A method, device, medium and equipment for evaluating the difficulty of wellbore trajectory drilling

Abstract

The present invention discloses a method, device, medium, and equipment for evaluating the drilling difficulty of a wellbore trajectory. The method includes: obtaining the horizontal and vertical projections of the wellbore trajectory, obtaining the first and second well inclination angles of the target segment based on the vertical projection, and obtaining the horizontal azimuth of the target segment based on the horizontal projection; calculating the full-angle change rate of the target segment based on the first well inclination angle, the second well inclination angle, and the horizontal azimuth; calculating the axial force exerted on the drill bit based on the length of the target segment and the drill bit weight; calculating the bending additional contact force based on the effective weight per unit length of the tubing; calculating the friction resistance of the target segment based on the friction resistance exerted on the drill bit at the starting point of the target segment; calculating the friction torque based on the bending additional contact force, the length of the target segment, the friction torque exerted on the drill bit at the starting point of the target segment, and the outer diameter of the drill bit; and determining the drilling difficulty level of the wellbore trajectory based on the friction resistance and friction torque. The above scheme enables an accurate evaluation of the drilling difficulty.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas field drilling, and in particular to a method, device, medium and equipment for evaluating the difficulty of wellbore trajectory drilling. Background Art

[0002] With the ever-increasing demand for oil in modern society, oil exploration and development have become globalized, with drilling operations spread across the globe. The challenges faced in drilling engineering design and construction are becoming increasingly complex, and safety issues often arise during the drilling process. Therefore, before drilling begins, a thorough assessment of the drilling difficulty should be conducted to ensure that operators fully understand the specific difficulty of the drilling task and improve the success rate of drilling.

[0003] There are two main existing methods for evaluating drilling difficulty. One is to calculate the friction resistance or friction torque during the drilling process and then evaluate the drilling difficulty based on the friction resistance and friction torque.

[0004] Since the existing technology calculates the friction resistance or friction torque during the drilling process mainly through empirical estimation or simplified engineering models, many variables that affect the friction resistance and friction torque are ignored in the calculation process. Therefore, the calculated friction resistance and friction torque are not accurate enough, resulting in an inaccurate evaluation of the drilling difficulty. Summary of the Invention

[0005] Based on this, it is necessary to provide a method, device, medium and equipment for evaluating the difficulty of wellbore trajectory drilling to address the technical problem that existing technologies cannot accurately evaluate the difficulty of drilling.

[0006] The present invention adopts the following technical solutions:

[0007] In a first aspect, the present invention provides a method for evaluating the difficulty of drilling a wellbore trajectory, the method comprising:

[0008] Obtain horizontal and vertical projections of the wellbore trajectory;

[0009] For each target segment in the wellbore trajectory, the first well inclination angle and the second well inclination angle of the target segment at the two end points are obtained based on the vertical projection, and the horizontal azimuth angle of the target segment is obtained based on the horizontal projection; the full-angle change rate of the target segment is calculated based on the first well inclination angle, the second well inclination angle and the horizontal azimuth angle; the axial force exerted on the drill tool when drilling in the target segment is calculated based on the full-angle change rate, the length of the target segment and the bit weight of the drill tool; the effective pressure per unit length of the tubing used in the wellbore trajectory is calculated based on the axial force, the full-angle change rate and the effective pressure per unit length of the tubing used in the wellbore trajectory. weight, calculate the additional bending contact force experienced by the drill tool when drilling the target section; calculate the friction resistance experienced by the drill tool when drilling the target section based on the additional bending contact force, the length of the target section, and the friction resistance experienced by the drill tool at the starting point of the target section; calculate the friction torque experienced by the drill tool when drilling the target section based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool, and obtain the friction resistance and friction torque experienced by the drill tool when drilling each target section;

[0010] The drilling difficulty level of the wellbore trajectory is determined based on the friction resistance and friction torque encountered by the drilling tool when drilling each target section.

[0011] Furthermore, the full angle change rate of the target section is calculated according to the first well inclination angle, the second well inclination angle and the horizontal azimuth angle. The specific expression is:

[0012] ;

[0013] ;

[0014] in, γ is the full angle change rate of the target segment, is the average well inclination angle of the target section, is the first well inclination angle, is the second well inclination angle, is the difference between the first well inclination angle and the second well inclination angle, is the difference in horizontal azimuth angles of the target segment at the two endpoints.

[0015] Furthermore, the axial force on the drill bit when drilling in the target section is calculated based on the full angle change rate, the length of the target section, and the weight on bit of the drill bit. The specific expression is:

[0016] ;

[0017] in, T en is the axial force, is the weight on bit of the drill tool, is the effective weight per unit length of the tubing used in the wellbore trajectory, For the i +1 length between the end of the track closest to the bottom of the well and the bottom of the well, For the i The length between the end of the track closest to the bottom of the well and the bottom of the well. L i+1 is the length of the target segment, γ is the full angle change rate of the target segment.

