Topological wellbore design

Abstract

A method for finding, efficiently evaluating and selecting wellbore paths takes into account placement rules and the presence of existing wells. Topological representations of paths of the connections are created and managed. The topological representation may be generated as a pre-computed spatial information database that represents the location of the existing well and takes into account limitations such as collision avoidance and parameters including geological and drilling equipment parameters. Using such a representation, the design of the wellbore path can be completed faster and more effectively. The topological structure can represent all connected spaces of a certain underground layer section. The topological representation can be used to assess all possible paths from a starting point (ground location, sidetrack connection points, replanning connection points, etc.) to a target, and can select paths that meet conditions and are optimized for existing constraints.

Description

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS

[0002] This application claims priority to U.S. Provisional Application No. 63 / 387,989, filed December 19, 2022, which is incorporated herein by reference in its entirety. Background Art

[0003] Finding a drillable path to a well can be challenging, especially when the subsurface is already occupied by existing wells. This can be a particular challenge when searching for a drillable re-entry path in an already developed field.

[0004] Traditionally, finding new candidate wellbore paths from a starting point (such as a tie point) is done manually and iteratively, where the team continuously evaluates and searches for free space where a well can be planned. This process also takes into account collision risk and other drilling constraints, such as drilling difficulty. Trying to find a drillable wellbore path that minimizes collision risk and meets other constraints is extremely time-consuming and error-prone. Summary of the Invention

[0005] Disclosed herein is a method for finding, efficiently evaluating, and selecting a wellbore path that takes into account placement rules and the presence of existing wells. In one embodiment, a topological representation of connected paths is created and managed. The topological representation can be generated as a pre-calculated spatial information database that represents the locations of existing wells and takes into account constraints such as collision avoidance. Using such a representation, the design of the wellbore path can be completed faster and more efficiently. The topological structure can represent all connected spaces in a certain layer section underground. The topological representation can be used to evaluate all possible paths from the starting point (ground location, side drilling connection point, re-planning connection point, etc.) to the target, and can select a path that meets the conditions and is optimized for the existing constraints.

[0006] One aspect of the present disclosure relates to a method comprising generating a representation of a three-dimensional volume ("3D volume") comprising a plurality of cells, wherein a portion of the 3D volume is below ground level, and data for each of the plurality of cells comprises a cell volume and a unique location within the 3D volume for each cell specified by three location parameters. One of the location parameters represents a depth layer relative to the ground level, and the other two parameters define a grid that divides the depth layer into two-dimensional regions. The method comprises identifying one or more existing wellbores within the 3D volume by listing those of the plurality of cells in the 3D volume that are associated with existing wellbores as occupied cells. The method further comprises calculating an unoccupied envelope homology group, wherein the occupied cells are excluded from the unoccupied envelope homology group. The method further comprises performing a first topological deformation contraction to find a 2D unoccupied envelope in 2D space that is homologically equivalent to the unoccupied envelope homology group in the 3D volume, and performing a deformation contraction on the unoccupied envelope homology group. The method further comprises performing a second topological deformation contraction to obtain a simplified graph contraction that can be mapped back to the 3D volume, and determining one or more candidate wellbore paths using the simplified graph contraction.

[0007] The above-mentioned method for identifying existing wellbores by listing occupied cells may include listing unique locations of occupied cells; wellbore directions of occupied cells, and uncertainty values ​​of cells adjacent to the occupied cells, and further wherein calculating an unoccupied envelope coherence group includes excluding cells with uncertainty values ​​above a threshold uncertainty value from the unoccupied envelope coherence group. The method may also include assigning supplemental information to a portion of the plurality of cells in the 3D volume, wherein the supplemental information includes one or more of: geological layer information; geological composition information; geological characteristic information; reservoir information; reservoir proximity information; petrophysical characteristic information; geomechanical characteristic information; and steering trend characteristic information. Furthermore, the method may include obtaining one or more candidate starting locations for a candidate wellbore path; and obtaining one or more candidate target locations for the candidate wellbore path, wherein the candidate starting locations and candidate target locations may be static when determining the candidate wellbore path, or may be dynamic in real time when determining the candidate wellbore path. Furthermore, performing a first topological deformation contraction also includes the unoccupied envelope coherence group, the cell data, the existing wellbore identification, the candidate starting location, the candidate target location, and the supplemental information. Determining candidate wellbore paths may include applying one or more placement rules to each candidate wellbore path, the method further comprising: determining a path score for each candidate wellbore path; selecting the candidate wellbore path with the highest path score; and performing a wellsite action in response to the selected candidate wellbore path.

[0008] The method may also include obtaining a set of drilling equipment parameters including downhole steering tool parameters, drilling assembly parameters, and steerability parameters, wherein determining the candidate wellbore path includes utilizing at least one of the drilling equipment parameters.

[0009] Determining candidate wellbore paths in the method may include applying one or more placement rules to each candidate wellbore path, the method also comprising: determining a path score for each candidate wellbore path; selecting the candidate wellbore path with the highest path score; and performing a wellsite action in response to the selected candidate wellbore path.

[0010] In another aspect of the present disclosure, a method includes generating a three-dimensional representation of a volume ("3D volume"), a portion of the volume being below ground level, the volume including a plurality of cells and data for each of the plurality of cells, the data including the cell volume and a unique location of each cell within the 3D volume specified by three location parameters; identifying one or more existing wellbores within the 3D volume by listing those of the plurality of cells in the 3D volume that are associated with the existing wellbores as occupied cells; assigning supplemental information to the portion of the plurality of cells in the 3D volume; generating a 3D unoccupied envelope of cells having an initial size surrounding the occupied cells and excluding the occupied cells; and assigning each cell contained in the 3D unoccupied envelope to the 3D unoccupied envelope. The elements are discretized into a set of cell sizes that are smaller than the initial size of the cell; a 3D unoccupied envelope is repeatedly generated until a resolution of the 3D unoccupied envelope satisfies a predetermined accuracy threshold; a first topological deformation shrinkage is performed to find a 2D unoccupied envelope in 2D space that is homologically equivalent to the unoccupied envelope of the 3D volume; a deformation shrinkage is performed on the unoccupied envelope 3D volume based on the first topological deformation shrinkage; a second topological deformation shrinkage is performed to obtain a simplified graph shrinkage configured to be mapped back to the 3D volume; and one or more candidate wellbore paths are determined using the simplified graph shrinkage, the cell data, the existing wellbore data, the candidate starting position, the candidate target position, the drilling equipment parameters, the supplementary information and the homology group.

