RU2779040C1 - Borehole planning using a geomechanical shift - Google Patents

Abstract

FIELD: computing technology.

SUBSTANCE: group of inventions relates to a method and a computer system for visualising the trajectory of a borehole. Method includes obtaining geomechanical and geological data for an underground area; obtaining the initial trajectory of the borehole, including the borehole path and reference points, wherein each reference point has one or more intervals of the borehole associated therewith. Analysing the stability of the wellbore along the borehole trajectory using the geomechanical and geological data, wherein the analysis of the stability of the wellbore includes identifying a subset of intervals of the borehole path along the borehole trajectory as at risk of instability. Calculating the geomechanical shift for one or more reference points along the borehole trajectory, wherein the geomechanical shift is calculated as a derivative of the stability of the wellbore at one or more reference points. Modifying one or more reference points and one or more associated intervals of the borehole path using the geomechanical shift to generate a modified borehole trajectory. Visualising the calculated geomechanical shift, modified borehole trajectory, or both in a digital model of the underground area.

EFFECT: minimised risk of rock collapse into the borehole and the risk of loss of drilling mud, and/or reduction in the density of drilling mud for the purpose of improving the productivity of drilling.

18 cl, 9 dwg

Description

Cross-reference to related application

[0001] The present application claims priority from US General Patent Application No. 16/248,943, WELL PLANNING USING GEOMECHANICS NUDGE, filed January 16, 2019, the contents of which are incorporated herein by reference.

BACKGROUND OF THE INVENTION

[0002] During the drilling of wellbores deep into the earth's surface, various types of problems arise. One problem that arises is mechanical failure of the wellbore wall, which can result from the interaction between the surrounding rock formation and the drilling operations. In an attempt to anticipate and eliminate such failures, the mechanical properties of the rock formation can be modeled using a mechanical earth model (MEM), which can allow the simulation and evaluation of the effects of drilling operations, different well plans, etc. on the efficiency and safety of well drilling. The mechanical properties of the rock, as well as drilling/well orientation, drilling fluid pressure and temperature, among others, are factors that govern this interaction and determine the stability of the wellbore. Based on the anisotropy of local stresses in the reservoir and deformation of the rock, as well as strength heterogeneities and anisotropy, there should be a number of trajectories that make well drilling safer and more efficient than drilling in other directions.

[0003] Thus, the analysis of geomechanical data and modeling is an integral part of planning the well path (ie, the trajectory along which the well will be drilled). Such analysis may provide a decision and/or recommendation regarding favorable well orientations and drilling practices based on the integration of geomechanical modeling into the well planning system. Moreover, such an analysis may take into account other engineering well design factors, such as the degree of curvature of the wellbore, which can be combined and included in the model to improve the design of the well.

[0004] This geomechanical modeling for the well design process is typically based on integrated multidisciplinary geoscience modeling experience and big data analytics modeling capabilities. Thus, this process is usually carried out through trial and error by an interdisciplinary team with a wide range of experience. The process typically starts with a well plan ("engineering and survey"), after which the well plan is iteratively replaced with other well plans (modifications of the previous well plan) until the resulting well path is selected. The success and efficiency of the process of determining how to change the well plan depends largely on the experience of the operator and the effective interaction between the well planning system and the geomechanical modeling system.

SUMMARY OF THE INVENTION

A method for planning and drilling a well is disclosed. The method includes obtaining geomechanical and geological data for a subterranean region and obtaining an initial well trajectory, including the well path and control points. Each control point has one or more well path intervals associated with it. The method includes performing a wellbore stability analysis along a well trajectory based in part on geomechanical and geological data. Conducting a wellbore stability analysis includes identifying a subset of the well path intervals along the wellbore trajectory as being at risk of instability. The method includes calculating a geomechanical shift for one or more control points along the well path. The geomechanical shift is calculated as a derivative of the wellbore stability at one or more control points. The method includes modifying one or more control points and one or more well trajectory intervals associated with them based in part on geomechanical shear to generate a modified well trajectory.

[0005] In addition, a computing system is disclosed. The computing system includes one or more processors and a storage system including one or more non-volatile computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to execute operations. The operations include obtaining geomechanical and geological data for the subterranean region and obtaining the initial well trajectory, including the well path and control points. Each control point has one or more well path intervals associated with it. The operations include performing a wellbore stability analysis along the well trajectory based in part on geomechanical and geological data. Conducting a wellbore stability analysis includes identifying a subset of the well path intervals along the wellbore trajectory as being at risk of instability. The operations include calculating the geomechanical shift for one or more control points along the well path. The geomechanical shift is calculated as a derivative of the wellbore stability at one or more control points. The operations include modifying one or more control points and one or more well trajectory intervals associated with them based in part on geomechanical shear to generate a modified well trajectory.

