Multi-well cushion block well drilling frame

Abstract

A method may include receiving an input regarding a multi-well pad; selecting a template of the multi-well pad based at least in part on a portion of the input; generating well trajectories for the multi-well pad based at least in part on the template, where each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories comprises at least one curve generated using one or more dog-leg severity values and one or more geometric control points that need not be located on one or more of the well trajectories; and outputting a specification of the generated trajectory of the multi-well cushion block.

Description

[0001] Related Applications

[0002] This application claims priority to and the benefit of U.S. Provisional Application Serial No. 63 / 269,274, filed on March 14, 2022, which is incorporated herein by reference in its entirety. Background Art

[0003] A reservoir may be a subsurface formation that can be characterized, at least in part, by its porosity and fluid permeability. As an example, a reservoir may be part of a basin, such as a sedimentary basin. A basin may be a depression in which sediments accumulate (e.g., caused by plate tectonic activity, sedimentation, etc.). As an example, in the case where source rocks are combined with appropriate burial depth and duration, a petroleum system may develop within a basin, thereby possibly forming a reservoir containing hydrocarbon fluids (e.g., oil, natural gas, etc.).

[0004] In oil and gas exploration, interpretation is a process involving data analysis to identify and locate various underground structures (e.g., horizons, faults, geological bodies, etc.) in a geological environment. Various types of structures (e.g., stratigraphic formations) can indicate oil and gas traps or flow channels, such as can be associated with one or more reservoirs (e.g., fluid reservoirs). In the field of resource extraction, the enhancement of interpretation can allow the construction of more accurate models of underground regions, which in turn can improve the description of underground regions for resource extraction. The characterization of one or more underground regions in a geological environment can guide the execution of one or more operations (e.g., field operations, etc.), for example. As an example, a plan can depend on a model of an underground region, where the plan can specify how a drilling operation can accurately construct a wellbore according to a trajectory that penetrates a reservoir, etc., where fluids can be produced via the wellbore (e.g., as a completion, etc.). As an example, one or more computing frameworks, systems, etc. can be used to execute one or more workflows for one or more of analysis, acquisition, model building, control, etc., for extraction, interpretation, drilling, fracturing, production, etc. Summary of the invention

[0005] A method may include: receiving input about a multi-well pad; selecting a template for the multi-well pad based at least in part on a portion of the input; generating well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, which do not necessarily have to be located on one or more of the well trajectories; and outputting specifications for the generated trajectories for the multi-well pad. A system may include: one or more processors; a memory accessible by the one or more processors; processor-executable instructions stored in the memory and executable to instruct the system to: receive input regarding a multi-well pad; select a template for the multi-well pad based at least in part on the input; generate a well trajectory for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, which do not necessarily have to be located on one or more of the well trajectories; and output a specification for the generated trajectory of the multi-well pad. One or more computer-readable storage media may include processor-executable instructions to instruct a computing system to: receive input about a multi-well pad; select a template for the multi-well pad based at least in part on a portion of the input; generate a well trajectory for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, the geometric control points not necessarily being located on one or more of the well trajectories; and output a specification of the generated trajectory for the multi-well pad. Various other devices, systems, methods, etc. are also disclosed.

[0006] This Summary is provided to introduce a selection of concepts that are further described below in the Detailed Description. This Summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter. BRIEF DESCRIPTION OF THE DRAWINGS

[0007] The following detailed description refers to the accompanying drawings. Where convenient, the features and advantages of the implementations may be more easily understood by referring to the following description in conjunction with the accompanying drawings.

[0008] Figure 1 An example of a system is shown;

[0009] Figure 2 An example of a system is shown;

[0010] Figure 3 An example of a system is shown;

[0011] Figure 4 An example of a system is shown;

[0012] Figure 5 An example of a system is shown;

[0013] Figure 6 An example of a system is shown;

[0014] Figure 7 An example of a method is shown;

[0015] Figure 8 An example of a diagram showing a multi-well pad;

[0016] Fig. 9 An example of the technique is shown;

[0017] Fig.10 An example of the technique is shown;

[0018] Fig.11 An example of the technique is shown;

[0019] Fig.12 An example of a graphical user interface is shown;

[0020] Fig.13 An example of a graphical user interface is shown;

[0021] Fig.14 An example of a method and an example of a graphical user interface are shown;

[0022] Fig.15 An example of a method and an example of a system are shown; and

[0023] Fig.16 An example of a system is shown. DETAILED DESCRIPTION

[0024] This description should not be taken in a limiting sense but is merely for the purpose of describing the general principles of implementations. Reference should be made to the issued claims to determine the scope of the described implementations.

[0025] Figure 1 An example of a system 100 is shown that includes a workspace framework 110 that can be used for instantiation, presentation, interaction with, etc. of a graphical user interface (GUI) 120. Figure 1In the example of , GUI 120 may include graphical controls for a computing framework (eg, application, etc.) 121 , projects 122 , visualization 123 , one or more other features 124 , data access 125 , and data storage 126 .

[0026] exist Figure 1 In the example of , the workspace framework 110 can be customized for a specific geological environment (such as the example geological environment 150). For example, the geological environment 150 may include multiple layers (e.g., stratification) that include a reservoir 151 and may intersect a fault 153. As an example, the geological environment 150 may be equipped with various sensors, detectors, actuators, and the like. For example, the device 152 may include communication circuits for receiving and transmitting information relative to one or more networks 155. Such information may include information associated with downhole equipment 154, which may be equipment for collecting information, assisting in resource recovery, and the like. Other equipment 156 may be located remotely from the well site and include sensing, detection, transmission, or other circuits. Such equipment may include storage and communication circuits to store and transmit data, instructions, and the like. As an example, one or more satellites may be provided for purposes of communication, data collection, and the like. For example, Figure 1 The satellite is shown in communication with a network 155 which may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imaging (eg, spatial, spectral, temporal, radiometric, etc.).

[0027] Figure 1 The geological environment 150 is also shown as optionally including equipment 157 and 158 associated with a well, the well including a substantially horizontal portion that may intersect one or more fractures 159. For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures), or a combination of natural fractures and artificial fractures. As an example, a laterally extending reservoir may be drilled. In such examples, there may be lateral changes in properties, stresses, etc., where an assessment of such changes may help plan, operate, etc. to develop a laterally extending reservoir (e.g., via fracturing, injection, extraction, etc.). As an example, equipment 157 and / or 158 may include components, one or more systems, etc. for fracturing, seismic sensing, seismic data analysis, assessment of one or more fractures, etc.

[0028] exist Figure 1 In the example of , GUI 120 shows some examples of computational frameworks, including DRILLPLAN, DRILLOPS, PETREL, TECHLOG, PETROMOD, ECLIPSE, PIPESIM, and INTERSECT frameworks (SLB, Houston, Texas).

[0029] The DRILLPLAN framework is used for digital well construction planning and includes features for automation of repetitive tasks and validation workflows, thereby enabling rapid generation of drilling plans (eg, digital drill plans, etc.) of improved quality while ensuring consistency.

[0030] The DRILLOPS framework can execute digital drilling plans and ensure compliance with plans while providing goal-based automation. The DRILLOPS framework can automatically generate activity plans for various operations, whether they are monitored and / or controlled at the well site or in town. Automation can use data analysis and learning systems to assist and optimize tasks, such as, for example, setting ROP to drill columns. A preset menu of automatable drilling tasks can be presented, and using data analysis and models, plans can be executed in a certain way to achieve specified goals, where, for example, measurements can be used for calibration. The DRILLOPS framework provides flexibility to dynamically modify and re-plan activities, for example, based on real-time assessments of various factors (such as equipment, personnel, and supplies). Well construction activities (such as tripping, drilling, cementing, etc.) can be continuously monitored and dynamically updated using feedback from operational activities. The DRILLOPS framework can provide various levels of automation based on planning and / or re-planning (such as via the DRILLPLAN framework), feedback, etc.

[0031] The PETREL framework can be part of the DELFI environment, used in geoscience and geoengineering, for example, for analyzing subsurface data from exploration to reservoir fluid production. The DELFI cognitive exploration and production (E&P) environment (SLB, Houston, Texas), referred to herein as the DELFI environment or the DELFI framework, is a secure, cognitive, cloud-based collaborative environment that uses digital technologies (such as artificial intelligence and machine learning) to integrate data with workflows.

[0032] The PETREL framework provides components that allow optimization of various exploration, development, and production operations. The PETREL framework includes a seismic to simulation software component that can output information for improving reservoir performance, such as by increasing asset team productivity. Using this framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes (e.g., with respect to one or more geological environments, etc.). This framework can be considered an application (e.g., executable using one or more devices) and can be considered a data-driven application (e.g., where data is input for the purpose of modeling, simulation, etc.).

[0033] The TECHLOG framework can handle and process field and laboratory data from various geological environments (e.g., deepwater exploration, shale, etc.). The TECHLOG framework can structure wellbore data for analysis, planning, etc.

[0034] The PETROMOD framework provides a petroleum system modeling capability that can combine one or more of seismic, well, and geological information to simulate the evolution of a sedimentary basin. The PETROMOD framework can predict whether and how a reservoir will be filled with hydrocarbons, including the source and timing of hydrocarbon generation, migration routes, quantities, and types of hydrocarbons in underground or surface conditions.

[0035] The ECLIPSE framework provides numerical solutions for reservoir simulators (eg, as a computational framework) for quickly and accurately predicting the dynamic behavior of various types of reservoirs and development scenarios.

[0036] The INTERSECT framework provides a high-resolution reservoir simulator for simulating detailed geological features and quantifying uncertainties, for example, by creating accurate production scenarios, and by integrating accurate models of surface facilities and field operations, the INTERSECT framework can produce reliable results that can be continuously updated through real-time data exchange (e.g., from one or more types of data acquisition equipment in the field that can acquire data during one or more types of field operations, etc.). The INTERSECT framework can provide completion configurations for complex wells, where such configurations can be built in the field; can provide detailed enhanced oil recovery (EOR) recipes, where such recipes can be implemented in the field; can analyze the application of steam injection and other thermal EOR technologies for field implementation, advanced production control in terms of reservoir coupling and flexible field management, and the flexibility to write customized solutions for improved modeling and field management control. As with other example frameworks, the INTERSECT framework can be used as part of the DELFI environment, for example, for rapid simulation of multiple concurrent cases. For example, a workflow can utilize one or more DELFI environment on-demand reservoir simulation features.

[0037] The aforementioned DELFI environment provides various features for workflows related to subsurface analysis, planning, construction, and production, as shown, for example, in the workspace framework 110. Figure 1 As shown, outputs from the workspace framework 110 can be used to guide, control, etc., one or more processes in the geological environment 150, and feedback 160 (e.g., acquired data regarding operating conditions, equipment conditions, environmental conditions, etc.) can be received via one or more interfaces in one or more forms.

[0038] As an example, the workflow may proceed to a geology and geophysics ("G&G") service provider, which may generate well trajectories, which may involve executing one or more G&G frameworks (e.g., consider the PETREL framework, etc.).

[0039] exist Figure 1 In the example of , visualization features 123 can be implemented via workspace framework 110, for example, to perform tasks associated with one or more of a subsurface region, planning operations, constructing wells and / or surface fluid networks, and producing from a reservoir.

[0040] As an example, the visualization process can implement one or more of the various features that may be suitable for one or more network applications. For example, the template may involve the use of JAVASCRIPT object notation format (JSON) and / or one or more other languages / formats. As an example, the framework can include one or more converters. For example, consider a JSON to PYTHON converter and / or a PYTHON to JSON converter. Such methods can provide compatibility of devices, frameworks, etc. with respect to one or more sets of instructions.

[0041] As an example, visualization features may be used to visualize various earth models, properties, and the like in one or more dimensions. As an example, visualization features may be used to present information in multiple dimensions, which presentation may optionally include multi-resolution presentation. In such examples, the information being presented may be associated with one or more frameworks and / or one or more data stores. As an example, visualization features may include one or more control features for controlling equipment, which may include, for example, field equipment that may perform one or more field operations. As an example, a workflow may utilize one or more frameworks to generate information that may be used to control one or more types of field equipment (e.g., drilling equipment, cable equipment, fracturing equipment, etc.).

[0042] With respect to reservoir models that may be suitable for use by the simulator, consider seismic data acquisition, such as acquired via reflection seismology, which can be used in geophysics, for example, to estimate the properties of underground strata. As an example, reflection seismology can provide seismic data that represent elastic energy waves (e.g., as transmitted by P-waves and S-waves, in a frequency range of about 1 Hz to about 100 Hz). Seismic data can be processed and interpreted, for example, to better understand the composition, fluid content, range, and geometry of underground rocks. Such interpretation results can be used to plan, simulate, perform, etc., one or more operations for extracting fluids from a reservoir (e.g., reservoir rock, etc.).

