Wellbore trajectory determination method

Abstract

This application discloses a method for determining a wellbore trajectory, belonging to the field of oilfield drilling technology. The method comprises obtaining multiple candidate wellbore trajectories for a planned well and determining the wellbore trajectory among the candidate trajectories whose test parameters meet target values ​​as the target wellbore trajectory for the planned well. The test parameters include the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, and the steady-angle angle of the long steady-angle section of the wellbore trajectory. This allows the wellbore trajectory to be determined based on multiple parameters, taking into account a more comprehensive range of factors.

Description

Technical Field

[0001] The present application relates to the technical field of oilfield drilling, and in particular to a method for determining a wellbore trajectory. Background Art

[0002] A wellbore trajectory is the path a well takes from the surface wellhead to the underground target area. The wellbore trajectory significantly impacts the tools and tubing used in drilling, directional drilling, logging, cementing, and subsequent production, so it is crucial to determine it. The method used to determine the wellbore trajectory directly impacts the overall profitability of a single well.

[0003] At present, a method for determining the wellbore trajectory is to analyze the advantageous orientation of the wellbore trajectory to improve the reservoir fracturing effect and wellbore stability through ground stress research, and use design software to design the wellbore trajectory that meets the advantageous orientation to improve drilling safety.

[0004] However, the above method only considers the impact of wellbore trajectory orientation on drilling safety, and the factors considered are not comprehensive enough. Summary of the Invention

[0005] The present application provides a method for determining a wellbore trajectory. The technical solution is as follows:

[0006] According to a first aspect of the present application, a method for determining a wellbore trajectory is provided, the method comprising:

[0007] Obtain multiple alternative wellbore trajectories for the designed well;

[0008] Determining an alternative wellbore trajectory whose test parameters meet target values ​​among the multiple alternative wellbore trajectories as the target wellbore trajectory of the designed well;

[0009] The test parameters include the borehole collision risk value, the full angle change rate of the borehole trajectory, and the stable inclination angle of the long stable inclination section of the borehole trajectory. The target value of the borehole collision risk value is greater than N1, and the range of N1 is 1 to 1.5. The collision risk value is F L ,

[0010] Wherein, a is the distance between the wellbore centers of the designed well and the adjacent well, b is the radius of the error ellipse of the wellbore trajectory of the designed well, and c is the radius of the error ellipse of the wellbore trajectory of the adjacent well;

[0011] The target value of the full angle change rate of the wellbore trajectory is less than N2° / 30m, and the N2° / 30m is 7° / 30m;

[0012] The target value of the steady inclination angle of the long steady inclination section of the wellbore trajectory is greater than N3°, wherein N3° is 10° when the drilling tool is a steerable drilling tool assembly, and N3° is 15° when the drilling tool is a steady inclination drilling tool assembly.

[0013] Optionally, the test parameters further include the weight on bit at the drill bit in sliding drilling, the torque at the drill bit in rotary drilling, and the maximum lateral force applied to the drill string;

[0014] The target value of the bit pressure during sliding drilling is greater than N4t, wherein when the drill bit outer diameter is ≥311.1mm, N4 is 10t; when 311.1mm> drill bit outer diameter ≥215.9mm, N4 is 8t; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 5t;

[0015] The target value of the torque value at the drill bit during rotary drilling is greater than N5N*m, wherein, when the drill bit outer diameter is ≥311.1mm, N5 is 8000; when 311.1mm> drill bit outer diameter ≥215.9mm, N5 is 6000; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 3000;

[0016] The target value of the maximum lateral force applied to the drill string is less than or equal to N6 kN, and the range of N6 is 1.5 kN to 2 kN.

[0017] Optionally, the test parameters further include the lowering position of the lifting tool and the fatigue safety factor of the drill string;

[0018] The fatigue safety factor value F of the drill string ti The target value is greater than N7, wherein the fatigue safety factor value satisfies: Wherein, d is the absolute value of the bending stress of the drill string, e is the absolute value of the buckling stress of the drill string, and f is the fatigue limit stress of the drill string;

[0019] Among them, when the drill rod is a grade 1 drill rod, N7 ​​is 1; when the drill rod is a grade P drill rod, N7 ​​is 1.25; when the drill rod is a grade 2 drill rod, N7 ​​is 1.33;

[0020] The target value of the lowering position of the lifting tool is greater than N8*m, where N8*m is the depth of the inclination point at the lower part of the wellbore trajectory.

[0021] Optionally, obtaining multiple alternative wellbore trajectories of the designed well includes:

[0022] Determining the maximum principal stress orientation and the minimum principal stress orientation of the formation, wherein the maximum principal stress orientation is perpendicular to the minimum principal stress orientation, and the maximum principal stress orientation is the dominant development orientation of the fracture;

[0023] Determining the horizontal orientation of the wellbore trajectory of the target layer based on the maximum principal stress orientation and the minimum principal stress orientation;

[0024] Obtaining the positions of multiple wellheads, the positions of multiple geological target points, and the vertical depth parameter of each geological target point based on the reservoir distribution area, the horizontal orientation of the wellbore trajectory of the target layer, etc.;

[0025] Based on the positions of the plurality of wellheads and the positions of the plurality of geological target points, matching the plurality of wellheads with the plurality of geological target points, wherein each wellhead is matched with at least one geological target point;

[0026] For a wellhead that matches at least two geological target points, adjusting the horizontal position of the geological target point so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range;

[0027] For any wellhead among the plurality of wellheads, determining a wellbore trajectory of a target layer segment to be determined for the any wellhead based on a position of the any wellhead, a position of a geological target point corresponding to the any wellhead, and a vertical depth parameter of the geological target point;

[0028] Adjusting the vertical depth parameter of the geological target point corresponding to any wellhead to reduce the drilling difficulty coefficient and full angle change rate of the wellbore trajectory of the undetermined target layer section;

[0029] Determining a wellbore trajectory of a target layer section of any wellhead based on the position of the wellhead, the position of a geological target point corresponding to the wellhead, and the adjusted vertical depth parameter of the geological target point;

[0030] Based on the wellbore trajectory of the target layer section of any wellhead, two wellbore trajectory types, namely the straight-increase-stabilization three-stage type and the straight-increase-stabilization five-stage type, are selected, the inclination point depth, full-angle change rate and well inclination angle of the wellbore trajectory design are adjusted, and multiple alternative wellbore trajectories for any wellhead are determined.

[0031] Optionally, determining the horizontal orientation of the wellbore trajectory of the target layer segment based on the maximum principal stress orientation and the minimum principal stress orientation includes:

[0032] The orientation perpendicular to the orientation of the maximum principal stress is determined as the horizontal orientation of the wellbore trajectory of the target layer interval.

[0033] Optionally, determining the maximum principal stress orientation and the minimum principal stress orientation of the formation includes:

[0034] The maximum principal stress orientation and the minimum principal stress orientation of the formation are determined based on formation coring measured data or formation orthogonal dipole array acoustic logging, formation microresistivity scanning imaging logging, formation dip logging data, or based on the direction of formation faults.

