WO2016094483A1

WO2016094483A1 - Visualization of vector fields using lights

Info

Publication number: WO2016094483A1
Application number: PCT/US2015/064632
Authority: WO
Inventors: Oyvind Yrke; Helge FOSSE
Original assignee: Schlumberger Canada Limited; Services Petroliers Schlumberger; Geoquest Systems B.V.; Schlumberger Technology Corporation
Priority date: 2014-12-09
Filing date: 2015-12-09
Publication date: 2016-06-16

Abstract

Computing systems, computer-readable media, and methods may include obtaining seismic data for a geological formation. The method also includes determining a point of view for viewing a graphical representation of the seismic data. Further, the method includes determining a light source for illuminating the graphical representation of the seismic data. Determining the light source may include determining a direction of the light source relative to the point of view and a color of the light source. Additionally, the method includes generating the graphical representation of the seismic data. The graphical representation of the seismic data may include shading, in the color, features of the seismic data based at least partially on the point of view and the direction of the light source. The method also includes displaying the graphical representation of the seismic data.

Description

VISUALIZATION OF VECTOR FIELDS USING LIGHTS

Cross-Reference To Related Applications

[0001] This application claims priority to U.S. Provisional Patent Application Serial No. 62/089,466 filed on December 9, 2014, which is incorporated by reference herein in its entirety.

Background

[0002] In three dimensional visualization, light and shadows are used to create realistic images, e.g., providing the perception of depth. Lighting and shadows are also used in maps to create insight into structure beyond what maps relying solely on color might achieve. Further, by way of illustration, at sunrise or sunset, our ability to see fine structure and detail in the landscape is much better than in broad daylight, because the light direction is nearly perpendicular to the surface being studied. As such, even small undulations may greatly impact the amount of reflected light.

[0003] Lighting may be used beyond creating realistic images. For example, light use may assist in analyzing data, such as when looking for subtle structural changes in elevation data (either surface or subsurface data).

[0004] Within energy exploration and seismic interpretation, "seismic attributes" are shown by applying an artificial light-source near a structure. In recent years, new methods have been developed that calculate dip or structural information directly from seismic data without calculating or extracting an explicit geometry. One of the challenges of these methods is they calculate reflected light from a single light source. In addition, these methods may be slow to change light parameters to these methods as it will trigger a time-consuming computation.

Summary

[0005] Embodiments of the present disclosure may provide a method. The method includes obtaining seismic data for a geological formation. The method also includes determining a point of view for viewing a graphical representation of the seismic data. Further, the method includes determining a light source for illuminating the graphical representation of the seismic data. Determining the light source may include determining a direction of the light source relative to the point of view and a color of the light source. Additionally, the method includes generating the graphical representation of the seismic data. The graphical representation of the seismic data may include shading, in the color, features of the seismic data based at least partially on the point of view and the direction of the light source. The method also includes displaying the graphical representation of the seismic data.

[0006] In an embodiment, the method may further include determining a new point of view for viewing the graphical representation of the seismic data, generating a new graphical representation of the seismic data, wherein the new graphical representation of the seismic data includes new shading, in the color, features of the seismic data based at least partially on the new point of view and the direction of the light source, and displaying the new graphical representation of the seismic data.

[0007] In an embodiment, generating the new graphical representation may be preformed in real-time with the determining the new point of view.

[0008] In an embodiment, the method may further include determining a change in the light source, generating a new graphical representation of the seismic data, wherein the new graphical representation of the seismic data includes new shading of features of the seismic data based at least partially on the point of view and the change in the light source, and displaying the new graphical representation of the seismic data.

[0009] In an embodiment, generating the new graphical representation may be preformed in real-time with the determining the change in the light source.

[0010] In an embodiment, the seismic data may include three dimensional seismic data.

[0011] In an embodiment, the seismic data may include dip estimate data for the seismic data.