[0006] In addition, a non-volatile computer-readable medium is disclosed. The storage medium stores instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations. The operations include obtaining geomechanical and geological data for the subterranean region and obtaining the initial well trajectory, including the well path and control points. Each control point has one or more well path intervals associated with it. The operations include performing a wellbore stability analysis along the well trajectory based in part on geomechanical and geological data. Conducting a wellbore stability analysis includes identifying a subset of the well path intervals along the wellbore trajectory as being at risk of instability. The operations include calculating the geomechanical shift for one or more control points along the well path. The geomechanical shift is calculated as a derivative of the wellbore stability at one or more control points. The operations include modifying one or more control points and one or more well trajectory intervals associated with them based in part on geomechanical shear to generate a modified well trajectory.

It should be understood that this summary is only intended to represent certain aspects of the present methods, systems, and media, which are described in detail and/or claimed below. Accordingly, this summary is not intended to be limiting.

BRIEF DESCRIPTION OF GRAPHICS

[0007] The accompanying graphics, which are included in and form part of this specification, illustrate embodiments of the present teachings and, together with the description, serve to explain the principles of the present teachings. On the figures:

[0008] in FIG. 1 depicts an example of a system comprising various control components for dealing with various aspects of the subsurface according to one embodiment;

[0009] in FIG. 2 is a flow diagram of a drilling method, for example, including designing and optimizing a well plan using geomechanical shear analysis, in accordance with one embodiment;

[0010] in FIG. 3 depicts a well trajectory in a subterranean region according to one embodiment;

[0011] in FIG. 4 shows the well trajectory shown in FIG. 3 superimposed with the result of a wellbore stability analysis according to one embodiment;

[0012] in FIG. 5 depicts a high risk interval of the well trajectory shown in FIG. 4 according to one embodiment;

[0013] in FIG. 6 is a visualization of the well trajectory shown in FIG. 4 with a geomechanical shift analysis calculated for its reference point, according to one embodiment;

[0014] in FIG. 7 depicts another well trajectory in a subterranean region with two geomechanical shift calculations performed along its interval, in accordance with one embodiment;

[0015] in FIG. 8 is a conceptual representation of a geomechanical shift calculation according to one embodiment;

[0016] in FIG. 9 is a schematic view of a computing system according to one embodiment.

DETAILED DESCRIPTION OF THE INVENTION

[0017] Embodiments will now be discussed in detail, examples of which are illustrated in the accompanying drawings and figures. In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention. However, one of ordinary skill in the art will appreciate that the invention may be practiced without these specific details. In other cases, known methods, procedures, components, circuits, and networks are not described in detail so as not to unnecessarily obscure aspects of the embodiments.

[0018] In addition, it should be understood that although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited to these terms. These terms are only used to distinguish one element from another. For example, the first object or step may be referred to as the second object or step, and similarly, the second object or step may be referred to as the first object or step, without departing from the scope of the present invention. Both the first object or step and the second object or step are objects or steps, respectively, but they should not be considered the same object or step.

[0019] the Terminology used in the description in this document is intended to describe specific embodiments and should not be construed as limiting. In the context of the description and the appended claims, all singular forms also include plural forms, unless the context clearly indicates otherwise. In addition, it should be understood that the term "and/or" in the context of this document means and covers any possible combinations of one or more related enumerated elements. Further, it should be understood that the terms "comprises", "comprising", "comprises" and/or "comprising" in the context of the present description indicate the presence of the specified features, integers, steps, operations, elements and/or components, but do not exclude the presence or adding one or more other features, integers, steps, operations, elements, components, and/or groups thereof. Further, in the context of this document, the term "if" may be taken to mean "when" or "at" or "in response to a determination" or "in response to a detection", depending on the context.

[0020] Attention should be paid to the processing procedures, methods, techniques and sequences of actions that correspond to some embodiments. Certain operations in the procedures, methods, techniques, and processing steps described herein may be combined and/or the order of some operations may be changed.

In FIG. 1 depicts an example of a system 100 that includes various control components 110 for dealing with various aspects of the subsurface 150 (e.g., an environment that contains a subsurface reservoir, a reservoir 151, one or more faults 153-1, one or more subsurface bodies 153-2 etc.). For example, control components 110 may provide direct or indirect control over the discovery, drilling, injection, extraction, etc. of the subsurface 150. In turn, additional information about the subsurface 150 may become available in the form of feedback 160 (e.g., optionally as input to one or more of the control components 110).

In the example shown in FIG. 1, control components 110 include a seismic data component 112, an additional information component 114 (e.g., well/log data), a data processing component 116, a simulation component 120, an attribute component 130, an analysis/visualization component 142, and a workflow component 144. In operation, the seismic data and other information provided to the components 112 and 114 may be used as input to the simulation component 120.