[0035] Optionally, determining the wellbore trajectory of the plurality of candidate wellbore trajectories whose test parameters meet target values ​​as the target wellbore trajectory of the designed well includes:

[0036] Obtain the ratio of horizontal displacement to vertical depth of the geological target with the deepest vertical depth;

[0037] When the ratio is less than or equal to 1, the test parameters further include the maximum lateral force on the drill string, the fatigue safety factor of the drill string, and the lowering position of the lifting tool;

[0038] When the ratio is greater than or equal to 1 and less than or equal to 2, the test parameters further include the weight on bit at the sliding drilling, the torque at the drill bit at the rotary drilling, the maximum lateral force applied to the drill string, the fatigue safety factor of the drill string, and the lowering position of the lifting tool;

[0039] When the ratio is greater than or equal to 2, the test parameters further include the weight on bit at the sliding drilling, the torque at the drill bit at the rotary drilling, and the lowering position of the lifting tool;

[0040] The target value of the bit pressure during sliding drilling is greater than N4t, wherein when the drill bit outer diameter is ≥311.1mm, N4 is 10t; when 311.1mm> drill bit outer diameter ≥215.9mm, N4 is 8t; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 5t;

[0041] The target value of the torque value at the drill bit during rotary drilling is greater than N5N*m, wherein, when the drill bit outer diameter is ≥311.1mm, N5 is 8000; when 311.1mm> drill bit outer diameter ≥215.9mm, N5 is 6000; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 3000;

[0042] The target value of the maximum lateral force on the drill string is less than or equal to N6kN, where N6 ranges from 1.5kN to 2kN;

[0043] The fatigue safety factor value F of the drill string ti The target value is greater than N7, wherein the fatigue safety factor value satisfies: Wherein, d is the absolute value of the bending stress of the drill string, e is the absolute value of the buckling stress of the drill string, and f is the fatigue limit stress of the drill string;

[0044] Among them, when the drill rod is a grade 1 drill rod, N7 ​​is 1; when the drill rod is a grade P drill rod, N7 ​​is 1.25; when the drill rod is a grade 2 drill rod, N7 ​​is 1.33;

[0045] The target value of the lowering position of the lifting tool is greater than N8*m, where N8*m is the depth of the inclination point at the lower part of the wellbore trajectory.

[0046] In another aspect, a wellbore trajectory determination device is provided, the wellbore trajectory determination device comprising:

[0047] An acquisition module, used to acquire multiple alternative wellbore trajectories of a designed well;

[0048] A determination module, configured to determine a wellbore trajectory whose test parameters meet target values ​​among the multiple candidate wellbore trajectories as a target wellbore trajectory of the designed well;

[0049] The test parameters include the borehole collision risk value, the full angle change rate of the borehole trajectory, and the stable inclination angle of the long stable inclination section of the borehole trajectory. The target value of the borehole collision risk value is greater than N1, and the range of N1 is 1 to 1.5. The collision risk value is F L ,

[0050] Wherein, a is the distance between the wellbore centers of the designed well and the adjacent wells, b is the radius of the error ellipse of the wellbore trajectory of the designed well, and c is the sum of the radii of the error ellipses of the wellbore trajectory of the adjacent wells;

[0051] The target value of the full angle change rate of the wellbore trajectory is less than N2° / 30m, and the N2° / 30m is 7° / 30m;

[0052] The target value of the steady inclination angle of the long steady inclination section of the wellbore trajectory is greater than N3°, wherein N3° is 10° when the drilling tool is a steerable drilling tool assembly, and N3° is 15° when the drilling tool is a steady inclination drilling tool assembly.

[0053] Optionally, the acquisition module includes:

[0054] A first determining unit is configured to determine a maximum principal stress orientation and a minimum principal stress orientation of the formation, wherein the maximum principal stress orientation is perpendicular to the minimum principal stress orientation, and the maximum principal stress orientation is a dominant development orientation of the fracture;

[0055] a second determining unit, configured to determine a horizontal orientation of a wellbore trajectory of a target layer segment based on the maximum principal stress orientation and the minimum principal stress orientation;

[0056] A first acquisition unit is configured to acquire positions of a plurality of wellheads, positions of a plurality of geological target points, and a vertical depth parameter of each of the geological target points based on the reservoir distribution area and the horizontal orientation of the wellbore trajectory of the target layer;

[0057] a matching unit, configured to match the plurality of wellheads with the plurality of geological target points based on the positions of the plurality of wellheads and the positions of the plurality of geological target points, wherein each wellhead is matched with at least one geological target point;

[0058] a first adjusting unit, configured to adjust, for a wellhead that matches at least two geological target points, a horizontal position of the geological target point so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range;

[0059] a third determining unit configured to determine, for any wellhead among the plurality of wellheads, a wellbore trajectory of a target layer segment to be determined for the any wellhead based on a position of the any wellhead, a position of a geological target point corresponding to the any wellhead, and a vertical depth parameter of the geological target point;

[0060] A second adjustment unit is used to adjust the vertical depth parameter of the geological target point corresponding to any wellhead to reduce the drilling difficulty coefficient and full angle change rate of the wellbore trajectory of the undetermined target layer section;

[0061] a fourth determining unit, configured to determine a wellbore trajectory of a target layer section of any wellhead based on the position of the any wellhead, the position of a geological target point corresponding to the any wellhead, and the adjusted vertical depth parameter of the geological target point;

[0062] The fifth determination unit is used to select two wellbore trajectory types, namely, a three-stage straight-increase stabilization type and a five-stage straight-increase stabilization type, based on the wellbore trajectory of the target layer segment of any wellhead, adjust the inclination point depth, full-angle change rate and well inclination angle of the wellbore trajectory design, and determine multiple alternative wellbore trajectories for any wellhead.

[0063] Optionally, the determining module includes:

[0064] A first acquisition unit is used to obtain the ratio of the horizontal displacement to the vertical depth of the geological target point with the deepest vertical depth;

[0065] a first determining unit, configured to determine required test parameters based on the ratio;

[0066] The second determining unit is configured to determine a wellbore trajectory whose test parameters meet target values ​​among the multiple candidate wellbore trajectories as a target wellbore trajectory of the designed well.