[0012] Embodiments of the present disclosure may provide a non-transitory computer readable storage medium storing instructions for causing one or more processors to perform a method. The method includes obtaining seismic data for a geological formation. The method also includes determining a point of view for viewing a graphical representation of the seismic data. Further, the method includes determining a light source for illuminating the graphical representation of the seismic data. Determining the light source may comprise determining a direction of the light source relative to the point of view and a color of the light source. Additionally, the method includes generating the graphical representation of the seismic data. The graphical representation of the seismic data may include shading, in the color, features of the seismic data based at least partially on the point of view and the direction of the light source. The method also includes displaying the graphical representation of the seismic data.

[0013] Embodiments of the present disclosure may provide a system. The system may include one or more memory devices storing instructions. The system may also include one or more processors coupled to the one or more memory devices and configured to execute the instructions to perform a method. The method includes obtaining seismic data for a geological formation. The method also includes determining a point of view for viewing a graphical representation of the seismic data. Further, the method includes determining a light source for illuminating the graphical representation of the seismic data. Determining the light source may comprise a direction of the light source relative to the point of view and a color of the light source. Additionally, the method includes generating the graphical representation of the seismic data. The graphical representation of the seismic data may include shading, in the color, features of the seismic data based at least partially on the point of view and the direction of the light source. The method also includes displaying the graphical representation of the seismic data.

[0014] In an embodiment, the one or more processors may include a graphics processor configured to execute the instructions to perform the generation of the graphical representation.

Brief Description of the Drawings

[0015] The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings. In the figures:

[0016] Figure 1 illustrates an example of a system that includes various management components to manage various aspects of a geologic environment according to an embodiment.

[0017] Figure 2 illustrates a flowchart of a method for generating a graphical representation of seismic data according to an embodiment.

[0018] Figure 3 A illustrate an example of seismic data according to an embodiment.

[0019] Figures 3B and 3C illustrate examples of shading techniques according to an embodiment.

[0020] Figures 4A and 4B illustrate examples of graphical representations of seismic data according to an embodiment. [0021] Figure 5 illustrates a schematic view of a computing system according to an embodiment.

Detailed Description

[0022] Reference will now be made in detail to the various embodiments in the present disclosure, examples of which are illustrated in the accompanying drawings and figures. The embodiments are described below to provide a more complete understanding of the components, processes and apparatuses disclosed herein. Any examples given are intended to be illustrative, and not restrictive. However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details. In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.

[0023] Throughout the specification and claims, the following terms take the meanings explicitly associated herein, unless the context clearly dictates otherwise. The phrases "in some embodiments" and "in an embodiment" as used herein do not necessarily refer to the same embodiment s), though they may. Furthermore, the phrases "in another embodiment" and "in some other embodiments" as used herein do not necessarily refer to a different embodiment, although they may. As described below, various embodiments may be readily combined, without departing from the scope or spirit of the present disclosure.

[0024] As used herein, the term "or" is an inclusive operator, and is equivalent to the term "and/or," unless the context clearly dictates otherwise. The term "based on" is not exclusive and allows for being based on additional factors not described, unless the context clearly dictates otherwise. In the specification, the recitation of "at least one of A, B, and C," includes embodiments containing A, B, or C, multiple examples of A, B, or C, or combinations of A/B, A/C, B/C, A/B/B/ B/B/C, A/B/C, etc. In addition, throughout the specification, the meaning of "a," "an," and "the" include plural references. The meaning of "in" includes "in" and "on."

[0025] It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms. These terms are used to distinguish one element from another. For example, a first object or step could be termed a second object or step, and, similarly, a second object could be termed a first object, without departing from the scope of the invention. The first object and the second object are both objects , but they are not to be considered the same object. It will be further understood that the terms "includes," "including," "comprises" and/or "comprising," when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof. Further, as used herein, the term "if may be construed to mean "when" or "upon" or "in response to determining" or "in response to detecting," depending on the context.

[0026] When referring to any numerical range of values herein, such ranges are understood to include each and every number and/or fraction between the stated range minimum and maximum. For example, a range of 0.5-6% would expressly include intermediate values of 0.6%, 0.7%, and 0.9%, up to and including 5.95%, 5.97%, and 5.99%. The same applies to each other numerical property and/or elemental range set forth herein, unless the context clearly dictates otherwise.