[0018] Furthermore, the bending additional contact force on the drilling tool during drilling in the target section is calculated based on the axial force, the full-angle change rate, and the effective weight per unit length of the tubing string used for the wellbore trajectory. The specific expression is:

[0019] ;

[0020] in, F Add contact force for the bend, q ei is the effective weight per unit length of the tubing used in the wellbore trajectory, γ is the full angle change rate of the target segment, T en is the axial force, R is the curvature radius of the vertical projection of the target segment.

[0021] Furthermore, the frictional resistance encountered by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, and the frictional resistance encountered by the drill tool at the starting point of the target section. The specific expression is:

[0022] ;

[0023] in, F Adding contact forces for the bends, T i is the friction resistance encountered by the drilling tool at the starting point of the target section, T i+1 is the friction resistance encountered by the drilling tool at the end point of the target section, For the i +1 length between the end of the track closest to the bottom of the well and the bottom of the well, For the i The length between the end of the track closest to the bottom of the well and the bottom of the well. is the length of the target segment, μ is the friction coefficient.

[0024] Furthermore, the friction torque experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool. The specific expression is:

[0025] ;

[0026] in, M i is the friction torque experienced by the drill at the starting point of the target segment, is the friction torque experienced by the drilling tool at the end point of the target section, For the i +1 length between the end of the track closest to the bottom of the well and the bottom of the well, For the i The length between the end of the track closest to the bottom of the well and the bottom of the well. is the length of the target segment, μ is the friction coefficient, r o is the outer diameter of the drill tool.

[0027] Furthermore, the drilling difficulty level of the wellbore trajectory is determined based on the friction resistance and friction torque encountered by the drilling tool during drilling in each target section, specifically including:

[0028] The drilling difficulty level of the wellbore trajectory in the target section is determined according to the numerical ranges of the friction resistance of the target section and the friction torque of the target section.

[0029] In a second aspect, the present invention provides a wellbore trajectory drilling difficulty evaluation device, comprising:

[0030] An acquisition module, used to obtain horizontal and vertical projections of the wellbore trajectory;

[0031] The calculation module is used to obtain, for each target segment in the wellbore trajectory, a first well inclination angle and a second well inclination angle of the target segment at two end points based on the vertical projection, and obtain a horizontal azimuth angle of the target segment based on the horizontal projection; calculate the full-angle change rate of the target segment based on the first well inclination angle, the second well inclination angle and the horizontal azimuth angle; calculate the axial force exerted on the drill tool when drilling in the target segment based on the full-angle change rate, the length of the target segment and the bit weight of the drill tool; calculate the axial force exerted on the drill tool based on the axial force, the full-angle change rate and the unit length of the tubing used in the wellbore trajectory; The effective weight of the drill bit is used to calculate the additional bending contact force applied to the drill bit when drilling the target section; the friction resistance applied to the drill bit when drilling the target section is calculated based on the additional bending contact force, the length of the target section, and the friction resistance applied to the drill bit at the starting point of the target section; the friction torque applied to the drill bit when drilling the target section is calculated based on the additional bending contact force, the length of the target section, the friction torque applied to the drill bit at the starting point of the target section, and the outer diameter of the drill bit, thereby obtaining the friction resistance and friction torque applied to the drill bit when drilling each target section;

[0032] The determination module is used to determine the drilling difficulty level of the wellbore trajectory according to the friction resistance and friction torque encountered by the drilling tool when drilling each target section.

[0033] The present invention provides a computer-readable storage medium, wherein the storage medium stores a computer program, and when the computer program is executed by a processor, the method for evaluating the difficulty of drilling a wellbore trajectory is implemented.

[0034] The present invention provides a computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the program, a method for evaluating the difficulty of drilling a wellbore trajectory is implemented.

[0035] At least one technical solution employed by the present invention can achieve the following beneficial effects: Based on the horizontal and vertical projections of the wellbore trajectory, the present invention can accurately obtain the wellbore inclination angle and the horizontal azimuth angle of each target segment at its two endpoints, thereby accurately calculating the full-angle change rate of the target segment based on the wellbore inclination angle and the horizontal azimuth angle of each target segment. Furthermore, based on the calculated full-angle change rate and the length of the target segment, combined with the drill bit weight, the axial force borne by each target segment is calculated; based on the axial force and the full-angle change rate, combined with the effective weight per unit length of the tubing used in the wellbore trajectory, the bending additional contact force of each target segment is calculated; based on the bending additional contact force and the length of the target segment, combined with the friction resistance of the drill bit at the starting point of each target segment, the friction resistance encountered by the drill bit in each target segment is accurately calculated; and based on the bending additional contact force and the length of the target segment, combined with the friction torque of the drill bit at the starting point of the target segment and the outer diameter of the drill bit, the friction torque encountered by the drill bit in each target segment is calculated. Through the above scheme, when calculating multiple intermediate variables of friction resistance and friction torque, combined with the properties of multiple target sections themselves and the parameters of the drilling tool, the friction resistance and friction torque of the target section can be accurately obtained, thereby achieving an accurate evaluation of the drilling difficulty. BRIEF DESCRIPTION OF THE DRAWINGS