[0067] The beneficial effects of the technical solutions provided in the embodiments of the present application include at least:

[0068] A wellbore trajectory determination method is provided. By obtaining multiple candidate wellbore trajectories for a planned well, the target wellbore trajectory is determined as the one whose test parameters meet target values. The test parameters include the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, and the steady-angle angle of the long steady-angle section of the wellbore trajectory. This allows the wellbore trajectory to be determined based on these multiple parameters, taking into account a comprehensive range of factors. BRIEF DESCRIPTION OF THE DRAWINGS

[0069] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0070] Figure 1 This is a flow chart of a wellbore trajectory determination method provided in an embodiment of the present application;

[0071] Figure 2 This is a flow chart of a method for obtaining multiple alternative wellbore trajectories for a designed well provided in an embodiment of the present application;

[0072] Figure 3 Schematic diagram of the relationship between the maximum and minimum principal stress orientations and the fault distribution orientations provided in the embodiment of the present application;

[0073] Figure 4 It is a horizontal azimuth schematic diagram of the wellbore trajectory of the target layer section provided in the embodiment of the present application;

[0074] Figure 5 This is a schematic diagram of the matching of matrix-arranged wellheads and geological targets provided in an embodiment of the present application;

[0075] Figure 6 This is a schematic diagram of matching double-row rectangular wellheads with geological targets provided in an embodiment of the present application;

[0076] Figure 7 Schematic diagram of adjusting the horizontal position of the wellbore trajectory of the target layer section provided in an embodiment of the present application;

[0077] Figure 8 This is a schematic diagram of the horizontal positions of the wellhead and the target before target adjustment provided in an embodiment of the present application;

[0078] Figure 9 This is a schematic diagram of the horizontal position of the wellhead and the target after the target is adjusted according to an embodiment of the present application;

[0079] Figure 10 This is a schematic diagram of the preliminary design of the wellbore trajectory provided in the embodiment of the present application;

[0080] Figure 11 This is a schematic structural diagram of a wellbore trajectory determination device provided in an embodiment of the present application;

[0081] Figure 12 It is a structural diagram of an acquisition module provided in an embodiment of the present application.

[0082] The above drawings illustrate specific embodiments of the present application, which will be described in more detail below. These drawings and the textual description are not intended to limit the scope of the present application in any way, but rather to illustrate the concepts of the present application to those skilled in the art by reference to specific embodiments. DETAILED DESCRIPTION

[0083] In order to make the objectives, technical solutions and advantages of this application clearer, the implementation methods of this application will be further described in detail below with reference to the accompanying drawings.

[0084] Figure 1 : is a flow chart of a method for determining a wellbore trajectory according to an embodiment of the present application. The method for determining a wellbore trajectory may include the following steps:

[0085] Step 101: Acquire multiple alternative wellbore trajectories of a designed well;

[0086] Step 102: Determine the candidate wellbore trajectory whose test parameters meet the target value among the multiple candidate wellbore trajectories as the target wellbore trajectory of the designed well;

[0087] The test parameters include the borehole collision risk value, the full-angle change rate of the borehole trajectory, and the stable inclination angle of the long stable inclination section of the borehole trajectory. The target value of the borehole collision risk value is greater than N1, and the range of N1 is 1 to 1.5.

[0088] Among them, the collision risk value is F L , is the ratio of the distance between the wellbore centers of the designed well and the adjacent wells (an adjacent well refers to an implemented well or a well to be drilled that exists in a cylindrical space with the wellhead of the designed well as the center, the horizontal displacement as the radius, and the vertical depth of the well bottom as the height, where the horizontal displacement is the horizontal distance between the well bottom position and the wellhead position) to the sum of the error ellipse radius of the designed wellbore trajectory (the distance from the intersection of the line segment formed by connecting the two ellipse center points with each ellipse boundary to the center point of the ellipse is the ellipse radius) and the error ellipse radius of the adjacent wellbore trajectory, that is:

[0089]

[0090] The target value of the full-angle change rate of the wellbore trajectory is less than N2° / 30m (i.e., N2 degrees / 30 meters). N2° / 30m is generally determined according to the lifting process and the requirements of the running tool, and is generally set at 7° / 30m.

[0091] The full-angle change rate refers to the angular change in the wellbore axis in three dimensions per unit well section length. Specifically, it represents the angle of change in the wellbore's trajectory from one point on the wellbore axis to another. This angle reflects both changes in well inclination and azimuth. Due to varying lifting techniques and the requirement that the lifting tool must not deform during lowering, requirements for the full-angle change rate of the wellbore trajectory are in place.

[0092] The target value of the stable inclination angle of the long stable inclination section of the wellbore trajectory is greater than N3° (i.e., N3 degrees). When the drill tool is a steerable drilling tool assembly, the value of N3° is 10°, and when the drill tool is a stable inclination drilling tool assembly, the value of N3° is 15°.

[0093] In summary, the wellbore trajectory determination method provided in the embodiments of the present application obtains multiple candidate wellbore trajectories for a planned well and then determines the wellbore trajectory whose test parameters meet target values ​​as the target wellbore trajectory for the planned well. The test parameters include the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, and the steady-angle angle of the long steady-angle section of the wellbore trajectory. This allows the wellbore trajectory to be determined based on these multiple parameters, taking into account a more comprehensive range of factors.

[0094] In the embodiment of the present application, the test parameters may also include the weight on bit at the drill bit in sliding drilling, the torque at the drill bit in rotary drilling, and the maximum lateral force on the drill string;

[0095] The target value of the bit pressure during sliding drilling is greater than N4t (i.e., N4 tons). When the drill bit outer diameter is ≥311.1mm, N4 is 10t; when 311.1mm> drill bit outer diameter ≥215.9mm, N4 is 8t; when 215.9mm> drill bit outer diameter ≥152.4mm, N4 is 5t.

[0096] Sliding drilling involves creating direction and inclination. During this time, the drill string is pressed against the wellbore wall, creating significant friction. The weight on bit (WOB) equals drill string weight minus accumulated friction. This accumulated friction is directly related to the shape of the wellbore trajectory. If friction reaches a certain level, WOB becomes ineffective, preventing the drill bit from breaking rock. Therefore, the WOB at the drill bit during sliding drilling should be greater than N4.

[0097] The target value of the torque value at the drill bit during rotary drilling is greater than N5N*m (i.e., N5 Newton*meter). When the drill bit outer diameter is ≥311.1mm, N5 is 8000; when 311.1mm> drill bit outer diameter ≥215.9mm, N5 is 6000; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 3000;

[0098] During rotary drilling, the corresponding working condition is in the stable inclination section, and the drill string is in a rotating state. At this stage, the friction between the drill string and the well wall is very small, and the drill bit's drilling pressure is almost unaffected. The main consideration is whether the torque at the drill bit meets the target value.

[0099] The target value of the maximum lateral force on the drill string is less than or equal to N6kN (i.e., N6 kilonewtons), with the range of N6 being 1.5kN to 2kN;

[0100] The drill string is the inner drill rod of the wellbore, the tool used to drill the wellbore. The wellbore trajectory is spatially inclined, and the drill string has weight. When the drill string contacts the wellbore wall along the wellbore trajectory, pressure is generated. This pressure is the lateral force exerted on the drill string. The shape of the wellbore trajectory affects the amount of pressure exerted by the drill string on the wellbore wall, meaning that the shape of the wellbore trajectory affects the amount of lateral force.

[0101] Optionally, the test parameters may also include the lowering position of the lifting tool and the fatigue safety factor of the drill string;

[0102] Fatigue safety factor value F of drill string ti The target value is greater than N7, where the fatigue safety factor value satisfies: Where d is the absolute value of the drill string bending stress, e is the absolute value of the drill string buckling stress, and f is the fatigue limit stress of the drill string;

[0103] When the drill pipe is grade 1 (brand new), N7 is 1; when the drill pipe is grade P (80% new), N7 is 1.25; when the drill pipe is grade 2 (70% new), N7 is 1.33;

[0104] The wellbore trajectory is curved. When the drill string rotates in the wellbore, it will be subjected to alternating loads. When the alternating load reaches a critical value, it may break. This critical value is the fatigue safety factor of the drill string.