[0011] The input data set for the first topological deformation contraction of the method may include at least one of data of a cell, existing wellbore identification, and supplemental information. The method may also include: obtaining one or more candidate starting positions for a candidate wellbore path; obtaining one or more candidate target positions for a candidate wellbore path; calculating an unoccupied envelope coherence group including a list of cell positions, wherein: an unoccupied envelope coherence group is a plurality of cells in a 3D volume excluding occupied cells; or an unoccupied envelope coherence group is a plurality of cells in a 3D volume having uncertainty values ​​below a threshold uncertainty; wherein the input data set for the first topological deformation contraction includes at least one of the candidate starting position, the candidate target position, and the unoccupied envelope coherence group. In a further implementation of the method, determining the candidate wellbore path may include applying one or more placement rules to each candidate wellbore path, and the method further includes: determining a path score for each candidate wellbore path; displaying each candidate wellbore path and the corresponding path score; selecting the candidate wellbore path with the highest path score; and performing a wellsite action in response to the selected candidate wellbore path. In a further embodiment of the method, identifying existing wellbores by listing occupied cells may include listing unique locations of occupied cells; wellbore directions of occupied cells, and uncertainty values ​​of cells adjacent to the occupied cells, and further, wherein calculating the unoccupied envelope coherence group includes excluding cells with uncertainty values ​​greater than a threshold uncertainty value from the unoccupied envelope coherence group. Furthermore, the supplemental information includes one or more of: geological layer information; geological composition information; geological characteristic information; reservoir and reservoir proximity information; petrophysical characteristic information; geomechanical characteristic information; and steering trend characteristic information. In the method, generating the 3D unoccupied envelope may include: selecting a plurality of cells in the 3D volume other than the occupied cells; or selecting a plurality of cells in the 3D volume with uncertainty values ​​less than a threshold uncertainty. The method may also involve obtaining a set of drilling equipment parameters, the set of drilling equipment parameters including downhole steering tool parameters, drilling assembly parameters, and steering trend capability parameters, wherein determining the candidate wellbore paths includes utilizing at least one of the drilling equipment parameters.

[0012] In another aspect of the present disclosure, a method includes generating a three-dimensional representation of a volume ("3D volume"), a portion of the volume being below ground level, the volume representation including a plurality of cells and data for each of the plurality of cells; the data may include the cell volume; and a unique location within the 3D volume for each cell specified by three location parameters, wherein one of the location parameters represents a depth layer relative to the ground level and the other two parameters define a grid that divides the depth layer into two-dimensional regions. The method may involve identifying one or more existing wellbores within the 3D volume by listing those of the plurality of cells in the 3D volume that are associated with existing wellbores as occupied cells. The information identifying each occupied cell may include a location of the occupied cell; a wellbore direction of the occupied cell; and an uncertainty value for the occupied cell. The method also includes assigning supplemental information to a portion of the plurality of cells in the 3D volume, the supplemental information including one or more of: geological layer information; geological composition information; geological characteristic information; reservoir and reservoir proximity information; petrophysical characteristic information; geomechanical characteristic information; and steering trend characteristic information. The method includes generating a 3D unoccupied envelope of cells having an initial size surrounding an occupied cell; discretizing each cell contained in the 3D unoccupied envelope into a set of cell sizes smaller than the initial size of the cell; repeatedly generating the 3D unoccupied envelope until a resolution of the 3D unoccupied envelope meets a predetermined accuracy threshold; obtaining one or more candidate starting positions of a candidate wellbore path, wherein the starting position is static or real-time dynamic; obtaining one or more candidate target positions of the candidate wellbore path, wherein the target position is static or real-time dynamic; obtaining a set of drilling equipment parameters, the set The drilling equipment parameters include downhole steering tool parameters, drilling assembly parameters, and steering capability parameters; calculating an unoccupied envelope homology group including a list of cell locations, wherein the unoccupied envelope homology group is a plurality of cells in the 3D volume excluding occupied cells, or the unoccupied envelope homology group is a plurality of cells in the 3D volume whose uncertainty values ​​are below a threshold uncertainty; performing a first topological deformation contraction to find a 2D unoccupied envelope in 2D space that is homologically equivalent to the 3D volume using the unoccupied envelope homology group, cell data, mapped wellbore data, candidate start positions, candidate target positions, and supplemental information. The method may further include performing a deformation contraction on the unoccupied envelope 3D volume based on the first topological deformation contraction; performing a second topological deformation contraction to obtain a simplified graph contraction configured to be mapped back to the 3D volume. The method may further include determining one or more candidate wellbore paths using the simplified graph contraction, cell data, existing wellbore data, candidate start positions, candidate target positions, drilling equipment parameters, supplemental information, and the homology group, wherein determining the candidate wellbore paths includes applying one or more placement rules to each candidate wellbore path.A path score may be determined for each candidate wellbore path, and each candidate wellbore path and corresponding path score may be displayed prior to selecting the candidate wellbore path with the highest path score and performing a wellsite action in response to the selected candidate wellbore path.

[0013] This summary introduces some concepts that are further described in the detailed description below. Other concepts and features are described below. The claims may include concepts described in this summary or elsewhere in the specification. BRIEF DESCRIPTION OF THE DRAWINGS

[0014] The following figures are not necessarily drawn to scale; dimensions may be altered to help illustrate or emphasize certain features.

[0015] Figure 1 An example of an environment in which drilling may occur is shown.

[0016] Figure 2 An example of a drilling system that may be used to drill a well is shown.

[0017] Figure 3 An exemplary computing system that may be used in conjunction with a drilling system is shown.

[0018] Figure 4 A flow chart illustrating a method for generating a 3D mesh of a geographic space is shown.

[0019] Figure 5 A flow chart illustrating a method for generating one or more candidate paths using a 3D grid map of a geospatial space is shown.

[0020] Figure 6 A flow chart of a method for generating a homology group representing a geographic space is shown.

[0021] Figure 7 A flow chart is shown of a method for utilizing a coherence group representing geographic space when generating one or more candidate wellbore paths using a 3D volume. DETAILED DESCRIPTION

[0022] Introduction

[0023] The following detailed description refers to the accompanying drawings. Whenever convenient, the same reference numerals are used in the drawings and the following description to refer to the same or similar parts. Although several embodiments and features of the present disclosure are described herein, modifications, adjustments and other implementations are possible without departing from the spirit and scope of the present disclosure.

[0024] Although the terms "first," "second," etc. may be used herein to describe various elements, these terms are used to distinguish one element from another. For example, a first object or step may be referred to as a second object or step, and similarly, a second object or step may be referred to as a first object or step without departing from the scope of this disclosure. A first object or step and a second object or step are both objects or steps, respectively, but should not be considered the same object or step.

[0025] The terms used in this specification are for the purpose of describing specific embodiments and are not intended to limit. As used in this specification and the appended claims, unless the context clearly indicates otherwise, the singular forms "one", "a kind of" and "said" are also intended to include plural forms. It should also be understood that the term "and / or" as used herein refers to and covers any possible combination of one or more of the associated listed items. It should also be understood that the terms "including" and / or "comprising" specify the presence of the features, integers, steps, operations, elements and / or parts when used in this specification, but do not exclude the presence or addition of one or more other features, integers, steps, operations, elements, parts and / or their groups. In addition, as used herein, the term "if" can be interpreted as meaning "when...", "after..." or "in response to determining" or "in response to detecting", which depends on the context.