[0027] Attention is now directed to processing procedures, methods, techniques, and workflows that are in accordance with some embodiments. Some operations in the processing procedures, methods, techniques, and workflows disclosed herein may be combined and/or the order of some operations may be changed.

[0028] Figure 1 illustrates an example of a system 100 that includes various management components 110 to manage various aspects of a geologic environment 150 (e.g., an environment that includes a sedimentary basin, a reservoir 151, one or more faults 153-1, one or more geobodies 153-2, etc.). For example, the management components 110 may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 150. In turn, further information about the geologic environment 150 may become available as feedback 160 (e.g., optionally as input to one or more of the management components 110).

[0029] In the example of Figure 1, the management components 110 include a seismic data component 112, an additional information component 114 (e.g., well/logging data), a processing component 116, a simulation component 120, an attribute component 130, an analysis/visualization component 142 and a workflow component 144. In operation, seismic data and other information provided per the components 112 and 114 may be input to the simulation component 120. [0030] In an example embodiment, the simulation component 120 may rely on entities 122. Entities 122 may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc. In the system 100, the entities 122 may include virtual representations of actual physical entities that are reconstructed for purposes of simulation. The entities 122 may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data 112 and other information 114). An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property). Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.

[0031] In an example embodiment, the simulation component 120 may operate in conjunction with a software framework such as an object-based framework. In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation. A commercially available example of an object-based framework is the MICROSOFT^® .NET^® framework (Redmond, Washington), which provides a set of extensible object classes. In the .NET^® framework, an object class encapsulates a module of reusable code and associated data structures. Object classes may be used to instantiate object instances for use in by a program, script, etc. For example, borehole classes may define objects for representing boreholes based on well data.

[0032] In the example of Figure 1, the simulation component 120 may process information to conform to one or more attributes specified by the attribute component 130, which may include a library of attributes. Such processing may occur prior to input to the simulation component 120 (e.g., consider the processing component 1 16). As an example, the simulation component 120 may perform operations on input information based on one or more attributes specified by the attribute component 130. In an example embodiment, the simulation component 120 may construct one or more models of the geologic environment 150, which may be relied on to simulate behavior of the geologic environment 150 (e.g., responsive to one or more acts, whether natural or artificial). In the example of Figure 1, the analysis/visualization component 142 may allow for interaction with a model or model-based results (e.g., simulation results, etc.). As an example, output from the simulation component 120 may be input to one or more other workflows, as indicated by a workflow component 144.

[0033] As an example, the simulation component 120 may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Texas), the INTERSECT reservoir simulator (Schlumberger Limited, Houston Texas), etc. As an example, a simulation component, a simulator, etc. may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.) and to implement one or more mesh techniques. As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.). As an example, a simulation component may be applied to any type of data that is represented as vector fields in general. Some examples include multi-component seismic attributes such as 3D curvature or dip estimation, material stress, and fluid flow. As an example, a simulation component may apply to regularly sampled cubes, while others may apply to a vector field from a continuous function in 3D space or may apply to both.

[0034] In an example embodiment, the management components 110 may include features of a commercially available framework such as the PETREL^® seismic to simulation software framework (Schlumberger Limited, Houston, Texas). The PETREL^® framework provides components that allow for optimization of exploration and development operations. The PETREL^® framework includes seismic to simulation software components that may output information for use in increasing reservoir performance, for example, by improving asset team productivity. Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) may develop collaborative workflows and integrate operations to streamline processes. Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).

[0035] In an example embodiment, various aspects of the management components 110 may include add-ons or plug-ins that operate according to specifications of a framework environment. For example, a commercially available framework environment marketed as the OCEAN^® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of addons (or plug-ins) into a PETREL^® framework workflow. The OCEAN^® framework environment leverages .NET^® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user- friendly interfaces for efficient development. In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.). [0036] Figure 1 also shows an example of a framework 170 that includes a model simulation layer 180 along with a framework services layer 190, a framework core layer 195 and a modules layer 175. The framework 170 may include the commercially available OCEAN^® framework where the model simulation layer 180 is the commercially available PETREL^® model-centric software package that hosts OCEAN^® framework applications. In an example embodiment, the PETREL^® software may be considered a data-driven application. The PETREL^® software may include a framework for model building and visualization.

