of the micro-element.

[0102] In one embodiment of the present invention, the calculated pressure value of a grid node is calculated based on the mass conservation equation, the momentum conservation equation, the drilling fluid density at preset temperature and pressure values, the drilling fluid yield stress at preset pressure and temperature values, the drilling fluid plastic viscosity at preset pressure and temperature values, the annular drilling fluid velocity, the annular cross-sectional area, the well inclination angle at the grid node, and the length of the micro-element. This includes: obtaining the fluctuating pressure per unit length of the annular drilling fluid based on the drilling fluid density at preset temperature and pressure values, the drilling fluid yield stress at preset pressure and temperature values, and the drilling fluid plastic viscosity at preset pressure and temperature values; obtaining the following calculated pressure value calculation formula based on the mass conservation equation and the momentum conservation equation; and determining the calculated pressure value using the following calculated pressure value calculation formula based on the drilling fluid density at preset temperature and pressure values, the annular drilling fluid velocity, the annular cross-sectional area, the well inclination angle at the grid node, and the length of the micro-element.

[0103]

[0104] 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 preset pressure values, and V a A is the annular drilling fluid velocity. a The cross-sectional area of ​​the annulus (m²) 2 ), P a To calculate the pressure value, P Surge,a denoted as , where is the fluctuating pressure of the drilling fluid per unit length in the annulus, g is the acceleration due to gravity, θ is the well inclination angle at the grid node, and Δz is the length of the micro-element segment.

[0105] Specifically, the mass conservation equation for drilling fluid flow is:

[0106]

[0107] Where ρ is the drilling fluid density (kg / m³) at preset temperature and preset pressure values. 3 V a A is the annular drilling fluid velocity (m / s). a The cross-sectional area of ​​the annulus (m²) 2 ), where z is the well depth (m).

[0108] The momentum conservation equation for drilling fluid flow is:

[0109]

[0110] Among them, P cal To calculate the pressure value (Pa), P Surge,a The pressure fluctuation per unit length of the annular drilling fluid is denoted as ρ, where g is the acceleration due to gravity (9.81 m / s²).2 ), where θ is the well inclination angle (°).

[0111] The above mass conservation equation and momentum conservation equation are discretized and solved using the finite difference method to obtain the formula for calculating the pressure value:

[0112]

[0113] In addition, the fluctuating pressure per unit length of the annular drilling fluid, obtained based on the drilling fluid density at preset temperature and pressure values, the drilling fluid yield stress at preset pressure and temperature values, and the drilling fluid plastic viscosity at preset pressure and temperature values, includes, for example:

[0114] (1) Fluid flow regime determination

[0115] When Re a >Re a,c At that time, the annular flow is turbulent; when Re a ≤Re a,c At that time, the annular flow is laminar.

[0116]

[0117] Where: Re a D is the Reynolds number of the annulus fluid. w D is the inner diameter of the wellbore (m). d,o ρ is the drill pipe outer diameter (m), and ρ is the drilling fluid density (kg / m³) at preset pressure and temperature values. 3 ), μ p The plastic viscosity (Pa·s) of the drilling fluid at preset pressure and temperature values.

[0118]

[0119] Where: Re a,c τ is the critical Reynolds number of the annular fluid. y τ is the yield stress (Pa) of the drilling fluid under preset pressure and temperature values. w Let be the yield stress (Pa) of the drilling fluid on the outer wall of the drill pipe, and He be the Hedstrom number.

[0120]

[0121]

[0122] (2) Laminar flow fluctuation pressure calculation (Re) a ≤Re a,c )

[0123]

[0124] Where: P Surge,a The fluctuation pressure per unit length of the annular drilling fluid (Pa / m).

[0125] (3) Turbulent wave pressure calculation (Re a >Re a,c )

[0126]

[0127] S305: Determine the pressure error value based on the preset pressure value and the calculated pressure value.

[0128] In one embodiment of the present invention, the pressure error value is determined using the following formula based on a preset pressure value and a calculated pressure value:

[0129]

[0130] Among them, P cal To calculate the pressure value, P ass m2 is the preset pressure value, and m2 is the pressure error value.

[0131] 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.

[0132] 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.

[0133] S308: Return 301 if the temperature error value is not less than the first error threshold.

