A method and apparatus for well control

Abstract

The application provides a drilling control method and device. The method comprises the following steps: obtaining drilling data of a neighboring well in a target area and design parameters of a target well in the target area; obtaining a target mechanical model of a drilling tool according to the drilling data of the neighboring well; determining a similarity parameter between the neighboring well and the target well according to the drilling data of the neighboring well and the design parameters of the target well; detecting whether the similarity parameter is greater than or equal to a first similarity threshold; in the case that the similarity parameter is determined to be greater than or equal to the first similarity threshold, determining a target drilling assembly of the target well and a target drilling parameter of the target well according to the target mechanical model and the design parameters of the target well; and controlling the drilling tool to drill the target well according to the target drilling assembly of the target well and the target drilling parameter of the target well. The above method can obtain a drilling assembly and drilling parameter that are more matched with the working condition of the target well.

Description

Technical Field

[0001] This manual belongs to the field of drilling engineering technology in the petroleum industry, and in particular relates to a drilling control method and device. Background Technology

[0002] With the rapid development of shale gas exploration and development, the number of long-distance, three-dimensional horizontal wells is increasing. Currently, the common horizontal section length in shale gas drilling has reached over 3000m, placing higher demands on wellbore trajectory control during drilling operations. Existing technologies mainly rely on construction experience to optimize drill string assemblies and drilling parameters, thus lacking accuracy. Furthermore, relying on experience to select drill string assemblies and drilling parameters makes it difficult to simultaneously apply them to both the build-up and stabilization sections of the target well, thereby limiting drilling efficiency.

[0003] There is currently no effective solution to the aforementioned technical problems. Summary of the Invention

[0004] This application provides a drilling control method and apparatus that can obtain drill string combinations and drilling parameters that are more closely matched to the target well conditions.

[0005] The purpose of the embodiments in this specification is to provide a drilling control method, including:

[0006] Obtain the preset parameters of the target well; and obtain the drilling data of the adjacent wells of the target well;

[0007] Based on drilling data from adjacent wells, a target mechanical model of the drilling tool is obtained;

[0008] Based on the drilling data of neighboring wells and the preset parameters of the target well, a similarity parameter between the neighboring well and the target well is determined; wherein, the similarity parameter includes at least one of the following: cumulative wellbore curvature difference parameter of the build-up section, and cumulative wellbore curvature difference parameter of the stable section;

[0009] Detect whether the similarity parameter is greater than or equal to the first similarity threshold;

[0010] If the similarity parameter is determined to be greater than or equal to the first similarity threshold, the target drilling tool assembly and target drilling parameters of the target well are determined according to the target mechanical model and the preset parameters of the target well.

[0011] The drilling tools are controlled to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

[0012] Furthermore, in another embodiment of the method, obtaining the target mechanical model of the drilling tool based on drilling data from adjacent wells includes:

[0013] Construct an initial mechanical model of the drilling tool;

[0014] Based on drilling data from adjacent wells, the initial mechanical model is corrected to obtain the target mechanical model of the drilling tool.

[0015] Furthermore, in another embodiment of the method, when the similarity parameter includes the cumulative wellbore curvature difference parameter of the build-up well section, the similarity parameter between the neighboring well and the target well is determined based on the drilling data of the neighboring well and the preset parameters of the target well, including:

[0016] Extract the wellbore curvature per unit depth of multiple adjacent wells' directional drilling sections from the drilling data of adjacent wells;

[0017] Extract the wellbore curvature per unit depth of multiple target wells from the preset parameters of the target wells;

[0018] The cumulative wellbore curvature of the adjacent well deviated well sections is obtained by summing the wellbore curvature per unit depth of multiple adjacent well deviated well sections;

[0019] The cumulative wellbore curvature of the target well's inclined section is obtained by summing the wellbore curvature per unit depth of the multiple target wells' inclined sections.

[0020] Based on the cumulative wellbore curvature of the adjacent well's inclined section and the cumulative wellbore curvature of the target well's inclined section, the cumulative wellbore curvature difference parameter of the inclined section is obtained.

[0021] Furthermore, in another embodiment of the method, when the similarity parameter includes the cumulative wellbore curvature difference parameter of the stable well section, the similarity parameter between the neighboring well and the target well is determined based on the drilling data of the neighboring well and the preset parameters of the target well, including:

[0022] Extract the wellbore curvature per unit depth of the stable inclination section of multiple adjacent wells from the drilling data of adjacent wells;

[0023] Extract the wellbore curvature per unit depth of the stable deviation section of multiple target wells from the preset parameters of the target wells;

[0024] The cumulative wellbore curvature of the adjacent well stable deflection sections is obtained by summing the wellbore curvature per unit depth of multiple adjacent well stable deflection sections;

[0025] The cumulative wellbore curvature of the stable deviated well section of the target well is obtained by summing the wellbore curvature per unit depth of the stable deviated well section of the target well.

[0026] Based on the cumulative wellbore curvature of the stable inclination section of the adjacent well and the cumulative wellbore curvature of the stable inclination section of the target well, the cumulative wellbore curvature difference parameter of the stable inclination section is obtained.

[0027] Furthermore, in another embodiment of the method, determining the target drill string assembly and target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well includes:

[0028] Extract the target well construction parameters from the preset parameters of the target well;

[0029] The target well construction parameters are input into the target mechanical model to obtain the drill bit lateral force and drill bit rotation angle of the target well;

[0030] Based on the lateral force of the drill bit and the drill bit rotation angle of the target well, determine the target drill string assembly and the target drilling parameters of the target well.

[0031] Furthermore, in another embodiment of the method, the method further includes:

[0032] From the drilling data of adjacent wells, we extract the drill string assemblies, drilling parameters, and composite drilling ratios of multiple adjacent wells; among them, the drill string assemblies, drilling parameters, and composite drilling ratios correspond one-to-one.

[0033] Detect whether the composite drilling ratio is greater than the first preset value, and filter out the composite drilling ratios that are greater than the first preset value as the first composite drilling ratio;

[0034] Determine the drill string combination corresponding to the first composite drilling ratio as the target drill string combination for the adjacent well;

[0035] The drilling parameters corresponding to the first composite drilling ratio are determined and used as the target drilling parameters for adjacent wells.

[0036] Furthermore, in another embodiment of the method, after determining the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well, the method further includes:

[0037] Detect whether the similarity parameter is less than a first similarity threshold and greater than a second similarity threshold;

[0038] If the similarity parameter is determined to be less than the first similarity threshold and greater than the second similarity threshold, the target drill string combination and the target drilling parameters of the adjacent well are modified to obtain the target drill string combination and the target drilling parameters of the target well.

[0039] The drilling tools are controlled to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

[0040] Furthermore, in another embodiment of the method, after determining the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well, the method further includes:

[0041] Detect whether the similarity parameter is less than or equal to the second similarity threshold;

[0042] If the similarity threshold is determined to be less than or equal to the second similarity threshold, the target drill string combination of the adjacent well is taken as the target drill string combination of the target well; and the target drilling parameters of the adjacent well are taken as the target drilling parameters of the target well.

[0043] The drilling tools are controlled to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

[0044] This application also provides a drilling control device, the device comprising:

[0045] The acquisition module is used to acquire the preset parameters of the target well and the drilling data of the adjacent wells of the target well.

[0046] The module is used to obtain the target mechanical model of the drilling tool based on drilling data from adjacent wells;

[0047] The first calculation module is used to determine the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well; wherein, the similarity parameters include at least one of the following: the cumulative wellbore curvature difference parameter of the deflection section and the cumulative wellbore curvature difference parameter of the stable deflection section;

[0048] The detection module is used to detect whether the similarity parameter is greater than or equal to a first similarity threshold;

[0049] The second calculation module is used to determine the target drilling tool combination and the target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well when the similarity parameter is determined to be greater than or equal to the first similarity threshold.

[0050] The control module is used to control the drilling tools to drill the target well according to the target drill string assembly and the target drilling parameters of the target well.

[0051] The purpose of this application embodiment is to provide a computer-readable storage medium storing computer instructions thereon, which, when executed by a processor, implements the above-described drilling control method.

[0052] Based on the drilling control method provided in this application, the following steps are taken: Preset parameters of the target well are obtained; drilling data of adjacent wells are obtained; a target mechanical model of the drilling tool is obtained based on the drilling data of the adjacent wells; a similarity parameter between the adjacent wells and the target well is determined based on the drilling data of the adjacent wells and the preset parameters of the target well; wherein the similarity parameter includes at least one of the following: cumulative wellbore curvature difference parameter of the build-up section, and cumulative wellbore curvature difference parameter of the stable-inclination section; it is detected whether the similarity parameter is greater than or equal to a first similarity threshold; if the similarity parameter is determined to be greater than or equal to the first similarity threshold, the target drill string assembly and target drilling parameters of the target well are determined based on the target mechanical model and the preset parameters of the target well; and the drilling tool is controlled to drill the target well based on the target drill string assembly and target drilling parameters. This method can obtain a drill string assembly and drilling parameters that are more compatible with the operating conditions of the target well, thereby improving drilling efficiency. Attached Figure Description

[0053] To more clearly illustrate the embodiments of this specification, the accompanying drawings used in the embodiments will be briefly introduced below. The drawings described below are only some embodiments recorded in this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0054] Figure 1 A schematic diagram of one embodiment of the drilling control method provided in this specification.