[0036] The drawings described herein are used to provide a further understanding of the present invention and constitute a part of the present invention. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute an improper limitation of the present invention. In the drawings:

[0037] Figure 1 A flow chart of a well trajectory drilling difficulty evaluation method provided by the present invention;

[0038] Figure 2 The vertical and horizontal projections of the wellbore trajectory provided by the present invention at the target section;

[0039] Figure 3 A three-dimensional trajectory diagram of the wellbore trajectory provided by the present invention;

[0040] Figure 4 A curve diagram of the friction resistance encountered by the drilling tool provided by the present invention when working in the target section;

[0041] Figure 5 A curve diagram of the friction torque experienced by the drilling tool provided by the present invention when working in the target section;

[0042] Figure 6 A schematic diagram of a wellbore trajectory drilling difficulty evaluation device provided by the present invention;

[0043] Figure 7A schematic diagram of a computer device for implementing a wellbore trajectory drilling difficulty evaluation method provided by the present invention. DETAILED DESCRIPTION

[0044] To make the objectives, technical solutions, and advantages of the present invention more clear, the technical solutions of the present invention will be clearly and completely described below in conjunction with specific embodiments of the present invention and corresponding drawings. Obviously, the embodiments described are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of the present invention.

[0045] The server mentioned in the present invention can be a server installed on a business platform, or a device such as a desktop computer or laptop computer capable of executing the solution of the present invention. For ease of explanation, the following description will only use the server as the execution entity. The following, combined with the accompanying drawings, details the technical solutions provided by various embodiments of the present invention.

[0046] Figure 1 The figure is a flow chart of a method for evaluating the difficulty of drilling a wellbore trajectory according to the present invention, which specifically includes the following steps:

[0047] S10: Obtain the horizontal projection and the vertical projection of the wellbore trajectory.

[0048] In this embodiment, the wellbore trajectory refers to all trajectories from the wellhead to the bottom of the well. Figure 2 , Figure 2 (a) in the figure is the vertical projection of the wellbore trajectory in the target section. Figure 2 (b) in the figure is the horizontal projection of the wellbore trajectory at the target section, where N represents the north-south displacement and E represents the east-west displacement. In this embodiment, the target section of the wellbore trajectory is a cylindrical spiral with a constant spiral angle, i.e., the inclination section of the wellbore trajectory. The inclination section refers to the section of the well where the drilling tool is used for directional inclination during the drilling process. In this section of the well, the wellbore trajectory gradually turns from the vertical direction to the inclination direction to achieve the desired inclination angle. The horizontal direction refers to the direction parallel to the ground, i.e. Figure 2 In (a), the S direction refers to the direction perpendicular to the ground, that is, Figure 2 The H direction in (a). Well inclination refers to the angle between the central axis of a point in an oil or water well and the plumb line of the earth, and is used to indicate the inclination of the wellbore trajectory.

[0049] refer to Figure 1 , the vertical projection and horizontal projection of the target segment are both arcs. The arc length between the starting point A and a certain point M of the vertical projection of the target segment is represented. B is the end point of the vertical projection. The well inclination angle at point B is the second well inclination angle. Represents the arc length between the starting point of the horizontal projection and a point M.

[0050] From the arc length formula, we know that R and r The calculation formulas are:

[0051] ;

[0052] ;

[0053] in, R represents the curvature radius of the vertical projection, is the curvature constant of the vertical projection, is the well inclination angle of the starting point A, that is, the first well inclination angle. r represents the curvature radius of the horizontal projection, is the curvature constant of the horizontal projection.

[0054] Specifically, the well inclination angle of a point M in the vertical projection of the target segment Deflection angle with the first well The relationship expression is:

[0055] ;

[0056] in, R represents the curvature radius of the vertical projection, L 0 is the projection position of the starting point A in the vertical direction, L is the projection position of a point M in the target segment in the vertical direction, that is, = L - L 0 .

[0057] Specifically, the horizontal azimuth of a point M in the horizontal projection of the target segment Horizontal azimuth from starting point A The relationship expression is:

[0058] ;

[0059] in, r represents the curvature radius of the horizontal projection, S 0 is the horizontal projection position of the starting point A, S is the horizontal projection position of a point M in the target segment, that is, S= S - S 0.

[0060] Specifically, the calculation formula for the three-dimensional coordinates (X, Y, Z) of a point M in the target segment is:

[0061] (sin );

[0062] ( );

[0063] (sin );

[0064] refer to Figure 3 The coordinates of the starting point of the target segment are (0, 0, -1000), and the coordinates of the ending point of the target segment are (200, 100, -1200), where the units of X, Y, and Z coordinates are meters.