[0134] This invention also provides a device for determining the tripping pressure of high-temperature and high-pressure wells, as described in the following embodiments. Since the principle by which this device solves the problem is similar to the method for determining the tripping pressure of high-temperature and high-pressure wells, the implementation of this device can refer to the implementation of the method for determining the tripping pressure of high-temperature and high-pressure wells; repeated details will not be elaborated further.

[0135] like Figure 5 The diagram shown is a schematic of a high-temperature, high-pressure well tripping and drilling pressure determination device provided in an embodiment of the present invention, comprising:

[0136] The parameter acquisition module 501 is used to acquire parameter data during the tripping and running-out operations; the parameter data includes at least: inclination measurement data and preset well depth;

[0137] The first processing module 502 is used to divide the grid nodes and obtain the length of the micro-element segment according to the preset number of nodes and the preset well depth.

[0138] The second processing module 503 is used to determine the well inclination angle at the grid node based on the inclination data;

[0139] The third processing module 504 is used to determine the tripping pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at grid nodes, and parameter data.

[0140] In one possible implementation, the first processing module is specifically used to divide the grid nodes according to the preset number of nodes and the total well depth using a method of equal spacing or variable spacing to obtain an initial grid node matrix;

[0141] The preset well depth is added to the initial grid node matrix to obtain the final divided grid node matrix; where each element value in the grid node matrix represents the well depth corresponding to a grid node;

[0142] The length of the micro-segment is determined based on the preset number of nodes and the total well depth.

[0143] In one possible implementation, the second processing module is specifically used to calculate the well inclination angle at the grid node using linear interpolation based on the inclination data.

[0144] In one possible implementation, the inclination data includes: well depth and inclination angle at inclination points above the grid nodes, and well depth and inclination angle at inclination points below the grid nodes;

[0145] The second processing module is specifically used to calculate the well depth and inclination angle at the survey points above the grid nodes, and the well depth and inclination angle at the survey points below the grid nodes, using the following formula:

[0146]

[0147] Where θ is the well inclination angle at the grid node; D m D1 represents the well depth at the grid node; D1 represents the well inclination angle at the survey point above the grid node; D m,1 θ1 represents the well depth at the survey point above the grid node; θ2 represents the well inclination angle at the survey point below the grid node; D m,2 The depth of the well at the inclination point below the grid node.

[0148] In one possible implementation, the parameter data further includes: the total heat transfer coefficient between the cement sheath and casing and the annular fluid, the total heat transfer coefficient between the drill pipe and the fluid inside 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, directional measurement data, drilling fluid density at test temperature and test pressure values, drilling fluid yield stress at test temperature and test pressure values, drilling fluid plastic viscosity at test temperature and test pressure values, drilling fluid specific heat capacity at test temperature and test pressure values, inlet drilling fluid temperature, formation specific heat capacity, formation thermal conductivity at test temperature and test pressure values, surface formation temperature, geothermal gradient and total well depth, preset well depth, inlet drilling fluid temperature, drilling fluid flow rate, and annular cross-sectional area;

[0149] The third processing module is specifically used to perform the following process for each grid node:

[0150] Based on the preset pressure value, preset temperature value, and parameter data of the grid nodes, calculate the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure value and preset temperature value.

[0151] Based on the energy conservation equation, the specific heat capacity of drilling fluid under preset pressure and temperature values, the thermal conductivity of formation under preset pressure and temperature values, the total heat transfer coefficient of cement sheath, casing and annulus fluid, the total heat transfer coefficient of drill pipe and tubing fluid, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, inlet drilling fluid temperature, surface formation temperature, geothermal gradient, and total well depth, the calculated temperature values ​​of the grid nodes are calculated.

[0152] The temperature error value is determined based on the preset temperature value and the calculated temperature value;

[0153] 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 and pressure values, the drilling fluid yield stress at the preset pressure and temperature values, the drilling fluid plastic viscosity at the preset pressure and temperature values, the annular drilling fluid velocity, the annular cross-sectional area, the well inclination angle at the grid node, and the length of the micro-element.