In an illustrative embodiment, the simulation component 120 may be based on entities 122. Entities 122 may include subsurface entities or geological objects such as wells, surfaces, bodies, reservoirs, etc. In system 100, entities 122 may include virtual representations of real physical entities that are reconstructed for simulation purposes. Entities 122 may include entities based on data obtained through detection, observation, etc. (eg, seismic data 112 and other information 114). An entity may be characterized by one or more properties (eg, an entity geometries reference network of an earth model may be characterized by a property of porosity). Such properties can represent one or more measurements (for example, received data), calculations, etc.

In an illustrative example, the simulation component 120 may operate in conjunction with a software workbench, such as an integrated object-oriented environment. In such a workbench, entities can include entities based on given classes to aid in modeling and simulation. A commercially available example of an integrated object-oriented environment is the MICROSOFT® ^{.NET® Workbench} (Redmond, Washington), which provides a set of extensible object classes. In the .NET ^® runtime, an object class encapsulates a reusable code module and its associated data structures. Object classes may be used to instantiate objects for use by a program, script, etc. For example, borehole classes may define objects to represent boreholes based on borehole data.

In the example shown in FIG. 1, simulation component 120 may process information to match one or more attributes specified by attribute component 130, which may contain an attribute library. Such processing may take place before data is entered into the simulation component 120 (eg, via the data processing component 116). As an example, the simulation component 120 can perform operations on incoming information based on one or more attributes specified by the attribute component 130 . In an exemplary embodiment, simulation component 120 may create one or more subsurface models 150 that may serve to simulate the behavior of subsurface 150 (eg, in response to one or more actions, which may be both natural and man-made). In the example shown in FIG. 1, analysis/visualization component 142 may provide interaction with a model or model-based results (eg, simulation results, etc.). As an example, the output from simulation component 120 may be input to one or more other workflows, as specified by workflow component 144.

By way of example, simulation component 120 may include one or more simulator elements, such as an ECLIPSE ^{™ reservoir simulator (Schlumberger Limited, Houston, Tex.), an INTERSECT™ reservoir} simulator (Schlumberger Limited, Houston, Tex.), etc. As example, simulation components, simulator, etc. may include elements for implementing one or more meshless techniques (eg, for solving one or more equations, etc.). By way of example, the reservoir or reservoirs may be simulated with respect to one or more well productivity enhancement techniques (eg, a thermal process such as steam assisted gravity drainage (SAGD), etc.).

In an exemplary embodiment, control components 110 may include elements of a commercially available workbench such as the ^PETREL® workbench for functions ranging from seismic data interpretation to simulation (Schlumberger Limited, Houston, TX). The PETREL ^® workspace provides components that allow you to optimize exploration and development operations. The PETREL ^® workspace includes software components that implement functions ranging from seismic data interpretation to simulation modeling that can output information for use in improving reservoir performance, for example by increasing the productivity of an asset group. The use of such a working environment can help various specialists (for example, geophysicists, geologists, and reservoir engineers) in developing collaborative workflows and integrating operations for process optimization. Such a work environment may be considered an application and may be considered a data-driven application (eg, where data is entered for the purposes of modeling, simulation, etc.).

In an exemplary embodiment, various aspects of control components 110 may include add-ons or plug-ins that function according to infrastructure environment specifications. For example, a commercially available framework marketed as the ^OCEAN® Framework (Schlumberger Limited, Houston, TX) allows integration of add-ons (or plug-ins) into the workflow for the ^PETREL® workbench. The ^OCEAN® framework uses ^.NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development. In an exemplary embodiment, various components may be implemented as add-ons (or plug-ins) that comply with and function in accordance with the specifications of the infrastructure environment (for example, in accordance with the specifications of the application programming interface (API - English: application programming interface), etc. d.).

In FIG. 1 also depicts an example runtime 170 that includes a model simulation layer 180, as well as a workbench services layer 190, a workbench core layer 195, and a module layer 175. Workbench 170 may include a commercially available ^OCEAN® workbench, where model simulation layer 180 is a commercially available PETREL® model-based software package that contains ^{OCEAN® workbench} applications. In an exemplary embodiment, the ^PETREL® software may be considered a data-driven application. The PETREL ^® software may include a working environment for building and visualizing models.

By way of example, the work environment may include elements for implementing one or more mesh generation techniques. For example, the work environment may include an input component for obtaining information as a result of the interpretation of seismic data, one or more attributes based at least in part on seismic data, well log data, image data, etc. Such work environment may include a component a network generator that processes the input information, optionally in conjunction with other information, to perform network generation.

In the example shown in FIG. 1, model simulation layer 180 may provide domain objects 182, function as a data source 184, render 186, and provide various user interfaces 188. Rendering 186 may provide a graphical environment in which applications may display their data, and user interfaces 188 may provide a common look and feel for the application's user interface components.