[0026] Implementation Plan

[0027] Figure 1 An example of an environment 100 in which drilling may occur is shown. The environment may include a reservoir 102 and various geological features, such as strata. The geological aspects of the environment 100 may include other features, such as faults, basins, etc. The reservoir 102 may be located on land or offshore.

[0028] The environment 100 may be equipped with sensors, detectors, actuators, etc. used in conjunction with the drilling process. Figure 1 Equipment 104 associated with a well 106 is shown constructed using downhole equipment 108. Downhole equipment 108 may be, for example, part of a bottom hole assembly (BHA). The BHA may be used to drill the well 106. Downhole equipment 108 may transmit information to equipment 104 at the surface, and may also receive instructions and information from surface equipment 104. Surface equipment 104 and downhole equipment 108 may communicate using various communication technologies, such as mud pulse telemetry, electromagnetic (EM) telemetry, or other technologies, depending on the equipment and technology used for the drilling operation.

[0029] The surface equipment 104 may also include a communication device to communicate with a remote computing device 112 via the network 110. For example, the surface equipment 104 may use a satellite network to transmit data to the computing device 112 to enable a remote team to monitor and assist in the creation of well 106 and other wells at other locations. Depending on the communication infrastructure available at the well site, various communication devices and technologies (cellular, satellite, wired Internet connection, etc.) may be used to transmit data from the surface equipment 104 to the remote computing device 112. In some embodiments, the surface equipment 104 transmits data from measurements taken at the surface and measurements taken downhole by the downhole equipment 108 to the remote computing device 112.

[0030] During the well construction process, various operations may also be performed such as cementing, wireline evaluation, testing, etc. In such embodiments, data collected by the tools and sensors and used for reasons such as reservoir characterization may also be collected and transmitted by surface equipment 104 .

[0031] exist Figure 1 In the embodiment of the present invention, well 106 includes a substantially horizontal portion (e.g., a lateral portion) that may intersect one or more fractures. For example, a well in a shale formation may pass through natural fractures, artificial fractures (e.g., hydraulic fractures), or a combination thereof. Such a well may be constructed using the directional drilling techniques described herein. However, these same techniques may be used in conjunction with other types of directional wells (such as deviated wells, S-shaped wells, deep deviated wells, etc.) and are not limited to horizontal wells.

[0032] Figure 2 An example of a wellsite system 200 is shown (e.g., at a wellsite that may be located on land or offshore). As shown, the wellsite system 200 may include: a mud tank 201 for storing mud and other materials (e.g., where the mud may be drilling fluid); a suction line 203 serving as an inlet to a mud pump 204 for pumping mud from the mud tank 201 to a vibrating hose 206; a winch 207 for reeling in one or more drilling wirelines 212; a riser 208 for receiving mud from the vibrating hose 206; a kelly hose 209 for receiving mud from the riser 208; one or more goosenecks 210; a traveling block 211; and a crown block 213 for carrying the traveling block 211 via the one or more drilling wirelines 212 (e.g., see FIG. 2 ). Figure 1 Crane 173); derrick 214 (see, for example, Figure 1 201; a kelly 218 or top drive 240; a kelly bushing 219; a rotary table 220; a drill floor 221; a bell-nose sub 222; one or more blowout preventers (BOPs) 223; a drill string 225; a drill bit 226; a casing head 227; and a flow line 228 for delivering mud and other materials to, for example, a mud tank 201.

[0033] exist Figure 2 In the example system, a wellbore 232 is formed in a subsurface formation 230 by rotary drilling; it is noted that various example embodiments may also utilize one or more directional drilling techniques, equipment, etc.

[0034] like Figure 2 As shown in the example of FIG, a drill string 225 is suspended within the wellbore 232 and has a drill string assembly 250 including a drill bit 226 at its lower end. As an example, the drill string assembly 250 can be a bottom hole assembly (BHA).

[0035] The wellsite system 200 can provide for the operation and other operations of the drill string 225. As shown, the wellsite system 200 includes a traveling block 211 and a derrick 214 positioned above the wellbore 232. As mentioned, the wellsite system 200 can include a rotary table 220, wherein the drill string 225 passes through an opening in the rotary table 220.

[0036] like Figure 2 As shown in the example of , the wellsite system 200 may include a kelly 218 and associated components, or a top drive 240 and associated components. Regarding the example of a kelly, the kelly 218 may be a square or hexagonal metal / alloy rod with a hole drilled therein for a mud flow path. The kelly 218 may be used to transmit rotational motion from the rotary table 220 to the drill string 225 via a kelly bushing 219, while allowing the drill string 225 to be lowered or raised during rotation. The kelly 218 may pass through the kelly bushing 219, which may be driven by the rotary table 220. As an example, the rotary table 220 may include a main bushing operatively coupled to the kelly bushing 219, such that rotation of the rotary table 220 may rotate the kelly bushing 219 and, thereby, the kelly 218. The kelly bushing 219 may include an interior profile that matches the exterior profile of the kelly 218 (eg, square, hexagonal, etc.); however, it is slightly larger in size so that the kelly 218 can move freely up and down within the kelly bushing 219 .

[0037] With respect to the example of a top drive, a top drive 240 can provide the functions performed by a kelly and a rotary table. The top drive 240 can rotate the drill string 225. As an example, the top drive 240 can include one or more motors (e.g., electric motors and / or hydraulic motors) connected by an appropriate transmission to a short section of pipe called a hollow shaft, which in turn can be screwed into a saver sub or the drill string 225 itself. The top drive 240 can be suspended from the traveling block 211 so that the rotating mechanism can travel freely up and down along the derrick 214. As an example, the top drive 240 can allow drilling to be performed using more single columns than the kelly / rotary table approach.

[0038] exist Figure 2 In the example of , mud tank 201 can store mud, which can be one or more types of drilling fluids. As an example, a wellbore can be drilled to produce fluids, inject fluids, or both (e.g., hydrocarbons, minerals, water, etc.).

[0039] exist Figure 2 In the example of FIG. 2 , a drill string 225 (e.g., including one or more downhole tools) can be comprised of a series of pipes that can be threaded together to form a long conduit with a drill bit 226 at its lower end. As the drill string 225 is advanced into the wellbore for drilling, prior to or at some point coincident with drilling, mud can be pumped from a mud tank 201 (e.g., or other source) via lines 206, 208, and 209 by pump 204 to a port of a kelly 218, or, for example, to a port of a top drive 240. The mud can then flow through a channel (e.g., or multiple channels) in the drill string 225 and out of a port located on the drill bit 226 (e.g., see directional arrows). When the mud exits the drill string 225 via the port in the drill bit 226, it can then circulate upward through the annular region between the outer surface of the drill string 225 and the surrounding wall (e.g., an open wellbore, casing, etc.), as indicated by the directional arrows. In this manner, the mud lubricates the drill bit 226 and carries heat (e.g., friction or other energy) and formation cuttings to the surface, where the mud (e.g., and cuttings) can be returned to the mud tank 201, for example, for recirculation (e.g., by processing to remove cuttings, etc.).