[0154] The pressure error value is determined based on the preset pressure value and the calculated pressure value;

[0155] 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;

[0156] 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 steps of calculating the calculated pressure value of the grid node are returned based on the mass conservation equation, the momentum conservation equation, the drilling fluid density under the preset temperature value and the preset pressure value.

[0157] When the temperature error value is not less than the first error threshold, return to the steps of calculating the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure and temperature values ​​based on the preset pressure value, preset temperature value, and parameter data of the grid nodes.

[0158] In one possible implementation, the third processing module is specifically used 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.

[0159] Based on the test temperature value, test pressure value, and the yield stress of the drilling fluid at the test temperature value and test pressure value, calculate the yield stress of the drilling fluid at the preset temperature value and preset pressure value.

[0160] Calculate the plastic viscosity of the drilling fluid at the preset test temperature and pressure values ​​based on the preset test temperature and pressure values.

[0161] Calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​based on the preset temperature and pressure values.

[0162] Calculate the thermal conductivity of the formation at the preset temperature value.

[0163] In one possible implementation, the third processing module is specifically used to calculate the drilling fluid density using the following formula:

[0164] ρ=ρ0+[A19T-T0)+A2(P-P0)]

[0165] Where ρ is the drilling fluid density at preset temperature and preset pressure values, ρ0 is the drilling fluid density at test temperature and test 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.

[0166] In one possible implementation, the third processing module is specifically used to calculate the drilling fluid yield stress using the following formula:

[0167]

[0168] Where, τ y τ is the yield stress of the drilling fluid at preset temperature and pressure values. y,0 The yield stress of the drilling fluid is determined by the test temperature and test pressure values, where α1, β1, γ1, δ1, and ε1 are drilling fluid characteristic parameters.

[0169] In one possible implementation, the third processing module is specifically used to calculate the plastic viscosity of the drilling fluid at the preset temperature and preset pressure values ​​using the following formula:

[0170]

[0171] Where, μ p The plastic viscosity (μ) of the drilling fluid at preset temperature and pressure values. p,0 The plastic viscosity of the drilling fluid is measured at the test temperature and test pressure values. α2, β2, γ2, δ2, and ε2 are characteristic parameters of the drilling fluid.

[0172] In one possible implementation, the third processing module is specifically configured to calculate the specific heat capacity of the drilling fluid at a preset temperature and a preset pressure using the following formula:

[0173] c fl = a + bT + cT -2

[0174] Among them, c fl denoted as the specific heat capacity of the drilling fluid at a preset temperature value T, where a, b, and c are characteristic parameters of the drilling fluid.

[0175] In one possible implementation, the third processing module is specifically used to calculate the formation thermal conductivity at a preset temperature value using the following formula:

[0176] k e =k e,0 (1+βT)

[0177] Where, k e k is the thermal conductivity of the formation at a preset temperature value T. e,0 β is the thermal conductivity of the formation at 0℃, and β3 is a formation characteristic parameter.

[0178] In one possible implementation, the third processing module is specifically used to obtain the following calculation formula for the calculated temperature value by employing the energy conservation equation, the specific heat capacity of the drilling fluid at preset pressure and temperature values, and the formation thermal conductivity at preset pressure and temperature values. The calculated temperature value is determined based on the total heat transfer coefficient between the cement sheath and the casing and the annulus fluid, the total heat transfer coefficient between the drill pipe and the fluid inside the pipe, the dimensionless temperature, the drilling fluid mass flow rate, the wellbore radius, the drill pipe inner radius, the inlet drilling fluid temperature, the surface formation temperature, the geothermal gradient, and the total well depth using the following calculation formula:

[0179]

[0180] Among them, T cal To calculate the temperature value, the boundary condition is T. t | z＝0 =T ti , T ti T represents the inlet drilling fluid temperature. es For surface strata temperature, g G Where L is the geothermal gradient and L is the total well depth. c fl k is the specific heat capacity of the drilling fluid at preset pressure and temperature values. e To test the formation thermal conductivity at the required temperature and pressure, U a U is the overall heat transfer coefficient between the cement ring, the casing, and the annular fluid. t T is the overall heat transfer coefficient between the drill pipe and the fluid inside the pipe. D Let w be the dimensionless temperature, w be the drilling fluid mass flow rate, and r be the drilling fluid mass flow rate. w r is the wellbore radius. t Let π be the inner radius of the drill pipe, and π be the value of pi.