[0043] Field acquisition equipment can be used to acquire seismic data, which can be in the form of a track, where the track can include values ​​organized with respect to time and / or depth (e.g., considering 1D, 2D, 3D, or 4D seismic data). For example, consider an acquisition device that acquires digital samples at a rate of one sample every about 4 ms. Given the speed of sound in one or more media, the sampling rate can be converted into an approximate distance. For example, the speed of sound in rock can be about 5 km per second. Therefore, a sampling time interval of about 4 ms will correspond to a sampling "depth" interval of about 10 meters (e.g., assuming a path length from the source to the boundary and from the boundary to the sensor). As an example, the duration of the track may be about 4 seconds; therefore, for a sampling rate of one sample at about 4 ms intervals, such a track will include about 1000 samples, where the samples acquired later correspond to deeper reflective boundaries. If the 4-second track duration of the above example is divided by two (e.g., to take into account reflections), the deepest boundary depth can be estimated to be about 10 km for vertically aligned sources and sensors (e.g., assuming a sound speed of about 5 km per second).

[0044] As an example, the model can be a simulated version of a geological environment. As an example, a simulator can include features for simulating physical phenomena in a geological environment based at least in part on one or more models. A simulator such as a reservoir simulator can simulate fluid flow in a geological environment based at least in part on a model that can be generated via a framework that receives seismic data. The simulator can be a computerized system (e.g., a computing system) that can use one or more processors to execute instructions to solve a set of equations describing physical phenomena subject to various constraints. In such examples, the set of equations can be spatially defined (e.g., numerically discretized) according to a spatial model including rock layers, geological bodies, etc., which have corresponding positions that can be based on interpretations of seismic and / or other data. The spatial model can be a cell-based model in which a cell is defined by a grid (e.g., a grid). A cell in a cell-based model can represent a physical region or volume in a geological environment, wherein the cell can be assigned physical properties (e.g., permeability, fluid properties, etc.) that may be closely related to one or more physical phenomena (e.g., fluid volume, fluid flow, pressure, etc.). A reservoir simulation model can be a spatial model that can be based on cells.

[0045] Simulators can be used to simulate production from real reservoirs, for example, to examine different production scenarios to find the best scenario before production or further production occurs. Reservoir simulators do not provide an exact replication of flow in and production from a reservoir, at least in part because the boundary conditions of the equations describing the reservoir and flow in porous rocks are generally known, but with a certain amount of uncertainty. Certain types of physical phenomena occur at spatial scales that may be relatively small compared to the size of the oil field. A balance can be struck between model scale and computational resources so that model cell sizes are on the order of meters; rather than smaller sizes (e.g., pore detail levels). Modeling and simulation workflows for multiphase flow in porous media (e.g., reservoir rocks, etc.) can include generalizing real microscale data from macroscale observations (e.g., seismic data and well data) and scaling them up to a manageable size and problem size. There may be uncertainty in the input data and solution process, so the simulation results are also uncertain to some extent. A process known as history matching may involve comparing simulation results with actual oil field data acquired during the production of fluids from the oil field. Information gleaned from history matching can provide adjustments to models, data, etc., which can help improve the accuracy of the simulation.

[0046] As an example, a simulator can utilize various types of constructs, which can be referred to as entities. Entities can include earth entities or geological objects, such as wells, ground, reservoirs, etc. Entities can include virtual representations of actual physical entities that may be reconstructed for simulation purposes. Entities can include entities based on data obtained via sensing, observation, etc. (e.g., considering entities based at least in part on seismic data and / or other information). As an example, an entity can be characterized by one or more properties (e.g., a geometric pillar grid entity of an earth model can be characterized by porosity properties, etc.). Such properties can represent one or more measurements (e.g., acquired data), calculations, etc.

[0047] As an example, a simulator can utilize an object-based software framework that can include entities based on predefined classes to facilitate modeling and simulation. As an example, an object class can encapsulate reusable code and associated data structures. Object classes can be used to instantiate object instances for use by programs, scripts, etc. For example, a wellbore class can define objects for representing wellbores based on well data. A model of a basin, reservoir, etc. can include one or more wellbores, where a wellbore can be used, for example, for measurement, injection, production, etc. As an example, a wellbore can be a wellbore of a well, and the well can be a completion (e.g., for producing resources from a reservoir, for injecting materials, etc.).

[0048] Although in Figure 1Several simulators are shown in the examples of, but one or more other simulators may be used in addition or alternatively. For example, consider the VISAGE geomechanical simulator (SLB, Houston, Texas) or the PIPESIM network simulator (SLB, Houston, Texas), etc. The VISAGE simulator includes a finite element numerical solver that can provide simulation results, such as, for example, compaction and settlement of the geological environment, well and completion integrity in the geological environment, cap rock and fault closure integrity in the geological environment, fracturing behavior in the geological environment, thermal recovery in the geological environment, CO2 disposal, etc. The PIPESIM simulator includes a solver that can provide simulation results, such as, for example, multiphase flow results (e.g., from the reservoir to the wellhead and beyond, etc.), flow lines and surface facility performance, etc. The PIPESIM simulator can be integrated, for example, with the AVOCET production operations framework (SLB, Houston, Texas). As an example, one or more reservoirs can be simulated with respect to one or more enhanced production technologies (e.g., considering thermal processes, such as steam-assisted gravity drainage (SAGD), etc.). As an example, the PIPESIM simulator can be an optimizer that can optimize one or more operational scenarios at least in part via simulation of physical phenomena. The MANGROVE simulator (SLB, Houston, Texas) optimizes stimulation designs (e.g., stimulation treatment operations, such as hydraulic fracturing) in a reservoir-centric environment. The MANGROVE framework can combine scientific and experimental work to predict the geomechanical propagation of hydraulic fractures, the reactivation of natural fractures, etc., and production predictions within a 3D reservoir model (e.g., production from drainage areas of a reservoir, where fluids move into and / or out of a well via one or more types of fractures). The MANGROVE framework can provide results related to the heterogeneous interactions between hydraulic fracture networks and natural fracture networks, which may help optimize the number and location of fracture treatment stages (e.g., stimulation treatments), for example, to improve perforation efficiency and production.

[0049] As an example, the data may include geochemical data. For example, consider data acquired using X-ray fluorescence (XRF) techniques, Fourier transform infrared spectroscopy (FTIR) techniques, and / or wireline geochemical techniques.

[0050] As an example, one or more probes may be deployed in a borehole via one or more cables. As an example, the probes may transmit energy and receive energy, wherein such energy may be analyzed to help determine the mineral composition of the rock surrounding the borehole. As an example, nuclear magnetic resonance may be implemented (e.g., via cables, downhole NMR probes, etc.), for example, to obtain data on the nuclear magnetic properties of elements (e.g., hydrogen, carbon, phosphorus, etc.) in the formation.

[0051] As an example, lithology scanning technology can be used to acquire and analyze data. For example, consider the LITHOSCANNER technology (SLB, Houston, Texas). As an example, the LITHO SCANNER tool can be or include a gamma ray spectroscopy analysis tool.

[0052] As an example, a tool may be positioned to acquire information in a portion of a wellbore. Analysis of such information may reveal caves, dissolution planes (e.g., dissolution along a bedding plane), stress-related features, subsidence events, etc. As an example, a tool may acquire information that may be helpful in characterizing a fractured reservoir, optionally where the fractures may be natural and / or artificial (e.g., hydraulic fractures). Such information may be helpful in completions, stimulation treatments, etc. As an example, information acquired by a tool may be analyzed using a framework such as the TECHLOG framework described above.

[0053] As an example, a workflow may use one or more types of data for one or more processes (e.g., formation modeling, basin modeling, completion design, drilling, production, injection, etc.). As an example, one or more tools may provide data that may be used in one or more workflows, which may implement one or more frameworks (e.g., PETREL, TECHLOG, PETROMOD, ECLIPSE, etc.).

[0054] exist Figure 1 In the example of , drilling can be performed in a geological environment 150, for example, to access a reservoir 151, which can be accessed from land or sea. Figure 1 In the embodiment of the present invention, the downhole equipment 154 can be, for example, part of a bottom hole assembly (BHA). The BHA can be used to drill a well. The downhole equipment 154 can transmit information to equipment on the surface and can receive instructions and information from equipment on the surface. During the well construction process, various operations (such as cementing, cable evaluation, testing, etc.) can be performed. In such embodiments, data collected by tools and sensors and used for reasons such as reservoir characterization can be collected and transmitted.

[0055] Wells may include substantially horizontal portions (e.g., lateral portions) that may intersect one or more fractures. For example, wells in shale formations may pass through natural fractures, artificial fractures (e.g., hydraulic fractures), or a combination thereof. Such wells 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 inclined wells, etc.) and are not limited to horizontal wells.

[0056] Figure 2An 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 for a mud pump 204 for pumping mud from the mud tank 201 to a vibrating hose 206; a winch 207 for hoisting one or more drilling wire ropes 212; a riser 208 for receiving mud from the vibrating hose 206; and a kelly hose for receiving mud from the riser 208. 209; one or more goosenecks 210; a traveling block 211; a crown block 213 for carrying the traveling block 211 via one or more drilling wirelines 212; a derrick 214; a kelly 218 or a top drive 240; a kelly bushing 219; a rotary table 220; a drill floor 221; a bell-mouth nipple 222; one or more blowout preventers (BOPs) 223; a drill string 225; a drill bit 226; a casing head 227; and a flow pipe 228 for conveying mud and other materials to, for example, a mud tank 201.

[0057] exist Figure 2 In the example system, a wellbore 232 is formed in a subsurface formation 230 by rotary drilling; it should be noted that various example embodiments may also use one or more directional drilling techniques, equipment, etc.

[0058] like Figure 2 As shown in the example of FIG. 2 , a drill string 225 is suspended in a 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 may be a bottom hole assembly (BHA).

[0059] The wellsite system 200 can provide for the operation of the drill string 225 and other operations. As shown, the wellsite system 200 includes a traveling block 211 and a derrick 214 positioned above a 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.

[0060] like Figure 2As shown in the example of , the wellsite system 200 may include a kelly 218 and associated components or the like or a top drive 240 and associated components. With respect to the kelly example, the kelly 218 may be a square or hexagonal metal / alloy column in which a wellbore is drilled that serves as a mud flow path. The kelly 218 may be used to transfer rotational motion from a rotary table 220 to a 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 a kelly bushing 219 that may be driven by the rotary table 220. As an example, the rotary table 220 may include a main bushing that is operatively coupled to the kelly bushing 219 such that rotation of the rotary table 220 may rotate the kelly bushing 219 and thereby rotate the kelly 218. The kelly bushing 219 may include an inner profile that matches the outer 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 .

[0061] 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 appropriate transmissions to a short pipe section 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 freely travel 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 method.

[0062] exist Figure 2 In the example of, mud tank 201 can store mud, and the mud 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.).

[0063] exist Figure 2In the example of FIG. 2 , a drill string 225 (e.g., including one or more downhole tools) can be composed of a series of pipes that can be threaded together to form a long pipeline with a drill bit 226 at the lower end. When the drill string 225 is advanced into the wellbore for drilling, at a certain point in time before or coincident with drilling, mud can be pumped from the mud tank 201 (e.g., or other source) to a port of the kelly 218, or, for example, to a port of the top drive 240, by the pump 204 via pipelines 206, 208, and 209. 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 leaves 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.).

[0064] 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 the friction between the drill string 225 and the surrounding walls (e.g., wellbore, casing, etc.), etc. The reduction in friction can help 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 sharp drill bit, a smaller diameter drill string, etc. As mentioned, the action of pulling the drill string out of the wellbore or replacing the drill string in the wellbore is called tripping. Depending on the tripping direction, tripping can be called up-tripping or out-tripping or down-tripping or in-tripping.

[0065] 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).

[0066] As an example, a mud pulse telemetry device may include a downhole device configured to implement changes in mud pressure to generate one or more acoustic waves based on which information may be modulated. In such examples, information from the downhole device (e.g., one or more modules of the drill string 225) may be transmitted uphole to the uphole device, which may forward such information to other devices for processing, control, etc.

[0067] As one example, the telemetry equipment may operate by transmitting energy through the drill string 225 itself. For example, consider a signal generator that transmits a coded energy signal to the drill string 225 and a repeater that may receive such energy and relay the energy for further transmission of the coded energy signal (e.g., information, etc.).

[0068] 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 so that mud can rotate the turbine wheel; a modulator rotor mechanically coupled to the drive shaft so that rotation of the turbine wheel rotates the modulator rotor; a modulator stator mounted adjacent to or near the modulator rotor so that rotation of the modulator rotor relative to the modulator stator forms a pressure pulse of the mud; and a controllable brake for selectively braking the rotation of the modulator rotor to modulate the pressure pulse. In such an example, an alternator may be coupled to the aforementioned drive shaft, wherein the alternator includes at least one stator winding, the at least one stator winding being electrically coupled to a control circuit to selectively short the at least one stator winding to electromagnetically brake the alternator and thereby selectively brake the rotation of the modulator rotor to modulate the pressure pulse of the mud.