[0055] Figure 2 A schematic diagram of the lower drill string assembly provided in the embodiments of this specification;

[0056] Figure 3 A schematic diagram of the lower drill string assembly micro-element provided in the embodiments of this specification;

[0057] Figure 4 A schematic diagram of one embodiment of the drilling control device provided in this specification.

[0058] Figure 5 A schematic diagram of one embodiment of the server structure provided in this specification;

[0059] Figure 6 This is a schematic diagram of the lower drill string assembly with a two-unit single stabilizer provided in the embodiments of this specification;

[0060] Figure 7 This is a schematic diagram of the lower drill string assembly in a specific scenario example of this specification. Detailed Implementation

[0061] To enable those skilled in the art to better understand the technical solutions in this specification, the technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of this specification.

[0062] With the rapid development of shale gas exploration and development, the number of long-distance, three-dimensional horizontal wells is increasing. Currently, the common horizontal section length in shale gas drilling has reached over 3000m, placing higher demands on wellbore trajectory control during drilling operations. Existing technologies mainly rely on construction experience to optimize drill string assemblies and drilling parameters, thus lacking accuracy. Furthermore, relying on experience to select drill string assemblies and drilling parameters makes it difficult to simultaneously apply them to both the build-up and stabilization sections of the target well, thereby limiting drilling efficiency.

[0063] In view of the aforementioned problems with existing methods and the specific reasons for these problems, this application proposes a drilling control method that distinguishes between the build-up section and the stable section, which can provide accurate drill string assembly and drilling parameters.

[0064] Based on the above ideas, this specification proposes a drilling control method, which includes: acquiring preset parameters of a target well; acquiring drilling data of adjacent wells of the target well; obtaining a target mechanical model of the drilling tool based on the drilling data of the adjacent wells; determining a similarity parameter between the adjacent wells and the target well based on the drilling data of the adjacent wells and the preset parameters of the target well; wherein the similarity parameter includes at least one of the following: a cumulative wellbore curvature difference parameter in the build-up section and a cumulative wellbore curvature difference parameter in the stable section; detecting whether the similarity parameter is greater than or equal to a first similarity threshold; if the similarity parameter is determined to be greater than or equal to the first similarity threshold, determining the target drill string assembly and the target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well; and controlling the drilling tool to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

[0065] See Figure 1 As shown, this specification proposes a drilling control method. In practice, this method may include the following:

[0066] S101: Obtain the preset parameters of the target well; and obtain the drilling data of the adjacent wells of the target well.

[0067] In some embodiments, the target well and its neighbors are located in the same area and are geographically close. The adjacent well is a well that has already been drilled, and the actual drilling data (i.e., drilling data) of the adjacent well is collected. The geological conditions of the adjacent well location are similar to those of the target well location; therefore, the drilling data of the adjacent well has certain reference value for the target well. The preset parameters of the target well include the target well construction parameters, and may also include data such as geological information of the target well location. The target well construction parameters are determined based on the geological data; they may also include the wellbore curvature per unit depth of the stable well section of the target well.

[0068] S102: Obtain the target mechanical model of the drilling tool based on the drilling data of the adjacent well.

[0069] In some embodiments, drilling tools refer to the bottom hole assembly (BHA). The BHA can be considered as a slender Euler beam in a three-dimensional curved wellbore. In the three-dimensional wellbore, the BHA undergoes spatial bending deformation due to its own weight, drilling pressure, torque, wellbore constraint, and drilling fluid pressure. The BHA refers to the drilling tool from the drill collar to the drill bit. The main body is a hollow column. The drill bit is placed at the bottom of the column, and multiple stabilizers are placed on the column. Other downhole tools are placed inside the column. The column, stabilizers, and the downhole tools inside can be collectively referred to as the drill string. To simplify the calculation, the following basic assumptions are adopted in this application: (1) The drill string is in a linear elastic deformation state; (2) The cross-section of the drill string is circular or annular; (3) The influence of shear force on the deformation of the drill string is neglected. See also Figure 2 As shown, a natural curve coordinate system is used, with the origin at the midpoint of the drill bit end face. The x-axis points towards the bottom of the wellbore, the y-axis points perpendicular to the bottom of the wellbore, and the x and y axes are orthogonal. The z-axis is perpendicular to the plane formed by the x and y axes and points towards the bottom of the well. Q represents the distance from the center of the drill string to the center of the wellbore, L represents the length of BHA (i.e., the drill string length), and F represents the internal force acting on the drill string.

[0070] In some embodiments, see Figure 3 As shown, a segment of the BHA micro-element is extracted from the BHA for analysis. The BHA micro-element can also be called a drill string micro-element or drill string micro-unit. O represents the origin of the coordinate system; r represents the radius vector, which is the vector formed by the line connecting a point on the BHA micro-element to the origin of the coordinate system; M represents the moment at that point; F represents the internal force at that point. Since the internal force is microscopically manifested as a lateral force, F can also be called the lateral force at that point; m represents the moment of the external force per unit length of the drill string about the center of the drill string; h represents the external force per unit length of the drill string; M represents the internal force on the drill string micro-element; Δl represents the change in arc length of the BHA micro-element; Δr represents the change in radius vector; ΔM represents the change in moment; and ΔF represents the change in internal force.

[0071] S102: Obtain the target mechanical model of the drilling tool based on the drilling data of the adjacent well.

[0072] In some embodiments, a target mechanical model of the drilling tool is obtained based on drilling data from adjacent wells, specifically including:

[0073] S1: Construct the initial mechanical model of the drilling tool;

[0074] S2: Based on the drilling data of adjacent wells, the initial mechanical model is corrected to obtain the target mechanical model of the drilling tool.

[0075] This application describes the steps for constructing an initial mechanical model of a drilling tool, and this application uses a natural curve coordinate system.

[0076] A segment of the BHA micro-element is extracted from the BHA for analysis. The BHA micro-element can also be called a drill string micro-element or drill string micro-unit. The tangential vector on the BHA micro-element is:

[0077]

[0078] Among them, e t denoted by r, where r represents the radius vector and l represents the arc length.

[0079] The radius vector can be decomposed according to the following formula:

[0080] r=Ue1+Ve2+We3 (2)

[0081] Where U represents the x-axis coordinate of a target point on the BHA infinitesimal axis, V represents the y-axis coordinate of a target point on the BHA infinitesimal axis, W represents the z-axis coordinate of a target point on the BHA infinitesimal axis, e1 represents the unit vector on the x-axis, e2 represents the unit vector on the y-axis, and e3 represents the unit vector on the z-axis.

[0082] Combining Formula 1 and Formula 2, we can obtain:

[0083]

[0084] The internal force on the BHA infinitesimal element is:

[0085] F = F x e1+F y e2+F z e3 (4)

[0086] Where F represents the internal force on the infinitesimal element BHA, F x F represents the component of the internal force along the x-axis. y F represents the component of the internal force along the y-axis. z This represents the component of the internal force along the z-axis.

[0087] For the BHA infinitesimal element, its physical equation is:

[0088]

[0089] Where M represents the moment of the BHA infinitesimal element, EI represents the bending stiffness, E represents the elastic modulus, and I represents the moment of inertia. t Indicates torque, GJ represents torsional stiffness, and γ represents the torsional angle. It represents bending moment.

[0090] Substituting formulas 3 and 4 into formula 5 yields:

[0091]

[0092] For the BHA infinitesimal element, the angular momentum theorem is:

[0093]

[0094] Where m represents the moment of the external force per unit length of the drill string about the center of the drill string, H represents the angular momentum of the external force per unit length of the drill string about the center of the drill string, and t represents time.

[0095] H can be represented in the following form:

[0096] H=Aρ(R-R0)×[Ω×(R-R0)]+I o w (8)

[0097] Where A represents the cross-sectional area of ​​the drill string element, ρ represents the density of the drill string element, R represents the wellbore radius, R0 represents the radius of the drill string element, Ω represents the angular velocity of the drill string element's revolution, and I... o Let w represent the moment of inertia of the drill string element and w represent the angular velocity of the drill string element's rotation.

[0098] Assuming the distributed torque applied to the drill string element is neglected (i.e., m = 0), and the longitudinal and torsional vibrations of the drill string element are ignored, and the rotational angular velocity w is a constant, then... That is, Formula 7 can be simplified to:

[0099]

[0100] Substituting formulas 4 and 6 into formula 9, we get:

[0101]

[0102] The change on the drill string element satisfies ΔU represents the change in coordinate along the x-axis, ΔV represents the change in coordinate along the y-axis, and Δl represents the change in arc length. If we assume the axial deformation of the drill string element is small, that is, let... Therefore, we can obtain:

[0103]

[0104] Therefore, it can be seen that the three equations in Formula 10 are not independent. By taking different assumptions, the specific form of the initial mechanical model can be further derived.