[0105] The target value of the lowering position of the lifting tool should be greater than N8*m (i.e. N8*meter), where N8*m is the depth of the inclination point at the bottom of the wellbore trajectory;

[0106] The lifting tool is a tool that lifts the oil, gas and water from the bottom of the well to the wellhead (including plunger pumps, screw pumps, electric submersible pumps, etc.). The lifting tool cannot be deformed when it is lowered into the wellbore, so the lowering position of the lifting tool must be considered.

[0107] Figure 2 A flowchart of a method for obtaining multiple alternative wellbore trajectories for a designed well provided in an embodiment of the present application is provided. The method for obtaining multiple alternative wellbore trajectories for a designed well may include the following steps:

[0108] Step 201: Determine the maximum principal stress orientation and the minimum principal stress orientation of the formation. The maximum principal stress orientation and the minimum principal stress orientation are perpendicular to each other. The maximum principal stress orientation is the dominant development orientation of the fracture, such as Figure 3 As shown in the figure, it is a schematic diagram of the relationship between the maximum and minimum principal stress orientations and the fault distribution orientations (the curves in the figure are contour lines).

[0109] The maximum principal stress σ of the formation can be determined based on the measured data of formation core sampling or the formation orthogonal dipole array acoustic logging, formation microresistivity scanning imaging logging, formation dip logging and other logging data. H Orientation and minimum principal stress σ h position;

[0110] Alternatively, if the aforementioned logging data is not available, the maximum principal stress σ can be determined based on the strike of the formation fault. H Orientation and minimum principal stress σ h Azimuth: According to the principle that cracks extend in the direction of minimum capacity loss, the principal stress perpendicular to the fault distribution direction is σ h Direction, and σ h The vertical direction (parallel to the fault distribution direction) is σ H ;

[0111] Maximum principal stress σ H The orientation is the dominant development orientation of the crack.

[0112] Step 202: Determine the horizontal orientation of the wellbore trajectory of the target layer based on the maximum principal stress orientation and the minimum principal stress orientation. Figure 4 The figure shows the horizontal azimuth diagram of the wellbore trajectory of the target layer.

[0113] The horizontal orientation of the wellbore trajectory of the target layer is perpendicular to the maximum principal stress σ H Orientation, that is, parallel to the minimum principal stress σ h Direction (such as Figure 4 This orientation is beneficial for fracturing to form fractures perpendicular to the wellbore axis, and is also beneficial for the wellbore to pass through as many natural fractures in the formation as possible, thereby increasing the oil and gas well production.

[0114] Alternatively, due to the influence of the formation dip, the horizontal orientation of the track cannot be perpendicular to the maximum principal stress σ H When the orientation is H and σ h The difference between the horizontal orientation of the wellbore trajectory and the orientation of the minimum principal stress is determined by ±a (e.g. Figure 4 (shown by the dashed line 2 in the middle), and then determine the horizontal orientation of the track. H and σ hWhen the difference is less than 5MPa, the angle between the horizontal orientation of the wellbore trajectory of the target layer and the orientation of the minimum principal stress is within ±45°. H and σ h When the difference is between 5MPa and 10MPa, the angle between the horizontal orientation of the wellbore trajectory of the target layer and the orientation of the minimum principal stress is within ±30°. H and σ h When the difference is greater than 10 MPa, the angle between the horizontal orientation of the wellbore trajectory of the target layer and the orientation of the minimum principal stress is within ±15°.

[0115] For example, the horizontal orientation of the wellbore trajectory is directly related to increasing the production of a single well. For fractured wells, the horizontal orientation of the wellbore trajectory is perpendicular to the orientation of the maximum principal stress, which can make the fractures easier to extend, expand the fracture transformation volume, and thus increase the production of a single well; for non-fractured wells (i.e., wells that do not undergo reservoir fracture transformation and only rely on the seepage channels of the formation for oil production), the horizontal orientation of the wellbore trajectory is perpendicular to the orientation of the maximum principal stress, which can allow the wellbore to pass through more natural fractures and increase the production of a single well.

[0116] Step 203: Based on the reservoir distribution area and the horizontal orientation of the wellbore trajectory of the target layer, the positions of multiple wellheads, the positions of multiple geological target points, and the vertical depth parameter of each geological target point are obtained.

[0117] The geological and engineering departments can determine the geological targets based on the reservoir distribution area, well pattern spacing, and horizontal orientation of the wellbore trajectory of the target layer in the reservoir engineering plan, and then determine the well site area. After that, the number and location of the wellheads are determined according to the development plan, and the wellheads are evenly distributed within the well site area.

[0118] Step 204: Based on the positions of the multiple wellheads and the positions of the multiple geological target points, the multiple wellheads are matched with the multiple geological target points, and each wellhead is matched with at least one geological target point.

[0119] The layout of wellheads depends primarily on the reservoir distribution and drilling equipment. If the reservoirs are primarily located on either side of the well site, a rectangular wellhead layout is used. If the reservoirs are distributed around the well site, a matrix wellhead layout is used. Matching wellheads and geological targets is essential to reduce the risk of collisions between the total well depth and the wellbore. Without this matching, arbitrarily selecting wellheads and targets for construction will result in a complex wellbore trajectory network in the lower part of the well site, potentially making some wellheads impossible to drill and forcing them to be abandoned. Therefore, meticulous matching of wellheads and their geological targets is essential.

[0120] (1) Figure 5 The figure shows a schematic diagram of the matching of matrix-arranged wellheads and geological targets.

[0121] a. Taking the center of the well site as the center point, divide all wellheads into n intervals according to the number of outermost wellheads n. Each interval radiates outward, including geological targets within the corresponding interval, and prioritizes matching wellheads and targets within the same interval.

[0122] b. Within the same interval, the wellhead and geological target are matched based on the shortest distance between the wellhead and the geological target in their horizontal projection diagram, that is, the principle of inside to inside and outside to outside. For wells with multiple targets, the wellhead is matched with the geological target closest to the wellhead. For the case where there are many wellheads and few targets within an interval, the wellhead and targets are matched across adjacent intervals based on the principle of inside to inside, outside to outside, and non-intersecting.

[0123] (2) Figure 6 The figure shows a schematic diagram of the matching of double-row rectangular wellheads and geological targets.

[0124] First, according to the number n of wellhead slots and the arrangement of wellheads, the reservoir area planned for the well site is divided into n areas with the same number of wellheads. According to the sorting rules of the wellheads, the n areas of the reservoir are numbered, and the wellheads with the same number are matched with the targets in the reservoir area. If it is a multi-target well, the reservoir area where the first target is located is matched with the wellhead with the corresponding number.

[0125] Step 205: For the wellhead that matches at least two geological target points, adjust the horizontal position of the geological target point so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range.