[0037] As an example, a framework may include features for implementing one or more mesh generation techniques. For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc. Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.

[0038] In the example of Figure 1, the model simulation layer 180 may provide domain objects 182, act as a data source 184, provide for rendering 186 and provide for various user interfaces 188. Rendering 186 may provide a graphical environment in which applications may display their data while the user interfaces 188 may provide a common look and feel for application user interface components.

[0039] As an example, the domain objects 182 may include entity objects, property objects and optionally other objects. Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters. For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).

[0040] In the example of Figure 1, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks. The model simulation layer 180 may be configured to model projects. As such, a particular project may be stored where stored project information may include inputs, models, results and cases. Thus, upon completion of a modeling session, a user may store a project. At a later time, the project may be accessed and restored using the model simulation layer 180, which may recreate instances of the relevant domain objects.

[0041] In the example of Figure 1, the geologic environment 150 may include layers (e.g., stratification) that include a reservoir 151 and one or more other features such as the fault 153-1, the geobody 153-2, etc. As an example, the geologic environment 150 may be outfitted with any of a variety of sensors, detectors, actuators, etc. For example, equipment 152 may include communication circuitry to receive and to transmit information with respect to one or more networks 155. Such information may include information associated with downhole equipment 154, which may be equipment to acquire information, to assist with resource recovery, etc. Other equipment 156 may be located remote from a well site and include sensing, detecting, emitting or other circuitry. Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc. As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc. For example, Figure 1 shows a satellite in communication with the network 155 that may be configured for communications, noting that the satellite may include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).

[0042] Figure 1 also shows the geologic environment 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal portion that may intersect with 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 and artificial fractures. As an example, a well may be drilled for a reservoir that is laterally extensive. In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.). As an example, the equipment 157 and/or 158 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.

[0043] As mentioned, the system 100 may be used to perform one or more workflows. A workflow may be a process that includes a number of worksteps. A workstep may operate on data, for example, to create new data, to update existing data, etc. As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms. As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow. In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc. As an example, a workflow may be a workflow implementable in the PETREL^® software, for example, that operates on seismic data, seismic attribute(s), etc. As an example, a workflow may be a process implementable in the OCEAN^® framework. As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).

[0044] As described above, the system 100 may be used to view or analyze seismic data for a geologic environment 150 and/or a reservoir 151. In embodiments, the system 100 may be used in displaying seismic data using shading to illuminate features in graphical representation of the seismic data. In embodiments, a user may select a point of view to display the graphical representation of the seismic data. In embodiments, the user may select one or more light sources to illuminate the features in the seismic data. In embodiments, based on the point of view and light sources, a graphical representation of the seismic data may be generated and displayed.

[0045] In embodiments, the graphical representation may be generated using graphics hardware, for example, one or more graphics processors and graphics memory. For example, a shader program that resides in the graphics hardware may be utilized to generate the graphical representation. The shader program may calculate the contribution for each light on seismic data, for example, the vector field data of the seismic data. Because graphics hardware is utilized, the user may select a different point of view and/or change the one or more light sources in real-time. This allows a user to interact with and explore the seismic data in real-time.

[0046] Figure 2 illustrates a flowchart of a method 200 for generating a graphical representation of seismic data according to an embodiment. The illustrated stages of the method are examples and any of the illustrated stages may be removed, additional stages may be added, and the order of the illustrated stages may be changed.