By way of example, domain objects 182 may include entity objects, property objects, and optionally other objects. Entity objects can be used to geometrically represent wells, surfaces, bodies, reservoirs, and so on, and property objects can be used to provide property values as well as data versions and display options. For example, entity objects may represent a well, for which a property object provides well logging information as well as version information and visual display information (eg, to display the well as part of a model).

In the example shown in FIG. 1, data may be stored in one or more data sources (or data stores, essentially physical storage devices) which may be located in the same or different physical areas and may be accessible through one or more networks. Model simulation layer 180 may be configured to model designs. Thus, a particular project can be saved, and the saved project information can include inputs, models, results, and cases. Thus, at the end of the simulation session, the user can save the project. The design can later be accessed and restored using the model simulation layer 180, which can recreate examples of relevant domain objects.

In the example shown in FIG. 1, subsurface 150 may include layers (eg, stratification) that include reservoir 151 and one or more other features such as fault 153-1, subsurface 153-2, etc. By way of example, subsurface 150 may be equipped with any of a variety of different sensors, detectors, actuators, etc. For example, equipment 152 may include communication circuitry for receiving and transmitting information regarding one or more networks 155. Such information may include information related to with downhole equipment 154, which may be equipment for obtaining information, assisting in the extraction of resources, etc. Other equipment 156 may be located remotely from the well site and include sensor, detector, emitter, or other circuitry. Such equipment may include storage and communication circuitry for storing and transmitting data, commands, etc. As an example, one or more satellites may be provided for purposes of communication, data acquisition, etc. For example, in FIG. 1 depicts a satellite in communication with a network 155 that may be configured to exchange data, wherein the satellite may additionally or alternatively include circuitry for imaging (e.g., spatial, spectral, temporal, radiometric, etc.) .

In FIG. 1 also depicts subsurface 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal section that may intersect with one or more fractures 159. For example, consider a well in a shale formation that may include include natural fractures, artificial fractures (eg hydraulic fractures) or a combination of natural and artificial fractures. As an example, a well may be drilled for a reservoir that extends laterally. In such an example, there may be lateral changes in properties, stresses, etc., and the assessment of such changes may assist in planning, operations, etc. to develop a laterally distributed reservoir (for example, by hydraulic fracturing, injection, production etc.). By way of example, equipment 157 and/or 158 may include components, system, systems, etc. for hydraulic fracturing, seismic detection, seismic data analysis, evaluation of one or more fractures, etc.

As noted above, system 100 may be used to implement one or more workflows. A workflow may be a process that includes a plurality of work steps. A work step may operate on data, such as to create new data, update existing data, etc. As an example, a work step may operate on one or more inputs and produce one or more results, such as based on one or more algorithms . As an example, the system may include a workflow editor for creating, editing, executing, etc. a workflow. In such an example, the workflow editor may provide a selection of one or more predefined work steps, one or more customized work steps, etc. As an example, a workflow may be a workflow implemented in ^PETREL® software, such as one that works with seismic data, seismic attribute(s), etc. As an example, a workflow could be a process implemented in the ^{OCEAN® workbench} . As an example, a workflow may include one or more work steps that access a module, such as a plug-in (eg, external executable code, etc.).

[0021] In FIG. 2 is a flow diagram of a method 200 for planning and drilling a well, according to one embodiment. More specifically, method 200 may relate to determining a well path along which a well may be drilled, and in some embodiments, also to controlling drilling operations along the determined well path. However, some embodiments of the method 200 may not include drilling, but rather may include rendering a 2D or 3D rendering of a particular well. In addition, it should be understood that the various actions shown in FIG. 2 and described herein may be performed out of the sequence shown, two or more acts may be combined or performed in parallel, or any of the acts may be separated into two or more separate acts without departing from the scope of the present invention.

[0022] Consider now the specific embodiment shown in FIG. 2, in which method 200 may begin by obtaining geomechanical and/or geological data as input, such as at 202. Geomechanical data may include data associated with mechanical properties of the subterranean region of interest, such as formation(s). ) rock through which a well can be drilled to reach a target, such as a hydrocarbon reservoir. Such data may include formation stress characteristics and the like. In addition, geological data may indicate rock type, structure, etc. Method 200 may also include obtaining or determining an initial well trajectory, such as at 204.

[0023] FIG. 3 shows an example of an initial well trajectory 300 within a subterranean region 302. The initial well trajectory 300 extends from a surface wellhead 304 (eg, depth=0) to a target 306 that can be offset from the wellhead 304 both vertically (in depth) and and horizontally (in the northeast plane). In addition, the initial well trajectory 300 may define reference points 308 (or "viewpoints") at various depth intervals along the well trajectory 300. Each anchor point 308 may have one or more intervals associated with it (eg, excluding the least deep and deepest anchor points 308, where each anchor point 308 may have two intervals associated with it).