[0069] exist Figure 2 In an example of , 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.

[0070] 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, wherein a drill string may include multiple tools.

[0071] With respect to RSS, it relates to techniques used for directional drilling. Directional drilling involves drilling into the earth to form a deflected borehole so that the trajectory of the borehole is not vertical; instead, the trajectory 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 a 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 (e.g., consider salt domes, etc.), where the formations are laterally extended (e.g., consider relatively thin but laterally extended reservoirs), where multiple boreholes are to be drilled from a single surface borehole, where relief wells are required, etc.

[0072] One method of directional drilling involves a mud motor; however, mud motors may encounter some 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. A mud motor may be a positive displacement motor (PDM) used to drive a drill bit (e.g., during directional drilling, etc.). A PDM operates when drilling fluid is pumped through it, where the PDM converts the hydraulic power of the drilling fluid into mechanical power to rotate the drill bit.

[0073] As an example, a mud motor (e.g., a PDM) can be operated in different modes, which may include a rotation mode and a sliding mode. The sliding mode involves drilling with a mud motor rotating the drill bit downhole without rotating the drill string at the surface. Such an operation can be performed when the BHA is equipped with a bent sub or a bent shell mud motor (or both) for directional drilling. Sliding can be used to build and control or adjust the angle of the wellbore. In directional drilling, the pointing of the drill bit can be achieved by a bent sub with a relatively small offset angle from the axis of the drill string and a measuring device for determining the offset direction. Without rotating the drill string, the drill bit can be rotated with the mud flowing through the mud motor to drill in the direction it is pointing. With a directional motor, when the desired wellbore direction is reached, the entire drill string can be rotated to drill in a straight line instead of drilling at a certain angle. By controlling the number of wellbores drilled in the sliding mode and the rotation mode, the trajectory of the wellbore can be controlled quite accurately.

[0074] As an example, the PDM may be operated in a combined rotation mode, where the drill bit of the drill string is rotated by rotating the entire drill string using surface equipment (e.g., rotary table, top drive, etc.), and the drill bit of the drill string is rotated using drilling fluid. 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.

[0075] As an example, when the drill string is not rotating from the surface, the PDM mud motor can be operated in a so-called sliding mode. In such examples, the drill bit RPM can be determined or estimated based on the RPM of the mud motor.

[0076] An RSS can perform directional drilling, where the surface equipment is continuously rotating, which can mitigate slippage of the directional motor (e.g., PDM). An RSS can be deployed when directional drilling (e.g., a deflected, horizontal, or extended well). An RSS can be designed to minimize its interaction with the wellbore wall, which can help maintain wellbore quality. An 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 a desired direction while continuously rotating at the same RPM as the drill string.

[0077] The LWD module 254 may be housed in a suitable type of drill collar and may contain one or more selected types of logging tools. It should also be understood that more than one LWD and / or MWD module may be employed, for example, as represented by module 256 of the drill string assembly 250. Where the location of an LWD module is mentioned, as an example, it may refer to a module at the location of the LWD module 254, module 256, etc. The LWD module may include capabilities for measuring, processing, and storing information, as well as communicating with surface equipment. In the example shown, the LWD module 254 may include a seismic measurement device.

[0078] The MWD module 256 may be housed in a suitable type of drill collar and may contain one or more devices for measuring characteristics of the drill string 225 and the drill bit 226. As an example, the MWD tool 254 may include a device for generating electricity, for example, to power various components of the drill string 225. As an example, the MWD tool 254 may include a telemetry device 252, for example, where a turbine wheel may generate electricity from the flow of mud; it will be appreciated that other power sources and / or battery systems may be employed to power the various components. As an example, the MWD module 256 may include one or more of the following types of measurement devices: a bit pressure measurement device, a torque measurement device, a vibration measurement device, an impact measurement device, a stick-slip measurement device, a direction measurement device, and an inclination measurement device.

[0079] Figure 2 Also shown are some examples of the types of wellbores that can be drilled. For example, consider a deviated wellbore 272, an S-shaped wellbore 274, a deep deviated wellbore 276, and a horizontal wellbore 278.

[0080] 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.

[0081] As an example, a directional well can include a variety of shapes, each of which can be designed to meet specific operational requirements. As an example, a drilling process can be performed based on the information when the information is forwarded to a drilling engineer. As an example, the inclination and / or direction can be modified based on the information received during the drilling process.

[0082] As one example, deflection of the borehole may be achieved in part by using downhole motors and / or turbines.With respect to motors, for example, the drill string may include a positive displacement motor (PDM).

[0083] As an example, the system may be a guidance system and include equipment for performing methods such as geosteering. As mentioned, the guidance system may be or include an RSS. As an example, the guidance system may include a PDM or turbine located at the bottom of the drill string, which is located just above the drill bit and a bent joint may be installed. As an example, above the PDM, MWD equipment and / or LWD equipment may be installed, which provides real-time or near real-time data of interest (e.g., inclination, direction, pressure, temperature, actual weight on the drill bit, torque stress, etc.). Regarding the latter, the LWD equipment may enable various types of data of interest to be sent to the ground, including, for example, geological data (e.g., gamma ray logging, resistivity, density, and sonic logging, etc.).

[0084] The coupling of sensors that provide information about the well trajectory in real time or near real time with one or more well logs that characterize the formation from a geological point of view, for example, can allow the implementation of geosteering methods. Such methods can include navigating the subsurface environment, for example, to follow a desired route to reach a desired target or targets.

[0085] 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.

[0086] 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 directing the wellbore to maintain the wellbore in a particular section of a reservoir, such as to minimize breakthrough of gas and / or water, and, for example, to maximize economic production from a well that includes the wellbore.

[0087] Reference again Figure 2, the wellsite system 200 may include one or more sensors 264, which are 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 about one hundred meters from the wellsite system 200. As an example, the one or more sensors may be located at a compensation wellsite, where the wellsite system 200 and the compensation wellsite are in a common oil and gas field (e.g., an oil field and / or a gas field).

[0088] As an example, one or more sensors 264 may be provided to track a pipe, track movement of at least a portion of a drill string, etc.

[0089] As an example, the system 200 may include one or more sensors 266 that may 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 the system 200, the one or more sensors 266 may be operatively coupled to a portion of the riser 208 through which mud flows. As an example, a downhole tool may generate pulses that may travel through the mud and be sensed by one or more of the one or more sensors 266. In such examples, the downhole tool may include associated circuitry, such as, for example, an encoding circuit that may encode the signal, for example, to reduce the need for transmission. As an example, the circuitry located at the surface may include a decoding circuit to decode encoded information transmitted at least in part via mud pulse telemetry. As an example, the circuitry located at the surface may include an encoder circuit and / or a decoder circuit, and the downhole circuitry may include an encoder circuit and / or a decoder circuit. As an example, the system 200 may include a transmitter that may generate a signal that may be transmitted downhole via mud (e.g., drilling fluid) as a transmission medium.

[0090] As an example, one or more portions of the 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, the pipe may be rotated or placed back into the borehole, or, for example, in a stuck condition, the drill string may not be moved axially in the borehole, although a certain amount of rotation may be possible. As an example, in a stuck condition, at least a portion of the drill string may not be moved axially and rotationally.

[0091] With respect to the term "stuck drill," this may refer to a portion of a drill string that is unable to rotate or move axially. As an example, a condition referred to 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 economic costs.

[0092] As an example, the stuck pipe 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 may have the same effect on stuck pipe as applying a high pressure differential over a small area.

[0093] As an example, a condition called "mechanically stuck" may be a condition where drill string movement is restricted or prevented by a mechanism other than differential pressure sticking. Mechanically stuck drill may be caused, for example, by one or more of trash in the wellbore, wellbore geometry anomalies, cement, keyways, or cuttings accumulation in the annulus.

[0094] Figure 3 An example of a wellsite system 300 is shown, specifically, Figure 3 An approximate side view and an approximate plan view of wellsite system 300 and a block diagram of system 370 are shown.

[0095] exist Figure 3 In the example of FIG. 3 , the wellsite system 300 may include a cabin 310, a rotary table 322, a drawworks 324, a rig 326 (e.g., optionally carrying a top drive, etc.), a mud tank 330 (e.g., with one or more pumps, one or more vibrators, etc.), one or more pump rooms 340, a boiler room 342, an HPU room 344 (e.g., with a rig oil tank, etc.), a combination room 348 (e.g., with one or more generators, etc.), a pipeline 362, a catwalk 364, a flare 368, etc. Such equipment may include one or more associated functions and / or one or more associated operational risks, which may be risks in terms of time, resources, and / or personnel.

[0096] like Figure 3As shown in the example of , the wellsite system 300 may include a system 370, which includes one or more processors 372, a memory 374 operatively coupled to at least one of the one or more processors 372, instructions 376 that may be stored, for example, in the memory 374, and one or more interfaces 378. As an example, the system 370 may include one or more processor-readable media, the processor-readable media including processor-executable instructions that may be executed by at least one of the one or more processors 372 to cause the system 370 to control one or more aspects of the wellsite system 300. In such an example, the memory 374 may be or include one or more processor-readable media, wherein the processor-executable instructions may be or include instructions. As an example, the processor-readable medium may be a computer-readable storage medium, which is not a signal and is not a carrier wave.

[0097] Figure 3 Also shown is a battery 380 that can be operably coupled to the system 370, for example, to power the system 370. As an example, the battery 380 can be a backup battery that operates when another power source is not available to power the system 370. As an example, the battery 380 can be operably coupled to a network, which can be a cloud network. As an example, the battery 380 can include smart battery circuitry and can be operably coupled to one or more pieces of equipment via an SMBus or other type of bus.

[0098] exist Figure 3 In the example of FIG. 3 , service 390 is shown as being available, for example, via a cloud platform. Such services may include data service 392, query service 394, and drilling service 396. As an example, service 390 may be such as Figure 1 As an example, services 390 may include one or more services for directional drilling (e.g., considering a computing framework that can provide one or more services for estimating one or more parameters using real-time data, etc.).

[0099] As one example, system 370 may be used to generate one or more rate-of-penetration drilling parameter values, which may be used, for example, to control one or more drilling operations.

[0100] As an example, a method may include automating the operation of one or more types of downhole tools. For example, consider automating the operation of one or more of a mud motor, a rotary steerable system (RSS), and a drill bit steerable system (ABSS). As an example, a method may include automating the operation of one or more types of downhole tools. Figure 2One or more features of system 200 may be used to implement one or more of these types of devices, systems, and the like.

[0101] As an example, an ABSS may include an actuator with dropout range, hold inclination and azimuth (HIA), and dual downlink capability. As an example, an ABSS may include an onboard near-bit sensor that can acquire continuous six-axis inclination and azimuth measurements with a range of 6 feet, and optional natural gamma ray and azimuth images with a range of 9 feet. As an example, an ABSS may include one or more features of one or more NEOSTEER series ABSS (SLB, Houston, Texas).

[0102] As an example, the framework can be used to: consider information in planning through deviation analysis and adjust the hybrid model for real-time execution; consider various downhole automation possibilities at a given time to optimize the recommended work trajectory execution, exploit tool capabilities and minimize unnecessary surface actions; consider real-time data information and derived tool health and tool state estimates at a given point in time to optimize the current ongoing recommendations and recommend real-time corrections to deal with deviations when they occur. This approach can involve different calculations and actions that can output the best recommendation, for example, the fastest path with the least risk based on drilling constraints and drilling environment.

[0103] As for the optimal path suggestion, it can be derived via a framework, which can be used for a single-objective approach and / or a multi-objective approach and can, for example, take into account various factors, which may include energy, emissions, etc.

[0104] Figure 4 An example of a system 400 is shown, the system including an off-site device 401 (e.g., remote) and a field device 402 (e.g., local). As shown, the off-site device 401 may include a drilling operation framework 410, a drilling planning framework 420, and a database 430, and the field device 402 may include a controller 440, the controller may receive real-time data and output suggestions (such as control instructions) to control the field device. In such examples, the drilling operation framework 410 may provide a guide table, execution parameters, etc., and the drilling planning framework 420 may provide an evaluation of the guide response and statistical data. As shown, the controller 440 may output information to the drilling operation framework 410 and receive information from the drilling planning framework 420. The system 400 may include a plan generation feature for real-time plan generation during the execution phase of the drilling operation and / or plan generation during the planning phase. The system 400 may be used for one or more types of drilling (e.g., rotation, mud motor, RSS, ABSS, etc.). The system 400 may operate a cycle, the cycle may include at least one real-time cycle, for controlling the device to perform the drilling operation.

[0105] A system such as system 400 may utilize various functions and constraints to generate a plan that may be used for single or multi-target targeting.As illustrated, a plan may be generated that is intended for a drilling operation targeting a multi-well pad.