[0047] In 202, seismic data may be obtained for a geological formation. In some embodiment, the seismic data may be captured or measured by the system 100. In some embodiments, the seismic data may be stored in one or more data stores of the system 100 and retrieved, in 202. In some embodiments, the seismic data may be selected by a user of the system 100. In some embodiments, the seismic data may be determined independently by the system 100. [0048] In some embodiments, the seismic data may include two dimensional (2D) seismic data. In some embodiments, the seismic data may include three dimensional (3D) seismic data. In some embodiments, the seismic data may be dip estimation data comprising a vector field calculated from seismic data. For example, the dip estimation data may comprise a calculated dip in e.g. inline and crossline directions (i.e. 2 orthogonal directions). This produces an estimated gradient [f_x, f_y] of the seismic amplitude at that point in 3D space. In some embodiments, the dip estimation data may be pre-calculated prior to 202. Figure 3A illustrates an example of seismic data according to an embodiment. As illustrated in Figure 3 A, the seismic data may include a horizontal slice 300 of a seismic amplitude cube.

[0049] In 204, a point of view may be determined for a graphical representation of the seismic data. In embodiments, the point of view may be the perspective from which the graphical representation will be generated and displayed. In some embodiments, the point of view may be selected by a user of the system 100. In some embodiments, the point of view may be determined independently by the system 100.

[0050] In 206, one or more light sources may be determined for illuminating the graphical representation of the seismic data. In embodiments, the one or more light sources and shadows created by the one or more light sources may be used for the purpose of creating realistic graphical representation of the seismic data and create a graphical representation of the seismic data where user gets a perception of depth. In some embodiments, the determination of the one or more light sources may include a determination of the location of the light source relative to the point of view and a color of the light source. In some embodiments, the one or more light sources may include different colored light sources providing illumination from different directions. In some embodiments, the one or more light sources may be selected by a user of the system 100. In some embodiments, the one or more light sources may be determined independently by the system 100.

[0051] In some embodiments, for example, the number, position, and location of the one or more light sources may be determined. In some embodiments, for example, the parameters of the one or more light sources may be determined. For example, the parameters may include color of the light source or features of the color of the light source such as ambient light, diffuse light, specular light, etc. Likewise, for example, the parameters of the light source may include a direction of the one or more light sources. Likewise, for example, the parameters may include a position of the one or more light sources. Likewise, for example, the parameters may include an intensity of the one or more for light sources such as constant attenuation, linear attenuation, quadratic attenuation, etc. Likewise, for example, the parameters may include a type of light source such as spotlight, point light, etc. Likewise, for example, the parameters of a light source may include features of the type of light source such as cutoff angle of a spotlight, direction of a spotlight, exponent of a spotlight, etc. In some embodiments, a combination of any of the above may be determined for the one or more light sources.

[0052] In 208, a graphical representation of the seismic data may be generated. In embodiments, graphics hardware of the system 100 may be utilized to generate the graphical representation of the seismic data. For example, a shader program, that resides in the graphics hardware may be utilized to generate the graphical representation. The shader program may calculate the contribution for each light on seismic data, for example, the vector field data of the seismic data.

[0053] In embodiments, to generate the graphical representation, the shading based on the one or more light and the point of view may be determined for the seismic data. In some embodiments, Phong shading may be utilized to generate the graphical representation. Phong shading (or Phong interpolation or normal-vector interpolation shading) refers to an interpolation technique for surface shading in 3D computer graphics. Phong shading may interpolate surface normals across rasterized polygons and computes pixel colors based on the interpolated normals and a reflection model. In some embodiment, Phong shading may also refer to the combination of Phong interpolation and the Phong reflection model. Figure 3B illustrates Phong shading. The color of a point on the surface of an object is / = Iambwnt + Lpecuiar + hmissive + Idiffase. Figure 3C illustrates some factors influencing light seen by a user. As shown, light direction (L), surface normal (N or it), reflected light (R) and viewer direction (V) may influence light seen by a user.

[0054] In embodiments, the shading for each unit of the seismic data may be determined, for example, a pixel in 2D seismic data or a voxel in 3D seismic data. For example, a three dimensional cube may be provided, where each sample has a unit length vector being the normal of a tiny plate or lamella at that point. The amount of light reflected may then determined by the micro- structure of the lamellae, and not the macro-structure of the slice itself. In using lamellae, a connected surface or geometry may not need to be created, while still allowing application of the one or more lights.