[0024] As shown in FIG. 2, method 200 may include determining geomechanical and geological properties along the well trajectory using geomechanical and geological data, for example, at 206. Next, method 200 may include performing a wellbore stability analysis along the well trajectory based on geomechanical and geological properties, for example , at step 208. A wellbore stability determination is performed using a wellbore-oriented model, for example, at step 208. An example of a wellbore-oriented model is provided by the Stonefish DLL, which provides geomechanical sensitivity modeling on the wellbore trajectory. In addition, the computing power for wellbore-oriented modeling can be deployed in a cloud infrastructure that enables the integration of geomechanical data and modeling with well planning systems, as well as their transfer to these systems.

[0025] For example, a wellbore stability analysis can determine the stress and strain caused by wellbore construction activities, the risk of wellbore failure, a safe and stable mud density range, the orientation and stability relationship of the wellbore, and an assessment of data uncertainty and model calibration.

[0026] The result of this wellbore stability analysis may be displayed on the well trajectory 300 as shown in FIG. 4. As can be seen, a spectrum of values for one or more stability metrics can be superimposed on the trajectory 300 itself, such as along gaps or intervals between anchor points 308. For example, the stability metric can be the minimum mud density to prevent caving in the wellbore, where higher drilling fluid densities indicate reduced stability. Further, method 200 may include a drilling risk analysis based on the wellbore stability analysis and make recommendations for updating and optimizing the well plan, such as creating a new well plan that is a modification of the original well plan, such as at 210. Such modifications may include adjusting the location of various reference points 308 along the well path 300 .

[0027] Method 200 may then include identifying high risk intervals along the well trajectory, eg, at 212. For example, referring again to FIG. 4, high risk interval 400 can be identified. In a specific example, a high risk interval 400 may be identified as a deep interval with a potential instability problem (e.g., a risk value that is higher than other (or all) intervals and/or a risk value that exceeds a predetermined tolerance threshold). risk), for example, a narrow range of drilling fluid density. In a specific example, the interval with the worst potential instability problem compared to each of the other intervals can be identified. In other embodiments, any subset consisting of one or more intervals may be identified as high risk. The depth intervals may be the same in depth/extent along the well path 300, for example, a specific distance such as 20 meters may be applied, or this parameter may be set in some other way. In FIG. 5 is an enlarged view of the interval 400 identified as high risk at step 212.

[0028] As will be described in more detail below, method 200 may further include calculating a geomechanical "shear" or trend for an interval, for example, at 214. In another embodiment, a geomechanical shear may be calculated for one, some, or all intervals along the well path. . "Geomechanical trend" is a derivative of the wellbore's resistance to well orientation changes (shifts or corrections from the current position) at one or more control points along the planned well path.

[0029] The method 200 may also include applying the calculated geomechanical shear, for example, at step 215, as a force vector to the reference point in 2D and/or 3D visualization of the well trajectory in the subterranean region, which will be described in more detail below. Moreover, in some implementations, this may trigger an interactive graphical design mode, for example, in which the well trajectory is shown along with the calculated geomechanical trend/shear, which may facilitate the user's work and simplify the analysis.

[0030] Next, the method 200 may proceed to modify the interval(s) based on the geomechanical shift, for example, at 216. In particular, the location and/or angle of penetration of the wellbore at the reference point may be adjusted, for example, by moving the reference point. In turn, this can affect the location and angle of penetration of the depth intervals associated with the specified control point. This workflow may be iterative, as one modification of the reference point may result in a recalculation of the well trajectory (e.g., returning to step 208) and a subsequent wellbore stability analysis (210) and/or calculation of another geomechanical shift (214) in one , some or all control points along the well trajectory. The method 200 may allow multiple well trajectory scenarios to be compared, for example, based on the state of wellbore stability, mud density range, degree of wellbore curvature, or any other relevant factors. The selected well trajectory may minimize the risk of caving into the well and the risk of mud loss and/or minimize mud density to improve drilling performance (eg, based on ROP).

[0031] In FIG. 6 is a visual representation of the geomechanical shear computed for reference point 600. As depicted in the figure, shear is represented as circle 602 centered at point 600. The interior of circle 602 may be filled, hatched, or otherwise filled to represent expected changes in wellbore stability index. well, for example, if the reference point 600 is moved to a different location within the circle 602, for example, thereby moving a section of the well path 300, as indicated by dashed line 604. In addition, such shift visualization can be easily perceived by a human user.

[0032] Similarly, in FIG. 7 depicts a well trajectory 700 that has been geomechanically scanned along interval 702. The geomechanical shift may be computed for a subset or each of the control points along the well path 700 . For example, the geomechanical shift calculation may apply an accelerating/damping force (vector) with an adjustment knob when the well planning system and/or the user attempts to adjust the orientation/location of the analyzed control points. The two polar plots 704, 706 on the right show background geomechanical scan analysis using geomechanical data and a model (eg, offset/trend calculation).