[0106] Pad / rig drilling in onshore and / or offshore well sites may present various challenges during the planning phase and / or execution phase, as crowded well locations may present significant risks. Such challenges may arise from the clustering of multiple wellheads in a relatively small area, which makes escape strategies for collision avoidance challenging. As an example, a system may automate and / or semi-automate a trajectory design workflow. Such a system may use various types of inputs, which may include, for example, surface location, target, and optional trajectory mode inputs, to generate trajectories on pads.

[0107] Pads can be temporary drilling sites, for example, built from local materials such as gravel, shells or even wood, noting that offshore pads can be steel plates with grooves. For some deep wells that take a long time to drill (such as ultra-deep wells in western Oklahoma) or some regulatory jurisdictions (such as the Netherlands), pads may be paved with asphalt or concrete. After the drilling operation is completed, most of the pads are usually removed or plowed back to the ground. If the pad includes multiple wells, it can be called a multi-well pad. Regarding the number of wells, a multi-well pad can include two to more than one hundred wells.

[0108] As an example, the system can utilize existing pad data such as from compensation wells, which can be located at one or more other pads. For example, consider one or more machine learning techniques that can be applied to pad data to generate a trained machine learning model that can generate output based on input. In such examples, the output can be an initial template of the pad, wherein the initial template can include an initial well trajectory. In such examples, the initial well trajectory can be shaped and sized to provide a certain amount of collision avoidance guarantees. As an example, the initial template can be generated using constraints and trajectory shapes associated with one or more collision avoidance strategies. Data analysis can be implemented for pads on land and / or offshore to help identify the main features, thereby classifying the pads into enumerable pad templates. Such features can include, for example, ground slot layouts (e.g., lines, matrices, or circles, etc.), nudge strategies (e.g., S nudges, J nudges, or mixed on a single pad), and landing preferences (e.g., single curve landing or multiple curves), etc. As an example, the template can provide a pattern about how the trajectory connects the ground position and the target; instructions for S nudges, J nudges, alignments, nudge starts, and ramp starts, etc. As an example, a template may specify the use of a single curve or, alternatively, one or more curves to achieve landing. For example, consider a ramp start point (ramp KOP), which may be the start point of a curve (e.g., curve start point), the curve having an end point (e.g., curve end point), the end point may be a landing point, and a straight line may extend from the landing point to a target, the straight line may be a target line.

[0109] As an example, a system can be used to generate a trajectory for a multi-well pad using one or more templates, where control points (e.g., key points) can be used for curve formation, defining straight sections, etc., where one or more control points can be one or more geometric points that may or may not be located on the trajectory. Such a system can be used to calculate point locations (e.g., control points and / or trajectory points) and adjust point locations, which can be performed using adjustments to one or more control points. In this method, geometric techniques can be quickly implemented to construct a trajectory for a pad, where the trajectory can have various anti-collision guarantees. As an example, a pad design with multiple trajectories can be output along with various associated specifications that may be related to drilling. For example, considering torque and drag (T&D), BHA specifications, hook load (HKLD), bit weight (WOB), etc., these can all be implemented through a drilling framework to speed up the drilling of the trajectory. As an example, during drilling, a replanning process can be called in response to data acquired using one or more sensors. For example, if the T&D differs from the specified T&D, if an obstacle is encountered (e.g., as evidenced by HKLD and / or WOB), the drilling framework can instruct the trajectory generation framework to re-plan (e.g., redesign) one or more trajectories in the multi-well pad. As explained, where the system implements a geometric control point based approach, planning and / or re-planning can be performed quickly in a manner that takes into account various constraints.

[0110] With respect to the term "nudge", it may refer to the process of changing a trajectory in one or more ways. For example, a nudge may change a trajectory in a multidimensional coordinate space (e.g., consider a north nudge, an east nudge, etc.). As an example, a nudge may change the angular direction of a trajectory (e.g., inclination, azimuth, etc.). As an example, a nudge may be a noun that refers to a particular shape of a portion of a trajectory of a well, such as an S nudge or a J nudge, where "S" and "J" correspond to shapes. With respect to an S nudge, it may have a first, upper vertical end and a second, lower vertical end, wherein there is a curve between the first end and the second end, or, for example, the upper end may be non-vertical (e.g., a portion having a non-zero inclination). Such nudges may be implemented as part of a collision avoidance strategy and / or to avoid one or more underground objects and / or areas. In practice, the introduction of an S nudge may complicate drilling because the drill string must drill the trajectory in a manner that deviates from a straight line (e.g., deviates from a vertical direction, etc.). An S-nudge may have at least two arc curves between two vertical portions (e.g., an inclined portion if the S-nudge is introduced from an inclined well), one of which curves upward (increases inclination) and one curves downward (declines inclination), while a J-nudge may have one or more arc curves that curve upward (increases inclination). During drilling, one or more techniques may be implemented to create curves in the wellbore that are intended to conform to a curved trajectory (e.g., a planned trajectory).

[0111] Another aspect of trajectory is known as doglegs, which can be characterized in part by dogleg severity (DLS or dls). A dogleg can be defined as a particularly curved place in the wellbore where the trajectory of the wellbore in three-dimensional space changes relatively rapidly. While doglegs are sometimes caused intentionally by directional drillers, the term can also refer to a section of the wellbore that changes direction more quickly than intended or desired, potentially with deleterious side effects. When surveying the wellbore trajectory, a standard calculation of dogleg severity can be performed, typically expressed in degrees in two dimensions per 100 feet of wellbore length (e.g., or degrees per 30 meters).

[0112] Doglegs can take into account various aspects of drilling, completion, well treatment, etc. For example, a planned casing string can be considered so that it can pass through a curved section. As another example, the effect of repeated wear of the drill string at a specific location of the dogleg can be considered to help reduce the risk of one or more wear points (e.g., one or more keyways) where the BHA may get stuck. As another example, consider casing that can be consolidated by doglegs, where the doglegs are designed and / or drilled to reduce the risk of casing wear due to higher contact forces between the drill string and the inner diameter surface of the casing passing through the doglegs. Other aspects that can be taken into consideration may include, for example, BHA stiffness and / or elasticity so that one or more BHAs can pass through the dogleg section and / or friction with the drill string, which may increase the possibility of getting stuck or failing to reach the planned target. In various cases, if the dogleg damages the well, one or more remedial measures can be taken, such as, for example, reaming or bottoming through the dogleg, or even sidetracking in extreme cases.

[0113] As an example, a system can generate a plan for a multi-well pad having trajectories suitable for taking one or more remedial actions. For example, consider a system that can generate a plan that can be presented to a display and contains information about various areas where one or more remedial actions can be taken if one or more types of problems occur during drilling, completion, injection, production, etc.

[0114] As an example, the system can generate and optimize the layout and geometry of the trajectory on the common pad. In one embodiment, each pad template can be generated accordingly. In one embodiment, given the ground position and underground target information of the pad well, assuming that the expected well is a horizontal well with a similar target line direction, the system can determine the micro-shift start depth (micro-shift KOP specified using depth), micro-shift inclination (e.g., specified using angle) and azimuth (e.g., specified using angle), so as to maximize the well trajectory separation and land on the target line with a relatively simple geometry (such as, for example, a single curve). As explained, in the case of designing one or more curves in a way that considers one or more types of constraints, it can help drilling. For example, the curve can be a curve designed by using a minimum curvature technique, so that problems are less likely to occur during drilling, completion, etc. As an example, the system can utilize a specified target, which can be connected by one or more curves to keep the combined sequence connected. Regarding the output of the system, it is expected that the pad trajectory can minimize the risk of collision and optimize drilling performance under given conditions.

[0115] Regarding inclination, it can be defined as the deviation from vertical, independent of compass direction, expressed in degrees. Inclination can be measured first using a pendulum mechanism and then confirmed using an MWD accelerometer or gyroscope. For most vertical wellbores, inclination may be the only measurement of the wellbore path. For intentionally deviated wellbores or wells close to legal boundaries, directional information can be measured.

[0116] With respect to azimuth, it can be defined as the compass direction of a directional survey or the compass direction of a wellbore planned and / or measured by a directional survey. Azimuth is usually specified in degrees relative to geographic or magnetic North.

[0117] In one embodiment, to evaluate the results and aid the user in making decisions, the system may implement one or more performance indicators (e.g., key performance indicators (KPIs)) that may be output via an estimation table. As an example, an estimation table of KPIs may be generated for an output set of pad trajectories, containing geometric information as well as collision avoidance, torque and drag (T&D), and other factors. As an example, the system may be used to compare trajectories and, for example, adjust pad levels. This approach may reduce the need for one-by-one iterations. Once a pad trajectory is determined, the system may include functionality for fine-tuning a single wellbore trajectory.

[0118] As an example, a system can define multiple trajectories that are drillable and satisfy constraints, such as, for example, one or more collision avoidance constraints. Such a system can generate trajectories that can be visualized and evaluated. The method can use pre-trained models from historical data to recommend initial design patterns and parameters. The layout and geometry of the well trajectory of the pad can be optimized to balance the need to maximize trajectory separation with other drilling issues.

[0119] As an example, the system can handle complex trajectory design that requires designing multiple trajectories. Such a system can improve efficiency and reduce the need for manpower when the workflow requires designing multiple trajectories that are clustered in a relatively small area of ​​an oil field.

[0120] Figure 5 An example of a system 500 is shown, the system including one or more input blocks 510, an analysis input block 515, one or more output blocks 520, an interaction block 525, a pad sketcher component 530, a pad template component 540, an optimizer component 550, and an evaluator component 560 (e.g., optionally as a ranker for ranking). As shown, the pad template component 540 and the optimizer component 550 can be operably coupled to the pad sketcher component 530. In this method, the pad sketcher component 530 can generate a pad design, which can be evaluated by the evaluator component 560, which can, for example, provide an output that can be used in the output block 520, optionally performing various interactions in accordance with the interaction block 525.

[0121] As an example, a pad sketcher component may be provided to generate a trajectory based on given inputs and background data. In such an example, the pad sketcher component may use inputs including ground position, target, and positioning. As an example, additional data may be provided that describes detailed settings regarding the trajectory to be designed and one or more compensation wells to be considered, including, for example: which trajectory profile is desired, such as a J-nudge single curve landing or other detailed settings; and whether there are existing compensation wells or final designs that need to be considered for collision avoidance. The pad sketcher component may generate a trajectory on the pad, which may be evaluated by one or more other components.

[0122] As an example, a pad template component can define and / or generate a pad trajectory template and one or more techniques to implement the trajectory and recommend an appropriate template based on the compensation well analysis of the new pad. As an example, the pad template component can be driven by one or more machine learning models (one or more ML models). As explained, the trained ML model can receive input and generate output, which can be a template or, for example, a selected template. For example, considering a trained ML model, the ML model can determine which template is the best template for a specific design problem. In such examples, the trained ML model can utilize data from compensation wells that have been designed and drilled and optionally completed and put into operation. The compensation well can provide optional data (e.g., provided directly by the user, accessed from one or more databases, etc.), and can also provide suggestions as appropriate to recommend pad template configurations. As an example, a template can be selected via interaction with a graphical user interface (GUI), which can provide multiple templates, which are optionally ranked based on an algorithmic technique that receives at least some input information about a multi-well pad.

[0123] As an example, the evaluator component can evaluate the trajectory output by the pad sketcher component, for example, against one or more specified KPIs and / or one or more other criteria. As an example, the KPIs can include, but are not limited to, whether the target is hit, geometric indicators (e.g., directional drilling indicators (DDI), along the wellbore displacement (AHD), large displacement extension ratio (ERR)), collision avoidance indicators (e.g., separation factors, minimum allowable separation from the new design in the pad, the final design defined from other sources and existing wells, etc.), torque and drag performance (T&D, final value and / or one or more sections along the trajectory), hydraulic verification, well stability, whether the danger zone can be avoided, etc.

[0124] As an example, the optimizer component can adjust one or more trajectory parameters to optimize one or more KPIs under given constraints through single-objective optimization (which can reflect the combined effects of desired KPIs) or multi-objective optimization, for example, to generate a Pareto surface or Pareto frontier and provide several candidate solutions.

[0125] As explained, the system can operate automatically or semi-automatically so that human intervention and / or interaction can be performed. As an example, the system can be used for human-computer interaction to set the trajectory preferences in more detail through optional input data. An example implementation of human intervention of the trajectory can be that one or more of the nudge tilt and nudge azimuth can be defined through batch and / or individual manual adjustments, and the nudge tilt and nudge azimuth can be used for initial draft pad trajectory design and / or adjusted after the draft pad trajectory is generated and when one or more users want to make some refinements to the trajectory.

[0126] As an example, a pad sketcher component can be implemented to perform a portion of a workflow that generates a pad trajectory based on one or more existing pad templates. The pad sketcher component can use basic inputs of pad information, including the surface location of each well; target points; dogleg severity (DLS or dls) of the nudge increase segment, nudge drop segment, and nudge increase segment. As an example, the target allocation of wells can be predefined using user input and / or calculated by the system, for example, based on the surface location and the geometric characteristics of the target. As an example, optional inputs can include detailed trajectory geometry parameter settings and / or parameter range settings. As an example, trajectory optional geometry parameters can include, but are not limited to, nudge inclination, nudge azimuth, nudge start point, etc. Such parameters can be used to generate points for connecting trajectories.

