Patent Application
20240384652
Wellbores may be drilled into a surface location or seabed for a variety of exploratory or extraction purposes. For example, a wellbore may be drilled to access fluids, such as liquid and gaseous hydrocarbons, stored in subterranean formations and to extract the fluids from the formations. Wellbores used to produce or extract fluids may be formed in earthen formations using earth-boring tools such as drill bits for drilling wellbores and reamers for enlarging the diameters of wellbores.
Wellbores can extend deep into the earth, often up to several kilometers. It is important and often difficult to accurately detect and map features of the geological formations to identify sources of oil, gas, or other valuable resources. Typically, this is achieved by imaging the wellbore through the use of wireline tools. These tools are typically lowered into the wellbore and are equipped with sensors that measure various parameters such as gamma ray emissions, electrical resistivity, and acoustic properties of the surrounding rock. These measurements are then used to create images of the wellbore. Additional tools may also be used to take a core sample of the formation. A specialized coring bit may be implemented downhole to cut and remove a portion of the wellbore in order that it might be examined and analyzed at the surface.
Wireline tools and coring tools, however, can be expensive to operate, in part due to the fact that they can typically only be used when the well is not actively drilling. The images produced by wireline tools are often of limited resolution which can significantly limit their usefulness. Formation cores can be burdensome and expensive to collect which may limit the number of cores that may be realistically collected. Thus, techniques for imaging the wellbore while drilling and/or facilitating mapping features of the downhole formation can have significant advantages over conventional techniques, such as with wireline and coring tools.
In some embodiments, a method of imaging an earth formation includes identifying engagement data from an engagement sensor. The engagement data corresponds to an engagement of the instrumented engagement element with a borehole in the earth formation. The method includes identifying rotation data from a rotation sensor. The rotation data corresponds to a rotational orientation of the engagement data with respect to the borehole. The method includes mapping the engagement data to the rotation data to generate oriented engagement data.
In other embodiments, a method of imaging an earth formation includes identifying engagement data from an engagement sensor. The engagement data corresponds to an engagement with a borehole in the earth formation. The method includes identifying depth data from a depth sensor. The depth data corresponds to a depth of the engagement data with respect to the borehole. The method includes mapping the engagement data to the depth data to generate mapped engagement data.
In yet other embodiments, a method of imaging an earth formation includes identifying engagement data from an engagement sensor. The engagement data corresponds to an engagement with a borehole in the earth formation. The method includes identifying rotation data from a rotation sensor or identifying depth data from a depth sensor. The rotation data corresponds to a rotational orientation of the engagement data with respect to the borehole and the depth data corresponds to a depth of the engagement data with respect to the borehole. The method includes identifying lithology data from a lithology sensor. The lithology data corresponds to one or more physical properties of the earth formation. The method includes mapping the engagement data to the lithology data and the rotation data to generate mapped data or mapping the engagement data to the lithology data and the depth data to generate mapped engagement data.
In yet other embodiments, a method of determining a geological feature on an earth formation includes receiving engagement data from an engagement sensor. The engagement data corresponds to an engagement with a borehole of the earth formation. The method includes defining a data feature in the engagement data. The method includes determining a geological feature of the earth formation based on identifying a plurality of instances of the data feature that each occur periodically with respect to a rotation of the downhole tool.
In yet other embodiments, a method of mapping an earth formation includes identifying first engagement data from a first engagement sensor. The first engagement data corresponds to a first engagement with a borehole in the earth formation. The method includes identifying second engagement data from a second engagement sensor. The second engagement data corresponds to a second engagement with the borehole. The method includes mapping the first engagement data to the second engagement data to generate mapped engagement data.
This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.
Additional features and advantages of embodiments of the disclosure will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of such embodiments. The features and advantages of such embodiments may be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims. These and other features will become more fully apparent from the following description and appended claims or may be learned by the practice of such embodiments as set forth hereinafter.