[0055] In some embodiments, the seismic data may be dip estimation data comprising a vector field calculated from seismic data. For example, the dip estimation data may comprise a calculated dip in e.g. inline and crossline directions (i.e. 2 orthogonal directions). This produces an estimated gradient [f_x, f_y] of the seismic amplitude at that point in 3D space. The normal of a surface with gradient [f_x, f_y] is n = [f_x, f_y,— l], or normalized n = n/ ||n|| .

[0056] In some embodiments, the specular and diffusive components for the one or more light sources may be used to determining the shading for each unit of the seismic data. The specular and diffusive components may depend on the local normal vector. The diffuse contribution from a single light may be:

^diffuse ^incoming ^' kdiffuse ^' Wi lx(N L, 0),

where N and L are unit vectors representing the local surface normal and direction to the light source respectively. I incoming is the color of the light source, and kdiffuse is the base color of the surface. In an embodiment, the direction of the vector field n replaces the surface normal, thus producing the above-noted effects.

[0057] Furthermore, in some embodiments, the vector volume may be sliced in any possible way, e.g., other than planar slices. Further, a volume visualization technique may be employed to visualize the volume of lamellae. To address occlusion issues, data volume visualized may be reduced or "sculpted" using any suitable process.

[0058] In 210, the graphical representation of the seismic data may be displayed. In embodiments, the graphical representation of the seismic data may be displayed on one or more displays of the system 100. In embodiments, graphics hardware of the system 100 may be utilized to display the graphical representation of the seismic data.

[0059] Figures 4A and 4B illustrate examples of a graphical representation of the seismic data generated using the method 200. Figure 4A illustrates an example of a slice 400 illuminated with two lights different colored light from different direction, for example, one orange light to the left and a blue light to the right. The resulting image shows that the structure in the region is dipping mostly to the left or right, and direction of faults is mainly in a north-east to south-west direction. Figure 4B shows a third colored light added for a new direction, for example, a red light added to the south (down in the image) and directed to north. As may be seen, the red light may highlight east-west structure in red, in addition to the main north-south features.

[0060] In 212, it may be determined if a new point of view is selected. If a new point of view is selected, a new graphical representation of the seismic data may be generated based at least partially on the new point of view. The method 200 may return to 208 and repeat. In some embodiments, if a new point of view is selected, the display of the graphical representation may be altered. The method 200 may return to 210 and repeat. In some embodiments, the new point of view may be selected by a user of the system 100. Because graphics hardware may be utilized in generating the graphical representation, the user may select a different point of view a in realtime. This allows a user to interact with and explore the seismic data in real-time.

[0061] In 214, it may be determined if a change in the one or more light sources is selected. In some embodiments, the change in the light source may be the removal of one or more of the light source. In some embodiments, the change in the one or more light sources may be an addition of one or more light sources.

[0062] In some embodiments, the change in the light source may be a change in parameters of the one or more light sources. For example, the parameters may include color of the light source or features of the color of the light source such as ambient light, diffuse light, specular light, etc. Likewise, for example, the parameters of the light source may include a direction of the one or more light sources. Likewise, for example, the parameters may include a position of the one or more light sources. Likewise, for example, the parameters may include an intensity of the one or more for light sources such as constant attenuation, linear attenuation, quadratic attenuation, etc. Likewise, for example, the parameters may include a type of light source such as spotlight, point light, etc. Likewise, for example, the parameters of a light source may include features of the type of light source such as cutoff angle of a spotlight, direction of a spotlight, exponent of a spotlight, etc. In some embodiments, the change of the one or more light sources may be a combination of any of the above.

[0063] In some embodiments, if certain changes in the one or more light sources are selected, a new graphical representation of the seismic data may be generated based at least partially on the change in the one or more light sources. The method 200 may return to 208 and repeat.