[0040] The mud pumped into the drill string 225 by the pump 204 can form a mud cake lining the wellbore after leaving the drill string 225, which can reduce friction between the drill string 225 and the surrounding wall (e.g., the wellbore, casing, etc.). The reduced friction can facilitate the advancement or retraction of the drill string 225. During the drilling operation, the entire drill string 225 can be pulled out of the wellbore and optionally replaced, for example, with a new or sharpened drill bit, a smaller diameter drill string, etc. As mentioned, the act of pulling the drill string out of the wellbore or replacing the drill string in the wellbore is called tripping. Depending on the direction of the tripping, the tripping can be referred to as pulling up, pulling out, pulling down, or pulling in.

[0041] As an example, consider drilling down, where, when the drill bit 226 of the drill string 225 reaches the bottom of the wellbore, the pumping of mud begins to lubricate the drill bit 226 for the purpose of drilling to expand the wellbore. As mentioned, the mud can be pumped into the channel of the drill string 225 by the pump 204, and when filling the channel, the mud can be used as a transmission medium for transmitting energy (e.g., energy that can encode information as in mud pulse telemetry).

[0042] As an example, a mud pulse telemetry device may include a downhole device configured to implement changes in mud pressure to form one or more acoustic waves based on which information may be modulated. In such an example, information from the downhole device (e.g., one or more modules of the drill string 225) may be transmitted uphole to the wellhead device, which may relay such information to other equipment for processing, control, etc.

[0043] As an example, the telemetry equipment may operate by transmitting energy through the drill string 225 itself. For example, consider a signal generator that transmits an encoded energy signal to the drill string 225, and a repeater that can receive such energy and relay it for further transmission of the encoded energy signal (e.g., information, etc.).

[0044] As an example, the drill string 225 may be equipped with: a telemetry device 252 including a rotatable drive shaft; a turbine wheel mechanically coupled to the drive shaft such that mud can rotate the turbine wheel; a modulator rotor mechanically coupled to the drive shaft such that rotation of the turbine wheel rotates the modulator rotor; a modulator stator mounted adjacent to or proximate the modulator rotor such that rotation of the modulator rotor relative to the modulator stator creates pressure pulses in the mud; and a controllable brake for selectively braking rotation of the modulator rotor to modulate the pressure pulses. In such an example, an alternator may be coupled to the drive shaft, wherein the alternator includes at least one stator winding electrically coupled to a control circuit for selectively short-circuiting the at least one stator winding to electromagnetically brake the alternator and thereby selectively brake rotation of the modulator rotor to modulate the pressure pulses in the mud.

[0045] exist Figure 2 In an example, the uphole control and / or data acquisition system 262 may include circuitry for sensing pressure pulses generated by the telemetry device 252 and, for example, transmitting the sensed pressure pulses or information derived therefrom for processing, control, etc.

[0046] The assembly 250 of the illustrated example includes a logging while drilling (LWD) module 254, a measurement while drilling (MWD) module 256, an optional module 258, a rotary steerable system (RSS) and / or motor 260, and a drill bit 226. Such components or modules may be referred to as tools, where a drill string may include multiple tools.

[0047] With respect to RSS, it relates to techniques used for directional drilling. Directional drilling involves drilling into the earth to form a deviated borehole so that the wellbore path of the borehole is not vertical; instead, the wellbore path deviates from vertical along one or more portions of the borehole. As an example, consider a target located at a lateral distance from a surface location where a drilling rig may be stationary. In such an example, drilling may begin at the vertical portion and then deviate from vertical so that the borehole is aligned with the target and ultimately reaches the target. Directional drilling may be implemented in the following situations: where the target cannot be reached from a vertical position on the earth's surface, where there are materials in the earth that may hinder drilling or are otherwise harmful (for example, consider salt domes, etc.), where the formation is laterally extended (for example, consider a relatively thin but laterally extended reservoir), where multiple boreholes are to be drilled from a single surface borehole, where relief wells are desired, etc.

[0048] One method of directional drilling involves a mud motor; however, mud motors can present challenges depending on factors such as rate of penetration (ROP), weight transfer to the drill bit due to friction (e.g., weight on bit, WOB), etc. The mud motor can be a positive displacement motor (PDM) that operates to drive the drill bit (e.g., during directional drilling, etc.). The PDM operates when drilling fluid is pumped through it, converting the hydraulic power of the drilling fluid into mechanical power to rotate the drill bit.

[0049] As an example, the PDM may be operated in a combined rotation mode, in which surface equipment is used to rotate the drill bit of the drill string by rotating the entire drill string (e.g., a rotary table, a top drive, etc.), and drilling fluid is used to rotate the drill bit of the drill string. In such an example, the surface RPM (SRPM) may be determined using the surface equipment, and the downhole RPM of the mud motor may be determined using various factors related to the flow of drilling fluid, the type of mud motor, etc. As an example, in the combined rotation mode, the drill bit RPM may be determined or estimated as the sum of the SRPM and the mud motor RPM, assuming that the SRPM and the mud motor RPM are in the same direction.

[0050] As an example, when the drill string is not rotating from the surface, the PDM mud motor may operate in a so-called sliding mode. In such an example, the drill bit RPM may be determined or estimated based on the RPM of the mud motor.

[0051] An RSS can be deployed when drilling a wellbore in a directional manner (e.g., a deviated, horizontal, or extended wellbore) from the continuous rotation of surface equipment. The RSS can be designed to minimize its interaction with the wellbore wall, which can help maintain wellbore quality. The RSS can be designed to apply a fairly consistent lateral force similar to a stabilizer that rotates with the drill string or orients the drill bit in the desired direction while continuously rotating at the same RPM as the drill string.

[0052] LWD module 254 can be housed in a suitable type of drill collar and can contain one or more selected types of logging tools. It should also be understood that more than one LWD and / or MWD module can be employed, for example, as represented by module 256 of drill string assembly 250. Where reference is made to the location of an LWD module, this may refer to a module at the location of LWD module 254, module 256, etc., as an example. The LWD module may include capabilities for measuring, processing, and storing information, as well as communicating with surface equipment. In the example shown, LWD module 254 may include a seismic measurement device.

[0053] The MWD module 256 can be housed in a suitable type of drill collar and can include one or more devices for measuring characteristics of the drill string 225 and drill bit 226. By way of example, the MWD tool 254 can include a device for generating electrical power, e.g., to power various components of the drill string 225. By way of example, the MWD tool 254 can include telemetry equipment 252, e.g., where a turbine wheel can generate electrical power from the flow of mud; it will be appreciated that other power sources and / or battery systems can be employed to power the various components. By way of example, the MWD module 256 can include one or more of the following types of measurement devices: a weight-on-bit measurement device, a torque measurement device, a vibration measurement device, a shock measurement device, a stick-slip measurement device, a direction measurement device, and an inclination measurement device.