[0065] S20: For each target segment in the wellbore trajectory, obtain the first and second well inclination angles of the target segment at the two end points based on the vertical projection, and obtain the horizontal azimuth of the target segment based on the horizontal projection; calculate the full-angle change rate of the target segment based on the first well inclination angle, the second well inclination angle and the horizontal azimuth; calculate the axial force applied to the drill bit when drilling in the target segment based on the full-angle change rate, the length of the target segment and the drilling pressure of the drill bit; calculate the bending additional contact force applied to the drill bit when drilling in the target segment based on the axial force, the full-angle change rate and the effective weight per unit length of the tubing; calculate the friction resistance applied to the drill bit when drilling in the target segment based on the bending additional contact force, the length of the target segment and the friction resistance applied to the drill bit at the starting point of the target segment; calculate the friction torque applied to the drill bit when drilling in the target segment based on the bending additional contact force, the length of the target segment, the friction torque applied to the drill bit at the starting point of the target segment and the outer diameter of the drill bit, and obtain the friction resistance and friction torque applied to the drill bit when drilling in each target segment.

[0066] In this embodiment, the full angle change rate of the target section is calculated based on the first well inclination angle, the second well inclination angle, and the horizontal azimuth. The specific expression is:

[0067] ;

[0068] ;

[0069] Among them, among them, γ is the full angle change rate of the target segment, is the average well inclination angle of the target section, is the first well inclination angle, is the second well inclination angle, is the difference between the first well inclination angle and the second well inclination angle, It is the difference in horizontal azimuth between the two endpoints of the target segment.

[0070] In this embodiment, the axial force on the drill tool during drilling in the target section is calculated based on the full angle change rate, the length of the target section, and the weight on bit of the drill tool. The specific expression is:

[0071] ;

[0072] in, T en is the axial force, is the drilling weight of the drilling tool, is the effective weight per unit length of the string, For the i +1 length between the end of the track closest to the bottom of the well and the bottom of the well, For the i The length between the end of the track closest to the bottom of the well and the bottom of the well. L i+1 - is the length of the target segment, γ is the full angle change rate of the target segment.

[0073] In this embodiment, the additional bending contact force on the drill string during drilling in the target section is calculated based on the axial force, the full-angle change rate, and the effective weight per unit length of the pipe string. The specific expression is:

[0074] ;

[0075] in, F is the additional contact force for bending, q ei is the effective weight per unit length of the string, in N / m, γ is the full angle change rate of the target segment, T en is the axial force, R is the curvature radius of the vertical projection of the target segment.

[0076] Among them, q ei The calculation expression is:

[0077] ;

[0078] ;

[0079] in, K B is the buoyancy coefficient, is the drilling fluid density, in g / cm 3 , is the steel density of the pipe column, in g / cm 3 , q ciIt is the weight per unit length of the pipe in air, in N / m.

[0080] In this embodiment, the frictional resistance experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, and the frictional resistance experienced by the drill tool at the starting point of the target section. The specific expression is:

[0081] ;

[0082] in, F Additional contact force for bending, T i is the friction resistance of the drilling tool at the starting point of the target section, T i+1 is the friction resistance of the drilling tool at the end point of the target section, For the i +1 length between the end of the track closest to the bottom of the well and the bottom of the well, For the i The length between the end of the track closest to the bottom of the well and the bottom of the well. is the length of the target segment, μ is the friction coefficient.

[0083] refer to Figure 4 When drilling in the target section, the frictional resistance experienced by the drill string decreases nonlinearly with increasing well depth. From 0 to 1000 meters, the frictional resistance experienced by the drill string is a fixed value of 175 kN*m. At a depth of 2500 meters, the frictional resistance is zero.

[0084] In this embodiment, the friction torque experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool. The specific expression is:

[0085] ;

[0086] in, M i is the friction torque of the drill bit at the starting point of the target section, is the friction torque of the drill bit at the end point of the target section, For the i +1 length between the end of the track closest to the bottom of the well and the bottom of the well, For the i The length between the end of the track closest to the bottom of the well and the bottom of the well. is the length of the target segment, μ is the friction coefficient, r o is the outer diameter of the drill tool.

[0087] refer to Figure 5 When drilling in the target section, the friction torque experienced by the drill string decreases nonlinearly with increasing well depth. From 0 to 1000 meters, the friction torque experienced by the drill string is 11.2 kN*m, and at a depth of 2500 meters, the friction torque is zero.

[0088] S30: Determine the drilling difficulty level of the wellbore trajectory based on the friction resistance and friction torque experienced by the drilling tool when drilling each target section.