[0064] In some embodiments, if certain changes in the one or more light sources are selected, the display of the graphical representation may be altered. The method 200 may return to 210 and repeat. For example, certain changes in the one or more light sources may not require a new graphical representation be generated and may only require a change in the current graphical representation. For example, certain changes in the one or more light sources may require a change in the shading, color, etc. of the pixels of the current graphical representation. In this example, the color, shading, etc. of the pixels of the current graphical representation may be changed based at least partially on the change in the one or more light sources. Because graphics hardware may be utilized in altering the display of the current graphical representation, the user may select a change of the one or more light sources in in real-time. This allows a user to interact with and explore the seismic data in real-time.

[0065] In some embodiments, the change in the one or more light sources may be selected by a user of the system 100. Because graphics hardware may be utilized in generating the graphical representation, the user may select a change in the one or more light sources in real-time. This allows a user to interact with and explore the seismic data in real-time. For example, referring to Figures 4 A, generating the graphical representation of Figure 4B from that of Figure 4 A may include finding a position for the third light. To find the position for the third light, the user may move the light (changing its azimuth and elevation). Since light calculations are done in graphics hardware, the user may receive instantaneous, or nearly so, feedback, which may facilitate a quick understanding the structure of the data to find a position for the third light.

[0066] In the method 200 described above, some volume visualization uses transparency to see inside the volume, where some data ranges are set transparent. In some embodiment, in the method 200, when determining the one or more light sources to visualize a vector volume, the transparency may be applied to the amount of light reflected, or the angle between the vector and each light source, or by modifying the light equations to achieve the same effects. The vectors in the vector field are not unit length, i.e. the vectors have both direction and magnitude. The magnitude may be visualized on its own, or in combination with the direction.

[0067] In some embodiment, if there is only one light with neutral color, a color-code magnitude using any standard color-scheme may be provided. Further, if there are multiple colored lights, colors may be used to encode magnitude, but it may be challenging to understand if a certain final color is due to the magnitude or the color of a light. Accordingly, greyscale may be used to encode magnitude. When using a greyscale, the physical analogy is the magnitude may determine the reflectivity of the tiny plate in the volume. The method 200 may be used in addition to or in lieu of RGB blending of any two or three measurements, where the two or three measurements may have a geometric interpretation in the surface normal formulae described.

[0068] Moreover, at least some embodiments may apply to regularly sampled cubes, while others may apply to a vector field from a continuous function in 3D space. Some embodiments may apply to both.

[0069] As described above, the method 200 may be utilized to visual seismic data. Embodiments of the present disclosure may be applied to any type of data that is represented as vector fields in general. Some examples include multi-component seismic attributes such as 3D curvature or dip estimation, material stress, and fluid flow.

[0070] In some embodiments, the methods of the present disclosure may be executed by one or more computing systems. Figure 5 illustrates an example of such a computing system 500, in accordance with some embodiments. The computing system 500 may include a computer or computer system 501 A, which may be an individual computer system 501 A or an arrangement of distributed computer systems. The computer system 501A includes one or more analysis modules 502 that are configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein. To perform these various tasks, the analysis module 502 executes independently, or in coordination with, one or more processors 504, which is (or are) connected to one or more storage media 506. The processor(s) 504 is (or are) also connected to a network interface 507 to allow the computer system 501 A to communicate over a data network 509 with one or more additional computer systems and/or computing systems, such as 501B, 501C, and/or 501D (note that computer systems 501B, 501C and/or 501D may or may not share the same architecture as computer system 501A, and may be located in different physical locations, e.g., computer systems 501A and 501B may be located in a processing facility, while in communication with one or more computer systems such as 501C and/or 501D that are located in one or more data centers, and/or located in varying countries on different continents).

[0071] A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.

[0072] The storage media 506 may be implemented as one or more computer-readable or machine-readable storage media. Note that while in the example embodiment of Figure 5 storage media 506 is depicted as within computer system 501A, in some embodiments, storage media 506 may be distributed within and/or across multiple internal and/or external enclosures of computing system 501 A and/or additional computing systems. Storage media 506 may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY^® disks, or other types of optical storage, or other types of storage devices. Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or alternatively, may be provided on multiple computer- readable or machine-readable storage media distributed in a large system having possibly plural nodes. Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture). An article or article of manufacture may refer to any manufactured single component or multiple components. The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.