[0127] As mentioned, the system can include a variety of techniques for handling trajectory generation. For example, consider a technique that can be associated with a scenario, which can be referred to as a case (e.g., case 1, case 2, etc.), which can be appropriately selected and executed to design one or more points of one or more trajectories.

[0128] As an example, a candidate technique may operate based in part on the assignment of a surface location and one or more targets to each well. For example, consider one or more techniques that may be configured to: connect surface locations and one or more targets using straight line segments and minimize the total length of the connecting line lengths (e.g., iteratively, line by line, on line segments, etc.); and fit target points using parallel straight lines, where the number of lines is equal to the number of bottom surface locations, to minimize the total displacement of the targets relative to the parallel straight lines, and assign each line to a surface location to minimize overlap or collision of trajectories.

[0129] Figure 6 An example of a pad sketcher system 600 is shown, which includes an input block 631, a preprocessor component 632, a constraint block 633, a pad constraint component 634, a preference block 635, and a generator component 636, which can be a type of computational solver that can generate outputs, such as indicated in output block 638. Figure 6 As shown in the example, output block 638 may include output of the trajectory on the pad in terms of background and geometry, where the background may include information such as ground location, target point, lease line, etc., and where the geometry may include geometric information for each well (e.g., well 1, well 2, well 3, etc.).

[0130] exist Figure 6In the example of , input block 631 can provide information such as ground position and optional data, lease line information, and target information. Regarding pre-processor component 632, it can be used for the assignment of target points; one or more optimizations; suggestions on azimuth, templates, where to use single curves, complex curves (e.g., multiple curves), and the like. As an example, the pad sketcher system 600 can include different operating modes. For example, consider a mode in which the pre-processor component 632 is bypassed so that the input from input block 631 is directed to the pad constraint component 634. Regarding constraint component 634, it can be used to implement well constraints (e.g., ground position, target, target line) and dogleg severity (DLS or dls). Regarding preference block 635, it can provide preferences that can be used by generator component 636, such as J-nudge, S-nudge, 2D, 3D, single, multiple, etc., which can implement one or more techniques, optionally in a scenario or case-based manner.

[0131] Below, an example of code for the Pad Sketcher constraint method is provided.

[0132] public class PadSketchConstraint

[0133] {

[0134] public string CoordinateSystemName{get;set;}."Default";

[0135] public string PadName{get;set;}."Default";

[0136] public string Comment{get;set;}."";

[0137] public double Latitude{get;set;}=double.NaN;

[0138] public double Longtitude{get;set;}=double.NaN;

[0139] public double MinimumStartMD{get;set;}=0;

[0140] public List <padwellconstraint>WellConstraints=new List <padwellconstraint>();

[0141] public double DefaultBuildDls{get; private set;}=double.Na N;

[0142] public double DefaultNudgeBuildDls{get; private set;}=double.NaN;

[0143] public double DefaultNudgeDropDls{get; private set;}=double.NaN;

[0144] }

[0145] Hereinafter, an example of code for a pad well constraint method is provided, which is called by the aforementioned example code.

[0146] public class PadWellConstraint

[0147] {

[0148] public string WellName{get;set;}

[0149] public double NudgeBuildDls=double.NaN;

[0150] private double nudgeDropDls=double.NaN;

[0151] public double BuildDls=double.NaN;

[0152] public double NudgeKOPLimit{get; set;} = 300; / / If you want the KOP to be at a precise position, take special treatment.

[0153] public Station Tieln;

[0154] public double SurfaceLocationNS{get=>TieIn.NS; set=>TieIn.NS=value;}

[0155] public double SurfaceLocationEW{get=>TieIn.EW; set=>TieIn.EW=value;}

[0156] public double StartTVD{get=>TieIn.TVD; set=>TieIn.TVD=value;}

[0157] internal DO_Line TargetWithDirection{get;set;}

[0158] Internal List<DO_Point> TargetPoints{get;private set;}=new List<DO_Point> ();

[0159] public double NudgeDropDls{get=>double.IsNaN(nudgeDrop Dls)?

[0160] NudgeBuildDls:

[0161] nudgeDropDls; set=>nudgeDropDls=value;}

[0162] public double TargetDls{get;internal set;}=MathLib.DEG_TO_RAD(2) / 30.48;

[0163] Below, an example of code for the preference method is provided.

[0164] public class PadSketchPreferenceDTO

[0165] {

[0166] public string Shape{get; protected set;}

[0167] public List <string>Labels{get;set;}new List <string>();

[0168] public string Name{get;set;

[0169] public eAlignTo AlignTo{get;set;}

[0170] public ConvexLeaseLine leaseLine{get;set;}

[0171] public PlaneDTO AlignToPlane{get;set;}

[0172] public eKickOff KickOffDistribution{get;set;}

[0173] public eBackToVertical BackToVerticalDistribution{get;set;}

[0174] public NudgeDistributionDTO NudgeDistributionRange{get;set;}

[0175] }

[0176] Below, an example of code for nudging the distribution preference method is provided.

[0177] public class NudgeDistributionDTO

[0178] {

[0179] public double NudgeStartMDRangeMin{get;set;}

[0180] public double NudgeStartMDRangeMax{get;set;}

[0181] public double InclinationRangeMin{get;set;}

[0182] public double InclinationRangeMax{get;set;}

[0183] public double AzimuthRangeMin{get;set;}

[0184] public double AzimuthRangeMax{get;set;}

[0185] }

[0186] With respect to nudges as part of a trajectory, as an example, the system can provide S nudges using inclination, TVD, and KOP / KOP range, J nudges using KOP / KOP range, and / or for nudges to, toward, and / or away from a plane, perpendicular to a target line, lease line, reference, and the like. As an example, nudges can be part of a collision avoidance method that provides various collision avoidance guarantees for trajectories in a multi-well pad. As explained, nudges can be introduced in accordance with one or more constraints. As explained, a control point-based geometric method can be quickly implemented to generate a trajectory for a multi-well pad, where nudges can be introduced using control points and / or points on the trajectory (e.g., a curve start or end, a landing point, a launch point, etc.).

[0187] As explained, the template can provide an initial layout of the trajectory, optionally with specifications, etc. As an example, a template database and / or a customizable template can be used to select a template. As an example, a trained ML model can provide template selection and / or template generation (e.g., customization, etc.) based on the input of a project (e.g., a multi-well pad). As an example, the input can include slots and targets, where the template can use such inputs to generate a trajectory, which can be visualized, for example, via a slot map, a target map, annotations and / or colors of the drawn slots / targets, compensation wells, options for displaying / not displaying well names, tooltip hover features, and a track with a mark at a specific site (e.g., a point on the trajectory). As an example, a site can be a point on the trajectory, which can correspond to a curve start point, a curve end point, or another point. For a plan, a site can be a point where a survey will be conducted during drilling, and the survey can utilize one or more types of tools (e.g., MWD, seismic, etc.). As an example, an output plan can include instructions associated with sites that can be used to conduct one or more downhole surveys during drilling. For example, consider a digital plan that can be loaded into a drilling framework, where instructions in the digital plan cause the equipment to perform one or more actions, including drilling actions, surveying actions, and the like.

[0188] Figure 7 An example of a method 700 is shown, which may be performed by, for example, Figure 6 A system implementation of the block sketcher system 600 (e.g., or the block sketcher component 530 of the system 500). Figure 7 In an example of the method 700, a method 700 is used to generate a trajectory. As shown, the method 700 includes a start / restart block 710, a setting block 712 for setting a default nudge range parameter, a decision block 714 for determining whether the pad has a high collision risk (e.g., using one or more collision criteria), an adjustment block 716 for adjusting the landing method (e.g., to reduce the collision risk), an update nudge block 718 for updating nudge start point (nudge KOP) candidates, a use block 720 for using nudge KOP based on background and selected templates, an update block 722 for updating the increase in inclination start point (increase in inclination KOP) candidates, a use block 724 for using the newly added inclination start point, an update block 726 for updating the return to vertical point candidates, a use block 728 for using the new return to vertical point candidates, and an attempt block 730 for attempting to calculate the trajectory of the well in the pad.

[0189] As shown, method 700 includes a series of decision blocks 732, 734, 736 and 738, which can cause method 700 to loop back to one or more of blocks 720, 724 and 728. Specifically, decision block 732 determines whether attempt block 730 has successfully calculated the trajectory, where, if so, method 700 can proceed to output block 750 to output the trajectory. However, if decision block 732 determines that attempt block 730 is unsuccessful, method 700 can proceed to decision block 734, which determines whether to determine one or more new return vertical candidates. As shown, decision block 736 is about one or more newly added oblique KOP candidates, and decision block 738 is about one or more new micro-shift KOP candidates. Decision block 734 may continue at use block 728 and / or update block 726, decision block 736 may continue at use block 724 and / or update block 722, and decision block 738 may continue at use block 720 and / or update block 718. In this approach, method 700 may utilize nudge starts, ramp starts, and return vertical point candidates to generate a trajectory that may be evaluated to determine if it is a successful trajectory.

[0190] like Figure 7 As shown in the example of , the trajectory may be successful and output in accordance with output block 750, or it may be unsuccessful for the wells in the multi-well pad, for example, as indicated by the no branch of decision block 738 (e.g., note that one or more decision points may result in an indication of unsuccessfulness). In such examples, method 700 may return to start block 710 to restart, where, for example, in accordance with cause block 740, one or more reasons for unsuccessfulness (e.g., failure) may be determined, and in accordance with adjustment block 744, one or more adjustments may be determined to restart. For example, consider a geometric constraint violated by an unsuccessful trajectory. In such examples, a geometric nudge tilt constraint may be limited to 30 degrees, where the trajectory may require at most 34 degrees. Upon restarting, method 700 may calculate trajectories for one or more previous wells for wells other than the first well. For example, consider an unsuccessful trajectory of a third well of a multi-well pad, where the adjustment block 744 may indicate that the nudge inclination and / or one or more other aspects of the trajectory of an adjacent second well of the multi-well pad are to be adjusted, and / or the nudge inclination and / or one or more other aspects of the trajectory of a first well of the multi-well pad are to be adjusted. In this method, trajectories may be automatically generated for wells in a multi-well pad in an automated manner or, for example, through a certain amount of user interaction (e.g., checking the cause of the unsuccessful, checking the recommended adjustments, making adjustments, etc.). As explained, the control point based trajectory generation method may speed up the generation of trajectories for a multi-well pad.

[0191] Figure 8 An example diagram 800 of three well trajectories extending from a surface location to a target or target line is shown. As an example, a system including a pad sketcher feature can be used to generate Figure 8 As an example, the pad sketcher component can implement the minimum curvature technique. For example, consider using minimum curvature to design each track based on "key points" (control points), which may not be absolutely located on the track, but have a decisive influence on the shape of the track. In one embodiment, the key points include two types of key points, connection points and curve starting points. In such examples, the connection points may not be on the track, while the latter, i.e., the curve starting point, will be on the track. As an example, the connection points can be points that are not on the track and are used to determine the curve, which includes the curve starting point on the track and the curve end point on the track. As an example, the connection points can be marked as "O", while other types of control points can be marked as "P" (e.g., P1 or P2). Regarding the curve starting point, it can be marked as "A", and the curve end point can be marked as "B". In various examples, the control points can be marked as O, P, A or B as appropriate (e.g., according to the case type, etc.) for a part of the track being designed. As an example, the position of the control point can be specified, or the position of the control point can be calculated. As an example, it may be assumed that known inputs for a well include surface location, target line, additional targets, dogleg severity value, nudge-to position reference, and nudge-initiate measured depth (MD).

[0192] As an example, a method may include extending to the target line in a backward direction to intersect the nudge position reference to define the nudge position. This method may optionally be skipped by giving a fixed nudge position. Figure 8 In Figure 800, the position to which the nudge is moved is shown as H and is set as a connection point (e.g., a type of control point that is not on the trajectory). In such examples, the method may include defining a nudge KOP based on a ground position and a nudge start depth (e.g., a measured depth (MD)) and setting a curve start nudge KOP here and calculating its position as a control point. In such examples, the method may include using a straight line to connect the various points together (e.g., a ground position as a connection type, a nudge KOP as a curve start type, a point H as a connection type, and all targets as a curve start type) to calculate the slope increase start as a control point. In such examples, the method may include calculating one or more stations on the trajectory, for example, based on a minimum curvature technique, including measured depth (MD), inclination (incl), azimuth (azi), and dogleg severity (DLS or dls).

[0193] exist Figure 8 In FIG. 1 , various example procedures are listed, which can be defined by a pad template, for example. As shown in the figure, the procedure can include a series of procedures, such as calculating key points H, calculating micro-shift KOP, calculating slope KOP, and calculating each station.