In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific implementations thereof which are illustrated in the appended drawings. For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures. While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale. Understanding that the drawings depict some example implementations, the implementations will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:
This disclosure generally relates to devices, systems, and methods for mapping an earth formation or a downhole environment. For example, a drilling system may implement one or more tools for engaging a borehole. An instrumented engagement element may be implemented in conjunction with one or more downhole tools and may engage and/or degrade the borehole. The instrumented engagement element may include one or more sensors for taking engagement measurements (e.g., drilling, milling, reaming, stabilizing, steering, other measurements, or combinations thereof), such as force measurements, associated with the engagement of the engagement element with the borehole. The observed downhole measurements (and/or changes in the observed downhole measurements) facilitate determining and/or mapping one or more features of the borehole, in at least one embodiment described herein. The downhole measurement system may take one or more additional measurements of or related to the downhole environment. For example, the downhole imaging system may take force measurements, rotation measurements, depth measurements, lithology measurements, other downhole measurements (e.g., drilling, milling, reaming, stabilizing, steering, other measurements, or combinations thereof), or combinations thereof for performing one or more of the techniques described herein.
The downhole system may include a computing device which may implement a downhole imaging system. For example, the downhole imaging system may be a computer-implemented method, or one or more aspects of the downhole imaging system may be performed as a computer-implemented method. The downhole imaging system may receive one or more of the measurements discussed above as sensor data. The downhole imaging system may map (e.g., associate) the data. For example, the downhole imaging system may associate portions of the engagement measurements with portions of the other measurements (e.g., force measurements, rotation measurements, depth measurements, lithology measurements, other downhole measurements, or combinations thereof) to orient the engagement measurements, for example, with respect to the borehole. The mapped data in this way may include oriented engagement data. The downhole imaging system may map any other data or portions of data. For example, the downhole imaging system may map the engagement data to a global reference frame, for example, such that the engagement data may be associated with the earth formation generally.
The downhole imaging system may generate one or more images based on, for example, the oriented (e.g., mapped) engagement data. The images may visually present or illustrate the oriented engagement data in the form of a graph, plot, picture, other visual representation, or combinations thereof. The images may illustrate the engagement data with respect to a rotational position or local angle within the borehole. The images may illustrate the engagement data with respect to a rotational position and/or global angle within the earth formation in which the borehole is located. The images may illustrate one or more geological features, such as a crack or fracture, of the earth formation.
The downhole imaging system may identify and/or may facilitate identifying one or more geological features of the earth formation. For example, the downhole imaging system may generate feature data indicating one or more geological features of the earth formation based on the sensor data, based on the mapped data, based on the generated image, or based on any other data. The downhole imaging system may transmit data to one or more drilling devices. For example, the downhole imaging system may transmit the sensor data, mapped data, feature data, the generated images, or combinations thereof to one or more drilling devices.
As will be discussed in further detail below, the present disclosure includes a number of practical applications having features described herein that provide benefits and/or solve problems associated with identifying geological features and/or characterizing an earth formation. Some example benefits are discussed herein in connection with various features and functionalities provided by a downhole imaging system implemented on one or more computing devices. It will be appreciated that benefits explicitly discussed in connection with one or more embodiments described herein are provided by way of example and are not intended to be an exhaustive list of all possible benefits of the downhole imaging system and further are not intended to limit the scope of the claims.
For example, in order to effectively plan and execute drilling operations, it can be critical to identify and/or map geological features and/or structures of an earth formation or of a reservoir. The downhole imaging techniques discussed herein may detect and/or facilitate detecting geological features of the earth formation such as cracks, fractures, formation boundaries, formation angles, etc. Identifying and/or understanding such geological features can be invaluable for determining, for example, where underground resources may be located, how to drill through and/or penetrate certain formations, well completion strategies, risk factors associated with certain formations, among other factors. Thus, implementing the downhole imaging techniques described herein to detect and/or map geological features of the earth formation may provide significant cost, time, and/or resource savings by providing a better understanding of the formations being drilled, as well as an increased confidence in the features presumed to be present in the earth formation.
In addition to generally detecting geological features, the downhole imaging techniques described herein can generate images of the borehole to facilitate determining and/or confirming geological features. For example, engagement measurements associated with geological features may be transformed into photograph-like images of the borehole which may facilitate determining the location, orientation, size, or general presence of geological features. Indeed, the downhole imaging techniques described herein may in essence provide a photograph of the borehole.