[0181] In one possible implementation, the third processing module is specifically used to determine the temperature error value based on a preset temperature value and a calculated temperature value using the following formula:

[0182]

[0183] Among them, T cal To calculate the temperature value, T ass m1 is the preset temperature value, and m2 is the temperature error value.

[0184] In one possible implementation, the third processing module is specifically used to obtain the fluctuating pressure per unit length of the annular drilling fluid based on the drilling fluid density, yield stress, and plastic viscosity at preset temperature and pressure values, as well as the drilling fluid yield stress and plastic viscosity at preset pressure and temperature values. Based on the mass conservation equation and momentum conservation equation, the following formula for calculating the calculated pressure value is obtained. Then, based on 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 pressure values, the calculated pressure value is determined using the following formula:

[0185]

[0186] 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 preset pressure values, and V a A is the annular drilling fluid velocity. a The cross-sectional area of ​​the annulus (m²) 2 ), P a To calculate the pressure value, P Surge,a denoted as , where is the fluctuating pressure of the drilling fluid per unit length in the annulus, g is the acceleration due to gravity, θ is the well inclination angle at the grid node, and Δz is the length of the micro-element segment.

[0187] In one possible implementation, the third processing module is specifically used to determine the pressure error value based on a preset pressure value and a calculated pressure value using the following formula:

[0188]

[0189] Among them, P cal To calculate the pressure value, P ass m2 is the preset pressure value, and m2 is the pressure error value.

[0190] Based on the aforementioned inventive concept, such as Figure 6 As shown, the present invention also proposes a computer device 600, including a memory 610, a processor 620, and a computer program 630 stored in the memory 610 and executable on the processor 620. When the processor 620 executes the computer program 630, it implements the aforementioned method for determining drilling pressure during high-temperature and high-pressure well tripping.

[0191] This invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for determining drilling pressure during high-temperature and high-pressure well tripping.

[0192] This invention also provides a computer program product, which includes a computer program that, when executed by a processor, implements the above-described method for determining drilling pressure during high-temperature and high-pressure well tripping.

[0193] In this embodiment of the invention, parameter data during the tripping and tripping operation is acquired. This parameter data includes at least: inclination measurement data and a preset well depth; grid nodes are defined based on the preset number of nodes and the preset well depth, and the length of each micro-element is obtained; the inclination angle at each grid node is determined based on the inclination measurement data; and the tripping and tripping pressure under temperature-pressure coupling is determined based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-element length, well inclination angle at each grid node, and the parameter data. This approach considers the effects of high temperature and high pressure on the drilling fluid properties, improves the accuracy of tripping and tripping pressure calculation, enhances the accuracy of well pressure prediction, effectively meets the requirements for accurate control of tripping and tripping pressure in high-temperature and high-pressure wells, and ensures safe and efficient tripping and tripping operations.

[0194] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0195] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0196] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0197] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0198] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above descriptions are merely specific embodiments of the present invention and are 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 within the scope of protection of the present invention.

Claims

1. A method for determining drilling pressure during tripping in high-temperature and high-pressure wells, characterized in that, include: Acquire parameter data during the tripping and running-out operations; the parameter data shall include at least: inclination measurement data and preset well depth; Based on the preset number of nodes and preset well depth, the grid nodes are divided, and the length of the micro-element segment is obtained; Determine the well inclination angle at the grid node based on the inclination measurement data; Based on the mass conservation equation, momentum conservation equation, energy conservation equation, infinitesimal segment length, well inclination angle at grid nodes, and parameter data, the tripping pressure under temperature-pressure coupling is determined, including: For each grid node, perform the following procedure: Based on the preset pressure value, preset temperature value, and parameter data of the grid nodes, calculate the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure value and preset temperature value. Based on the energy conservation equation, the specific heat capacity of drilling fluid under preset pressure and temperature values, the thermal conductivity of formation under preset pressure and temperature values, the total heat transfer coefficient of cement sheath, casing and annulus fluid, the total heat transfer coefficient of drill pipe and tubing fluid, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, inlet drilling fluid temperature, surface formation temperature, geothermal gradient, and total well depth, the calculated temperature values ​​of the grid nodes are calculated. The temperature error value is determined based on 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 based on the mass conservation equation, the momentum conservation equation, the drilling fluid density at the preset temperature and pressure values, the drilling fluid yield stress at the preset pressure and temperature values, the drilling fluid plastic viscosity at the preset pressure and temperature values, the annular drilling fluid velocity, the annular cross-sectional area, the well inclination angle at the grid node, and the length of the micro-element. The pressure error value is determined based on the preset pressure value and the calculated pressure value; When the pressure error value is less than the second error threshold, the calculated pressure value is determined 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 steps of calculating the calculated pressure value of the grid node are returned based on the mass conservation equation, the momentum conservation equation, the drilling fluid density under the preset temperature value and the preset pressure value. When the temperature error value is not less than the first error threshold, return to the steps of calculating the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure and temperature values ​​based on the preset pressure value, preset temperature value, and parameter data of the grid nodes.

2. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 1, characterized in that, Based on the preset number of nodes and preset well depth, the grid nodes are divided, and the length of the micro-element segment is obtained, including: Based on the preset number of nodes and the total well depth, the grid nodes are divided using equal or variable spacing methods to obtain the initial grid node matrix; The preset well depth is added to the initial grid node matrix to obtain the final divided grid node matrix; where each element value in the grid node matrix represents the well depth corresponding to a grid node; The length of the micro-segment is determined based on the preset number of nodes and the total well depth.

3. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 1, characterized in that, Preset well depth, including: Well depth at casing shoe, well depth at drill string diameter change, and well depth at abnormal formation pressure.

4. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 1, characterized in that, Determine the well inclination angle at the grid node based on the inclination data, including: Based on the inclination data, the inclination angle at the grid nodes is calculated using linear interpolation.

5. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 3, characterized in that, The inclination data includes: well depth and inclination angle at inclination points above the grid nodes, and well depth and inclination angle at inclination points below the grid nodes; Based on the inclination data, the inclination angle at the grid nodes is calculated using linear interpolation, including: The well depth and inclination angle at the survey points above the grid nodes, and the well depth and inclination angle at the survey points below the grid nodes, are used to calculate the well inclination angle at the grid nodes: in, The well inclination angle at the grid node; The depth of the well at the grid node; The well inclination angle at the survey point above the grid node; The well depth at the inclination point above the grid node; The inclination angle at the survey point below the grid node; The depth of the well at the inclination point below the grid node.

6. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 1, characterized in that, The parameter data also include: the total heat transfer coefficient between the cement sheath, casing, and annulus fluid; the total heat transfer coefficient between the drill pipe and the fluid inside the pipe; dimensionless temperature; drilling fluid mass flow rate; wellbore radius; drill pipe inner radius; test temperature value; test pressure value; annulus drilling fluid velocity; drilling fluid density at test temperature and test pressure values; drilling fluid yield stress at test temperature and test pressure values; drilling fluid plastic viscosity at test temperature and test pressure values; drilling fluid specific heat capacity at test temperature and test pressure values; inlet drilling fluid temperature; formation specific heat capacity; formation thermal conductivity at test temperature and test pressure values; surface formation temperature; geothermal gradient and total well depth; drilling fluid velocity; and annulus cross-sectional area.

7. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 6, characterized in that, Calculate the drilling fluid density, yield stress, plastic viscosity, specific heat capacity, and formation thermal conductivity at preset pressure and temperature values, including: Based on the test temperature value, test pressure value, drilling fluid density at the test temperature value and test pressure value, preset temperature, and preset pressure, calculate the drilling fluid density at the preset temperature value and preset pressure value. Based on the test temperature value, test pressure value, and the yield stress of the drilling fluid at the test temperature value and test pressure value, calculate the yield stress of the drilling fluid at the preset temperature value and preset pressure value. Calculate the plastic viscosity of the drilling fluid at the preset test temperature and pressure values ​​based on the preset test temperature and pressure values. Calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​based on the preset temperature and pressure values. Calculate the thermal conductivity of the formation at the preset temperature value.

8. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 7, characterized in that, Based on the test temperature value, test pressure value, drilling fluid density at the test temperature value and test pressure value, preset temperature, and preset pressure, calculate the drilling fluid density at the preset temperature value and preset pressure value, including: The drilling fluid density at the preset temperature and preset pressure values ​​is calculated using the following formula based on the test temperature and test pressure values, the drilling fluid density at the test temperature and test pressure values, the preset temperature, and the preset pressure: in, The drilling fluid density at preset temperature and pressure values. To test the drilling fluid density at the specified temperature and pressure values, To test the temperature value, To test the pressure value, For the preset temperature value, To preset the pressure value, and These are drilling fluid characteristic parameters.

9. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 7, characterized in that, Based on the test temperature, test pressure, and the yield stress of the drilling fluid at the test temperature and test pressure, calculate the yield stress of the drilling fluid at the preset temperature and preset pressure, including: The following formula is used to calculate the yield stress of the drilling fluid at 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: in, The yield stress of the drilling fluid at preset temperature and pressure values. To test the yield stress of the drilling fluid under test temperature and test pressure values, These are drilling fluid characteristic parameters.

10. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 7, characterized in that, Based on the preset test temperature, test pressure, and the plastic viscosity of the drilling fluid at the preset temperature and pressure, calculate the plastic viscosity of the drilling fluid at the preset temperature and pressure, including: The following formula is used to calculate the plastic viscosity of the drilling fluid at preset test temperature and pressure values, based on the plastic viscosity of the drilling fluid at the preset test temperature and pressure values: in, The plastic viscosity of the drilling fluid at preset temperature and pressure values. To test the plastic viscosity of drilling fluid at the specified temperature and pressure values, These are drilling fluid characteristic parameters.

11. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 7, characterized in that, Based on the preset temperature value, calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values, including: The specific heat capacity of the drilling fluid at a preset temperature and a preset pressure is calculated using the following formula: in, Preset temperature value The specific heat capacity of the drilling fluid at that time These are drilling fluid characteristic parameters.

12. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 7, characterized in that, Calculate the thermal conductivity of the formation at the preset temperature value, including: The thermal conductivity of the formation at a preset temperature is calculated using the following formula: in, Preset temperature value The thermal conductivity of the formation at that time, 0 The thermal conductivity of the formation at that time, These are formation characteristic parameters.

13. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 6, characterized in that, Based on the energy conservation equation, the specific heat capacity of the drilling fluid at preset pressure and temperature values, the formation thermal conductivity at preset pressure and temperature values, the total heat transfer coefficient between the cement sheath, casing, and annulus fluid, the total heat transfer coefficient between the drill pipe and the fluid inside the pipe, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, inlet drilling fluid temperature, surface formation temperature, geothermal gradient, and total well depth, the calculated temperature values ​​for the grid nodes are calculated, including: Using the energy conservation equation, and based on preset pressure and temperature values ​​for the drilling fluid specific heat capacity, formation thermal conductivity, and other parameters, the following formula for calculating the calculated temperature is derived. The calculated temperature value is then determined using the following formula, taking into account the overall heat transfer coefficients between the cement sheath, casing, and annulus fluids; the overall heat transfer coefficients between the drill pipe and the fluid inside the casing; the dimensionless temperature; the drilling fluid mass flow rate; the wellbore radius; the drill pipe inner radius; the inlet drilling fluid temperature; the surface formation temperature; the geothermal gradient; and the total well depth. in, To calculate the temperature value, the boundary conditions are as follows: , It represents the surface temperature of the Earth's strata. For geothermal gradient, For the total well depth, , The specific heat capacity of the drilling fluid at preset pressure and temperature values. To test the thermal conductivity of the formation at the required temperature and pressure values, The total heat transfer coefficient between the cement ring, the sleeve, and the annular fluid is given. The total heat transfer coefficient between the drill pipe and the fluid inside the pipe is given. The temperature is dimensionless. This refers to the drilling fluid mass flow rate. The radius of the wellbore. The inner radius of the drill pipe. Pi is the mathematical constant of a circle.

14. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 6, characterized in that, The temperature error value is determined based on the preset temperature value and the calculated temperature value, including: The temperature error value is determined using the following formula based on the preset temperature value and the calculated temperature value: in, To calculate the temperature value, For the preset temperature value, This represents the temperature error value.

15. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 6, characterized in that, Based on the mass conservation equation, momentum conservation equation, drilling fluid density at preset temperature and pressure values, drilling fluid yield stress at preset pressure and temperature values, drilling fluid plastic viscosity at preset pressure and temperature values, annular drilling fluid velocity, annular cross-sectional area, well inclination angle at grid nodes, and micro-element length, calculate the calculated pressure values ​​for the grid nodes, including: The fluctuating pressure per unit length of the annular drilling fluid is obtained based on the drilling fluid density, yield stress, and plastic viscosity at preset temperature and pressure values. Based on the mass conservation equation and the momentum conservation equation, the following formula for calculating the calculated pressure value is obtained. Based on the preset temperature and pressure values, drilling fluid density, annular drilling fluid velocity, annular cross-sectional area, well inclination angle at the grid nodes, and the length of the micro-element, the following formula is used to determine the calculated pressure value: in, To calculate the pressure value, Representing the One grid node, The drilling fluid density at preset temperature and pressure values. The annular drilling fluid velocity, For the cross-sectional area of ​​the annulus, This refers to the fluctuating pressure of the drilling fluid per unit length in the annulus. It is the acceleration due to gravity. The well inclination angle at the grid node. is the length of the infinitesimal segment.

16. The method for determining drilling pressure during high-temperature and high-pressure well tripping as described in claim 6, characterized in that, The pressure error value is determined based on the preset pressure value and the calculated pressure value, including: The pressure error value is determined using the following formula based on the preset pressure value and the calculated pressure value: ； in, To calculate the pressure value, To preset the pressure value, This is the pressure error value.

17. A device for determining drilling pressure during high-temperature and high-pressure well tripping, characterized in that, include: The parameter acquisition module is used to acquire parameter data during the tripping and running-out operations; the parameter data includes at least: inclination measurement data and preset well depth; The first processing module is used to divide the grid nodes and obtain the length of the micro-element segment according to the preset number of nodes and the preset well depth. The second processing module is used to determine the well inclination angle at the grid node based on the inclination data; The third processing module is used to determine the tripping pressure under temperature-pressure coupling based on the mass conservation equation, momentum conservation equation, energy conservation equation, micro-segment length, well inclination angle at grid nodes, and parameter data. The third processing module is specifically used to perform the following process for each grid node: Based on the preset pressure value, preset temperature value, and parameter data of the grid nodes, calculate the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure value and preset temperature value. Based on the energy conservation equation, the specific heat capacity of drilling fluid under preset pressure and temperature values, the thermal conductivity of formation under preset pressure and temperature values, the total heat transfer coefficient of cement sheath, casing and annulus fluid, the total heat transfer coefficient of drill pipe and tubing fluid, dimensionless temperature, drilling fluid mass flow rate, wellbore radius, drill pipe inner radius, inlet drilling fluid temperature, surface formation temperature, geothermal gradient, and total well depth, the calculated temperature values ​​of the grid nodes are calculated. The temperature error value is determined based on 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 based on the mass conservation equation, the momentum conservation equation, the drilling fluid density at the preset temperature and pressure values, the drilling fluid yield stress at the preset pressure and temperature values, the drilling fluid plastic viscosity at the preset pressure and temperature values, the annular drilling fluid velocity, the annular cross-sectional area, the well inclination angle at the grid node, and the length of the micro-element. The pressure error value is determined based on the preset pressure value and the calculated pressure value; When the pressure error value is less than the second error threshold, the calculated pressure value is determined 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 steps of calculating the calculated pressure value of the grid node are returned based on the mass conservation equation, the momentum conservation equation, the drilling fluid density under the preset temperature value and the preset pressure value. When the temperature error value is not less than the first error threshold, return to the steps of calculating the drilling fluid density, drilling fluid yield stress, drilling fluid plastic viscosity, drilling fluid specific heat capacity, and formation thermal conductivity at the preset pressure and temperature values ​​based on the preset pressure value, preset temperature value, and parameter data of the grid nodes.

18. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 17, characterized in that, The first processing module is specifically used to divide the grid nodes according to the preset number of nodes and the total well depth, using a method of equal spacing or variable spacing, to obtain an initial grid node matrix; The preset well depth is added to the initial grid node matrix to obtain the final divided grid node matrix; where each element value in the grid node matrix represents the well depth corresponding to a grid node; The length of the micro-segment is determined based on the preset number of nodes and the total well depth.

19. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 17, characterized in that, The second processing module is specifically used to calculate the well inclination angle at the grid node based on the inclination data using linear interpolation.

20. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 19, characterized in that, The inclination data includes: well depth and inclination angle at inclination points above the grid nodes, and well depth and inclination angle at inclination points below the grid nodes; The second processing module is specifically used to calculate the well depth and inclination angle at the survey points above the grid nodes, and the well depth and inclination angle at the survey points below the grid nodes, using the following formula: in, The well inclination angle at the grid node; The depth of the well at the grid node; The well inclination angle at the survey point above the grid node; The well depth at the inclination point above the grid node; The inclination angle at the survey point below the grid node; The depth of the well at the inclination point below the grid node.

21. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 17, characterized in that, The parameter data also include: the total heat transfer coefficient between the cement sheath, casing, and annulus fluid; the total heat transfer coefficient between the drill pipe and the fluid inside the pipe; dimensionless temperature; drilling fluid mass flow rate; wellbore radius; drill pipe inner radius; test temperature value; test pressure value; annulus drilling fluid velocity; drilling fluid density at test temperature and test pressure values; drilling fluid yield stress at test temperature and test pressure values; drilling fluid plastic viscosity at test temperature and test pressure values; drilling fluid specific heat capacity at test temperature and test pressure values; inlet drilling fluid temperature; formation specific heat capacity; formation thermal conductivity at test temperature and test pressure values; surface formation temperature; geothermal gradient and total well depth; drilling fluid velocity; and annulus cross-sectional area.

22. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 21, characterized in that, The third processing module is specifically used to calculate the drilling fluid density at the preset temperature and preset pressure values ​​based on the test temperature value, test pressure value, drilling fluid density at the test temperature and test pressure values, preset temperature, and preset pressure. Based on the test temperature value, test pressure value, and the yield stress of the drilling fluid at the test temperature value and test pressure value, calculate the yield stress of the drilling fluid at the preset temperature value and preset pressure value. Calculate the plastic viscosity of the drilling fluid at the preset test temperature and pressure values ​​based on the preset test temperature and pressure values. Calculate the specific heat capacity of the drilling fluid at the preset temperature and pressure values ​​based on the preset temperature and pressure values. Calculate the thermal conductivity of the formation at the preset temperature value.

23. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 22, characterized in that, The third processing module is specifically used to calculate the drilling fluid density using the following formula: in, The drilling fluid density at preset temperature and pressure values. To test the drilling fluid density at the specified temperature and pressure values, To test the temperature value, To test the pressure value, For the preset temperature value, To preset the pressure value, and These are drilling fluid characteristic parameters.

24. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 22, characterized in that, The third processing module is specifically used to calculate the drilling fluid yield stress using the following formula: in, The yield stress of the drilling fluid at preset temperature and pressure values. To test the yield stress of the drilling fluid under test temperature and test pressure values, These are drilling fluid characteristic parameters.

25. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 22, characterized in that, The third processing module is specifically used to calculate the plastic viscosity of the drilling fluid at preset temperature and pressure values ​​using the following formula: in, The plastic viscosity of the drilling fluid at preset temperature and pressure values. To test the plastic viscosity of drilling fluid at the specified temperature and pressure values, These are drilling fluid characteristic parameters.

26. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 22, characterized in that, The third processing module is specifically used to calculate the specific heat capacity of the drilling fluid at the preset temperature and preset pressure values ​​using the following formula: in, Preset temperature value The specific heat capacity of the drilling fluid at that time These are drilling fluid characteristic parameters.

27. The high-temperature and high-pressure well tripping and drilling pressure determination device as described in claim 22, characterized in that, The third processing module is specifically used to calculate the thermal conductivity of the formation at the preset temperature value using the following formula: in, Preset temperature value The thermal conductivity of the formation at that time, 0 The thermal conductivity of the formation at that time, These are formation characteristic parameters.

28. 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, it implements the method of any one of claims 1 to 16.

29. 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 method of any one of claims 1 to 16.

30. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the method of any one of claims 1 to 16.

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