[0089] based on Figure 1 A method for evaluating the drilling difficulty of a wellbore trajectory is shown. Based on the horizontal and vertical projections of the wellbore trajectory, the wellbore inclination angle and the horizontal azimuth of each target segment at its two endpoints can be accurately obtained. This allows the full-angle variation rate of the target segment to be accurately calculated based on the wellbore inclination angle and the horizontal azimuth of each target segment. Furthermore, the axial force borne by each target segment is calculated based on the calculated full-angle variation rate and the length of the target segment, combined with the drill string's weight on bit. The bending additional contact force of each target segment is then calculated based on the axial force and the full-angle variation rate, combined with the effective weight per unit length of the tubing used in the wellbore trajectory. The friction resistance encountered by the drill string during drilling in each target segment is then accurately calculated based on the bending additional contact force and the length of the target segment, combined with the friction resistance of the drill string at the starting point of each target segment. Furthermore, the friction torque encountered by the drill string during drilling in each target segment is calculated based on the bending additional contact force and the length of the target segment, combined with the friction torque of the drill string at the starting point of the target segment and the outer diameter of the drill string. Through the above scheme, when calculating multiple intermediate variables of friction resistance and friction torque, combined with the properties of multiple target sections themselves and the parameters of the drilling tool, the friction resistance and friction torque of the target section can be accurately obtained, thereby achieving an accurate evaluation of the drilling difficulty.

[0090] When applying the method for evaluating the difficulty of drilling a wellbore trajectory provided by the present invention, it is not necessary to Figure 1 The steps are executed in the order shown. The specific execution order of the steps can be determined according to needs, and the present invention does not limit this.

[0091] Furthermore, in one or more embodiments of the present invention, the drilling difficulty level of the wellbore trajectory is determined based on the friction resistance and friction torque encountered by the drilling tool during drilling of each target section, specifically including:

[0092] The drilling difficulty level of the wellbore trajectory in the target section is determined according to the numerical ranges of the friction resistance and the friction torque of the target section.

[0093] In this embodiment, after determining the drilling difficulty level of the wellbore trajectory in the target section, since the friction-torque diagram can clearly observe the high friction-torque section, the wellbore trajectory can be optimized and different build-up rates can be selected to ensure the passability of the drill tool, so that the drill tool assembly can be lowered more smoothly and ensure that the drill tool assembly can be smoothly lowered into the target layer section; in addition, under the premise of meeting the requirements for safe drilling, the drill tool assembly can be optimized, the number of weighted drill pipes can be increased, the bending and vibration of the drill tool can be reduced in the wellbore, high-strength drill pipes can be used in the well section with a large build-up rate to reduce the deformation of the drill tool, and different target parameters such as the inner and outer diameters and line weights of the drill tool can be selected; finally, the drilling pressure suitable for the local formation can be selected based on other adjacent well data, and the drilling fluid can be optimized. For the high friction-torque section, a drilling fluid with good lubrication performance can be selected to ensure good fluidity at the bottom of the well, reduce the friction between the drill tool and the cuttings, and keep the wellbore clean. Through the above technical means, the friction-torque can be effectively reduced, thereby achieving the goal of reducing the drilling difficulty level.

[0094] The difficulty level is used to measure the difficulty of drilling a target section of a wellbore trajectory. For example, Table 1 shows the drilling difficulty levels corresponding to different friction torques and different friction resistances.

[0095] Table 1 Drilling difficulty levels corresponding to different friction torques and friction resistances

[0096]

[0097] Among them, level one represents easy, level two represents moderate difficulty, and level three represents difficult.

[0098] The scheme shown in this embodiment uses friction resistance in different numerical ranges and friction torque in different numerical ranges to grade the drilling difficulty, which can accurately measure the difficulty of drilling in the target section of the wellbore trajectory, allowing construction personnel to grasp the difficulty of the drilling work in advance, improve the success rate of drilling, and reduce the risks in the drilling work.

[0099] Optionally, in one or more embodiments of the present invention, after determining the drilling difficulty level of the wellbore trajectory in the target section based on the friction resistance and friction torque, the optimal drill tool combination can be selected based on the friction resistance and friction torque through a pre-trained drill tool recommendation model to reduce the difficulty of the drill tool during the drilling process and improve the drilling efficiency.

[0100] The drilling tool recommendation model is trained based on a multi-layer perceptron (MLP). The specific training process is as follows:

[0101] Step 1: During the drilling operation, friction resistance, friction torque, build-up rate, drilling parameters, and drill tool assembly data are acquired to obtain a data set. Drilling parameters include, but are not limited to, drilling fluid performance parameters (e.g., density, viscosity), bit pressure, and well depth.

[0102] Step 2: Preprocess the dataset to obtain a preprocessed dataset. The preprocessing process includes data cleaning and data normalization.

[0103] Step 3: Design the MLP network structure. The number of neurons in the input layer should be the same as the number of input features, that is, 2 (friction resistance and friction torque). The number of neurons in the output layer is determined by the output dimension. For example, if the build rate has 1 value and the drilling parameters have 3 values (drilling fluid density, bit pressure, and well depth), and if the drill tool assembly has n possible encodings, the number of neurons in the output layer should be n + 4. The number of hidden layers and neurons needs to be determined through experimentation and tuning. Generally, one to three hidden layers can be used initially, with 10 to 100 neurons per layer.