[0126] For example, Figure 7 The figure shows a schematic diagram of adjusting the horizontal orientation of the wellbore track of the target layer. a 、T b and Wellhead W H , if the geological target T a 、T b With Wellhead W H , the three points are not collinear, so we need to change T a To T a1 Direction adjustment or T b To T b1 Direction adjustment or T a To T a1 Direction and T b To T b1 The direction is adjusted at the same time, in order to meet the requirements of the geological department and the horizontal orientation of the track and σ h Under the condition that the angle between the track horizontal orientation and the wellhead W is within ±a (i.e. within the predetermined range), reduce the H The angle b can make the adjustment result wellhead W H 、T a、T b Collinear, that is, b is equal to 0. For geological targets with more than 2 points, the adjustment method is the same as above, and the adjustment result can be wellhead W H 、T a 、T b 、T c ...、T n Collinearity can greatly reduce the difficulty of drilling and improve drilling efficiency.

[0127] Step 206 : For any wellhead among the multiple wellheads, determine the wellbore trajectory of the target layer segment to be determined for any wellhead based on the position of the wellhead, the position of the geological target point corresponding to the wellhead, and the vertical depth parameter of the geological target point.

[0128] The geological target point, wellhead, and vertical depth parameters of the geological target point determined by adjustment in step 205 are used as initial data, and the well trajectory design software is applied to complete the preliminary well trajectory design.

[0129] Step 207: Adjust the vertical depth parameter of the geological target point corresponding to any wellhead to reduce the drilling difficulty coefficient and the full-angle change rate of the wellbore trajectory of the target layer to be determined.

[0130] Based on the preliminary wellbore trajectory design completed in step 206, in accordance with the principle of reducing construction difficulty and saving construction costs, the vertical depth of the geological target is adjusted with the goal of reducing the well inclination angle and the full angle change rate, such as T a Reduce vertical depth, T b Increase vertical depth, T c Reduce the vertical depth. Adjust the vertical depth of the geological target according to the conditions that prioritize the reservoir control requirements. If the azimuth parameters need to be adjusted simultaneously, adjust them according to the method of step 205 above.

[0131] Step 208: Determine the wellbore trajectory of the target layer section of any wellhead based on the position of any wellhead, the position of the geological target point corresponding to any wellhead, and the adjusted vertical depth parameter of the geological target point.

[0132] The target parameters determined in step 207 are used as the final geological target parameters, and the well trajectory design software is used to complete the well trajectory design. The geological target T a With T c The wellbore trajectory design is the wellbore trajectory determination plan for the final target layer section, which determines the wellbore trajectory of the target layer section at any wellhead.

[0133] Step 209: Based on the wellbore trajectory of the target layer section at any wellhead, select two wellbore trajectory types: a three-stage straight-increase-stabilization type and a five-stage straight-increase-stabilization type, adjust the inclination point depth, full-angle change rate, and well inclination angle of the wellbore trajectory design, and determine multiple alternative wellbore trajectories for any wellhead.

[0134] Under the condition that the wellbore trajectory parameters of the target layer determined by the method in step 208 remain unchanged, two wellbore trajectory types are selected: straight-increasing-stable three-stage and straight-increasing-stable-increasing-stable five-stage. The depth of the inclination point, the full angle change rate and the well inclination angle of the wellbore trajectory design are adjusted. The wellbore trajectory design software is used to design the optimal 2*n 3 There are several alternative well trajectory designs, where the inclination point, full angle change rate, and well inclination angle can have n values ​​and can match each other. According to the permutation and combination algorithm, theoretically, n possible combinations can be made. 3 There are two types of wellbore trajectories, so the final wellbore trajectory design alternatives can be 2*n 3 indivual.

[0135] Among them, the inclination point KP n A larger value means a smaller total well depth and lower drilling costs, but the friction torque increases, which reduces the applied weight on bit and affects the drilling speed. n If the full angle change rate deglog n If it is too large, it will affect whether the subsequent oil production equipment can be safely lowered. n The larger the angle, the worse the wellbore track cleanliness, the greater the total well depth, the greater the friction and torque, the more difficult it is to apply drilling pressure, the lower the drilling speed, and the inclination angle INC n Too small an angle is detrimental to trajectory control. When the angle is less than 15°, conventional inclination-stabilized drilling tools cannot effectively control the trajectory. Therefore, based on the parameters of the wellbore trajectory for the target interval, these three key parameters must be adjusted to determine multiple alternative wellbore trajectories for any wellhead.

[0136] Step 2091: Obtain the ratio of the horizontal displacement to the vertical depth of the geological target point with the deepest vertical depth;

[0137] When the ratio is less than or equal to 1, the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, the stable inclination angle of the long stable inclination section of the wellbore trajectory, the maximum lateral force on the drill string, the fatigue safety factor of the drill string, and the lowering position of the lifting tool need to be considered when determining the wellbore trajectory.

[0138] When the ratio is greater than or equal to 1 and less than or equal to 2, the wellbore trajectory should be determined by considering the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, the stable inclination angle of the long stable inclination section of the wellbore trajectory, the bit pressure during sliding drilling, the torque during rotary drilling, the maximum lateral force on the drill string, the fatigue safety factor of the drill string, and the lowering position of the lifting tool.

[0139] When the ratio is greater than or equal to 2, the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, the stable inclination angle of the long stable inclination section of the wellbore trajectory, the bit pressure during sliding drilling, the bit torque during rotary drilling, and the running position of the lifting tool need to be considered when determining the wellbore trajectory.

[0140] The target value of the bit pressure during sliding drilling is greater than N4t. When the drill bit outer diameter is ≥311.1mm, N4 is 10t; when 311.1mm> drill bit outer diameter ≥215.9mm, N4 is 8t; when 215.9mm> drill bit outer diameter ≥152.4mm, N4 is 5t.

[0141] The target torque value at the drill bit during rotary drilling is greater than N5N*m. When the drill bit outer diameter is ≥311.1mm, N5 is 8000; when 311.1mm> drill bit outer diameter ≥215.9mm, N5 is 6000; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 3000;

[0142] The target value of the maximum lateral force on the drill string is less than or equal to N6kN, where N6 ranges from 1.5kN to 2kN;

[0143] Fatigue safety factor value F of drill string ti The target value is greater than N7, where the fatigue safety factor value satisfies: Where d is the absolute value of the drill string bending stress, e is the absolute value of the drill string buckling stress, and f is the fatigue limit stress of the drill string;

[0144] Among them, when the drill rod is a grade 1 drill rod, N7 ​​is 1; when the drill rod is a grade P drill rod, N7 ​​is 1.25; when the drill rod is a grade 2 drill rod, N7 ​​is 1.33;

[0145] Alternatively, the total length of the wellbore trajectory, L, can be used. ZZX and Ibuka T D The sum of the above parameters can be used to determine the difficulty of drilling. For each wellbore trajectory that meets the above parameters for determining the wellbore trajectory, the total inclination length L of the wellbore trajectory can be used. ZZX and Ibuka T D The sum of the wellbore trajectory drilling difficulty is determined by the total length of the deflection section L. ZZX and Ibuka T D The smaller the sum, the lower the difficulty. A wellbore trajectory that meets the above parameters for determining the wellbore trajectory and has low drilling difficulty can be determined.