[0054] Figure 2 Also shown are some examples of the types of wellbores that can be drilled. For example, consider a slanted vertical wellbore 272, an S-shaped wellbore 274, a deep deviated wellbore 276, and a horizontal wellbore 278.

[0055] As an example, the drilling operation may include directional drilling, wherein, for example, at least a portion of the well includes a curved axis. For example, consider a radius defining a curvature wherein the inclination relative to the vertical may vary until reaching an angle between about 30 degrees and about 60 degrees, or, for example, reaching an angle of about 90 degrees or possibly greater than about 90 degrees.

[0056] As an example, a directional well can include several shapes, each of which can be designed to meet specific operational requirements. As an example, when information is communicated to a drilling engineer, the drilling process can be performed based on the information. As an example, the inclination and / or direction can be modified based on information received during the drilling process.

[0057] As an example, deflection of the borehole may be achieved in part through the use of downhole motors and / or turbines.With respect to motors, for example, the drill string may include a positive displacement motor (PDM).

[0058] As an example, the system can be a steering system and include equipment for performing methods such as geosteering. As mentioned, the steering system can be or include an RSS. As an example, the steering system can include a PDM or turbine located at the lower part of the drill string, the PDM or turbine just above the drill bit, and a bent sub can be installed. As an example, above the PDM, an MWD device and / or a LWD device can be installed, the MWD device providing real-time or near real-time data of interest (e.g., inclination, direction, pressure, temperature, actual weight on the drill bit, torque stress, etc.). With respect to the latter, the LWD device can send various types of data of interest to the surface, including, for example, geological data (e.g., gamma ray logging, resistivity, density, and sonic logging, etc.).

[0059] The coupling of sensors that provide information about the wellbore path in real time or near real time with one or more well logs that characterize the formation from a geological perspective, for example, can allow for the implementation of geosteering methods. Such methods can include navigating the subsurface environment, for example, to follow a desired route to a desired target or targets.

[0060] As an example, a drill string may include: an azimuthal density neutron (AND) tool for measuring density and porosity; an MWD tool for measuring inclination, azimuth, and shock; a compensated dual resistivity (CDR) tool for measuring resistivity and gamma-ray related phenomena; one or more variable diameter stabilizers; one or more curved joints; and a geosteering tool, which may include a motor and (optionally) equipment for measuring and / or responding to one or more of inclination, resistivity, and gamma-ray related phenomena.

[0061] As an example, geosteering may include intentional directional control of a wellbore based on downhole geological logging measurements in a manner intended to maintain the directional wellbore within a desired area, zone (e.g., a pay zone), etc. As an example, geosteering may include guiding the wellbore to maintain the wellbore within a specific section of a reservoir, e.g., to minimize breakthrough of gas and / or water, and, e.g., to maximize economic production from a well that includes the wellbore.

[0062] Reference again Figure 2, the wellsite system 200 may include one or more sensors 264 operatively coupled to the control and / or data acquisition system 262. As an example, the one or more sensors may be located at a surface location. As an example, the one or more sensors may be located at a downhole location. As an example, the one or more sensors may be located at one or more remote locations within a distance of approximately one hundred meters from the wellsite system 200. As an example, the one or more sensors may be located at a reference wellsite, where the wellsite system 200 and the reference wellsite are located in a common oil and gas field (e.g., an oil field and / or a gas field).

[0063] As an example, one or more of sensors 264 may be provided to track a pipe, track movement of at least a portion of a drill string, etc.

[0064] As an example, system 200 may include one or more sensors 266 that can sense signals and / or transmit signals to a fluid conduit, such as a drilling fluid conduit (e.g., a drilling mud conduit). For example, in system 200, one or more sensors 266 may be operatively coupled to a portion of riser 208 through which mud flows. As an example, a downhole tool may generate pulses that travel through the mud and are sensed by one or more of the one or more sensors 266. In such an example, the downhole tool may include associated circuitry, such as, for example, encoding circuitry that can encode signals, for example, to reduce transmission requirements. As an example, circuitry located at the surface may include decoding circuitry to decode encoded information transmitted at least in part via mud pulse telemetry. As an example, circuitry located at the surface may include encoder circuitry and / or decoder circuitry, and the downhole circuitry may include encoder circuitry and / or decoder circuitry. As an example, system 200 may include a transmitter that can generate signals that can be transmitted downhole via mud (e.g., drilling fluid) as a transmission medium.

[0065] As an example, one or more portions of a drill string may become stuck. The term "stuck" may refer to one or more varying degrees of inability to move or remove the drill string from the borehole. As an example, in a stuck condition, it may be possible to rotate the drill rod or return it to the borehole. Alternatively, in a stuck condition, it may be impossible to axially move the drill string within the borehole, although some degree of rotation is possible. For example, in a stuck condition, it may be impossible to move at least a portion of the drill string both axially and rotationally.

[0066] Regarding the term "stuck drill," this may refer to a portion of the drill string being unable to rotate or move axially. By way of example, a condition known as "differential stuck drill" may be a condition in which the drill string is unable to move (e.g., rotate or reciprocate) along the axis of the borehole. Differential stuck drill may occur when high contact forces, caused by low reservoir pressure, high wellbore pressure, or both, are applied to a sufficiently large area of ​​the drill string. Differential stuck drill may have both time and financial costs.

[0067] As an example, the sticking force can be the product of the pressure differential between the wellbore and the reservoir and the area over which the pressure differential acts. This means that applying a relatively low pressure differential (Δp) over a large working area can have the same effect on sticking as applying a high pressure differential over a small area.

[0068] As an example, a condition known as "mechanical stuck pipe" may be a condition in which drill string movement is restricted or prevented by a mechanism other than differential pressure sticking. Mechanical stuck pipe may be caused, for example, by one or more of trash in the wellbore, anomalies in wellbore geometry, cement, keyways, or debris accumulation in the annulus.

[0069] Figure 3 A schematic diagram of such a computing or processor system 300 according to an embodiment is shown. The processor system 300 may include one or more processors 302 having different core configurations (including multiple cores) and clock frequencies. The one or more processors 302 are operable to execute instructions, application logic, etc. It should be understood that these functions can be provided by multiple processors operating in parallel and / or communicatively linked together or multiple cores on a single chip. In at least one embodiment, the one or more processors 302 may be or include one or more GPUs.

[0070] The processor system 300 may also include a memory system, which may be or include one or more memory devices and / or computer-readable media 304 of varying physical size, accessibility, storage capacity, etc., such as a flash drive, hard drive, magnetic disk, random access memory, etc., for storing data, such as images, files, and program instructions executed by the processor 302. In an embodiment, the computer-readable medium 304 may store instructions that, when executed by the processor 302, are configured to cause the processor system 300 to perform operations. For example, execution of such instructions may cause the processor system 300 to implement one or more portions of the methods and / or embodiments described above.

[0071] The processor system 300 may also include one or more network interfaces 306. The network interfaces 306 may include any hardware, application programs, and / or other software. Thus, the network interfaces 306 may include an Ethernet adapter, a wireless transceiver, a PCI interface, and / or a serial network component for communicating over a wired or wireless medium using protocols such as Ethernet, wireless Ethernet, and the like.