[0104] Step 4: Select the activation function: for the hidden layer, the activation function is ReLU or Sigmoid; for the output layer, use the linear activation function for the build-up rate; and use the Softmax activation function for the drill tool assembly and drilling parameters.

[0105] Step 5, model training:

[0106] Initialization parameters: Use normal distribution or uniform distribution to initialize the model weights. The bias can be initialized to 0 or a small constant.

[0107] Define the loss function: for predicting the build rate, use the mean square error loss function; for predicting the drill tool assembly type and drilling parameters, use the cross entropy loss function.

[0108] Select optimization algorithm: Select the Adaptive Moment Estimation (Adam) algorithm as the optimization algorithm.

[0109] Training: Split the preprocessed data into a training set and a validation set in a 7:3 ratio. During training, the training data is fed into the model, and the output is calculated using forward propagation. The loss function is then used to calculate the loss between the predicted results and the true labels. Backpropagation is then used to calculate the gradient and update the network weights and biases. This process is repeated until the loss function converges or the preset number of training rounds is reached. After each round of training, the model's performance is evaluated on the validation set, observing metrics such as loss and accuracy on the validation set to prevent overfitting.

[0110] Step 6: Model evaluation and tuning:

[0111] Model evaluation: Use the test set data to evaluate the trained model, calculate the values of various evaluation indicators, and observe the model's generalization ability on unknown data.

[0112] Hyperparameter tuning: Based on the model evaluation results, adjust and optimize the model's hyperparameters. Methods for adjusting hyperparameters include but are not limited to grid search, random search, and genetic algorithms.

[0113] Specifically, such as Figure 4 and Figure 5 As shown, the friction resistance is 175 kN and the friction torque is 11.2 kN*m. According to the evaluation criteria, this evaluation level is Level 2. Therefore, a data set including friction resistance, friction torque, build-up rate, drilling parameters, and drill tool assembly was obtained. Through parameter optimization, a smoother build-up rate was selected. Drill pipe and drill collars of the same steel grade but different strengths were selected while ensuring safe drilling. A low-density drilling fluid within the safe density window was selected. The bit pressure was appropriately increased. Ultimately, the friction resistance value was reduced to 86 kN and the friction torque value to 6.4 kN*m, thus downgrading the drilling evaluation level to Level 1.

[0114] The above is a method for evaluating the difficulty of drilling a wellbore trajectory provided by one or more embodiments of the present invention. Based on the same idea, the present invention also provides a corresponding device for evaluating the difficulty of drilling a wellbore trajectory, such as Figure 6 Shown, including:

[0115] The acquisition module is used to obtain the horizontal projection and vertical projection of the wellbore trajectory.

[0116] The calculation module is used to obtain, for each target segment in the wellbore trajectory, a first well inclination angle and a second well inclination angle of the target segment at two end points based on the vertical projection, and obtain the horizontal azimuth angle of the target segment based on the horizontal projection; calculate the full-angle change rate of the target segment based on the first well inclination angle, the second well inclination angle, and the horizontal azimuth angle; calculate the axial force applied to the drill tool when drilling in the target segment based on the full-angle change rate, the length of the target segment, and the weight on bit of the drill tool; calculate the additional bending contact force applied to the drill tool when drilling in the target segment based on the axial force, the full-angle change rate, and the effective weight per unit length of the tubing; calculate the friction resistance applied to the drill tool when drilling in the target segment based on the additional bending contact force, the length of the target segment, and the friction resistance applied to the drill tool at the starting point of the target segment; calculate the friction torque applied to the drill tool when drilling in the target segment based on the additional bending contact force, the length of the target segment, the friction torque applied to the drill tool at the starting point of the target segment, and the outer diameter of the drill tool, thereby obtaining the friction resistance and friction torque applied to the drill tool when drilling in each target segment.

[0117] The determination module is used to determine the drilling difficulty level of the wellbore trajectory according to the friction resistance and friction torque encountered by the drilling tool when drilling in each target section.

[0118] The specific definition of a wellbore trajectory drilling difficulty assessment device can be found in the definition of a wellbore trajectory drilling difficulty assessment method described above and will not be repeated here. Each module in the wellbore trajectory drilling difficulty assessment device can be implemented in whole or in part via software, hardware, or a combination thereof. Each module can be embedded in or independent of a processor in a computer device in hardware form, or can be stored in a computer device memory in software form, so that the processor can call and execute the corresponding operations of each module.

[0119] The present invention also provides a computer-readable storage medium, wherein the storage medium stores a computer program, which can be used to execute the Figure 1 A method for evaluating the difficulty of wellbore trajectory drilling is provided.