[0105] For a drill string micro-element, its dynamic equilibrium equation is:

[0106]

[0107] Where h represents the external force per unit length of drill string.

[0108] Assuming the drill string element is stationary, then we have Considering only the effects of gravity and buoyancy, we have:

[0109] h=qg=qsinαe1-qcosαe3 (13)

[0110] Where q represents the buoyant weight per unit length of drill string, also known as the linear weight per unit length of drill string in drilling fluid, g represents the unit vector in the direction of gravity, and α represents the well inclination angle.

[0111] Substituting Equation 13 into Equation 12 and integrating, we get:

[0112]

[0113] Where F0 represents the internal force on the drill bit (l=0), S x S represents the component of the internal force along the x-axis at the drill bit (l=0). y B represents the internal force component along the y-axis at the drill bit (l=0), and B represents the internal force component along the z-axis at the drill bit (l=0) (i.e., drilling pressure).

[0114] F0 can be specifically represented as:

[0115] F0 = S x e1+S y e2-Be3 (15)

[0116] Combining formulas 14 and 15, we can obtain:

[0117]

[0118] Assuming the deflection of the drill string element is small relative to its length, then:

[0119]

[0120] Substituting Equation 17 into Equation 10, and omitting higher-order minor quantities, we get:

[0121]

[0122] Neglecting the longitudinal and torsional vibrations of the drill string element, and considering only the lateral acceleration (because the longitudinal acceleration is relatively small compared to the lateral acceleration locally), we obtain:

[0123]

[0124] Assuming the lateral resistance of the drilling fluid is proportional to the lateral velocity of the drill string element, we get:

[0125]

[0126] Among them, h x h represents the external force per unit length of the drill string in the x-axis direction. y h represents the external force per unit length of the drill string in the y-axis direction. z This represents the external force per unit length of drill string in the z-axis direction, and C represents the damping coefficient.

[0127] Substituting formulas 14, 15, 19, and 20 into formula 12, we get:

[0128]

[0129] Integrating over l in Equation 21, we get:

[0130]

[0131] Combining formulas 4 and 22, we can obtain:

[0132]

[0133] Differentiating Equation 18 with respect to l and substituting it into Equation 23, we get:

[0134]

[0135] If we neglect the lateral vibration of the drill string element, that is, disregard the velocity and acceleration terms, then...

[0136]

[0137] This yields the differential equations for the BHA three-dimensional small deflection static analysis (i.e., the initial mechanical equations):

[0138]

[0139] Due to the complexity of Formula 26, an analytical solution is not feasible. Therefore, a numerical method is required to solve Formula 26. The BHA can be considered as a longitudinally and transversely curved beam-column structure, with the drill bit at the lower end and the tangent point at the upper end. It is divided into n BHA micro-elements (drill string micro-elements) by n-1 stabilizers and bends; n represents the total number of drill string micro-elements, and n-1 equals the sum of the number of stabilizers and bends; stabilizers, bends, drill bits, and tangent points are collectively called nodes, therefore the number of nodes is equal to n+1.

[0140] For the i-th drill string element (where i represents the element number, i = 1, 2, 3, ..., n), its upper node is denoted as i, and its lower node is denoted as i-1. The wellbore axis coordinates at the upper end of this drill string element are represented by r. oi =X i e1+Y i e2+Z i e3 indicates; the axis of the drill string micro-element is represented by r. i =U i e1+V i e2+W i e3 indicates; r oi X represents the vector formed by the line connecting the upper node of the wellbore axis corresponding to the i-th drill string element and the origin. i This represents the x-axis coordinate of the upper node of the wellbore axis corresponding to the i-th drill string element, and the y-axis coordinate is... i Z represents the y-axis coordinate of the upper node of the wellbore axis corresponding to the i-th drill string element. i r represents the z-axis coordinate of the upper node of the wellbore axis corresponding to the i-th drill string element. i U represents the vector formed by connecting the origins of the coordinates of the upper nodes of the i-th drill string element. i V represents the x-axis coordinate of the upper node of the i-th drill string element. i W represents the y-axis coordinate of the upper node of the i-th drill string element. i This represents the z-axis coordinate of the upper node of the i-th drill string element.

[0141] Discretizing Equation 26 yields the discretized initial mechanical equations:

[0142]

[0143] Among them, E i I represents the elastic modulus of the upper node of the i-th drill string element. i M represents the moment of inertia of the upper node of the i-th drill string element. ti Let q represent the torque at the upper node of the i-th drill string element. i α represents the linear weight of the upper node of the i-th drill string element in the drilling fluid. iB represents the well inclination angle of the upper node of the i-th drill string element. i This represents the internal force exerted on the upper node of the i-th drill string element in the z-axis direction, where i represents the number of the drill string element and the value range of i is i = 1, 2, 3, ..., n.

[0144] For the specific form of the parameters in Formula 27, please refer to the following formula:

[0145]

[0146]

[0147]

[0148]

[0149]

[0150] Among them, L j N represents the length of the j-th drill string element (j = 1, 2, ..., i-1). j f represents the contact pressure between the upper node of the j-th drill string element (i.e., the j-th stabilizer or bend) and the wellbore. a f represents the first intermediate parameter. t D represents the second intermediate parameter. w denoted by , v represents the drilling speed, and f represents the coefficient of friction between the stabilizer and the wellbore.

[0151] According to formulas 19 and 23, the lateral forces (also known as internal forces) at the nodes of the drill string element can be obtained:

[0152]

[0153] Among them, F xi F represents the lateral force exerted on the upper node of the i-th drill string element in the x-axis direction. yi Let represent the lateral force exerted on the upper node of the i-th drill string element in the y-axis direction.

[0154] When a drill string unit operates in a wellbore, it must meet boundary conditions and continuity conditions.

[0155] Boundary condition 1: Boundary conditions at the drill bit:

[0156] With zero drill bit displacement and no bending moment between the drill bit and the formation, we can obtain:

[0157] [U1(0)] 2 +[V1(0)] 2 +[U”1(0)] 2 +[V”1(0)]2 =0 (34)

[0158] U1(0) represents the x-axis coordinate of the lower node (i.e., the drill bit) of the first drill string element, V1(0) represents the y-axis coordinate of the lower node (i.e., the drill bit) of the first drill string element, U”1(0) represents the second derivative of the x-axis coordinate of the lower node (i.e., the drill bit) of the first drill string element with respect to the arc length, and V”1(0) represents the second derivative of the y-axis coordinate of the lower node (i.e., the drill bit) of the first drill string element with respect to the arc length.

[0159] Boundary condition 2: Boundary conditions at the stabilizer:

[0160] (1) The stabilizer contacts the wellbore. The displacement and first derivative of the drill string elements on both sides of the stabilizer are continuous, and the bending moment is continuous:

[0161]

[0162] Among them, U i (L i V represents the x-axis coordinate of the upper node of the i-th drill string element. i (L i U represents the y-axis coordinate of the upper node of the i-th drill string element. i+1 (0) represents the x-axis coordinate of the lower node of the (i+1)th drill string element, V i+1 (0) represents the y-axis coordinate of the lower node of the (i+1)th drill string element, e ci δ represents the eccentricity of the i-th drill string element. i It represents the deflection angle of the i-th drill string element.

[0163] (2) Stabilizer suspended state. The drill string coordinates, derivatives, bending moments, and internal forces on both sides of the suspended stabilizer are continuous.

[0164]

[0165] Boundary condition 3: Boundary conditions at the point of tangency:

[0166] The slope and curvature of the drill string micro-element are basically consistent with the slope and curvature of the wellbore axis.

[0167]

[0168] Among them, D on This represents the outer diameter of the drill string element at the tangent point. l m0 Indicates the wellbore axis.

[0169] Boundary condition 4: Wellbore constraint. The deformation of the drill string element is restricted by the wellbore, and the following condition must be met at any point:

[0170]

[0171] Among them, D oi This represents the outer diameter of the i-th drill string element.

[0172] Continuity condition: Continuity condition at bends:

[0173] If a new bend is added to the i-th drill string element located between the (i-1)-th and i-th stabilizers, dividing the drill string element into two parts with a bend value of β, then... i1 The device angle is β i2 The lengths of the two parts are L respectively. i1 L i2 According to the adjacent function theorem, the condition for continuity of displacement between two segments is:

[0174]

[0175]

[0176]

[0177] Among them, U i1 U represents the x-coordinate of the midpoint of the drill string element closest to the (i-1)th stabilizer. i2 k represents the x-coordinate of the midpoint of the drill string element closest to the i-th stabilizer. i Indicates the third intermediate parameter, l i V represents the arc length of the i-th drill string element. i1 V represents the ordinate value of the midpoint of the drill string element closest to the (i-1)th stabilizer. i2 This represents the ordinate value of the midpoint of the drill string element closest to the i-th stabilizer.