[0146] In summary, the wellbore trajectory determination method provided in the embodiments of the present application obtains multiple candidate wellbore trajectories for a planned well and then determines the wellbore trajectory whose test parameters meet target values ​​as the target wellbore trajectory for the planned well. The test parameters include the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, and the steady-angle angle of the long steady-angle section of the wellbore trajectory. This allows the wellbore trajectory to be determined based on these multiple parameters, taking into account a more comprehensive range of factors.

[0147] For example, a horizontal shale oil well is deployed in a fault block in an oil field. The wellhead slots are arranged in two rows of rectangles in an east-west direction, with 36 wellheads in each row, for a total of 72 wellheads. The wellbore trajectory of this well is designed according to the above method.

[0148] Determine the maximum principal stress orientation and minimum principal stress orientation of the formation according to the method in step 201. According to the X-MAC logging data of this well site, the maximum horizontal principal stress orientation of the target layer is between 55° and 65° northeast, which is basically consistent with the distribution direction of the main fault in this well site, which is 50° to 70°. Therefore, the maximum principal stress σ is determined. H Orientation and minimum principal stress σ h The directions are 55°-65° northeast and 145°-155° northeast respectively.

[0149] Determine the horizontal orientation of the wellbore trajectory of the target layer according to the method of step 202. According to the difference between the maximum and minimum horizontal principal stresses in this area <10MPa, determine the optimal horizontal orientation of the wellbore trajectory and σ h The maximum angle is ±15°, that is, 130°-170° northeast.

[0150] According to step 203, a preliminary plan of coordinates of three geological target points is obtained, as shown in Table 1.

[0151] Table 1 Target parameters

[0152]

[0153] According to step 204, the area is often divided into 72 regions equal to the number of wellheads. The target point a is matched with the corresponding target point in the corresponding area. The coordinates of the corresponding wellhead are: east-west: 503975.90m, north-south: 4227428.10m.

[0154] According to step 205, the horizontal position of the geological target point is adjusted so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range. a 、T b 、T c The horizontal projections are not collinear, e.g. Figure 8The figure shows the horizontal position diagram of the wellhead and the target before the target is adjusted (the horizontal axis is the east-west direction, and the vertical axis is the north-south direction). Since this well is a horizontal well, T a The window point is the intersection of the horizontal wellbore trajectory and the top surface of the oil and gas layer. Its position is critical for smooth window entry. Try not to adjust it. Therefore, adjust T b With T c The parameters of T are calculated by b Move 69.08m in the direction of 69.44°northeast, T c Move 89.06m to the south-west at 72.39°, and the wellhead is aligned with the adjusted target point T a 、T b1 、T c1 Four points are collinear, such as Figure 9 The figure shows the horizontal position diagram of the wellhead and the target after the target is adjusted (the horizontal axis is the east-west direction and the vertical axis is the north-south direction). The geological part is determined by seismic section projection. The adjustment plan is agreed and T is determined. b1 Coordinates: East-West: 504420.53m, North-South: 4226206.50m, T c1 Coordinates: East-West: 504557.33m, North-South: 4225830.62m.

[0155] According to step 206, step 207 and step 208, the wellbore trajectory design parameters of the target layer section of the wellhead are determined, as shown in Table 2, which are the wellbore trajectory design parameters of the target layer section. Apply the wellbore trajectory design software to form a preliminary wellbore trajectory design scheme, such as Figure 10 As shown in the figure, it is a schematic diagram of the preliminary design of the wellbore trajectory (the vertical depth of the wellbore trajectory is the vertical depth, and the horizontal coordinate is the horizontal displacement of the wellbore trajectory). Since this well is a horizontal well, it is affected by the reservoir thickness and occurrence, and the target vertical depth parameter cannot be adjusted. Therefore, the wellbore trajectory between the target point Ta and the bottom of the wellbore in the preliminary design of the wellbore trajectory is determined as the wellbore trajectory design for the preferred target layer segment.

[0156] Table 2 Well trajectory design parameters for target interval

[0157]

[0158] According to step 209, under the condition that the wellbore trajectory design parameters of the target layer remain unchanged, two wellbore trajectory types, straight-increasing-stable and straight-increasing-stable-increasing-stable, are designed. A total of 64 wellbore trajectory schemes are designed. The key parameters and numbers of the wellbore trajectories are shown in Table 3, which is the key parameter table of the preliminary wellbore trajectory design scheme.

[0159] Table 3 Key parameters of preliminary scheme for wellbore trajectory design

[0160]

[0161]

[0162] According to step 2091, the ratio of the horizontal displacement to the vertical depth of the geological target with the deepest vertical depth in this embodiment is obtained, and the result is HD / TVD = 1734.22 m / 3947.33 m = 0.44 < 1. Therefore, when determining the wellbore trajectory, it is necessary to consider whether the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, the stable inclination angle of the long stable inclination section of the wellbore trajectory, the maximum lateral force on the drill string, the fatigue safety factor of the drill string, and the lowering position of the lifting tool meet the target values. Table 4 shows the test parameters of the preliminary wellbore trajectory design scheme.

[0163] Table 4 Test parameters of the preliminary wellbore trajectory design scheme

[0164]

[0165]

[0166] The test parameters in the above table are screened, and the wellbore trajectory that meets all target values ​​is determined as the target wellbore trajectory of the designed well.

[0167] Figure 11 A wellbore trajectory determination device 110 provided in an embodiment of the present application includes an acquisition module 1101 and a determination module 1102:

[0168] The acquisition module 1101 is used to acquire multiple alternative wellbore trajectories of the designed well.

[0169] The determination module 1102 is configured to determine a wellbore trajectory whose test parameters meet target values ​​among the multiple candidate wellbore trajectories as a target wellbore trajectory for the designed well.

[0170] The test parameters include the borehole collision risk value, the full-angle change rate of the borehole trajectory, and the stable inclination angle of the long stable inclination section of the borehole trajectory. The target value of the borehole collision risk value is greater than N1, and the range of N1 is 1 to 1.5.

[0171] The target value of the full-angle change rate of the wellbore trajectory is less than N2° / 30m. N2° / 30m is generally determined according to the lifting process and the requirements of the running tool, and is generally set at 7° / 30m.

[0172] The target value of the stable inclination angle of the long stable inclination section of the wellbore trajectory is greater than N3°, wherein the value N3° is 10° when the drilling tool is a steerable drilling tool assembly, and the value N3° is 15° when the drilling tool is a stable inclination drilling tool assembly.

[0173] In summary, the wellbore trajectory determination method provided in the embodiments of the present application obtains multiple candidate wellbore trajectories for a planned well and then determines the wellbore trajectory whose test parameters meet target values ​​as the target wellbore trajectory for the planned well. The test parameters include the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, and the steady-angle angle of the long steady-angle section of the wellbore trajectory. This allows the wellbore trajectory to be determined based on these multiple parameters, taking into account a more comprehensive range of factors.

[0174] Figure 12 An acquisition module 1101 provided in an embodiment of the present application includes a first determination unit 11011, a second determination unit 11012, a first acquisition unit 11013, a matching unit 11014, a first adjustment unit 11015, a third determination unit 11016, a second adjustment unit 11017, a fourth determination unit 11018, and a fifth determination unit 11019:

[0175] The first determining unit 11011 is used to determine the maximum principal stress orientation and the minimum principal stress orientation of the formation, where the maximum principal stress orientation is the dominant development orientation of the fracture.