[0072] As an example, the processor system 300 may be a mobile device that includes one or more network interfaces for communicating information. For example, the mobile device may include a wireless network interface (e.g., capable of communicating via one or more IEEE 802.11 protocols, ETSIGSM, As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM card slot, audio / video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery. As an example, a mobile device may be configured as a cellular phone, a tablet computer, etc. As an example, a method may be implemented (e.g., in whole or in part) using a mobile device. As an example, a system may include one or more mobile devices.

[0073] The processor system 300 may also include one or more peripheral interfaces 308 for communicating with a display, projector, keyboard, mouse, touchpad, sensors, other types of input and / or output peripherals, and the like. In some embodiments, the components of the processor system 300 need not be housed in a single housing, or even in close proximity to one another, but in other embodiments, the components and / or other components may be provided in a single housing. By way of example, the system may be a distributed environment, such as a so-called "cloud" environment, in which various devices, components, and the like interact for purposes of data storage, communication, computation, and the like. By way of example, the method may be implemented in a distributed environment (e.g., in whole or in part as a cloud-based service).

[0074] As an example, information can be input from a display (e.g., a touch screen), output to a display, or both. As an example, information can be output to a projector, a laser device, a printer, etc. so that the information can be viewed. As an example, information can be output stereoscopically or holographically. With respect to printers, consider 2D or 3D printers. As an example, a 3D printer may include one or more substances that can be output to construct a 3D object. For example, data can be provided to a 3D printer to construct a 3D representation of an underground stratum. As an example, layers (e.g., horizons, etc.) can be constructed in 3D, geological bodies, etc. can be constructed in 3D. As an example, wellbores, fractures, etc. can be constructed in 3D (e.g., as positive structures, as negative structures, etc.).

[0075] The memory device 304 can be physically or logically arranged or configured to store data on one or more storage devices 310. The storage device 310 can include one or more file systems or databases in any suitable format. The storage device 310 can also include one or more software programs 312, which can contain interpretable or executable instructions for performing one or more of the disclosed processes. Upon request by the processor 302, one or more of the software programs 312, or portions thereof, can be loaded from the storage device 310 to the memory device 304 for execution by the processor 302.

[0076] Those skilled in the art will appreciate that the above components are merely an example of a hardware configuration, as the processor system 300 may include any type of hardware components for executing the disclosed embodiments, including any accompanying firmware or software. The processor system 300 may also be implemented partially or entirely by electronic circuit components or processors, such as application-specific integrated circuits (ASICs) or field-programmable gate arrays (FPGAs).

[0077] Processor system 300 may be configured to receive a directional drilling plan 320. As described above, a drilling plan is a description of a proposed wellbore for the drilling team to use when drilling the well. A well plan typically includes information regarding the shape, orientation, depth, completion, and evaluation of the well, as well as information regarding the equipment to be used, actions to be taken at different stages of the well construction process, and other information that the well planning team deems relevant / helpful to the drilling team. A directional drilling plan will also include information regarding how to guide and manage the direction of the well.

[0078] As an example, the processor system 300 can be configured to receive drilling data 322. The drilling data 322 can include data collected by one or more sensors associated with surface equipment or downhole equipment. The drilling data 322 can include data such as the position of the BHA (such as survey data or continuous position data), drilling parameters (such as weight on bit (WOB), rate of penetration (ROP), torque, or other), text information entered by individuals working at the well site, or other data collected during the construction of the well.

[0079] In one embodiment, the processor system 300 is part of the drilling rig's rig control system (RCS). In another embodiment, the processor system 300 is a separately installed computing unit that includes a display installed at the drilling site and receives data from the RCS. In such an embodiment, the software on the processor system 300 can be installed on the computing unit, brought to the well site, and installed and communicatively connected to the drilling rig control system to prepare for construction of a well or a portion thereof.

[0080] In another embodiment, the processor system 300 can be located at a location remote from the well site and receive the drilling data 322 via a communication medium using a protocol such as the Well Site Information Transfer Specification or Standard (WITS) and Markup Language (WITSML). In such an embodiment, the software on the processor system 300 can be a web-native application accessed by a user using a web browser. In such an embodiment, the processor system 300 can be remote from the well site where the well is being constructed, and the user can be at the well site or at a location remote from the well site.

[0081] In one embodiment, the method involves generating a three-dimensional map of wells within a certain geographic area. The process may involve obtaining the location of the wells within the geographic area. The location information includes the location of the well in x and y space, as well as the depth information of the well. The x, y location can be expressed as latitude and longitude, distance from a specified point or location, or other locations or coordinate systems that can represent the location of the well above ground and underground. The location may be obtained from survey data, public records, or other sources.

[0082] The method may also involve generating a three-dimensional grid representing locations in the geographic area in the x, y, and z (or depth) dimensions. The size of the grid representing the geographic area may be selected based on the size of the area being modeled. In one embodiment, the geographic area is an oil and gas field. In another embodiment, the geographic area is manually configured. In another embodiment, the size of the geographic area is set based on the locations of wells selected for inclusion in the grid representing the geographic area.

[0083] In one embodiment, a depth to which the grid should extend is selected, and a starting depth is selected. The grid can be divided into one or more depth layers in the z dimension, where these layers represent different layers from the starting depth to the target. The grid can also be divided into multiple cubes in the x and y dimensions, so that the grid is composed of different elements representing specific depths and x and y positions.

[0084] Existing wells can be mapped onto a grid to create a three-dimensional representation of the underground and the space occupied by the existing wells. In one embodiment, mapping is performed for each element or cell of the grid. Cells can be mapped to information indicating the certainty of the existence of existing wells at that particular cell. In one embodiment, the mapping takes into account appropriate uncertainty factors. For example, the existence of a well can be represented by a percentage certainty. For example, an adjacent cell can represent a point 5 meters away from the reported position of the well at a specific depth. Depending on the granularity or resolution of the survey used to obtain the data, the probability that a well (or a portion thereof) is actually located in an adjacent cell may be non-zero. Adjacent cells can be given a certain value (percentage or other) to represent a non-zero probability.

[0085] In another embodiment, cells with a threshold level of certainty that a well is located at that cell are also assigned a direction that represents the direction of the wellbore at that cell.

[0086] In one embodiment, a three-dimensional graph is used to create a topological group representing a 3D grid of available space within a geographic area. A topology can be a homology group or a fundamental group, which is the first homology group of a topological space or volume. This application primarily uses the terms topology and homology group. This can be used when planning the path of a new well and can allow designers to quickly and easily reduce collision risks.

[0087] The method may also involve the process of planning a wellbore path (such as a reentry wellbore path). The method may involve obtaining one or more candidate starting locations for the reentry wellbore path. As described above, the starting location may be a surface location, a connection location, or other location. The method may also include obtaining one or more candidate targets for reentry. The candidate targets represent one or more locations where the wellbore path should terminate underground.