[0178] This application uses the weighted residual method to solve formula 27. (See also...) Figure 6 As shown, this application uses a simple BHA structure (i.e., drill bit-stabilizer-tangent point) with two elements (i.e., infinitesimal elements) as an example to describe the weighted residual method. In this structure, n = 2, the number of nodes (drill bit, stabilizer, and tangent point are all nodes) is 3, and i takes the value 1 or 2. In the weighted residual method, the choice of the trial function is quite important; it must be continuous and complete, and must satisfy the boundary conditions and continuity conditions mentioned above.

[0179] For a two-element, three-node structure, the displacement trial function can be chosen as a fourth-degree polynomial:

[0180]

[0181] Where p represents the power of l, s represents the highest power of l, and a ip b represents the first coefficient. ip This represents the second coefficient.

[0182] Let s = 4, then the displacement trial function can be written in the following form:

[0183]

[0184] Then we have:

[0185]

[0186] According to boundary condition formula 34 at the drill bit, we can obtain:

[0187] a 10 =0, b 10 =0, a 12 =0, b 12 =0 (45)

[0188] According to Formula 35, the boundary condition for the stabilizer contacting the wellbore can be obtained as follows:

[0189]

[0190]

[0191] a 11 +2a 12 L1+3a 13 L1 2 +4a 14 L1 3 =a 21 (47)

[0192]

[0193] E1I1(2a 12 +6a 13 L1+12a 14 L1 2 )=E2I2(2a 22 (49)

[0194]

[0195] Since n = 2, according to the boundary condition formula 37 at the point of tangency, we can obtain:

[0196]

[0197]

[0198]

[0199]

[0200]

[0201]

[0202] According to formula 27, we can obtain:

[0203]

[0204]

[0205]

[0206]

[0207] Solving the system of equations consisting of equations 45 to 60, while simultaneously satisfying the constraints of equations 38, 39, and 40, yields the coefficients of the trial function equation 43, which in turn allows us to obtain a. 10 a 11 a 12 a 13 a 14 a 20 a 21 a 22 a 23 a 24 b 10 b 11 b 12 b 13 b 14 b 20 b 22 b 23 b 24 Formula 43 can be written in matrix form:

[0208] [Γ][χ]=[B N (61)

[0209] In the formula,

[0210]

[0211]

[0212]

[0213]

[0214]

[0215] For Equation 61, the number of equations is the same as the number of unknowns with undetermined coefficients, and the equations are linearly independent; therefore, the equations are solvable. By following the steps described above, the coordinates of the nodes in the BHA can be obtained. For a BHA with multiple nodes, where the first node is the drill bit and the second node is the first stabilizer, the drill bit coordinates can be approximated by the coordinates of the first stabilizer. Knowing the drill bit coordinates, the lateral force of the drill bit can be calculated using Equation 33, and then the drill bit rotation angle can be calculated using the following formula:

[0216]

[0217] Where θ represents the drill bit rotation angle, F y_bit F represents the lateral force exerted on the drill bit in the y-axis direction. x_bit This represents the lateral force experienced by the drill bit in the x-axis direction.

[0218] In some embodiments, after obtaining the initial mechanical model, simulation data can be used to test the calculation accuracy of the initial mechanical model. If the calculation accuracy does not meet the requirements, parameters such as the position of the bends, the position of the stabilizers, and the number of stabilizers in the initial mechanical model can be adjusted, and the initial mechanical model can be reconstructed until the accuracy of the initial mechanical model meets the requirements.

[0219] In some embodiments, the lateral force of the drill bit is the guiding force of the BHA, and the drill bit rotation angle is the direction of the BHA.

[0220] In some embodiments, after obtaining the initial mechanical model, drilling data from adjacent wells can be used to correct the initial mechanical model. For example, the drilling data from adjacent wells can be substituted into the target model to obtain the calculated values ​​of the drill bit lateral force and the drill bit rotation angle. The difference between the calculated values ​​of the drill bit lateral force and the actual values ​​of the drill bit lateral force (extracted from the drilling data) is compared, and the difference between the calculated values ​​of the drill bit rotation angle and the actual values ​​of the drill bit rotation angle (extracted from the drilling data) is also compared. Based on the differences, a correction scaling factor is determined, and the initial mechanical model is corrected using the scaling factor to obtain a target mechanical model that better matches the operating conditions of the adjacent well. Furthermore, since the operating conditions and geological conditions of the adjacent well are similar to those of the target well, the target mechanical model also has good applicability to the target well.

[0221] In some embodiments, the input parameters required for the target mechanical model include: stabilizer dimensions (i.e., outer diameter), stabilizer location, bend location, bend size, well inclination angle, wellbore azimuth angle, wellbore curvature, drilling fluid density, bit pressure, and rotational speed. The input parameters include both drill string assembly and drilling parameters.

[0222] S103: Based on the drilling data of the adjacent well and the preset parameters of the target well, determine the similarity parameters between the adjacent well and the target well; wherein, the similarity parameters include at least one of the following: the cumulative wellbore curvature difference parameter of the deflection section and the cumulative wellbore curvature difference parameter of the stable deflection section.

[0223] In some embodiments, adjacent wells are divided into a build-up section and a stabilized section. The target well is also divided into a build-up section and a stabilized section. Using the cumulative wellbore curvature difference parameter of the build-up section, the degree of difference between the build-up section of the adjacent well and the target well can be measured; a larger cumulative wellbore curvature difference parameter indicates a greater difference in the build-up section. Similarly, using the cumulative wellbore curvature difference parameter of the stabilized section, the degree of difference between the stabilized section of the adjacent well and the target well can be measured; a larger cumulative wellbore curvature difference parameter indicates a greater difference in the stabilized section.

[0224] In some embodiments, when the similarity parameter includes the cumulative wellbore curvature difference parameter of the build-up well section, the similarity parameter between the neighboring well and the target well is determined based on the drilling data of the neighboring well and the preset parameters of the target well, specifically including:

[0225] S1: Extract the wellbore curvature per unit depth of multiple adjacent wells from the drilling data of adjacent wells;

[0226] S2: Extract the wellbore curvature per unit depth of multiple target wells from the preset parameters of the target wells;

[0227] S3: Sum the wellbore curvature per unit depth of multiple adjacent well deviated well sections to obtain the cumulative wellbore curvature of the adjacent well deviated well sections;

[0228] S4: Sum the wellbore curvature per unit depth of the deviated well sections of multiple target wells to obtain the cumulative wellbore curvature of the deviated well sections of the target wells;

[0229] S5: Based on the cumulative wellbore curvature of the adjacent well's inclined section and the cumulative wellbore curvature of the target well's inclined section, obtain the cumulative wellbore curvature difference parameter of the inclined section.

[0230] In some embodiments, the cumulative wellbore curvature of the adjacent well deviated section can be calculated according to the following formula:

[0231]

[0232] Among them, K c_邻井_造斜 The cumulative wellbore curvature of adjacent well deviated sections is expressed in ° / 30m; n1 represents the number of adjacent well deviated sections; K d_邻井_造斜 This represents the wellbore curvature per unit depth of the d-th build-up section of the adjacent well, expressed in ° / 30m.

[0233] In some embodiments, the cumulative wellbore curvature of the target well's directional drilling section can be calculated according to the following formula:

[0234]

[0235] Among them, K c_目标井_造斜 The n2 represents the cumulative wellbore curvature of the target well's deviated section, in degrees per 30m; the n2 represents the number of deviated sections in the target well; K d_目标井_造斜 This represents the wellbore curvature per unit depth of the d-th build-up section of the target well, expressed in ° / 30m.

[0236] In some embodiments, the cumulative wellbore curvature difference parameter of the directional drilling section can be calculated according to the following formula:

[0237]

[0238] Among them, M 造斜井段 This parameter represents the cumulative wellbore curvature difference in the directional well section.

[0239] In some embodiments, when the similarity parameter includes the cumulative wellbore curvature difference parameter of the stable well section, the similarity parameter between the neighboring well and the target well is determined based on the drilling data of the neighboring well and the preset parameters of the target well, specifically including:

[0240] S1: Extract the wellbore curvature per unit depth of the stable inclination section of multiple adjacent wells from the drilling data of adjacent wells;

[0241] S2: Extract the wellbore curvature per unit depth of multiple target well stable sections from the preset parameters of the target well;

[0242] S3: Sum the wellbore curvature per unit depth of multiple adjacent well stable deviated sections to obtain the cumulative wellbore curvature of adjacent well stable deviated sections;

[0243] S4: Sum the wellbore curvature per unit depth of the stable deviated well sections of multiple target wells to obtain the cumulative wellbore curvature of the stable deviated well sections of the target wells;

[0244] S5: Based on the cumulative wellbore curvature of the stable inclination section of the adjacent well and the cumulative wellbore curvature of the stable inclination section of the target well, obtain the cumulative wellbore curvature difference parameter of the stable inclination section.

[0245] In some embodiments, the cumulative wellbore curvature of the adjacent well stable deviation section can be calculated according to the following formula:

[0246]

[0247] Among them, K c_邻井_稳斜 n3 represents the cumulative wellbore curvature of adjacent well stable sections, in ° / 30m; n3 represents the number of adjacent well stable sections; K d_邻井_稳斜This represents the wellbore curvature per unit depth of the d-th stable deflection section of the adjacent well, expressed in ° / 30m.