[0176] The second determining unit 11012 is configured to determine the horizontal orientation of the wellbore trajectory of the target layer segment based on the maximum principal stress orientation and the minimum principal stress orientation.

[0177] The first acquisition unit 11013 is used to acquire the positions of multiple wellheads, the positions of multiple geological targets, and the vertical depth parameters of each geological target based on the reservoir distribution area, the horizontal orientation of the wellbore trajectory of the target layer, etc.

[0178] The matching unit 11014 is configured to match the multiple wellheads with the multiple geological target points based on the positions of the multiple wellheads and the positions of the multiple geological target points, wherein each wellhead is matched with at least one geological target point.

[0179] The first adjustment unit 11015 is configured to adjust the horizontal position of the geological target point for a wellhead that matches at least two geological target points, so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range.

[0180] The third determination unit 11016 is used to determine the wellbore trajectory of the undetermined target layer segment of any wellhead among the multiple wellheads based on the position of any wellhead, the position of the geological target point corresponding to any wellhead, and the vertical depth parameter of the geological target point.

[0181] The second adjustment unit 11017 is used to adjust the vertical depth parameter of the geological target point corresponding to any wellhead to reduce the drilling difficulty coefficient and the full angle change rate of the wellbore trajectory of the target layer to be determined.

[0182] The fourth determining unit 11018 is configured to determine the wellbore trajectory of the target layer section of any wellhead based on the position of any wellhead, the position of the geological target point corresponding to any wellhead, and the adjusted vertical depth parameter of the geological target point.

[0183] The fifth determination unit 11019 is used to select two wellbore trajectory types, namely, a three-stage straight-increase stabilization type and a five-stage straight-increase stabilization type, based on the wellbore trajectory of the target layer segment at any wellhead, adjust the inclination point depth, full-angle change rate and well inclination angle of the wellbore trajectory design, and determine multiple alternative wellbore trajectories for any wellhead.

[0184] The second determining unit 11012 is configured to determine the orientation perpendicular to the orientation of the maximum principal stress as the horizontal orientation of the wellbore trajectory of the target layer segment.

[0185] In summary, the wellbore trajectory determination method provided in the embodiments of the present application obtains multiple candidate wellbore trajectories for a planned well and then determines the wellbore trajectory whose test parameters meet target values ​​as the target wellbore trajectory for the planned well. The test parameters include the wellbore collision risk value, the full-angle change rate of the wellbore trajectory, and the steady-angle angle of the long steady-angle section of the wellbore trajectory. This allows the wellbore trajectory to be determined based on these multiple parameters, taking into account a more comprehensive range of factors.

[0186] In this application, the terms "first", "second", "third" and "fourth" are used for descriptive purposes only and should not be understood as indicating or implying relative importance. The term "plurality" refers to two or more, unless otherwise expressly limited.

[0187] The above description is merely an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present application shall be included in the scope of protection of the present application.

Claims

1. A method for determining a wellbore trajectory, characterized in that: The method comprises: Obtain multiple alternative wellbore trajectories for the designed well; Determining an alternative wellbore trajectory whose test parameters meet target values ​​among the multiple alternative wellbore trajectories as the target wellbore trajectory of the designed well; The test parameters include the borehole collision risk value, the full angle change rate of the borehole trajectory, and the stable inclination angle of the long stable inclination section of the borehole trajectory. The target value of the borehole collision risk value is greater than N1, and the range of N1 is 1 to 1.

5. The collision risk value is F L , Wherein, a is the distance between the wellbore centers of the designed well and the adjacent well, b is the radius of the error ellipse of the wellbore trajectory of the designed well, and c is the radius of the error ellipse of the wellbore trajectory of the adjacent well; The target value of the full angle change rate of the wellbore trajectory is less than N2° / 30m, and the N2° / 30m is 7° / 30m; The target value of the stable inclination angle of the long stable inclination section of the wellbore trajectory is greater than N3°, wherein N3° is 10° when the drilling tool is a steerable drilling assembly, and N3° is 15° when the drilling tool is a stable inclination drilling assembly; Wherein, the obtaining of multiple alternative wellbore trajectories of the designed well includes: Determining the maximum principal stress orientation and the minimum principal stress orientation of the formation, wherein the maximum principal stress orientation is perpendicular to the minimum principal stress orientation, and the maximum principal stress orientation is the dominant development orientation of the fracture; Determining the horizontal orientation of the wellbore trajectory of the target layer based on the maximum principal stress orientation and the minimum principal stress orientation; Acquire the positions of multiple wellheads, the positions of multiple geological target points, and the vertical depth parameter of each geological target point based on the reservoir distribution area and the horizontal orientation of the wellbore trajectory of the target layer; Based on the positions of the plurality of wellheads and the positions of the plurality of geological target points, matching the plurality of wellheads with the plurality of geological target points, wherein each wellhead is matched with at least one geological target point; For a wellhead that matches at least two geological target points, adjusting the horizontal position of the geological target point so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range; For any wellhead among the plurality of wellheads, determining a wellbore trajectory of a target layer segment to be determined for the any wellhead based on a position of the any wellhead, a position of a geological target point corresponding to the any wellhead, and a vertical depth parameter of the geological target point; Adjusting the vertical depth parameter of the geological target point corresponding to any wellhead to reduce the drilling difficulty coefficient and full angle change rate of the wellbore trajectory of the undetermined target layer section; Determining a wellbore trajectory of a target layer section of any wellhead based on the position of the wellhead, the position of a geological target point corresponding to the wellhead, and the adjusted vertical depth parameter of the geological target point; Based on the wellbore trajectory of the target layer section of any wellhead, two wellbore trajectory types, straight-increasing-stable three-stage and straight-increasing-stable-increasing-stable five-stage, are selected, the inclination point depth, full-angle change rate and well inclination angle of the wellbore trajectory design are adjusted, and multiple alternative wellbore trajectories for any wellhead are determined.

2. The method according to claim 1, characterized in that The test parameters also include the weight on bit during sliding drilling, the torque during rotary drilling, and the maximum lateral force on the drill string. The target value of the bit pressure during sliding drilling is greater than N4, wherein when the drill bit outer diameter is ≥311.1 mm, N4 is 10 t; when 311.1 mm> drill bit outer diameter ≥215.9 mm, N4 is 8 t; when 215.9 mm> drill bit outer diameter ≥152.4 mm, N4 is 5 t; The target value of the torque value at the drill bit during rotary drilling is greater than N5N*m, wherein, when the drill bit outer diameter is ≥311.1mm, N5 is 8000; when 311.1mm> drill bit outer diameter ≥215.9mm, N5 is 6000; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 3000; The target value of the maximum lateral force applied to the drill string is less than or equal to N6, and the range of N6 is 1.5 kN to 2 kN.