[0120] The present invention also provides Figure 7 The structural diagram of the computer equipment shown in FIG. Figure 7 As shown, at the hardware level, the computer device includes a processor, an internal bus, a network interface, a memory, and a non-volatile memory, and may also include hardware required for other services. The processor reads the corresponding computer program from the non-volatile memory into the memory and then runs it to implement the Figure 1 A method for evaluating the difficulty of wellbore trajectory drilling is provided.

[0121] Those skilled in the art will appreciate that all or part of the processes in the described method embodiments can be implemented by instructing the relevant hardware using a computer program. The computer program can be stored in a non-volatile computer-readable storage medium. When executed, the computer program can include the processes of the described method embodiments. Any reference to memory, storage, database, or other media used in the embodiments provided herein may include at least one of non-volatile and volatile memory. Non-volatile memory may include read-only memory (ROM), magnetic tape, floppy disk, flash memory, or optical storage. Volatile memory may include random access memory (RAM) or external cache memory. By way of illustration and not limitation, RAM can take various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM).

[0122] The technical features of the above embodiments can be combined arbitrarily. In order to make the description concise, not all possible combinations of the technical features in the embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of the present invention.

Claims

1. A method for evaluating the difficulty of drilling a wellbore trajectory, characterized in that: include: Obtain horizontal and vertical projections of the wellbore trajectory; For each target segment in the wellbore trajectory, a first well inclination angle and a second well inclination angle of the target segment at two end points are obtained based on the vertical projection, and a horizontal azimuth angle of the target segment is obtained based on the horizontal projection; a full-angle change rate of the target segment is calculated based on the first well inclination angle, the second well inclination angle, and the horizontal azimuth angle; an axial force applied to the drill tool when drilling in the target segment is calculated based on the full-angle change rate, the length of the target segment, and the weight on bit of the drill tool; and an additional bending contact force applied to the drill tool when drilling in the target segment is calculated based on the axial force, the full-angle change rate, and the effective weight per unit length of the tubing used in the wellbore trajectory. Calculating the frictional resistance experienced by the drill tool when drilling in the target section based on the additional bending contact force, the length of the target section, and the frictional resistance experienced by the drill tool at the starting point of the target section; Calculating the friction torque experienced by the drill tool during drilling in the target section based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool to obtain the friction resistance and friction torque experienced by the drill tool during drilling in each target section; determining a drilling difficulty level of the wellbore trajectory based on the friction resistance and friction torque experienced by the drilling tool during drilling of each target section; The axial force on the drill bit during drilling in the target section is calculated based on the full angle change rate, the length of the target section, and the weight on bit of the drill bit. The specific expression is: T en =-W0+q ei ×(L i+1 -L i )×cosγ; Among them, T en is the axial force, W0 is the drilling pressure of the drilling tool, q ei is the effective weight per unit length of the tubing used in the wellbore trajectory, L i+1 L is the length between the end of the i+1th track closest to the bottom of the well and the bottom of the well, i is the length between the end of the i-th track near the bottom of the well and the bottom of the well, L i+1 -L i is the length of the target segment, γ is the full angle change rate of the target segment; The additional bending contact force on the drilling tool during drilling in the target section is calculated based on the axial force, the full-angle change rate, and the effective weight per unit length of the tubing used in the wellbore trajectory. The specific expression is: Where F is the additional contact force of the bending, q ei is the effective weight per unit length of the tubing used in the wellbore trajectory, γ is the full angle change rate of the target section, T en is the axial force, R is the curvature radius of the vertical projection of the target segment; The frictional resistance experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, and the frictional resistance experienced by the drill tool at the starting point of the target section. The specific expression is: T i+1 =T i +|F|×(L i+1 -L i )×μ; Where F is the additional contact force of the bending, T i is the friction resistance encountered by the drilling tool at the starting point of the target section, T i+1 is the friction resistance encountered by the drilling tool at the end of the target section, L i+1 L is the length between the end of the i+1th track closest to the bottom of the well and the bottom of the well, i is the length between the end of the i-th track near the bottom of the well and the bottom of the well, L i+1 -L i is the length of the target segment, μ is the friction coefficient; The friction torque experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool. The specific expression is: M i+1 =M i +|F|×(L i+1 -L i )×μ×r o ; Among them, M i is the friction torque of the drill bit at the starting point of the target segment, M i+1 is the friction torque experienced by the drill at the end of the target section, L i+1 L is the length between the end of the i+1th track closest to the bottom of the well and the bottom of the well, i is the length between the end of the i-th track near the bottom of the well and the bottom of the well, L i+1 -L i is the length of the target segment, μ is the friction coefficient, r o is the outer diameter of the drill tool.