[0194] Fig. 9 An example of technique 900 is shown, referred to as Case 1, and Fig.10 An example of technique 1000 is shown, referred to as Case 2. Example techniques 900 and 1000 may be implemented by a pad sketcher component and / or system. As mentioned, one technique may employ curve minimization.

[0195] like Fig. 9 and Fig.10 As shown, one or more of the techniques 900 and 1000 can be used as a control point technique to connect point O and the curve start point A. For example, considering the input of the previous, current, and subsequent point positions, the design station on the trajectory can be set as the start and end point of the filter curve between two adjacent straight line segments. In such examples, moving the control point can result in a relatively intuitive change in the shape of the trajectory. This approach can achieve an effective optimization method for multi-trajectory design (for example, considering Figure 7 Method 700).

[0196] exist Fig. 9 In the example technique 900 (referred to as Case 1), the and Two adjacent straight line segments, the straight line segment is a vector. These two segments can provide a basis for calculating the curve. As shown in the figure, the segment can be defined as a unit vector originating from point O and pointing to point P1, and segment can be defined as a unit vector originating from point O and pointing to point P2. As indicated, a method can include assuming that the positions of points O, P1, and P2 are known in NEV coordinates (e.g., north, east, and vertical) and that the DLS (dls) is known (e.g., optionally specified based on one or more equipment capabilities, formation characteristics, etc.). In such examples, a curve between points A and B can be determined, where the measured depth (MD), inclination, and azimuth of points A and B can be determined. Thus, technique 900 can be used to connect points of a minimum curvature portion of a trajectory. In example technique 900, points O, P1, and P2 can be geometric points (e.g., control points) used to determine one or more points on a trajectory (e.g., partially define a trajectory), where points O, P1, and P2 are not necessarily limited to being on the trajectory (e.g., one or more of points O, P1, and P2 may be a certain distance from the trajectory being designed). As explained, in the event that the trajectory does not meet one or more criteria, an iterative approach can be employed, which may involve adjusting one or more control points (e.g., see Figure 7 Method 700). This method can be part of a multi-well pad design framework that can generate trajectories for multi-well pads with collision avoidance guarantees and / or one or more drilling-related guarantees (e.g., HKLD, STOR, stuck pipe risk, wellbore integrity, etc.).

[0197] exist Fig.10 In the example technique 1000 (referred to as Case 2), two adjacent straight line segments are also shown, however, in Case 2, it is assumed that the positions of A (the start of the curve), P1, and P2 are known in NEV coordinates, and DLS (dls) is also known. In such an example, the position of point O (the connection point) can be determined, and therefore the position of point B. Therefore, the technique 1000 can be used to connect the points of the minimum curvature portion of the trajectory using the specified control points.

[0198] exist Fig. 9 and Fig.10 In the example of , points A and B are on the trajectory, while points O, P1, and P2 are geometric and not necessarily on the trajectory. With respect to technique 1000 (Case 2), it can include specifying where the curve begins (e.g., the curve starting point), which is shown as point A, and point B is determined as the point where the curve ends (e.g., the curve end point). Although the minimum curvature method can be implemented, one or more other methods can also be used. In various examples, the task can be to find one or more control points to control the trajectory, where the control points are not necessarily on the trajectory. In this method, the control points can be determined to quickly generate the trajectory.

[0199] As an example, one or more techniques may employ one or more types of continuity, which may be used as one or more continuity constraints. For example, consider G0 geometric continuity, where two curve segments are connected together; G1 geometric continuity, where the directions of the tangent vectors of the two segments are equal at the connection point; C0 continuity, where the curves share the same connection point; C1 connectivity, where the magnitude and direction of the tangent vectors of the two segments are equal (share the same parametric derivatives); and C2 continuity, where the curves share the same parametric second derivatives at the connection. As an example, a technique may employ one or more of interpolation and approximation.

[0200] Although the minimum curvature is taken as an example, one or more other techniques may also be used. For example, consider the balanced tangent technique, the average angle technique, the radius of curvature technique, the mercury technique (e.g., the improved balanced tangent technique), etc. As an example, a technique designed to generate a smooth curve may be used. As an example, the Hermite cubic technique may be used, in which the curve is defined by its two endpoints and the tangent vector at the endpoint. The endpoints of a set of Hermite curves may have the same value and the tangent vectors may have the same direction, but the magnitude of one of the tangent vectors is different, while the magnitude of the other tangent vector may remain fixed. Similar to the radius of curvature technique, the minimum curvature technique uses space vectors defined by the inclination and direction measurement results and smoothes these space vectors onto the trajectory curve using a ratio factor, which may be defined by the curvature (dogleg) of the trajectory segment. The minimum curvature technique may produce circular arcs, just like the radius of curvature technique. However, this is not a hypothesis of the technique, but a result of minimizing the total curvature within the physical constraints of the trajectory segment. The minimum curvature technique is a computational technique implemented using a processor and instructions stored in a memory that are executable by the processor (e.g., considering a pad sketcher component implementation). As an example, a curve can be curved in multiple dimensions (e.g., horizontal and / or vertical planes). As an example, a curve can be defined using depth changes, northing changes, and easting changes in NEV coordinates.

[0201] As explained, by using control points, appropriate, constraint-based, safe nudge directions can be determined. For example, consider a method that can include moving one or more control points so that results can be generated more efficiently than moving one or more points that are directly on (e.g., a portion of) a trajectory. For example, consider a method that involves moving a control point a desired distance (e.g., one meter, ten meters, etc.) in a particular direction (e.g., depth, east, north, etc.) so that a trajectory can be quickly generated in a manner that takes into account various constraints. For a user, this method may be more intuitive than attempting to reshape the trajectory by adjusting various points directly on the trajectory.

[0202] As an example, a method may include generating a trajectory of a well in a pad, wherein the method involves using control points. In such an example, inclination and azimuth may be spatially constrained in one or more regions, while some flexibility is built in to quickly construct multiple trajectories that satisfy various constraints (which may include collision avoidance constraints).

[0203] Reference again Figure 8 800, each point can be associated with a scene (such as, for example, Fig. 9 Case 1 or Fig.10 Case 2) is related. In Figure 800, the various points are not necessarily located on one or more trajectories. For example, point H is shown as a point that is not on the trajectory. As an example, point H can be a control point (e.g., a geometric point) that helps determine one or more points on the trajectory. As an example, point H can correspond to a lease line that can intersect with the target line, such as, for example, a rear boundary lease line. In Figure 800, each trajectory can be defined by multiple curves, such as, for example, a curve associated with the KOP and a curve associated with the increased slope section. As shown, the trajectories are substantially vertical, then bend backward, and then they continue to travel in a straight line until they reach their respective increased slope sections. After the increased slope section, each trajectory continues to extend along the target line. As explained, through the control point method, each trajectory can be generated relatively quickly while satisfying various constraints, which may include anti-collision constraints.

[0204] As an example, one can implement Fig. 9 Example 1 of the technique 900 to determine an increased slope KOP, such as, for example, Figure 8 As explained, one or more geometric constraints (such as lease lines and target lines) may be used to define control points (e.g., key points), where the control points may be located at the intersection of the geometric constraints. For example, consider point H in diagram 800 as Fig. 9 Example 1 of technique 900 of point O, where the upper hollow circle is P1 (e.g., close to the nudge KOP), and where another hollow circle that may be on the target line is P2. In this method, the solid circles can be circles A and B, which are on the trajectory and define a curve start and a curve end, where the curve between the curve start and the curve end conforms to one or more DLS (dls) related constraints.

[0205] As an example, one can implement Fig.10 Example 2 of the technique 1000 to determine a micro shift KOP, such as, for example, Figure 8 One or more micro-shift KOPs shown in FIG800. In such examples, a depth may be given as an input for the micro-shift KOP, which may optionally act as a constraint. Fig.10 , the depth of the nudged KOP can correspond to point A as the starting point of the curve, which has an assumed known position, and where the ground position can be point P1, and where point H can be point P2, from which the pad sketcher component or system can determine the position of the control point (e.g., point O), and therefore determine point B, as the end point of the curve.

[0206] As explained, the system may include a variety of techniques for determining one or more curved portions of a trajectory in a relatively fast manner by using one or more control points, noting that a trajectory may consist of multiple curves and hold segments (e.g., straight segments). This approach may be helpful in designing a plan for a multi-well pad, particularly where there is a risk of collision and the risk needs to be minimized.

[0207] Fig.11 An example of a technique 1100 is shown in which two curves may be determined, for example, using one or more DLS (dls) constraints and a curvature minimization technique (e.g., for each curve or for both curves). With respect to control points P1 and P2 having known NEV positions, a length-preserving dls1 and dls2 are used as input to implement technique 1100. The direction of P1 is The direction of P2 is The two curves can be determined via corresponding points, wherein a holding section may exist between the two curves. Fig.11 In the example, we can use the curve referenced with respect to control point P1 after the unit vector The technique 1100 is implemented by maintaining the length in the direction of As shown in the figure, the hold length is the length between the end point of the previous curve on the track and the start point of the first curve of the current segment, where the hold length is defined as a straight line segment on the track. Fig.11 In the example of , as shown in the figure, two curves are determined via corresponding points, wherein a straight line segment (holding segment) may exist between the two curves.

[0208] As shown, one curve may have an associated DLS labeled dls1, while another curve may have an associated DLS labeled dls2. As an example, the technique 1100 may be a multi-dimensional technique (e.g., 3D) that includes Inputs of dls1 and dls2. As shown in the figure, there may be two different scenarios, where P1 can be the curve start point (curve start point type) and it may not need The input is either a connection point (connection type) where For calculating the end point of the P1 curve and where the end point can be used as a connection point. As an example, in the case where P1 is the starting point of the curve, the associated vector may not be specified as an input. For example, a technique may include dls1 and dls2 are taken as input, where P1 is the curve starting point (for example, consider moving P1 to the curve starting point of the curve associated with dls1, which can make point P1 similar to point A in Case 2: In such examples, the technology can use the P1 input position as the connection point of the curve immediately following P1. In such examples, the hold length is not used, where there may still be a hold segment between the curves associated with dls1 and dls2.

[0209] As an example, a method may optionally include replanning during field operations such as drilling a well. For example, consider drilling the first well from a multi-well pad where obstructions may be encountered and mapped. In such an example, such as Figure 5 The system 500 can be used to re-plan the trajectory and / or one or more other trajectories in the pad. This method can be implemented in a relatively fast manner, thereby reducing non-productive time (NPT).

[0210] As explained, the template can be a pad template, which can define the initial characteristics of the trajectory profile and how to generate them. In one embodiment, the pad template can be derived from data analysis of existing trajectories (e.g., trajectories within the pad), noting that one or more sources are not limited to pad trajectories or real-world trajectories. As explained, one or more machine learning methods can be implemented to perform trajectory design of the template. As an example, the pad template can be manually extracted using human experience. As an example, the pad template can be summarized using automatic data analysis techniques.

[0211] In one embodiment, the template defines the profile of vertical segments (e.g., nudge segments), ramp segments, landing segments, target segments, etc. As a simple example, a pad template may be: S nudge start at MD1, nudge slope α, return to vertical at true vertical depth TVD1, single curve or curve-curve landing on a first given target.

[0212] As an example, a pad template can embed some domain knowledge to prevent unreasonable trajectories. For example, a pad template can be configured to avoid serpentine trajectory design within a segment or trajectory, check whether two targets belonging to different trajectories are too close to each other, or adjust the template when a collision-free trajectory is not possible for a given input with or without a nearby compensation well or design.

[0213] As an example, a pad template can be used for one or more compensation well analysis techniques, for example, to recommend an appropriate pad template for a new input with or without optional settings. In one embodiment, the input can be a ground position and a target, and there may be no customization as to whether S-nudge or J-nudge will be used, where to start the nudge and / or where to increase the inclination and landing. The pad template can be configured to reasonable default settings based on historical data, such as existing pad patterns near its location, user or customer habits. As an example, the logic can involve the pad template extraction process, design objectives, etc.

[0214] In one embodiment, the evaluator performs a rigorous or simplified engineering analysis to evaluate the output trajectory from multiple aspects. The evaluator can assist engineers or other automated decision systems in making engineering decisions. As an example, the evaluation metric can be the same or different from the optimizer objective. As an example, geometric properties can be used to assist the user in evaluating and, if appropriate, to assist the user in adjusting the trajectory shape. The evaluation metric can include a single trajectory, such as ERD, tortuosity, or multiple trajectories, such as the minimum allowable separation distance for collision avoidance, or be evaluated against other existing wells or external well plans.

[0215] In one embodiment, the estimator is configured to achieve reasonable accuracy under specific user cases. Since trajectory design can be the first step during the entire well planning process, the detailed calculation settings of some evaluation indicators may not be ready yet. For example, when evaluating torque and resistance indicators in the early stage, BHA information may be unknown. In such cases, a default BHA design (predefined or recommended using some intelligent algorithm based on offset wells or historical data analysis) can be used for rough evaluation or simply omitted from the evaluation.