[0073] In some embodiments, computing system 500 contains one or more visualization modules 508. In the example of computing system 500, computer system 501A includes the visualization module 508. In some embodiments, a visualization module 508 may be used to perform some aspects of one or more embodiments of the method 200 disclosed herein. In alternate embodiments, a plurality of visualization modules 508 may be used to perform some aspects of method 200 herein.

[0074] It should be appreciated that computing system 500 is merely one example of a computing system, and that computing system 500 may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of Figure 5, and/or computing system 500 may have a different configuration or arrangement of the components depicted in Figure 5. The various components shown in Figure 5 may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits. [0075] Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices. These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of the present disclosure.

[0076] The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or limiting to the precise forms disclosed. Many modifications and variations are possible in view of the above teachings. Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously. The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosed embodiments and various embodiments with various modifications as are suited to the particular use contemplated.

Claims

CLAIMS What is claimed is:

1. A method, comprising:

obtaining seismic data for a geological formation;

determining a point of view for viewing a graphical representation of the seismic data; determining a light source for illuminating the graphical representation of the seismic data, wherein determining the light source comprises determining a direction of the light source relative to the point of view and a color of the light source;

generating the graphical representation of the seismic data, wherein the graphical representation of the seismic data includes shading, in the color, features of the seismic data based at least partially on the point of view and the direction of the light source; and

displaying the graphical representation of the seismic data.

2. The method of claim 1, the method further comprising:

determining a new point of view for viewing the graphical representation of the seismic data;

generating a new graphical representation of the seismic data, wherein the new graphical representation of the seismic data includes new shading, in the color, features of the seismic data based at least partially on the new point of view and the direction of the light source; and

displaying the new graphical representation of the seismic data.

3. The method of claim 2, wherein generating the new graphical representation is preformed in real-time with the determining the new point of view.

4. The method of claim 1, the method further comprising:

determining a change in the light source;

generating a new graphical representation of the seismic data, wherein the new graphical representation of the seismic data includes new shading of features of the seismic data based at least partially on the point of view and the change in the light source; and

displaying the new graphical representation of the seismic data.

5. The method of claim 4, wherein generating the new graphical representation is preformed in real-time with the determining the change in the light source.

6. The method of claim 1, wherein the seismic data comprises three dimensional seismic data.

7. The method of claim 1, wherein the seismic data comprises dip estimate data for the seismic data.

8. A non-transitory computer readable medium storing instructions for causing one or more processors to perform a method comprising:

obtaining seismic data for a geological formation;

displaying the graphical representation of the seismic data.

9. The non-transitory computer readable medium of claim 8, the method further comprising: determining a new point of view for viewing the graphical representation of the seismic data;

displaying the new graphical representation of the seismic data.

10. The non-transitory computer readable medium of claim 9, wherein generating the new graphical representation is preformed in real-time with the determining the new point of view.

11. The non-transitory computer readable medium of claim 8, the method further comprising: determining a change in the light source;

displaying the new graphical representation of the seismic data.

12. The non-transitory computer readable medium of claim 11, wherein generating the new graphical representation is preformed in real-time with the determining the change in the light source.

13. A system, comprising:

one or more memory devices storing instructions; and

one or more processors coupled to the memory devices and configured to execute the instructions to perform a method comprising:

obtaining seismic data for a geological formation;

determining a point of view for viewing a graphical representation of the seismic data;

determining a light source for illuminating the graphical representation of the seismic data, wherein determining the light source comprises determining a direction of the light source relative to the point of view and a color of the light source;

displaying the graphical representation of the seismic data.

14. The system of claim 13, wherein the one or more processors are configured to execute the instructions to perform the method further comprising: determining a new point of view for viewing the graphical representation of the seismic data;

displaying the new graphical representation of the seismic data.

15. The system of claim 13, wherein the one or more processors comprise a graphics processor configured to execute the instructions to perform the generation of the graphical representation.