3. The method according to claim 2, characterized in that The test parameters also include the lowering position of the lifting tool and the fatigue safety factor of the drill string; The fatigue safety factor value F of the drill string ti The target value is greater than N7, wherein the fatigue safety factor value satisfies: Wherein, d is the absolute value of the bending stress of the drill string, e is the absolute value of the buckling stress of the drill string, and f is the fatigue limit stress of the drill string; When the drill pipe is grade 1, N7 is 1; when the drill pipe is grade P, N7 is 1.25; when the drill pipe is grade 2, N7 is 1.33; The target value of the lowering position of the lifting tool is greater than N8*m, where N8*m is the depth of the inclination point at the lower part of the wellbore trajectory.

4. The method according to claim 1, wherein The determining the horizontal orientation of the wellbore trajectory of the target layer segment based on the maximum principal stress orientation and the minimum principal stress orientation includes: The orientation perpendicular to the orientation of the maximum principal stress is determined as the horizontal orientation of the wellbore trajectory of the target layer interval.

5. The method according to claim 1, wherein Determining the maximum principal stress orientation and the minimum principal stress orientation of the formation includes: The maximum principal stress orientation and the minimum principal stress orientation of the formation are determined based on formation coring measured data or formation orthogonal dipole array acoustic logging, formation microresistivity scanning imaging logging, formation dip logging data, or based on the direction of formation faults.

6. The method according to claim 1, wherein The step of determining the wellbore trajectory whose test parameters meet the target value among the multiple candidate wellbore trajectories as the target wellbore trajectory of the designed well includes: Obtain the ratio of horizontal displacement to vertical depth of the geological target with the deepest vertical depth; When the ratio is less than or equal to 1, the test parameters further include the maximum lateral force on the drill string, the fatigue safety factor of the drill string, and the lowering position of the lifting tool; When the ratio is greater than 1 and less than or equal to 2, the test parameters further include the weight on bit at the drill bit in sliding drilling, the torque at the drill bit in rotary drilling, the maximum lateral force applied to the drill string, the fatigue safety factor of the drill string, and the running position of the lifting tool; When the ratio is greater than 2, the test parameters further include the weight on bit at the drill bit in the sliding drilling, the torque at the drill bit in the rotary drilling, and the running position of the lifting tool; The target value of the bit pressure during sliding drilling is greater than N4, wherein when the drill bit outer diameter is ≥311.1 mm, N4 is 10 t; when 311.1 mm> drill bit outer diameter ≥215.9 mm, N4 is 8 t; when 215.9 mm> drill bit outer diameter ≥152.4 mm, N4 is 5 t; The target value of the torque value at the drill bit during rotary drilling is greater than N5N*m, wherein, when the drill bit outer diameter is ≥311.1mm, N5 is 8000; when 311.1mm> drill bit outer diameter ≥215.9mm, N5 is 6000; when 215.9mm> drill bit outer diameter ≥152.4mm, N5 is 3000; The target value of the maximum lateral force on the drill string is less than or equal to N6, and the range of N6 is 1.5kN to 2kN; The fatigue safety factor value F of the drill string ti The target value is greater than N7, wherein the fatigue safety factor value satisfies: Wherein, d is the absolute value of the bending stress of the drill string, e is the absolute value of the buckling stress of the drill string, and f is the fatigue limit stress of the drill string; Among them, when the drill rod is a grade 1 drill rod, N7 ​​is 1; when the drill rod is a grade P drill rod, N7 ​​is 1.25; when the drill rod is a grade 2 drill rod, N7 ​​is 1.33; The target value of the lowering position of the lifting tool is greater than N8*m, where N8*m is the depth of the inclination point at the lower part of the wellbore trajectory.

7. A wellbore trajectory determination device, characterized in that: The wellbore trajectory determination device comprises: An acquisition module, used to acquire multiple alternative wellbore trajectories of a designed well; A determination module, configured to determine an alternative wellbore trajectory whose test parameters meet target values ​​among the multiple alternative wellbore trajectories as a target wellbore trajectory of the designed well; The test parameters include the borehole collision risk value, the full angle change rate of the borehole trajectory, and the stable inclination angle of the long stable inclination section of the borehole trajectory. The target value of the borehole collision risk value is greater than N1, and the range of N1 is 1 to 1.

5. The collision risk value is F L , Wherein, a is the distance between the wellbore centers of the designed well and the adjacent well, b is the radius of the error ellipse of the wellbore trajectory of the designed well, and c is the radius of the error ellipse of the wellbore trajectory of the adjacent well; The target value of the full angle change rate of the wellbore trajectory is less than N2° / 30m, and the N2° / 30m is 7° / 30m; The target value of the stable inclination angle of the long stable inclination section of the wellbore trajectory is greater than N3°, wherein N3° is 10° when the drilling tool is a steerable drilling assembly, and N3° is 15° when the drilling tool is a stable inclination drilling assembly; The acquisition module includes: A first determining unit is configured to determine a maximum principal stress orientation and a minimum principal stress orientation of the formation, wherein the maximum principal stress orientation is perpendicular to the minimum principal stress orientation, and the maximum principal stress orientation is a dominant development orientation of the fracture; a second determining unit, configured to determine a horizontal orientation of a wellbore trajectory of a target layer segment based on the maximum principal stress orientation and the minimum principal stress orientation; A first acquisition unit is configured to acquire positions of a plurality of wellheads, positions of a plurality of geological target points, and a vertical depth parameter of each of the geological target points based on the reservoir distribution area and the horizontal orientation of the wellbore trajectory of the target layer; a matching unit, configured to match the plurality of wellheads with the plurality of geological target points based on the positions of the plurality of wellheads and the positions of the plurality of geological target points, wherein each wellhead is matched with at least one geological target point; a first adjusting unit, configured to adjust, for a wellhead that matches at least two geological target points, a horizontal position of the geological target point so that the horizontal position of the wellhead and the horizontal positions of the corresponding at least two geological target points are collinear within a predetermined range; a third determining unit configured to determine, for any wellhead among the plurality of wellheads, a wellbore trajectory of a target layer segment of the any wellhead based on a position of the any wellhead, a position of a geological target point corresponding to the any wellhead, and a vertical depth parameter of the geological target point; A second adjustment unit is used to adjust the vertical depth parameter of the geological target point corresponding to any wellhead to reduce the drilling difficulty coefficient and full angle change rate of the wellbore trajectory of the target layer; a fourth determining unit, configured to determine a wellbore trajectory of a target layer section of any wellhead based on the position of the any wellhead, the position of a geological target point corresponding to the any wellhead, and the adjusted vertical depth parameter of the geological target point; The fifth determination unit is used to select two wellbore trajectory types, namely, a three-stage straight-increasing-stable and a five-stage straight-increasing-stable-increasing-stable, based on the wellbore trajectory of the target layer segment of any of the wellheads, adjust the depth of the inclination point, the full-angle change rate and the well inclination angle of the wellbore trajectory design, and determine multiple alternative wellbore trajectories for any of the wellheads.

8. The wellbore trajectory determination device according to claim 7, wherein the second determination unit is configured to: The orientation perpendicular to the orientation of the maximum principal stress is determined as the horizontal orientation of the wellbore trajectory of the target layer interval.

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