[0248] In some embodiments, the cumulative wellbore curvature of the stable deviation section of the target well can be calculated according to the following formula:

[0249]

[0250] Among them, K c_目标井_稳斜 n4 represents the cumulative wellbore curvature of the stable deviated section of the target well, in degrees per 30m; K represents the number of stable deviated sections of the target well; d_目标井_稳斜 This represents the wellbore curvature per unit depth of the d-th stable deviation section of the target well, expressed in ° / 30m.

[0251] In some embodiments, the cumulative wellbore curvature difference parameter of the stable deviated well section can be calculated according to the following formula:

[0252]

[0253] Among them, M 稳斜井段 This parameter represents the cumulative wellbore curvature difference in the stable deviated well section.

[0254] S104: Detect whether the similarity parameter is greater than or equal to the first similarity threshold.

[0255] In some embodiments, the first similarity threshold is set to 20%. If the cumulative wellbore curvature difference parameter of the build-up section is greater than or equal to 20%, it indicates that the build-up sections of the adjacent well and the target well are significantly different, and the drill string assembly and drilling parameters of the adjacent well's build-up section are not applicable to the target well's build-up section. If the cumulative wellbore curvature difference parameter of the stable section is greater than or equal to 20%, it indicates that the stable section of the adjacent well and the target well are significantly different, and the drill string assembly and drilling parameters of the adjacent well's stable section are not applicable to the target well's stable section.

[0256] S105: If the similarity parameter is determined to be greater than or equal to the first similarity threshold, the target drilling tool assembly and target drilling parameters of the target well are determined according to the target mechanical model and the preset parameters of the target well.

[0257] In some embodiments, the drill string assembly includes: the size (i.e., outer diameter) of the stabilizer, the location of the stabilizer, the location of the bend, and the size of the bend. Drilling parameters include: pressure on bit, rotation speed, and drilling fluid density (drilling parameters may also include only pressure on bit and rotation speed).

[0258] In some embodiments, the target drill string assembly and target drilling parameters of the target well are determined based on the target mechanical model and preset parameters of the target well, specifically including:

[0259] S1: Extract the target well construction parameters from the preset parameters of the target well;

[0260] S2: Input the target well construction parameters into the target mechanical model to obtain the drill bit lateral force and drill bit rotation angle of the target well;

[0261] S3: Based on the lateral force of the drill bit and the drill bit rotation angle of the target well, determine the target drill string assembly and the target drilling parameters of the target well.

[0262] In some embodiments, the target well construction parameters, which are also the input parameters of the target mechanical model, include: the size (i.e., outer diameter) of the target well stabilizer, the position of the target well stabilizer, the position of the target well bend, the size of the target well bend, the inclination angle of the target well, the azimuth angle of the target well, the curvature of the target well, the drilling fluid density of the target well, the drilling pressure of the target well, and the rotational speed of the target well.

[0263] In some embodiments, the target well drilling parameters are determined based on geological data of the target well location. The target drill string assembly and target drilling parameters are determined based on the lateral force of the drill bit and the drill bit rotation angle of the target well, including:

[0264] S1: Determine the first difference between the lateral force of the drill bit in the target well and the preset lateral force of the drill bit; wherein, the preset lateral force of the drill bit is determined based on the geological data of the location of the target well;

[0265] S2: Determine the second difference between the target well's drill bit angle and the preset drill bit angle; wherein, the preset drill bit angle is determined based on the geological data of the target well's location;

[0266] S3: Detect whether the first difference is less than the drill bit lateral force threshold, and detect whether the second difference is less than the drill bit rotation angle threshold;

[0267] S4: If the first difference is less than the drill bit lateral force threshold and the second difference is less than the drill bit rotation threshold, extract the target drill string assembly and the target drilling parameters of the target well from the target well construction parameters.

[0268] In some embodiments, if the first difference is greater than or equal to the drill bit lateral force threshold or the second difference is greater than or equal to the drill bit rotation angle threshold, it indicates that the target well construction parameters need further adjustment. In this case, the value range corresponding to the target well construction parameters can be determined based on the target well construction parameters. For example, if the size of the target well stabilizer is 200 mm, 90% × 200 mm can be used as the left endpoint of the value range, and 110% × 200 mm as the right endpoint, resulting in the value range [180, 220] corresponding to the size of the target well stabilizer. Similarly, the value ranges corresponding to other target well construction parameters can be obtained. Then, the values ​​within different value ranges are combined and sequentially input into the target mechanical model to obtain multiple sets of different target well drill bit lateral forces and target well drill bit rotation angles. The target well construction parameter combination that is closest to the preset drill bit lateral force and preset drill bit rotation angle is selected, thereby determining the target drill string combination and the target drilling parameters of the target well.

[0269] S106: Control the drilling tools to drill the target well according to the target drill string assembly and the target drilling parameters of the target well.

[0270] In some embodiments, if the cumulative wellbore curvature difference parameter of the build-up section is greater than or equal to the first similarity threshold, it is necessary to determine the drill bit lateral force and drill bit rotation angle of the target well according to the target mechanical model; apply the parameters corresponding to the drill bit lateral force and drill bit rotation angle of the target well to the build-up section of the target well, and control the drilling tool to drill in the build-up section.

[0271] In some embodiments, if the cumulative wellbore curvature difference parameter of the stable inclination section is greater than or equal to the first similarity threshold, it is necessary to determine the drill bit lateral force and drill bit rotation angle of the target well according to the target mechanical model; apply the parameters corresponding to the drill bit lateral force and drill bit rotation angle of the target well to the stable inclination section of the target well, and control the drilling tool to drill in the stable inclination section.

[0272] In some embodiments, the method further includes: when the cumulative wellbore curvature difference parameter in the deflection section is greater than or equal to a first similarity threshold, or when the cumulative wellbore curvature difference parameter in the stable deflection section is greater than or equal to the first similarity threshold, controlling the drilling tool to drill the target well according to the target drill string assembly and the target drilling parameters of the target well, and collecting the drilling data of the target well and the drill bit lateral force and drill bit rotation angle of the target well corresponding to the drilling data during the drilling process; using the drilling data, drill bit lateral force and drill bit rotation angle of the target well, recalibrating the target mechanical model so that the calculation results of the target mechanical model are more consistent with the target well.

[0273] In some embodiments, the method further includes:

[0274] S1: Extract drill string assemblies, drilling parameters, and composite drilling ratios for multiple adjacent wells from the drilling data of adjacent wells; among them, the drill string assemblies, drilling parameters, and composite drilling ratios correspond one-to-one.

[0275] S2: Detect whether the composite drilling ratio is greater than the first ratio preset value, and filter out the composite drilling ratios that are greater than the first ratio preset value as the first composite drilling ratio;

[0276] S3: Determine the drill string combination corresponding to the first composite drilling ratio as the target drill string combination for the adjacent well;

[0277] S4: Determine the drilling parameters corresponding to the first composite drilling ratio as the target drilling parameters for adjacent wells.

[0278] In some embodiments, the operating conditions of adjacent wells can be divided into sliding drilling and combined drilling. When the drilling pressure is >0 kN, the rotation speed is 0 rpm, and the footage is >0 m, it is sliding drilling. When the drilling pressure is >0 kN, the rotation speed is >0 rpm, and the footage is >0 m, it is combined drilling. The higher the proportion of combined drilling, the better the drilling effect, indicating that the drilling tool combination and drilling parameters used are more optimal.

[0279] In some embodiments, the composite drilling ratio is determined according to the following formula:

[0280]

[0281] Among them, M 复合比例 Indicates the proportion of composite drilling; l 复合进尺 L represents the cumulative composite drilling footage per single drill bit, in meters (m). 总 This indicates the cumulative footage advanced in a single drilling trip, in meters (m).

[0282] In some embodiments, a first ratio preset value is set to 90%, and composite drilling ratios greater than 90% are selected as the first composite drilling ratio; the drill string combination corresponding to the first composite drilling ratio is determined as the target drill string combination for the adjacent well; the drilling parameters corresponding to the first composite drilling ratio are determined as the target drilling parameters for the adjacent well. Based on the target drill string combination and target drilling parameters selected in the above manner, superior drilling results can be achieved in adjacent wells.

[0283] In some embodiments, after determining the similarity parameters between the neighboring well and the target well based on drilling data of the neighboring well and preset parameters of the target well, the method further includes:

[0284] S1: Detect whether the similarity parameter is less than the first similarity threshold and greater than the second similarity threshold;

[0285] S2: If the similarity parameter is determined to be less than the first similarity threshold and greater than the second similarity threshold, the target drill string combination and the target drilling parameters of the adjacent well are modified to obtain the target drill string combination and the target drilling parameters of the target well.

[0286] S3: Control the drilling tools to drill the target well according to the target drill string assembly and the target drilling parameters of the target well.