в опорной точке i представлены как:[0033] For example, a planned well path can be defined by n control points (e.g., observation points) ( i =1,2, ..., n), and a prerequisite for running geomechanical modeling is ready (e.g., a geomechanical model and a geological description before drilling for analyzed reservoir were created and entered into the system, for example, at step 202). Wellbore stability/indicator and their change

at pivot point i are represented as:

and geomechanical shift (trend vector) is represented as:

является результатом сканирования устойчивости ствола скважины как функции от регулировки углов ориентации буровой скважины (азимутального угла и угла отклонения ствола скважины) в точке i,

является весовой функцией, которая может быть связана с риском механического разрушения буровой скважины, и

является штрафным коэффициентом, представляющим другие геомеханические факторы, которые могут быть не включены в анализ методом геомеханического сканирования. Два примера результат сканирования

в двух интервалах, на которые воздействовала эта опорная точка i, показаны на фиг. 7, как отмечено выше.where x is the well trace depth = MD(i-1) to MD(i), represents the well trace intervals that can be affected by adjusting this reference point i ,

is the result of the wellbore stability scan as a function of adjusting the borehole orientation angles (azimuth angle and wellbore deviation angle) at point i ,

is a weighting function that can be associated with the risk of mechanical failure of the borehole, and

is a penalty factor representing other geomechanical factors that may not be included in the geomechanical scanning analysis. Two examples of scan result

in the two intervals affected by this reference point i are shown in FIG. 7 as noted above.

Geomechanical shearing can work directly in a well planning system, as shown in FIG. 7. The trend vector at anchor point i will be applied with the "adjustment knob" when the user is working on the well trajectory and triggering this anchor point.

) и геомеханического сдвига (

), вычисленного в одной опорной точке. In FIG. 8 shows the calculation of the geomechanical shift at the reference point i . In the graph, the various circles represent the contour of the wellbore stability state, and the vectors represent the geomechanical shift to change (adjust) the azimuth angle and the wellbore deviation angle at the reference point. In other words, in FIG. 8 shows one example of wellbore stability changes (

) and geomechanical shear (

) calculated at one reference point.

The geomechanical shift can also be determined and calculated in a spatial coordinate system (North-East-Vertical), where the position of the reference point i represents the parameters of change for analysis by the scan method and adjustment of the wellbore path, as shown at 602. By introducing this shift and carrying out the analysis of geomechanical data and the model, direct transfer of the geomechanical model to the well trajectory plan and optimization can be achieved. The geomechanical modeling simulator is in the background to scan the potential direction of movement in the well path interval (MD(i-1) to MD(i)) and run the simulation.

[0034] Some embodiments of this method 200 may be applied outside of well path design based on wellbore stability and drilling safety. In fact, some embodiments may apply to other parts of well planning, drilling, and completion programs, for example, geomechanical shear may be determined in relation to the possibility of hydraulic fracturing of the reservoir and production without sanding out in the well, where the wellbore angles and perforation angles passing through reservoir, are important factors affecting well productivity. Thus, this geomechanical shear can be extended and applied to wellbore fracturing design and sandless production design programs.

[0035] In addition, the apparatus may be used during the drilling execution phase of the well, when the measured and observed drilling data suggest updating a previous drilling model, and this method 200 may be used to scan for any potential changes in the well path ahead of the bit, calculate geomechanical shear to steer the bit to continue drilling, for example, at step 208.

[0036] In some embodiments, the methods of the present invention may be performed by a computer system. In FIG. 9 depicts an example of such a computing system 900, in accordance with some embodiments. Computer system 900 may include a computer or computer system 901A, which may be a single computer system 901A or a configuration of distributed computer systems. Computer system 901A includes one or more analysis modules 902 that are configured to perform various tasks in accordance with some embodiments, such as one or more of the methods described herein. The analysis module 902 performs these various tasks independently or in cooperation with one or more processors 904 which is(are) connected to one or more storage media 906. The processor(s) 904 are also connected (or connected) to the network interface. 907 to enable computer system 901A to communicate over network 909 with one or more additional computer systems and/or computing systems such as 901B, 901C, and/or 901D (it should be noted that computer systems 901B, 901C, and/or 901D may may or may not have the same architecture as computer system 901A and may be in different physical locations, for example, computer systems 901A and 901B may be located at a processing point while in communication with one or more computer systems, such as 901C and/or 901D that are located in one or more data centers, and/or located in different countries on different continents).

[0037] A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or other control or computing device.