[0088] The method may also include obtaining one or more placement rules for the wellbore path. Placement rules are one or more rules that restrict where a planned wellbore path may be located. For example, a placement rule may specify that a wellbore path may not be planned within a specified distance of an existing well. A placement rule may also specify wellbore tortuosity or path constraints for the wellbore path to prevent problems during or after drilling.

[0089] The method can also consider optimizing the wellbore path being planned. For example, the designer can specify one or more parameters such as cost, time, carbon footprint, or other parameters to be minimized. Other parameters can be selected to be maximized.

[0090] The system can then use the 3D mesh of existing wells to generate one or more paths that avoid collisions with existing wells and satisfy one or more of the placement rules. In one embodiment, the system can present multiple candidate paths that satisfy the constraints but have different optimizations. For example, the system can generate the most cost-effective wellbore path, the fastest wellbore path, and the wellbore path with the lowest carbon footprint and present these paths to the user. The user can then select the wellbore path that best suits the project requirements.

[0091] In another embodiment, the system also allows the user to select a candidate wellbore path and edit the wellbore path at one or more points. During the editing process, the system may suggest whether the edit will result in a collision or fail to meet one or more of the specified rules. In another embodiment, the system presents a visual representation of the grid and shows the location of existing wells relative to the planned wellbore path. The system may display a subset of existing wells and may only present wells that are relevant to the wellbore path.

[0092] In another embodiment, the system displays a topology so that the designer can see where the designer can position the elements of the planned wellbore path while meeting collision avoidance and other requirements. The topology can include a visual representation of the well.

[0093] As described above, the workflow can be configured to automate wellbore path design for reentry wells from a topological perspective. The subsurface space with pre-existing wellbores can be preprocessed into a database of labeled grids. Specifically, the entire subsurface can be divided vertically into several layers, each of which is divided into a grid and labeled with a numerical index based on the presence and orientation of a wellbore. This grid defines the topological representation of each layer. The connected free paths within that layer form a candidate cluster. The union of the clusters from the top to each layer generates a complete set of candidate paths based on topological equality. These clusters can be stored in a database. Given a connection location and a target, optimized path candidates can be dynamically calculated according to specific collision avoidance rules and other drilling constraints.

[0094] Figure 4 An embodiment of a method for creating a 3D representation of wells in a region is shown. The method may include: obtaining locations of the wells in a geographic region; generating a 3D grid representing the locations in the geographic region; mapping the locations of the wells onto the 3D grid; and calculating a homology group of the 3D grid representing the available space in the geographic region.

[0095] Figure 5 An embodiment of a method for planning a wellbore path using a 3D representation of wells in a region is shown. The method may include obtaining one or more candidate starting locations for a reentry wellbore path and one or more candidate targets for the reentry wellbore path. The method may also involve obtaining one or more placement rules for the reentry wellbore path. Using the three-dimensional representation, the method may involve determining one or more reentry paths that avoid collisions with existing wells and satisfy the one or more placement rules for the wellbore path.

[0096] A wellsite action may be or may include generating and / or transmitting a signal that causes a physical action to occur at the wellsite (e.g., using a computing system). A wellsite action may also or alternatively include performing a physical action at the wellsite. The physical action may include selecting where to drill a wellbore, drilling the wellbore, changing the weight and / or torque of a drill bit used to drill the wellbore, changing the wellbore path of the wellbore, changing the concentration and / or flow rate of a fluid pumped into the wellbore, etc.

[0097] Figure 6Another method for generating a 3D map of a geographic area for planning well paths is shown. The method may involve obtaining a known reference well path (whether from survey, planning, or other data sources) and associated uncertainties. The method may also involve configuring one or more parameters of a separation rule for the planned wellbore path.

[0098] The method may also involve dividing the subsurface into layers along a vertical direction. The method may involve gridding each layer and labeling the grids with a numerical index, such as whether a wellbore (with or without uncertainty) passes through it and the direction of the wellbore. The method may involve computing the set of basis groups of paths connecting the grids on the layers and computing the homology group of the group Hi = G1 + G2 + ... Gi. The homology groups Hi ... Hk may be stored in a data structure such as a database.

[0099] Figure 7 An embodiment of a method for planning a wellbore path using a 3D representation, a plurality of cells, and data about wells (i.e., existing wellbores) in a certain area is shown. The method may include assigning supplementary information to a portion of the plurality of cells. A 3D unoccupied envelope of cells having an initial size surrounding an occupied cell is generated and modified by discretizing each cell and repeating the generation of a 3D preservation envelope at a reset resolution until a predetermined accuracy threshold is met. In addition, one or more candidate starting positions for a reentry wellbore path and one or more candidate targets for a reentry wellbore path are obtained. A set of drilling equipment parameters may also be obtained. An unoccupied envelope homology group may also be generated from the plurality of cells and the existing wellbore data. The unoccupied envelope homology group is used to perform a first topological deformation contraction and a deformation of the unoccupied envelope 3D volume. The second topological deformation contraction is used to obtain a simplified graphical contraction configured to map back to a 3D volume. The method involves determining one or more wellbore paths that avoid collisions with existing wells and satisfy one or more placement rules for the wellbore path. The method may also involve obtaining one or more placement rules for each wellbore path and determining a path score for each candidate wellbore path, and displaying the wellbore paths and associated path scores. The highest path score may be used to perform a wellsite action in response to the selected candidate wellbore path.

[0100] Implementation of placement rules may involve evaluating how well a particular candidate wellbore path satisfies a particular rule. For the same reasons, this evaluation may be assigned a "score." Other factors associated with a particular candidate wellbore path may also receive a score. For example, a score may be assigned to each uncertainty value associated with a cell not occupied by an existing wellbore, or a score may be assigned to the total length of the candidate wellbore. Essentially, any parameter relevant to drilling a candidate wellbore (whether based on the equipment used or the geology through which the wellbore passes) can be scored. The scores for all or a relevant subset of these parameters can be summed to obtain a score for each candidate wellbore, and the highest of these scores can be used to select the "best" candidate wellbore.

[0101] in conclusion

[0102] The embodiments disclosed in this disclosure are intended to help explain the concepts described herein. This description is not exhaustive and does not limit the claims to the precise embodiments disclosed. Modifications and variations to the precise embodiments in this disclosure may still fall within the scope of the claims.

[0103] Likewise, the steps described need not be performed in the same order or with the same degree of separation as discussed. Individual steps may be omitted, repeated, combined, or divided as needed. Accordingly, the present disclosure is not limited to the embodiments described above, but is defined by the appended claims according to their full scope of equivalents. In the above description and in the following claims, unless otherwise indicated, the term "execution" and its variations should be interpreted as referring to any operation on program code or instructions on a device, whether compiled, interpreted, or run using other techniques.

[0104] Unless the phrase “means for” is explicitly used with a relevant function, a subsequent claim will not invoke Section 112(f).