[0287] In some embodiments, the second similarity threshold is set to 15%. If the second similarity threshold < the cumulative wellbore curvature difference parameter of the build-up section < the first similarity threshold, it indicates that there are certain differences between the adjacent well and the target well in the build-up section. In this case, the drill string assembly and drilling parameters of the adjacent well cannot be directly adapted to the target well. It is necessary to modify the target drill string assembly and target drilling parameters of the adjacent well to obtain a more suitable target drill string assembly and target drilling parameters for the target well. Based on the target drill string assembly and target drilling parameters of the target well, the drilling tools are controlled to drill in the build-up section of the target well.

[0288] In some embodiments, if the second similarity threshold < the cumulative wellbore curvature difference parameter of the stable deviated section < the first similarity threshold, it indicates that there are certain differences between the adjacent well and the target well in the stable deviated section. In this case, the drill string assembly and drilling parameters of the adjacent well cannot be directly adapted to the target well. It is necessary to modify the target drill string assembly and target drilling parameters of the adjacent well to obtain a more suitable target drill string assembly and target drilling parameters for the target well. Based on the target drill string assembly and target drilling parameters of the target well, the drilling tools are controlled to drill in the stable deviated section of the target well.

[0289] In a specific scenario example, both the target well and adjacent wells are applicable. Figure 7 The BHA shown includes: a drill bit, stabilizer 1, a bend, a drill collar, and stabilizer 2. L1 represents the length of the first drill string element, i.e., the distance between the drill bit and stabilizer 1. L2 represents the length of the second drill string element, i.e., the distance between stabilizer 1 and stabilizer 2. There is a bend between stabilizer 1 and stabilizer 2. 21 This represents the distance from stabilizer 1 to the bend. β 21 This represents the bend angle value. At this point, if the second similarity threshold < the cumulative wellbore curvature difference parameter of the stable deviated section < the first similarity threshold, the drill string assembly and drilling parameters of adjacent wells cannot be directly used. Refer to the following steps to determine the target drill string assembly and target drilling parameters for the target well:

[0290] Step 1: Extract a set of input parameters from the drilling data of adjacent wells that show good drilling performance (the higher the composite drilling ratio, the better the drilling performance) and are suitable for the stable inclination section. The adjacent well input parameters include: the size (outer diameter) of the adjacent well stabilizer, the position of the adjacent well stabilizer, the position of the adjacent well bend, the size of the adjacent well bend, the inclination angle of the adjacent well, the azimuth angle of the adjacent well, the curvature of the adjacent well, the drilling fluid density of the adjacent well, the bit pressure of the adjacent well, and the rotation speed of the adjacent well. Among these, the inclination angle, the azimuth angle, and the curvature of the adjacent well cannot be adjusted, so they are not considered. The size (outer diameter) of the adjacent well stabilizer, the position of the adjacent well stabilizer, the position of the adjacent well bend, the size of the adjacent well bend, the drilling fluid density of the adjacent well, the bit pressure of the adjacent well, and the rotation speed of the adjacent well are determined as adjustment parameters.

[0291] Step 2: From the adjustment parameters, select 4-5 key parameters that have a significant impact on the lateral force of the drill bit. For example, the partial derivatives of the target mechanical model with respect to the adjustment parameters can be calculated sequentially. Based on the changes in the partial derivatives, 4-5 key parameters that have a significant impact on the lateral force of the drill bit can be selected. Changes in key parameters will significantly affect the changes in partial derivatives. In this embodiment, the key parameters include the first key parameter, the second key parameter, the third key parameter, and the fourth key parameter.

[0292] Step 3: Define the value range of the first key parameter as the first interval; define the value range of the second key parameter as the second interval; define the value range of the third key parameter as the third interval; define the value range of the fourth key parameter as the fourth interval.

[0293] Step 4: Combine the values ​​extracted from the first interval, the second interval, the third interval, and the fourth interval to obtain multiple sets of parameter combinations. Input the multiple parameter combinations and the adjustment parameters other than the key parameters into the target mechanical model in sequence to obtain multiple sets of drill bit lateral force and multiple sets of drill bit rotation angle.

[0294] Step 5: Select the drill bit lateral force and drill bit angle that are closest to the preset drill bit lateral force and drill bit rotation angle of the target well; and determine the corresponding key parameters and adjustment parameters, thereby determining the target drill string combination and target drilling parameters of the target well.

[0295] For example, the first key parameter is the location of the adjacent well stabilizer, specifically the distance L2 between stabilizer 1 and stabilizer 2, and the value of L2 is in the range of [6, 30]. With other parameters unchanged, inputting different values ​​of L2 within [6, 30] into the target mechanical model, it can be found that when L2 is 6 to 9, the lateral force of the drill bit is larger.

[0296] For example, the second key parameter is the size of the stabilizer, specifically the size (outer diameter) D of stabilizer 1.s1 And D s1 The value range of is [202, 214]. With other parameters remaining unchanged, the different values ​​of D within [202, 214] will be... s1 Inputting this into the target mechanical model, we can obtain that the lateral force of the drill bit varies with D. s1 It decreases as D increases. Therefore, a smaller D is chosen. s1 It is beneficial to increase the lateral force of the drill bit in the stable deviated well section.

[0297] For example, the second key parameter is the size of the stabilizer, specifically the size (outer diameter) D of stabilizer 2. s2 And D s2 The value range of is [202, 214]. With other parameters remaining unchanged, the different values ​​of D within [202, 214] will be... s2 Inputting this into the target mechanical model, we can obtain that the lateral force of the drill bit varies with D. s2 It increases with the increase of D. Therefore, a larger D is selected. s2 It is beneficial to increase the lateral force of the drill bit in the stable deviated well section.

[0298] Based on the above embodiments, considering the drill bit lateral force corresponding to different values ​​of key parameters, the target parameter (including key parameters) corresponding to the maximum drill bit lateral force can be selected, thereby determining the corresponding drill string assembly and drilling parameters; alternatively, the target parameter corresponding to the closest preset drill bit lateral force can be selected, thereby determining the corresponding drill string assembly and drilling parameters.

[0299] In some embodiments, multiple sets of large-value drill bit lateral forces can be selected from the calculation results of the target mechanical model. Then, from the drill bit angles corresponding to the multiple sets of large-value drill bit lateral forces, the target drill bit angle that is closest to the preset drill bit angle can be selected. From the target parameters corresponding to the target drill bit angle, the corresponding drill string assembly and drilling parameters can be extracted as the target drill string assembly and target drilling parameters of the target well.

[0300] In some embodiments, after determining the similarity parameters between the neighboring well and the target well based on drilling data of the neighboring well and preset parameters of the target well, the method further includes:

[0301] S1: Detect whether the similarity parameter is less than or equal to the second similarity threshold;

[0302] S2: If the similarity threshold is determined to be less than or equal to the second similarity threshold, the target drill string combination of the adjacent well is taken as the target drill string combination of the target well; and the target drilling parameters of the adjacent well are taken as the target drilling parameters of the target well.

[0303] S3: Control the drilling tools to drill the target well according to the target drill string assembly and the target drilling parameters of the target well.

[0304] In some embodiments, if the cumulative wellbore curvature difference parameter of the build-up section is less than or equal to the second similarity threshold, it indicates that the neighboring well and the target well have a high degree of similarity in the build-up section. Therefore, the target drilling parameters and drill string combination of the neighboring well can be directly applied to the build-up section of the target well to control the drilling tools to drill the build-up section of the target well.

[0305] In some embodiments, if the cumulative wellbore curvature difference parameter of the stable deviated section is less than or equal to the second similarity threshold, it indicates that the neighboring well and the target well have a high degree of similarity in the stable deviated section. Therefore, the target drilling parameters and drill string combination of the neighboring well can be directly applied to the stable deviated section of the target well to control the drilling tools to drill the stable deviated section of the target well.

[0306] Based on the above drilling control method, this specification also proposes an embodiment of a drilling control device, see reference. Figure 4 As shown, the drilling control device specifically includes the following modules: acquisition module 401, construction module 402, first calculation module 403, detection module 404, second calculation module 405, and control module 406.

[0307] The acquisition module 401 is used to acquire the preset parameters of the target well and the drilling data of the adjacent wells of the target well.

[0308] Module 402 is used to obtain the target mechanical model of the drilling tool based on the drilling data of adjacent wells;

[0309] The first calculation module 403 is used to determine the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well; wherein, the similarity parameters include at least one of the following: the cumulative wellbore curvature difference parameter of the deflection section and the cumulative wellbore curvature difference parameter of the stable deflection section;

[0310] Detection module 404 is used to detect whether the similarity parameter is greater than or equal to the first similarity threshold;

[0311] The second calculation module 405 is used to determine the target drilling tool combination and the target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well when the similarity parameter is determined to be greater than or equal to the first similarity threshold.

[0312] The control module 406 is used to control the drilling tools to drill the target well according to the target drilling tool combination and the target drilling parameters of the target well.

[0313] In some embodiments, the construction module 402 is specifically used to construct an initial mechanical model of the drilling tool; and to correct the initial mechanical model based on drilling data from adjacent wells to obtain a target mechanical model of the drilling tool.