[0216] Fig.12 An example of an output visualization 1200 is shown, in which the trajectories of three wells are shown in a 3D space with coordinates, and a table is also shown, the table including various information, which may include KPIs generated by the system as part of the multi-well pad trajectory generation. In the table, the name of each well is listed as well as various geometric information and drilling related information. Regarding drilling related information, it includes, for example, hook load (HKLD) and surface torque (STOR), which can be calculated for one or more locations on the trajectory and used during drilling. As explained, such information can be used during actual drilling to make one or more decisions about whether to continue, whether the risk is increased or reduced, whether to re-plan one or more trajectories, etc. As an example, the visualization 1200 can be a graphical user interface (GUI) that allows user interaction, and the user interaction can include making one or more adjustments to one or more trajectories, which can automatically trigger a return to the pad sketcher component.

[0217] As an example, the optimizer can adjust editable parameters of different pad templates with the goal of achieving an "optimal" solution given the inputs and constraints. Using the example discussed above with respect to pad templates, consider an S nudge start at MD1, a nudge tilt of α, a return to vertical at a true vertical depth of TVD1, a single curve or curve-to-curve (CC) landing on a first given target. In such examples, the values ​​of MD1, TVD1, α, single curve or curve-to-curve (CC) can be editable parameters. In such examples, changing these parameters will result in different KPIs (e.g., see Fig.12 The optimization result can be achieved by one or more optimization techniques (e.g., domain-specific optimization, multi-objective particle swarm optimization (MOPSO), multi-objective genetic algorithm (MOGA), non-dominated sorting genetic algorithm (NSGA(-II)), etc.).

[0218] As an example, in some cases, optimization objectives and constraints can be transformed into each other. For example, the collision avoidance index separation factor can be a goal to be maximized or treated as a constraint to be no less than a specific value. As an example, one or more KPIs and constraints can be predefined and / or configured for each use case.

[0219] As an example, the system may provide one or more instances and / or one or more types of manual intervention. For example, by using one or more GUIs, a user may intervene at one or more different points within or outside the automated pad trajectory design workflow.

[0220] Fig.13 The example of GUI 1300 that can be used for user interaction is shown.For example, consider the workflow of the system that can be run in automation mode and / or semi-automation mode.In such examples, GUI 1300 can be presented to display so that the user can view, edit, input etc. to the information of well, and for multi-well pads, this can be carried out well by well.As shown in the figure, GUI 1300 includes the information of slot layout, including pad center position, row, row spacing, column, column spacing and rotation.As shown in the figure, GUI 1300 can include target information, including one or more targets and / or one or more target lines.As an example, advanced setting options and control graphics may be available to cause the system to generate pads with tracks.In such examples, once control graphics are started, the workflow can continue to complete, optionally presenting one or more GUIs that can be used for additional interaction.

[0221] Fig.14 An example of a method 1400 is shown, which includes a definition block 1410 for defining a well, a nudge pattern block 1420 for defining a nudge pattern, and a generation block 1430 for generating an output. Fig.14 In the example of , method 1400 can be run in a semi-automated mode of the system. For example, in the semi-automated mode, a user can enter information about slots, targets, lease lines, etc. and / or enter information for individual wells. As shown, one option can be referred to as a slot and target method, while another option can be referred to as a define each well method. With respect to the nudge mode block 1420, a GUI can be presented to a display, allowing nudge related information to be viewed, edited, input, etc., and the nudge related information can include nudge increase DLS, nudge decrease DLS, nudge increase DLS, etc. As shown, various nudge preferences for multi-well pads can be specified, including, for example, J nudge, S nudge, and / or J and S nudges, as well as a start option, return to vertical position, nudge TVD distance, and one or more alignment options. With respect to the output of the generate block 1430, it can include presenting a GUI to visualize the information, for example, such as information about Fig.12 The visualization 1200 illustrates that the information may include spatial information as well as tabular information that may be relevant to optimization (eg, KPI optimization, etc.).

[0222] In one embodiment, within the workflow, manual intervention can be achieved through optional input data. If the user does not have the information to provide the optional data, the pad trajectory design workflow can define the optional data based on a combination or analysis of the input data, data analysis from a database, or a more detailed compensation well analysis using internal logic. However, if the user has enough information, the user can set more details to generate the trajectory. As an example, intervention may occur after a first draft with mandatory inputs is generated, where the output KPI from the evaluator provides the user with enough data to adjust the optional data and thus refine the trajectory based on the output within the pad trajectory design workflow.

[0223] As an example, the system can interact with one or more other applications, frameworks, systems, etc. to adjust trajectory geometry. For example, the output trajectory can be converted to a specific format or data structure so that it can be modified using other applications. As an example, the output of the system can be introduced into a simulator, which can be a drilling simulator, a wellbore geomechanics simulator, a reservoir simulator, a stimulation simulator, etc. In such examples, one or more of the multiple trajectories from the pad sketcher system can be rigorously analyzed so that feedback can be generated, which can be implemented in another round of trajectory generation, for example, to refine one or more trajectories to meet certain goals, optimize production, minimize NPT, etc. As an example, consider a reservoir simulation where the oil leakage of the reservoir may be lower than expected, so that the target spacing can be adjusted to increase the production of a group of wells from a common pad. As another example, consider a drilling simulator that shows that one BHA can perform drilling more efficiently than another BHA, however, the DLS criteria of the two BHAs may be different. In such an example, the pad sketcher system may be executed to generate a trajectory for a more efficient BHA, where the results from both may be evaluated (eg, using KPIs, additional simulations, etc.) to arrive at a final plan.

[0224] As an example, in addition to various types of information manually entered and calculated within the pad trajectory design workflow, optional input data may also come from one or more other sources, such as from an input suggestion service, to define a very detailed setup for the entire pad and / or each well.

[0225] As one example, pad trajectory design may be integrated with one or more other applications, such as, for example, single trajectory design, well-while-drilling replanning, and even formation interpretation.

[0226] As an example, pad trajectory design can be integrated with one or more single trajectory design workflows. As an example, consider a method that converts output trajectories from pad design into trajectory design inputs and uses a trajectory design tool to generate a set of trajectory candidates within a range, where one or more users can explore solutions and select the best solution based on their engineering constraints and experience.

[0227] As an example, pad trajectory design can be integrated into one or more while drilling processes to monitor one or more drilling trajectories and assist in one or more re-planning processes, for example, when deviations from the plan are too great (e.g., based on one or more criteria). As an example, pad trajectory design can be integrated into a stratigraphic interpretation framework, for example, to combine a geological target definition process with a pad trajectory design process. In such examples, lithology information can be utilized, which can come from one or more pilot wells, offset wells, seismic survey analysis, etc. In this approach, drilling mechanics can be considered, for example, to reduce drilling distances in one or more materials, etc., which can speed up drilling, improve wellbore integrity, etc.

[0228] Fig.15 An example of a method 1500 and an example of a system 1590 are shown. As shown, the method 1500 may include: a receiving block 1510 for receiving input regarding a multi-well pad; a selecting block 1520 for selecting a template for the multi-well pad based at least in part on a portion of the input; a generating block 1530 for generating well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, the geometric control points not necessarily being located on one or more of the well trajectories; and an outputting block 1540 for outputting specifications of the generated trajectories for the multi-well pad.

[0229] Fig.15 Various computer readable media (CRM) blocks 1511, 1521, 1531, and 1541 are also shown. Such blocks may include instructions that can be executed by one or more processors, which may be one or more processors of a computing framework, system, computer, etc. A computer readable medium may be a non-signal, non-carrier, and non-transitory computer readable storage medium. For example, a computer readable medium may be a physical memory component that can store information in a digital format.

[0230] exist Fig.15 In the example of , system 1590 includes one or more information storage devices 1591, one or more computers 1592, one or more networks 1595, and instructions 1596. With respect to the one or more computers 1592, each computer may include one or more processors (e.g., or processing cores) 1593 and a memory 1594 for storing instructions 1596, which instructions may be executed, for example, by at least one of the one or more processors. As an example, a computer may include one or more network interfaces (e.g., wired or wireless), one or more graphics cards, a display interface (e.g., wired or wireless), etc. System 1590 may be specifically configured to perform Fig.15 One or more portions of method 1500.

[0231] As an example, a computing framework may include a solver that may be implemented via executable instructions. For example, consider a computing framework that includes a processor and a memory accessible to the processor, wherein executable instructions may be stored in the memory and accessible to the processor for execution, thereby causing the computing framework to perform one or more actions. Such a computing framework may include one or more interfaces for receiving information and / or for outputting information, which may include parameter values, instructions, etc. As an example, a computing framework may be part of a controller. As an example, a computing framework may be part of a system.

[0232] As an example, various systems, methods, etc. may implement one or more ML models. Regarding the type of ML model, consider one or more of a support vector machine (SVM) model, a k-nearest neighbor (KNN) model, an ensemble classifier model, a neural network (NN) model, etc. As an example, the machine learning model may be a deep learning model (e.g., a deep Boltzmann machine, a deep belief network, a convolutional neural network, a stacked autoencoder, etc.), an ensemble model (e.g., a random forest, a gradient boosting machine, a bootstrap ensemble, an adaptive boosting, a stacked generalization, a gradient boosting regression tree, etc.), a neural network model (e.g., a radial basis function network, a perceptron, a back propagation, a Hopfield network, etc.), a regularization model (e.g., a ridge regression, a least absolute shrinkage and selection operator, an elastic net, a least angle regression), a rule system model (e.g., a cubist, a one-rule, a zero-rule, repeated incremental pruning to reduce error), a regression model (e.g., a linear regression, an ordinary least squares regression, a stepwise regression, a multivariate adaptive regression spline, a local scatter smoothing estimate, a logistic regression, etc.), a Bayesian model types (e.g., naive Bayes, average dependency estimator, Bayesian belief network, Gaussian naive Bayes, multinomial naive Bayes, Bayesian network), decision tree models (e.g., classification and regression tree, iterated binary tree 3 generations, C4.5, C5.0, chi-square automatic interaction detection, decision tree stump, conditional decision tree, M5), dimensionality reduction models (e.g., principal component analysis, partial least squares regression, Sammon map, multidimensional scaling, projection pursuit, principal component regression, partial least squares discriminant analysis, mixed discriminant analysis, quadratic discriminant analysis, regularized discriminant analysis, flexible discriminant analysis, linear discriminant analysis, etc.), instance models (e.g., k-nearest neighbor, learning vector quantization, self-organizing map, local weighted learning, etc.), clustering models (e.g., k-means, k-median, expectation maximization, hierarchical clustering, etc.), etc.

[0233] As an example, the system can utilize one or more recurrent neural networks (RNNs). One type of RNN is called a long short-term memory (LSTM), which can be a unit or (e.g., a component of one or more units) that can be located in one or more layers. The LSTM component can be a type of artificial neural network (ANN) designed to recognize patterns in data sequences (such as time series data). When provided with time series data, the LSTM takes into account time and sequence, so that the LSTM can include a time dimension. For example, consider utilizing one or more RNNs to process time data from one or more sources, optionally in combination with spatial data. This approach can identify temporal patterns that can be used to make predictions (e.g., one or more patterns about future times, etc.).

[0234] As an example, the TENSORFLOW framework (Google LLC, Mountain View, California) can be implemented, which is an open source software library for data flow programming, including a symbolic math library that can be implemented for machine learning applications that can include neural networks. As an example, the CAFFE framework can be implemented, which is a DL framework developed by the Berkeley AI Research Center (BAIR) (University of California, Berkeley, California). As another example, consider the SCIKIT platform (e.g., scikit-learn), which utilizes the PYTHON programming language. As an example, a framework such as the APOLLO AI framework can be utilized (APOLLO.AI GmbH, Germany). As mentioned, a framework such as the PYTORCH framework can be utilized.

[0235] As an example, a training method may include various actions that may be performed on a dataset to train an ML model. As an example, a dataset may be divided into training data and test data, where the test data may be used for evaluation. A method may include cross-validation of parameters and optimal parameters, which may be used for model training.

[0236] The TENSORFLOW framework can run on multiple CPUs and GPUs with optional CUDA extensions (NVIDIA Corporation, Santa Clara, California) and SYCL extensions (Khronos Group Ltd., Beaverton, Oregon) for general-purpose computing on graphics processing units (GPUs). TENSORFLOW can be used on 64-bit LINUX, MACOS (Apple Inc., Cupertino, California), WINDOWS (Microsoft Corporation, Redmond, Washington), and mobile computing platforms including Android (Google LLC, Mountain View, California) and iOS (Apple Inc.) operating system-based platforms.

[0237] TENSORFLOW computations can be represented as stateful data flow graphs; it should be noted that the name TENSORFLOW derives from the operations that such neural networks perform on multidimensional arrays of data. Such arrays can be referred to as "tensors".