Claims

1. A method comprising: a. generating a representation of a three-dimensional volume ("3D volume") comprising a plurality of cells, wherein a portion of the 3D volume is located below ground level; b. identifying one or more existing wellbores within the 3D volume by listing those of the plurality of cells in the 3D volume that are associated with existing wellbores as occupied cells; c. Calculating an unoccupied envelope homology group, wherein the occupied unit is excluded from the unoccupied envelope homology group; d. performing one or more topological deformation contractions to determine a 2D unoccupied envelope that is homologically equivalent to the unoccupied envelope homology group; and e. Determine one or more candidate wellbore paths based at least in part on the 2D unoccupied envelope.

2. The method of claim 1 , wherein generating the 3D volume comprises recording data for each of the plurality of cells, the data comprising a cell volume and a unique position of each cell within the 3D volume specified by three position parameters, wherein one of the position parameters represents a depth layer relative to the ground, and the other two parameters define a grid that divides the depth layer into two-dimensional blocks.

3. The method according to claim 1, further comprising: a. Apply one or more placement rules to each candidate wellbore path: b. Determining a path score for each candidate wellbore path based on the placement rules; c. Display each candidate wellbore path and the corresponding path score; d. selecting the candidate wellbore path having the highest path score; as well as e. Performing wellsite actions in response to the selected candidate wellbore path.

4. The method of claim 1 , further comprising determining a simplified graph contraction based at least in part on the 2D unoccupied envelope, wherein the simplified graph contraction is configured to map back to the 3D volume, and wherein the one or more candidate wellbore paths are determined using the simplified graph contraction.

5. A method comprising: a. generating a representation of a three-dimensional volume ("3D volume") comprising a plurality of cells, wherein a portion of the 3D volume is below a ground surface, and data for each of the plurality of cells comprises a cell volume and a unique position of each cell within the 3D volume specified by three position parameters, wherein one of the position parameters represents a depth layer relative to the ground surface, and the other two parameters define a grid dividing the depth layer into two-dimensional blocks; b. identifying one or more existing wellbores within the 3D volume by listing those of the plurality of cells in the 3D volume that are associated with existing wellbores as occupied cells; c. Calculating an unoccupied envelope homology group, wherein the occupied unit is excluded from the unoccupied envelope homology group; d. performing a first topological deformation contraction to find a 2D unoccupied envelope in 2D space that is homologically equivalent to the unoccupied envelope homology group in the 3D volume; e. performing deformation contraction on the unoccupied envelope homology group; f. performing a second topological deformation contraction to obtain a simplified graph contraction configured to be mapped back to the 3D volume; as well as g. Determine one or more candidate wellbore paths using the simplified graph contraction.

6. The method of claim 5 , wherein identifying existing wellbores by listing occupied cells comprises listing the unique location of the occupied cell, the wellbore direction of the occupied cell, and uncertainty values ​​of cells adjacent to the occupied cell, and further wherein calculating the unoccupied envelope coherence group comprises excluding cells having uncertainty values ​​above a threshold uncertainty value from the unoccupied envelope coherence group.

7. The method according to claim 5 or claim 6, further comprising: assigning supplemental information to a portion of the plurality of cells in the 3D volume, wherein the supplemental information comprises one or more of: geological layer information; geological composition information; geological characteristics information; Reservoir information; reservoir proximity information; rock physical property information; geomechanical characteristic information; and steering trend characteristic information.

8. The method according to any one of claims 5 to 7, further comprising: a. Obtain one or more candidate starting positions of a candidate wellbore path; as well as b. Obtaining one or more candidate target positions of the candidate wellbore path, wherein the candidate starting position and the candidate target position are static when determining the candidate wellbore path, or are dynamic in real time when determining the candidate wellbore path.

9. The method of any one of claims 5 to 8, wherein performing the first topology deformation shrinkage further comprises the unoccupied envelope homology group, the cell's data, existing wellbore identification, candidate starting locations, candidate target locations, and supplemental information.

10. The method of any one of claims 5 to 9, wherein determining the candidate wellbore paths comprises applying one or more placement rules to each candidate wellbore path, the method further comprising: a. Determine a path score for each candidate wellbore path; b. Selecting the candidate wellbore path with the highest path score; as well as c. Performing wellsite actions in response to the selected candidate wellbore path.

11. The method according to claim 5, further comprising: a. Obtaining a set of drilling equipment parameters, the set of drilling equipment parameters including downhole steering tool parameters, drilling assembly parameters, and steering tendency capability parameters, wherein determining the candidate wellbore path includes utilizing at least one of the drilling equipment parameters.

12. The method of any one of claims 5 to 11, wherein determining the candidate wellbore paths comprises applying one or more placement rules to each candidate wellbore path, the method further comprising: a. Determine a path score for each candidate wellbore path; b. Selecting the candidate wellbore path with the highest path score; as well as c. Performing wellsite actions in response to the selected candidate wellbore path.

13. A method comprising: a. generating a three-dimensional representation of a volume ("3D volume"), a portion of which is located below ground level, the volume comprising a plurality of cells and data for each of the plurality of cells, the data comprising a cell volume and a unique location within the 3D volume for each cell specified by three location parameters; b. identifying one or more existing wellbores within the 3D volume by listing those of the plurality of cells in the 3D volume that are associated with existing wellbores as occupied cells; c. assigning supplemental information to a portion of the plurality of cells in the 3D volume; d. generating a 3D unoccupied envelope of cells having an initial size around the occupied cells and excluding the occupied cells; c. discretizing each cell contained in the 3D unoccupied envelope into a set of cell sizes that are smaller than the initial size of the cell; d. Repeatedly generating the 3D unoccupied envelope until the resolution of the 3D unoccupied envelope meets a predetermined accuracy threshold; e. performing a first topological deformation contraction to find a 2D unoccupied envelope in 2D space that is homologically equivalent to the 3D volume unoccupied envelope; f. Based on the first topological deformation and shrinkage, performing deformation and shrinkage on the unoccupied envelope 3D volume; g. performing a second topological deformation contraction to obtain a simplified graph contraction configured to be mapped back to the 3D volume; as well as h. Determine one or more candidate wellbore paths using at least one of the simplified graph contraction, the cell's data, existing wellbore data, candidate start locations, candidate target locations, drilling equipment parameters, supplemental information, and coherence groups.

14. The method of claim 13, wherein the input data set for the first topological deformation contraction includes at least one of data of the cell, existing wellbore identification, and supplemental information.

15. The method according to claim 13 or claim 14, further comprising: a. Obtain one or more candidate starting positions of a candidate wellbore path; b. obtaining one or more candidate target locations of the candidate wellbore path; c. Compute the unoccupied envelope homology group consisting of a list of unit positions, where The unoccupied envelope homology group is a plurality of cells in the 3D volume excluding the occupied cells; or The unoccupied envelope homology group is the plurality of cells in the 3D volume having uncertainty values ​​below a threshold uncertainty; The input data set contracted by the first topological deformation includes at least one of the candidate starting position, the candidate target position and the unoccupied envelope homology group.

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