[0314] In some embodiments, the first calculation module 403 is specifically used to extract the wellbore curvature per unit depth of multiple adjacent wells' directional drilling sections from the drilling data of adjacent wells; extract the wellbore curvature per unit depth of multiple target wells' directional drilling sections from preset parameters of the target well; sum the wellbore curvature per unit depth of multiple adjacent wells' directional drilling sections to obtain the cumulative wellbore curvature of the adjacent wells' directional drilling sections; sum the wellbore curvature per unit depth of multiple target wells' directional drilling sections to obtain the cumulative wellbore curvature of the target wells' directional drilling sections; and obtain the cumulative wellbore curvature difference parameter of the directional drilling sections based on the cumulative wellbore curvature of the adjacent wells' directional drilling sections and the cumulative wellbore curvature of the target wells' directional drilling sections.

[0315] In some embodiments, the first calculation module 403 is specifically used to extract the wellbore curvature per unit depth of multiple adjacent well stable inclination sections from the drilling data of adjacent wells; extract the wellbore curvature per unit depth of multiple target well stable inclination sections from preset parameters of the target well; sum the wellbore curvature per unit depth of multiple adjacent well stable inclination sections to obtain the cumulative wellbore curvature of the adjacent well stable inclination sections; sum the wellbore curvature per unit depth of multiple target well stable inclination sections to obtain the cumulative wellbore curvature of the target well stable inclination section; and obtain the cumulative wellbore curvature difference parameter of the stable inclination section based on the cumulative wellbore curvature of the adjacent well stable inclination sections and the cumulative wellbore curvature of the target well stable inclination section.

[0316] In some embodiments, the second calculation module 405 is specifically used to extract the target well construction parameters from the preset parameters of the target well; input the target well construction parameters into the target mechanical model to obtain the drill bit lateral force and the drill bit rotation angle of the target well; and determine the target drill string assembly and the target drilling parameters of the target well based on the drill bit lateral force and the drill bit rotation angle of the target well.

[0317] In some embodiments, the apparatus is further configured to extract from the drilling data of adjacent wells multiple sets of drill string assemblies, multiple sets of drilling parameters of adjacent wells, and multiple sets of composite drilling ratios of adjacent wells; wherein the drill string assemblies, drilling parameters, and composite drilling ratios correspond one-to-one; detect whether the composite drilling ratio is greater than a first preset value, and filter out composite drilling ratios greater than the first preset value as the first composite drilling ratio; determine the drill string assembly corresponding to the first composite drilling ratio as the target drill string assembly of the adjacent well; and determine the drilling parameters corresponding to the first composite drilling ratio as the target drilling parameters of the adjacent well.

[0318] In some embodiments, the device is further configured to detect whether the similarity parameter is less than a first similarity threshold and greater than a second similarity threshold; if it is determined that the similarity parameter is less than the first similarity threshold and greater than the second similarity threshold, modify the target drill string combination and the target drilling parameters of the adjacent well to obtain the target drill string combination and the target drilling parameters of the target well; and control the drilling tool to drill the target well according to the target drill string combination and the target drilling parameters of the target well.

[0319] In some embodiments, the apparatus is further configured to detect whether the similarity parameter is less than or equal to a second similarity threshold; if it is determined that the similarity threshold is less than or equal to the second similarity threshold, to use the target drill string combination of the adjacent well as the target drill string combination of the target well; and to use the target drilling parameters of the adjacent well as the target drilling parameters of the target well; and to control the drilling tool to drill the target well according to the target drill string combination and the target drilling parameters of the target well.

[0320] It should be noted that the units, devices, or modules described in the above embodiments can be implemented by computer chips or physical entities, or by products with certain functions. For ease of description, the above devices are described by dividing them into various modules according to their functions. Of course, in implementing this specification, the functions of each module can be implemented in one or more software and / or hardware, or the module that implements the same function can be implemented by a combination of multiple sub-modules or sub-units, etc. The device embodiments described above are merely illustrative. For example, the division of units is only a logical functional division, and there may be other division methods in actual implementation. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection between the devices or units shown or discussed can be through some interfaces, and the indirect coupling or communication connection between devices or units can be electrical, mechanical, or other forms.

[0321] This specification also provides a computer storage medium for a drilling control method, wherein the computer storage medium stores computer program instructions, which, when executed by a processor, perform the following: acquiring preset parameters of a target well; acquiring drilling data of adjacent wells of the target well; obtaining a target mechanical model of the drilling tool based on the drilling data of the adjacent wells; determining a similarity parameter between the adjacent wells and the target well based on the drilling data of the adjacent wells and the preset parameters of the target well; wherein the similarity parameter includes at least one of the following: a cumulative wellbore curvature difference parameter in the build-up section and a cumulative wellbore curvature difference parameter in the stable section; detecting whether the similarity parameter is greater than or equal to a first similarity threshold; if the similarity parameter is determined to be greater than or equal to the first similarity threshold, determining a target drill string assembly and target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well; and controlling the drilling tool to drill the target well based on the target drill string assembly and target drilling parameters of the target well.

[0322] In this embodiment, the storage medium includes, but is not limited to, Random Access Memory (RAM), Read-Only Memory (ROM), cache, hard disk drive (HDD), or memory card. The memory can be used to store computer program instructions. The network communication unit can be an interface configured according to standards specified in the communication protocol for network connection communication.

[0323] In this embodiment, the specific functions and effects implemented by the program instructions stored in the computer storage medium can be explained in comparison with other implementation methods, and will not be repeated here.

[0324] This specification also provides a server, including a processor and a memory for storing processor-executable instructions. In specific implementations, the processor can perform the following steps according to the instructions: acquiring preset parameters of a target well; acquiring drilling data of adjacent wells; obtaining a target mechanical model of the drilling tool based on the drilling data of the adjacent wells; determining a similarity parameter between the adjacent wells and the target well based on the drilling data of the adjacent wells and the preset parameters of the target well; wherein the similarity parameter includes at least one of the following: a cumulative wellbore curvature difference parameter in the build-up section and a cumulative wellbore curvature difference parameter in the stable-inclination section; detecting whether the similarity parameter is greater than or equal to a first similarity threshold; if the similarity parameter is determined to be greater than or equal to the first similarity threshold, determining the target drill string assembly and target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well; and controlling the drilling tool to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

[0325] To execute the above instructions more accurately, please refer to... Figure 5 As shown in the embodiments of this specification, another specific server is also provided, wherein the server includes a network communication port 501, a processor 502 and a memory 503, and the above structures are connected by internal cables so that the various structures can perform specific data interaction.

[0326] Specifically, the network communication port 501 can be used to acquire preset parameters of the target well and to acquire drilling data of adjacent wells of the target well.

[0327] The processor 502 can specifically be used to obtain a target mechanical model of the drilling tool based on the drilling data of the adjacent well; determine a similarity parameter between the adjacent well and the target well based on the drilling data of the adjacent well and the preset parameters of the target well; wherein the similarity parameter includes at least one of the following: a cumulative wellbore curvature difference parameter in the build-up section and a cumulative wellbore curvature difference parameter in the stable section; detect whether the similarity parameter is greater than or equal to a first similarity threshold; if the similarity parameter is determined to be greater than or equal to the first similarity threshold, determine the target drill string assembly and the target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well; and control the drilling tool to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

[0328] The memory 503 can be used to store the corresponding instruction program.

[0329] In this embodiment, the network communication port 501 can be a virtual port bound to different communication protocols, thereby enabling the sending or receiving of different data. For example, the network communication port can be a port responsible for web data communication, a port responsible for FTP data communication, or a port responsible for email data communication. Furthermore, the network communication port can also be a physical communication interface or communication chip. For example, it can be a wireless mobile network communication chip, such as GSM or CDMA; it can also be a Wi-Fi chip; or it can be a Bluetooth chip.

[0330] In this embodiment, the processor 502 can be implemented in any suitable manner. For example, the processor can take the form of a microprocessor or processor and a computer-readable medium storing computer-readable program code (e.g., software or firmware) executable by the (micro)processor, logic gates, switches, application-specific integrated circuits (ASICs), programmable logic controllers, and embedded microcontrollers, etc. This specification is not limiting.

[0331] In this embodiment, the memory 503 may include multiple layers. In a digital system, anything that can store binary data can be a memory. In an integrated circuit, a circuit with storage function but no physical form is also called a memory, such as RAM, FIFO, etc. In a system, a storage device with a physical form is also called a memory, such as a memory stick, TF card, etc.

[0332] While this specification provides the steps of operation for the methods described in the embodiments or flowcharts, more or fewer steps may be included based on conventional or non-inventive means. The order of steps listed in the embodiments is merely one possible order of execution among many steps and does not represent the only possible order. In actual device or client product execution, the methods shown in the embodiments or drawings may be executed sequentially or in parallel (e.g., in a parallel processor or multi-threaded processing environment, or even a distributed data processing environment). The terms "comprising," "including," or any other variations thereof are intended to cover a non-exclusive inclusion, such that a process, method, product, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, product, or apparatus. Without further limitations, the presence of other identical or equivalent elements in a process, method, product, or apparatus that includes said elements is not excluded. The terms "first," "second," etc., are used to denote names and do not indicate any particular order.