[0038] The storage media 906 may be implemented as one or more computer-readable or machine-readable storage media. It should be noted that although in the illustrative embodiment of FIG. 9, storage media 906 is depicted as located within computer system 901A, in some embodiments, storage media 906 may be distributed within and/or across multiple internal and/or external enclosures of computing system 901A and/or additional computing systems. The storage media 906 may include one or more different forms of memory, including semiconductor memories such as dynamic or static random access memories (DRAM or SRAM), erasable and programmable read only memory (EPROM), electrically erasable, and programmable read-only memories (EEPROM) and flash memory, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact discs (CDs) or digital video discs (DVDs) , BLURAY ^® discs, or other types of optical storage devices or other types of information storage devices. It should be noted that the instructions described above may be provided on a single computer-readable or computer-readable storage medium, or may be provided on multiple computer-readable or computer-readable storage media distributed in a large system, possibly having multiple nodes. It is believed that such a computer-readable or machine-readable storage medium or media should (should) be part of the product (or manufactured product). Product can mean any single component or a plurality of components manufactured. The storage medium or media may reside either on the machine executing the machine-readable instructions, or may be located at a remote location from which the machine-readable instructions can be downloaded over the network for execution.

[0039] In some embodiments, computing system 900 includes one or more geomechanical shear analysis modules 908. In the example of computer system 900, computer system 901A includes a geomechanical shear analysis module 908. In some embodiments, a single geomechanical shift analysis module may be used to perform some aspects of one or more embodiments of the methods described herein. In other embodiments, a plurality of geomechanical shear analysis modules may be used to perform some aspects of the methods described herein.

[0040] It should be understood that computing system 900 is merely one example of a computing system, and that computing system 900 may have more or fewer components than shown, may combine additional components not shown in the exemplary embodiment of FIG. 9 and/or computing system 900 may have a different configuration or placement of the components shown in FIG. 9. The various components shown in FIG. 9 may be implemented in hardware, software, or a combination of hardware and software, including one or more signal processing and/or application specific integrated circuits.

[0041] In addition, the steps in the processing methods described herein may be implemented by executing one or more functional modules in an information processing device such as general purpose processors or specialized chips such as ASICs, FPGAs, PLDs, or other appropriate devices. These modules, combinations of these modules and/or their combination with the underlying hardware are included within the scope of the present invention.

Computational interpretations, models, and/or other interpretation tools can be iteratively optimized; and this concept is applicable to the methods described in this document. This may include the application of feedback loops that are performed algorithmically, for example, on a computing device (for example, computing system 900 shown in Fig. 9), and/or through manual control by the user, who can determine whether whether a given step, action, template, model, or set of curves is accurate enough to evaluate the subsurface 3D subterranean formation under consideration.

[0042] The above description, for purposes of explanation, has been described with reference to specific embodiments. However, the foregoing description is not meant to be exhaustive or to limit the present invention to the specific forms described. Many modifications and variations are possible, taking into account the above ideas. Moreover, the order in which the elements of the method described herein are illustrated and described may be changed and/or two or more elements may appear simultaneously. The embodiments have been selected and described in an order that best illustrates the principles of the present invention and its practical application, in order to enable those skilled in the art to make best use of the disclosed embodiments, as well as various embodiments with various modifications suitable for the particular form envisaged. applications.

Claims (56)