2. A method for evaluating the difficulty of wellbore trajectory drilling according to claim 1, characterized in that: The full angle change rate of the target section is calculated according to the first well inclination angle, the second well inclination angle and the horizontal azimuth angle. The specific expression is: Wherein, γ is the full angle change rate of the target segment, α c is the average well inclination angle of the target section, α1 is the first well inclination angle, α2 is the second well inclination angle, Δα is the difference between the first well inclination angle and the second well inclination angle, is the difference in horizontal azimuth angles of the target segment at the two endpoints.

3. A method for evaluating the difficulty of wellbore trajectory drilling according to claim 1, characterized in that: The drilling difficulty level of the wellbore trajectory is determined based on the friction resistance and friction torque encountered by the drilling tool during drilling in each target section, specifically including: The drilling difficulty level of the wellbore trajectory in the target section is determined according to the numerical ranges of the friction resistance of the target section and the friction torque of the target section.

4. A wellbore trajectory drilling difficulty evaluation device, characterized in that: include: An acquisition module, used to obtain horizontal and vertical projections of the wellbore trajectory; a calculation module configured to obtain, for each target segment in the wellbore trajectory, a first well inclination angle and a second well inclination angle of the target segment at two end points based on the vertical projection, and obtain a horizontal azimuth angle of the target segment based on the horizontal projection; calculate a full-angle change rate of the target segment based on the first well inclination angle, the second well inclination angle, and the horizontal azimuth angle; calculate an axial force applied to the drill tool during drilling in the target segment based on the full-angle change rate, the length of the target segment, and the weight on bit of the drill tool; and calculate a bending additional contact force applied to the drill tool during drilling in the target segment based on the axial force, the full-angle change rate, and the effective weight per unit length of the tubing used in the wellbore trajectory; Calculating the frictional resistance experienced by the drill tool when drilling in the target section based on the additional bending contact force, the length of the target section, and the frictional resistance experienced by the drill tool at the starting point of the target section; Calculating the friction torque experienced by the drill tool during drilling in the target section based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool to obtain the friction resistance and friction torque experienced by the drill tool during drilling in each target section; a determination module, configured to determine a drilling difficulty level of the wellbore trajectory based on the friction resistance and friction torque experienced by the drilling tool when drilling each target section; The axial force on the drill bit during drilling in the target section is calculated based on the full angle change rate, the length of the target section, and the weight on bit of the drill bit. The specific expression is: T en =-W0+q ei ×(L i+1 -L i )×cosγ; Among them, T en is the axial force, W0 is the drilling pressure of the drilling tool, q ei is the effective weight per unit length of the tubing used in the wellbore trajectory, L i+1 L is the length between the end of the i+1th track closest to the bottom of the well and the bottom of the well, i is the length between the end of the i-th track near the bottom of the well and the bottom of the well, L i+1 -L i is the length of the target segment, γ is the full angle change rate of the target segment; The additional bending contact force on the drilling tool during drilling in the target section is calculated based on the axial force, the full-angle change rate, and the effective weight per unit length of the tubing used in the wellbore trajectory. The specific expression is: Where F is the additional contact force of the bending, q ei is the effective weight per unit length of the tubing used in the wellbore trajectory, γ is the full angle change rate of the target section, T en is the axial force, R is the curvature radius of the vertical projection of the target segment; The frictional resistance experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, and the frictional resistance experienced by the drill tool at the starting point of the target section. The specific expression is: T i+1 =T i +|F|×(L i+1 -L i )×μ; Where F is the additional contact force of the bending, T i is the friction resistance encountered by the drilling tool at the starting point of the target section, T i+1 is the friction resistance encountered by the drilling tool at the end of the target section, L i+1 L is the length between the end of the i+1th track closest to the bottom of the well and the bottom of the well, i is the length between the end of the i-th track near the bottom of the well and the bottom of the well, L i+1 -L i is the length of the target segment, μ is the friction coefficient; The friction torque experienced by the drill tool during drilling in the target section is calculated based on the additional bending contact force, the length of the target section, the friction torque experienced by the drill tool at the starting point of the target section, and the outer diameter of the drill tool. The specific expression is: M i+1 =M i +|F|×(L i+1 -L i )×μ×r o ; Among them, M i is the friction torque of the drill bit at the starting point of the target segment, M i+1 is the friction torque experienced by the drill at the end of the target section, L i+1 L is the length between the end of the i+1th track closest to the bottom of the well and the bottom of the well, i is the length between the end of the i-th track near the bottom of the well and the bottom of the well, L i+1 -L i is the length of the target segment, μ is the friction coefficient, r o is the outer diameter of the drill tool.

5. A computer-readable storage medium, characterized in that The storage medium stores a computer program, and when the computer program is executed by a processor, the method for evaluating the difficulty of drilling a wellbore trajectory according to any one of claims 1 to 3 is implemented.

6. A computer device, characterized in that: The invention comprises a memory, a processor and a computer program stored in the memory and capable of running on the processor. When the processor executes the program, a method for evaluating the difficulty of drilling a wellbore trajectory according to any one of claims 1 to 3 is implemented.

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