[0333] Those skilled in the art will also know that, besides implementing the controller using purely computer-readable program code, the same functions can be achieved by logically programming the method steps, making the controller function as logic gates, switches, application-specific integrated circuits (ASICs), programmable logic controllers (PLCs), and embedded microcontrollers. Therefore, such a controller can be considered a hardware component, and the devices within it used to implement various functions can also be considered structures within that hardware component. Alternatively, the devices used to implement various functions can be considered as both software modules implementing the method and structures within a hardware component.

[0334] This specification can be described in the general context of computer-executable instructions that are executed by a computer, such as program modules. Generally, program modules include routines, programs, objects, components, data structures, classes, etc., that perform a specific task or implement a specific abstract data type. This specification can also be practiced in distributed computing environments, where tasks are performed by remote processing devices connected via a communication network. In distributed computing environments, program modules can reside in local and remote computer storage media, including storage devices.

[0335] As can be seen from the above description of the embodiments, those skilled in the art can clearly understand that this specification can be implemented by means of software plus necessary general-purpose hardware platforms. Based on this understanding, the technical solutions of this specification can essentially be embodied in the form of a software product. This computer software product can be stored in a storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., and includes several instructions to cause a computer device (which may be a personal computer, mobile terminal, server, or network device, etc.) to execute the methods described in the various embodiments or some parts of the embodiments of this specification.

[0336] The various embodiments in this specification are described in a progressive manner. Similar or identical parts between embodiments can be referred to interchangeably. Each embodiment focuses on its differences from other embodiments. This specification can be used in numerous general-purpose or special-purpose computer system environments or configurations. Examples include: personal computers, server computers, handheld or portable devices, tablet devices, multiprocessor systems, microprocessor-based systems, set-top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, and distributed computing environments including any of the above systems or devices, etc.

[0337] Although this specification has been described by way of examples, those skilled in the art will recognize that many variations and modifications are possible without departing from the spirit of this specification, and it is intended that the appended claims cover such variations and modifications without departing from the spirit of this specification.

Claims

1. A drilling control method, characterized in that, The method includes: Obtain the preset parameters of the target well; and obtain the drilling data of the adjacent wells of the target well; Based on drilling data from adjacent wells, a target mechanical model of the drilling tool is obtained; Based on the drilling data of neighboring wells and the preset parameters of the target well, a similarity parameter between the neighboring well and the target well is determined; wherein, the similarity parameter includes at least one of the following: cumulative wellbore curvature difference parameter of the build-up section, and cumulative wellbore curvature difference parameter of the stable section; Detect whether the similarity parameter is greater than or equal to the first similarity threshold; If the similarity parameter is determined to be greater than or equal to the first similarity threshold, the target drilling tool assembly and target drilling parameters of the target well are determined according to the target mechanical model and the preset parameters of the target well. Based on the target drill string assembly and target drilling parameters of the target well, the drilling tools are controlled to drill the target well. The method further includes: From the drilling data of adjacent wells, we extract the drill string assemblies, drilling parameters, and composite drilling ratios of multiple adjacent wells; among them, the drill string assemblies, drilling parameters, and composite drilling ratios correspond one-to-one. Detect whether the composite drilling ratio is greater than the first preset value, and filter out the composite drilling ratios that are greater than the first preset value as the first composite drilling ratio; Determine the drill string combination corresponding to the first composite drilling ratio as the target drill string combination for the adjacent well; The drilling parameters corresponding to the first composite drilling ratio are determined as the target drilling parameters for the adjacent well; wherein, the target drilling parameters for the adjacent well are used to determine the target drill string combination and the target drilling parameters for the target well.

2. The method according to claim 1, characterized in that, Based on drilling data from adjacent wells, a target mechanical model for the drilling tool is obtained, including: Construct an initial mechanical model of the drilling tool; Based on drilling data from adjacent wells, the initial mechanical model is corrected to obtain the target mechanical model of the drilling tool.

3. The method according to claim 1, characterized in that, When the similarity parameters include the cumulative wellbore curvature difference parameter of the build-up well section, the similarity parameters between the neighboring well and the target well are determined based on the drilling data of the neighboring well and the preset parameters of the target well, including: Extract the wellbore curvature per unit depth of multiple adjacent wells from the drilling data of adjacent wells; Extract the wellbore curvature per unit depth of multiple target wells from the preset parameters of the target wells; The cumulative wellbore curvature of the adjacent well deviated well sections is obtained by summing the wellbore curvature per unit depth of multiple adjacent well deviated well sections; The cumulative wellbore curvature of the target well's inclined section is obtained by summing the wellbore curvature per unit depth of the multiple target wells' inclined sections. Based on the cumulative wellbore curvature of the adjacent well's inclined section and the cumulative wellbore curvature of the target well's inclined section, the cumulative wellbore curvature difference parameter of the inclined section is obtained.

4. The method according to claim 1, characterized in that, When the similarity parameters include the cumulative wellbore curvature difference parameter of the stable well section, the similarity parameters between the neighboring well and the target well are determined based on the drilling data of the neighboring well and the preset parameters of the target well, including: Extract the wellbore curvature per unit depth of the stable inclination section of multiple adjacent wells from the drilling data of adjacent wells; Extract the wellbore curvature per unit depth of the stable deviation section of multiple target wells from the preset parameters of the target wells; The cumulative wellbore curvature of the adjacent well stable deflection sections is obtained by summing the wellbore curvature per unit depth of multiple adjacent well stable deflection sections; The cumulative wellbore curvature of the stable deviated well section of the target well is obtained by summing the wellbore curvature per unit depth of the stable deviated well section of the target well. Based on the cumulative wellbore curvature of the stable inclination section of the adjacent well and the cumulative wellbore curvature of the stable inclination section of the target well, the cumulative wellbore curvature difference parameter of the stable inclination section is obtained.

5. The method according to claim 1, characterized in that, Based on the target mechanical model and the preset parameters of the target well, the target drill string assembly and target drilling parameters of the target well are determined, including: Extract the target well construction parameters from the preset parameters of the target well; The target well construction parameters are input into the target mechanical model to obtain the drill bit lateral force and drill bit rotation angle of the target well; Based on the lateral force of the drill bit and the drill bit rotation angle of the target well, determine the target drill string assembly and the target drilling parameters of the target well.

6. The method according to claim 1, characterized in that, After determining the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well, the method further includes: Detect whether the similarity parameter is less than a first similarity threshold and greater than a second similarity threshold; If the similarity parameter is determined to be less than the first similarity threshold and greater than the second similarity threshold, the target drill string combination and the target drilling parameters of the adjacent well are modified to obtain the target drill string combination and the target drilling parameters of the target well. The drilling tools are controlled to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

7. The method according to claim 1, characterized in that, After determining the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well, the method further includes: Detect whether the similarity parameter is less than or equal to the second similarity threshold; If the similarity threshold is determined to be less than or equal to the second similarity threshold, the target drill string combination of the adjacent well is taken as the target drill string combination of the target well; and the target drilling parameters of the adjacent well are taken as the target drilling parameters of the target well. The drilling tools are controlled to drill the target well based on the target drill string assembly and the target drilling parameters of the target well.

8. A drilling control device, characterized in that, The device includes: The acquisition module is used to acquire the preset parameters of the target well and the drilling data of the adjacent wells of the target well. The module is used to obtain the target mechanical model of the drilling tool based on drilling data from adjacent wells; The first calculation module is used to determine the similarity parameters between the neighboring well and the target well based on the drilling data of the neighboring well and the preset parameters of the target well; wherein, the similarity parameters include at least one of the following: the cumulative wellbore curvature difference parameter of the deflection section and the cumulative wellbore curvature difference parameter of the stable deflection section; The detection module is used to detect whether the similarity parameter is greater than or equal to a first similarity threshold; The second calculation module is used to determine the target drilling tool combination and the target drilling parameters of the target well based on the target mechanical model and the preset parameters of the target well when the similarity parameter is determined to be greater than or equal to the first similarity threshold. The control module is used to control the drilling tools to drill the target well according to the target drill string assembly and the target drilling parameters of the target well; The device is further configured to: extract multiple sets of drill string assemblies, drilling parameters, and composite drilling ratios of adjacent wells from drilling data of adjacent wells; wherein the drill string assemblies, drilling parameters, and composite drilling ratios correspond one-to-one; detect whether the composite drilling ratio is greater than a first preset value, and select composite drilling ratios greater than the first preset value as the first composite drilling ratio; determine the drill string assembly corresponding to the first composite drilling ratio as the target drill string assembly of the adjacent well; determine the drilling parameters corresponding to the first composite drilling ratio as the target drilling parameters of the adjacent well; wherein the target drilling parameters of the adjacent well are used to determine the target drill string assembly and target drilling parameters of the target well.

9. A computer-readable storage medium, characterized in that, It stores computer instructions that, when executed by a processor, implement the steps of the method according to any one of claims 1 to 7.

Images