1. A method for visualizing the well trajectory, including: obtaining geomechanical and geological data for the underground area; obtaining an initial well trajectory including a well path and control points, each control point having one or more well path intervals associated with it; performing a wellbore stability analysis along the wellbore trajectory using geomechanical and geological data, the wellbore stability analysis comprising identifying a subset of wellpath intervals along the wellbore trajectory as at risk of instability; calculating a geomechanical shift for one or more reference points along the well trajectory, wherein the geomechanical shift is calculated as a derivative of the wellbore stability at the one or more reference points; and modifying one or more control points and one or more well trajectory intervals associated with them using geomechanical shear to generate a modified well trajectory, visualization of the computed geomechanical shift, modified well trajectory, or both in a digital subsurface model. 2. The method of claim. 1, characterized in that the modification of one or more control points includes adjusting the location and/or angle of penetration of one or more control points to improve the stability of the wellbore in one or more control points and one or more intervals well traces associated with them. 3. The method of claim. 1, characterized in that the identification of a subset of intervals along the initial well trajectory as at risk of instability includes: calculating a wellbore stability value for the respective intervals; comparing said value with a given threshold value or values associated with other intervals; determining that the intervals have a high risk based on the comparison, and high risk has a risk value that is higher than other intervals or all intervals, and/or a risk value that exceeds a predetermined tolerable risk threshold; and in response to determining that the intervals are high risk, determining the geomechanical shift for one or more control points in the identified intervals, and not in one or more other intervals that have not been identified as high risk. 4. The method of claim 1, further comprising: determining wellbore stability for the well trajectory after modifying one or more control points; selecting an interval between two points from the reference points based on the stability of the wellbore; calculation of geomechanical shift for two points from the control points and modifying the location and penetration angle of two points from the control points based on the geomechanical shift. 5. The method of claim. 4, characterized in that the geomechanical shift includes the derivative of the stability of the wellbore in relation to the change in azimuth and the derivative of the stability of the wellbore in relation to the change in deviation of the wellbore. 6. The method according to claim. 4, characterized in that the geomechanical shift includes the derivative of the stability of the wellbore with respect to changes in the spatial position of the reference point. 7. The method of claim 1, wherein performing the wellbore stability analysis includes calculating the wellbore stability for one or more intervals affected by one of the control points as a function of the control point adjustment, a weight function, and a penalty factor representing geomechanical factors that are not included in the wellbore stability scan result. 8. The method of claim. 1, further comprising applying the calculated geomechanical shear as a force vector to the reference point when visualizing the initial well trajectory in the subterranean region and launching an interactive graphic design mode. 9. The method of claim. 1, further comprising drilling the wellbore along the modified well trajectory. 10. A computing system comprising one or more processors and a storage system including one or more non-volatile computer-readable media storing instructions that, when executed by at least one of one or more processors, cause the computing system to perform operations, said operations including myself: obtaining geomechanical and geological data for the underground area; obtaining an initial well trajectory including a well path and control points, each control point having one or more well path intervals associated with it; performing a wellbore stability analysis along the wellbore trajectory using geomechanical and geological data, the wellbore stability analysis comprising identifying a subset of wellpath intervals along the wellbore trajectory as at risk of instability; calculating a geomechanical shift for one or more reference points along the well trajectory, wherein the geomechanical shift is calculated as a derivative of the wellbore stability at the one or more reference points; and modifying one or more control points and one or more intervals of the well path associated with them, using geomechanical shear to generate a modified well trajectory; visualizing the calculated geomechanical shift of the modified well trajectory, or both, in a digital subsurface model. 11. The system of claim. 10, characterized in that the modification of one or more control points includes adjusting the location and/or angle of penetration of one or more control points to improve the stability of the wellbore in one or more control points and one or more intervals well traces associated with them. 12. The system of claim. 10, characterized in that the identification of a subset of intervals along the initial well trajectory as at risk of instability includes: calculating a wellbore stability value for the respective intervals; comparing said value with a given threshold value or values associated with other intervals; determining that the intervals have a high risk based on the comparison, and high risk has a risk value that is higher than other intervals or all intervals, and/or a risk value that exceeds a predetermined tolerable risk threshold; and in response to determining that the intervals are high risk, determining the geomechanical shift for one or more control points in the identified intervals, and not in one or more other intervals that have not been identified as high risk. 13. The system according to claim 10, characterized in that the operations additionally include: determining wellbore stability for the well trajectory after modifying one or more control points; selecting an interval between two points from the reference points based on the stability of the wellbore; calculation of geomechanical shift for two points from the control points and modifying the location and penetration angle of two points from the control points based on the geomechanical shift. 14. The system of claim. 13, characterized in that the geomechanical shift includes the derivative of the stability of the wellbore in relation to the change in azimuth and the derivative of the stability of the wellbore in relation to the change in deviation of the wellbore. 15. The system of claim. 10, characterized in that the analysis of the stability of the wellbore includes calculating the stability of the wellbore for one or more intervals affected by one of the control points, as a function of the adjustment of the reference point, a weight function and a penalty factor representing geomechanical factors that are not included in the wellbore stability scan result. 16. A non-volatile computer-readable medium that stores instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations, said operations including: obtaining geomechanical and geological data for the underground area; obtaining an initial well trajectory including a well path and control points, each control point having one or more well path intervals associated with it; performing a wellbore stability analysis along the wellbore trajectory using geomechanical and geological data, the wellbore stability analysis comprising identifying a subset of wellpath intervals along the wellbore trajectory as at risk of instability; calculating a geomechanical shift for one or more reference points along the well trajectory, wherein the geomechanical shift is calculated as a derivative of the wellbore stability at the one or more reference points; and modifying one or more control points and one or more well trajectory intervals associated with them using geomechanical shear to generate a modified well trajectory, visualizing the calculated geomechanical shift of the modified well trajectory, or both, in a digital subsurface model. 17. The carrier according to claim 16, characterized in that the operations additionally include: determining wellbore stability for the well trajectory after modifying one or more control points; selecting an interval between two points from the reference points based on the stability of the wellbore; calculation of geomechanical shift for two points from the control points and modifying the location and penetration angle of two points from the control points based on the geomechanical shift. 18. The carrier of claim. 16, characterized in that the operations further include applying the calculated geomechanical shear as a force vector to the reference point when visualizing the initial well trajectory in the underground region and launching an interactive graphic design mode.

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