[0238] As an example, a method may include: receiving input regarding a multi-well pad; selecting a template for the multi-well pad based at least in part on a portion of the input; generating well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, the geometric control points not necessarily being located on one or more of the well trajectories; and outputting specifications for the generated trajectories for the multi-well pad. In such an example, the multi-well pad may include at least three well trajectories. As an example, such trajectories may be generated iteratively, optionally in a serial manner, wherein the success of a trajectory may allow the generation of a neighboring trajectory, wherein such a method may be automatically performed to generate the trajectory for the multi-well pad.

[0239] As an example, at least one curve may be generated using a minimum curvature technique. As an example, at least one curve may be generated using a technique selected from a plurality of different techniques. In such examples, the technique may be automatically selected based at least in part on the known positions of three control points. As an example, the three control points may include an upper point at an upper depth and two lower points below the upper depth. As an example, a technique may be automatically selected based at least in part on the known positions of two control points and a track point. In such examples, a track point may be a starting curve point, and, for example, the two control points may include an upper control point at an upper depth and a lower control point at a lower depth.

[0240] As one example, the plurality of different techniques may include one or more single-curve techniques and one or more multi-curve techniques.

[0241] As an example, one or more dogleg severity values ​​may correspond to one or more bottom hole assemblies.

[0242] As an example, a method may include selecting a template by implementing a trained machine learning model. In such examples, a template may be selected, and / or multiple candidate templates may be generated, whereby a user may select one of the candidate templates (e.g., optionally using a Pareto-type analysis, etc.).

[0243] As an example, a method may include generating, the generating including implementing an optimizer, the optimizer optimizing a well trajectory based on one or more drilling-related physical parameters. For example, one or more drilling-related physical parameters are considered, the physical parameters may include one or more of a torque and drag physical parameter and a formation dogleg severity physical parameter. As an example, drilling a dogleg in a soft material (e.g., a soft formation) may be more difficult than drilling a dogleg in a hard material (e.g., a hard formation). As an example, a transition from one material to another at a certain depth may be used as a basis for specifying one or more constraints, one or more control points, and the like. For example, if a tighter curve is desired, the launch point may be limited to a specific depth corresponding to a specific formation (rock formation), which may be evaluated and characterized relative to one or more other formations (e.g., rock formations).

[0244] As one example, generating may include implementing an evaluator that evaluates the well trajectory based on one or more performance indicators.

[0245] As an example, the generation may include implementing one or more collision avoidance features to reduce the risk of well trajectory collisions during drilling of the well trajectory. As explained, the trajectory may include nudges as part of the trajectory, where the nudges may be used to reduce the risk of collision avoidance. For a multi-well pad, the nudges of the trajectory may be coordinated so that drilling can be performed according to the trajectory without reducing the risk of trajectory-to-trajectory collisions. In such examples, the nudges may be optionally iteratively adjusted until a final plan is generated for the trajectory of the wells of the multi-well pad.

[0246] As an example, a method may include presenting a graphical user interface that includes a visualization of at least one of a plurality of well trajectories and a control point graphical control for adjusting the position of at least one of the one or more control points. In such examples, a user may intervene in a method of trajectory generation for a multi-well pad. For example, consider a method that may indicate a cause of trajectory failure and provide one or more suggestions for adjustment. In such examples, a GUI with one or more suggestions may be presented that may allow a user to select and / or otherwise implement at least one of the one or more suggestions. For example, consider a suggestion to adjust the micro-shift parameters of one or more other wells so that the generation method may be rerun for multiple wells in order to obtain a set of suitable trajectories with appropriate characteristics that satisfy constraints, which may include collision avoidance-related constraints.

[0247] As an example, a method may include receiving information about a multi-well pad, in which one or more wells may have been drilled or partially drilled. In such examples, the known existing portions may be input and used for template selection and / or control point designation, determination, etc. In such examples, one or more trajectories may be generated for one or more portions of the partially drilled wells and / or the wells that have not yet been drilled.

[0248] As an example, a method may include outputting a specification including one or more performance indicators. For example, one or more collision-related performance indicators, one or more drilling-related performance indicators (eg, HKLD, STOR, etc.) may be considered.

[0249] As an example, a system may include: one or more processors; a memory accessible by at least one of the one or more processors; processor executable instructions stored in the memory and executable to instruct the system to: receive input regarding a multi-well pad; select a template for the multi-well pad based at least in part on the input; generate well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, which do not necessarily have to be located on one or more of the well trajectories; and output specifications for the generated trajectory of the multi-well pad.

[0250] As an example, one or more computer-readable storage media may include processor-executable instructions to instruct a computing system to: receive input regarding a multi-well pad; select a template for the multi-well pad based at least in part on a portion of the input; generate well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, which do not necessarily have to be located on one or more of the well trajectories; and output a specification of the generated trajectory for the multi-well pad.

[0251] As an example, a computer program product may include computer-executable instructions to instruct a computing system to perform one or more methods, such as one or more of the methods described herein (eg, partially, fully, and / or in various combinations).

[0252] In some embodiments, one or more methods may be performed by a computing system. Fig.16 An example of a system 1600 is shown, which may include one or more computing systems 1601-1, 1601-2, 1601-3, and 1601-4, which may be operatively coupled via one or more networks 1609, which may include wired and / or wireless networks.

[0253] As an example, a system may include a single computer system or an arrangement of distributed computer systems. Fig.16 In the example, computer system 1601-1 may include one or more modules 1602, which may be or include processor-executable instructions, which may be executable to perform various tasks (e.g., receive information, request information, process information, simulate, output information, etc.).

[0254] As an example, the modules may be executed independently or in conjunction with one or more processors 1604, which are operably coupled to one or more storage media 1606 (e.g., via cables, wirelessly, etc.). As an example, one or more of the one or more processors 1604 may be operably coupled to at least one of the one or more network interfaces 1607. In such examples, the computer system 1601-1 may transmit and / or receive information, for example, via one or more networks 1609 (e.g., consider one or more of the Internet, a private network, a cellular network, a satellite network, etc.). As shown, one or more other components 1608 may be included in the computer system 1601-1.

[0255] As an example, computer system 1601-1 can receive information from and / or transmit information to one or more other devices, which can be or include, for example, one or more of computer systems 1601-2, etc. The device can be located in a different physical location than computer system 1601-1. As an example, the location can be, for example, a processing facility location, a data center location (e.g., a server farm, etc.), a drilling rig location, a well site location, a downhole location, etc.

[0256] As an example, a processor may be or include a microprocessor, a microcontroller, a processor module or subsystem, a programmable integrated circuit, a programmable gate array, or another control or computing device.

[0257] As an example, storage media 1606 may be implemented as one or more computer-readable or machine-readable storage media. As an example, the storage device may be distributed within and / or between multiple internal and / or external enclosures of the computing system and / or additional computing systems.

[0258] As an example, the one or more storage media may include one or more different forms of memory, including: semiconductor memory devices, such as dynamic or static random access memory (DRAM or SRAM), erasable and programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM), and flash memory; magnetic disks, such as fixed disks, floppy disks, and removable disks; other magnetic media, including magnetic tape; optical media, such as compact disks (CDs) or digital video disks (DVDs), Blu-ray disks, or other types of optical storage devices; or other types of storage devices.

[0259] As an example, one or more storage media may be located in the machine running the machine-readable instructions, or located at a remote site from which the machine-readable instructions may be downloaded over a network for execution.

[0260] As one example, various components of a system (such as, for example, a computer system) may be implemented in hardware, software, or a combination of both hardware and software (eg, including firmware), including one or more signal processing circuits and / or application specific integrated circuits.

[0261] As an example, a system may include a processing device, which may be or include a general purpose processor or a dedicated chip (eg, or chipset) such as an ASIC, FPGA, PLD, or other suitable device.

[0262] As an example, the device may be a mobile device including one or more network interfaces for transmitting information. For example, the mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH, satellite, etc.). As an example, the mobile device may include components such as a main processor, a memory, a display, a display graphics circuit (e.g., optionally including a touch and gesture circuit), a SIM slot, an audio / video circuit, a motion processing circuit (e.g., an accelerometer, a gyroscope), a wireless LAN circuit, a smart card circuit, a transmitter circuit, a GPS circuit, and a battery. As an example, the mobile device may be configured as a cellular phone, a tablet computer, etc. As an example, the method may be implemented (e.g., in whole or in part) using a mobile device. As an example, the system may include one or more mobile devices.

[0263] As an example, the system may be a distributed environment, such as a so-called "cloud" environment, in which various devices, components, etc. interact for purposes of data storage, communication, computing, etc. As an example, a device or system may include one or more components for transmitting information via one or more of the Internet (e.g., where communication is performed via one or more Internet protocols), a cellular network, a satellite network, etc. As an example, a method may be implemented in a distributed environment (e.g., in whole or in part as a cloud-based service).

[0264] As an example, information can be input from a display (e.g., consider 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. Regarding printers, consider 2D or 3D printers. As an example, a 3D printer can include one or more substances that can be output to build a 3D object. For example, data can be provided to a 3D printer to build a 3D representation of an underground formation. As an example, layers (e.g., horizons, etc.) can be built in 3D, geological bodies, etc. can be built in 3D. As an example, wellbores, fractures, etc. can be built in 3D (e.g., as positive structures, as negative structures, etc.).

[0265] Although only a few examples have been described in detail above, it should be readily appreciated by those skilled in the art that many modifications may be made in the examples. Therefore, all such modifications are intended to be included within the scope of the present disclosure as defined in the appended claims. In the claims, means-plus-function clauses are intended to cover structures described herein as performing the recited functions, and not only structural equivalents, but also equivalent structures. Thus, while a nail and a screw may not be structural equivalents because a nail employs a cylindrical surface to fasten wooden parts together, while a screw employs a helical surface, in the context of fastening wooden parts, a nail and a screw may be equivalent structures.< / string> < / string> < / padwellconstraint> < / padwellconstraint>

Claims

1. A method, comprising: receiving input regarding a multi-well pad; selecting a template for the multi-well pad based at least in part on a portion of the input; generating well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, the geometric control points not necessarily being located on one or more of the well trajectories; as well as A specification of the generated trajectory for the multi-well pad is output.

2. The method of claim 1, wherein the multi-well pad comprises at least three well trajectories. The method of claim 1 , wherein the at least one curve is generated using a minimum curvature technique. The method of claim 1 , wherein the at least one curve is generated using a technique selected from a plurality of different techniques.

5. The method of claim 4, wherein the technique is automatically selected based at least in part on the known positions of three control points.

6. The method of claim 5, wherein the three control points include an upper point at an upper depth and two lower points below the upper depth.

7. The method of claim 4, wherein the technique is automatically selected based at least in part on known locations of two control points and a trajectory point. The method of claim 6 , wherein the one trajectory point is a starting curve point.

9. The method of claim 8, wherein the two control points include an upper control point at an upper depth and a lower control point at a lower depth.

10. The method of claim 4, wherein the plurality of different techniques comprises one or more single-curve techniques and one or more multi-curve techniques.

11. The method of claim 1 , wherein the one or more dogleg severity values ​​correspond to one or more bottom hole assemblies.

12. The method of claim 1, wherein said selecting said template comprises implementing a trained machine learning model.

13. The method of claim 1, wherein the generating comprises implementing an optimizer that optimizes the well trajectory based on one or more drilling-related physical parameters.

14. The method of claim 13, wherein the one or more drilling-related physical parameters include one or more of a torque and drag physical parameter and a formation dogleg severity physical parameter.

15. The method of claim 1, wherein the generating comprises implementing an evaluator that evaluates the well trajectory based on one or more performance indicators.

16. The method of claim 1, wherein the generating comprises implementing one or more collision avoidance features that reduce the risk of a well trajectory collision occurring during drilling of the well trajectory.

17. The method of claim 1, comprising presenting a graphical user interface including a visualization of at least one of the well trajectories and a control point graphical control for adjusting a position of at least one of the one or more control points.

18. The method of claim 1, wherein the output specification comprises one or more performance indicators.

19. A system, comprising: one or more processors; a memory accessible by at least one of the one or more processors; processor-executable instructions stored in the memory and executable to instruct the system to: receiving input regarding a multi-well pad; selecting a template for the multi-well pad based at least in part on a portion of the input; generating well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, the geometric control points not necessarily being located on one or more of the well trajectories; as well as A specification of the generated trajectory for the multi-well pad is output.

20. One or more computer-readable storage media comprising processor-executable instructions to instruct a computing system to: receiving input regarding a multi-well pad; selecting a template for the multi-well pad based at least in part on a portion of the input; generating well trajectories for the multi-well pad based at least in part on the template, wherein each of the well trajectories extends from a surface location of the multi-well pad to one or more reservoir target locations, and wherein each of the well trajectories includes at least one curve generated using one or more dogleg severity values ​​and one or more geometric control points, the geometric control points not necessarily being located on one or more of the well trajectories; as well as A specification of the generated trajectory for the multi-well pad is output.

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