Additionally, some conventional borehole surveying and/or characterization methods require specialized tools implemented in the borehole by stopping or pausing drilling operations. In some cases, drilling tools are removed from the borehole to perform conventional imaging techniques, resulting in costly downtime of the drilling system. The borehole images described herein may be generated based on data taken during drilling operations, and in some situations the images may also be generated during drilling operations or in real time. In this way, the earth formation may be mapped and/or characterized without the downtime expenses of some conventional methods, resulting in cost and resource savings. As such, a variety and/or any number of images may be generated of the borehole, for example, at any depth and/or for any duration (e.g., length) of the borehole. In contrast, the downtime associated with some conventional borehole characterization techniques may impose practical limits to how much or how long such techniques may be implemented. Indeed, the imaging techniques described herein may realistically be implemented to image any portion (or an entirety) of a borehole with little to no operational limits on duration, detail, etc.
Some conventional borehole surveying and/or characterization methods require specialized tools implemented in the borehole as part of the drilling tool assembly and/or as part of the BHA, such a measurement-while-drilling (MWD) and/or logging-while-drilling (LWD) tools. MWD and LWD tools are often implemented above or uphole from one or more downhole (e.g., drilling) tools such as a bit or reamer. MWD and LWD tools may take measurements and/or facilitate generating images associated with the borehole. However, because these tools are located uphole of the drilling tools (e.g., up to 100 ft), any information gathered by these measurement tools can realistically only be used to make delayed decisions regarding the operation of the drilling tools located further down the borehole. In other words, MWD and LWD tools cannot practically be implemented to make real-time decisions concerning, for example, a present engagement and/or a present formation associated with one or more drilling tools. In contrast, the techniques described herein may be implemented to take measurements at a point of engagement of one or more drilling tools with the earth formation. In this way, real-time information relevant to an immediate proximity of the drilling tools may be used to inform decisions about the operation of the drilling tools.
Additionally, while conventional MWD and LWD tools may take measurements and/or facilitate generating images of the borehole, such measurements and/or images are typically of limited resolution. The imaging techniques of the present disclosure may generate images of improved resolution over, for example, conventional borehole images. MWD and LWD imaging tools are also typically quite expensive to both manufacture and to implement downhole. Exposing expensive instrumentation to the harsh downhole environment presents the possibility that the instrumentation may become damaged or lost. In contrast, the imaging techniques described herein may be implemented through simple and inexpensive instrumentation in connection with engagement elements that may already be designed and/or configured to withstand the harsh environment downhole.
Further, one technique that is conventionally used to gather and/or analyze specific information about an earth formation is the technique of taking a core sample. A special bit is implemented downhole to remove and bring to the surface a sample of the borehole in order that it may be analyzed to gather information about the earth formation. This can be costly and time consuming as it requires stopping drilling operations as well as removing downhole tools from the borehole. The imaging techniques described herein can generate a virtual core image by incorporating lithology data (e.g., data associated with physical properties of the earth formation) into the images described above. In this way, a virtual representation of a core sample may be analyzed in much the same way as is conventionally completed to characterize the earth formation, but without the costly downtime. Thus, a virtual core image may provide significant cost and resource savings over conventional core sampling techniques.
As illustrated in the foregoing discussion and as will be discussed in further detail herein, the present disclosure utilizes a variety of terms to describe features and advantages of the methods and systems described herein. Some of these terms will be discussed in further detail below.
As used herein, a “data feature” may refer to any feature or distinguishable instance of the data or a portion of the data. For example, a data feature may correspond with one or more instances of the data over, under, or within a threshold value, or instances of a threshold change in the data. A data feature may correspond to one or more instance of the data that occurs a threshold number of times. A data feature may correspond to one or more instances that deviate or occur outside a threshold level, expected range, or other defined limit of the data. Indeed, a data feature may be any other element, aspect, pattern, variance, outlier, or correlation of the data, and combinations thereof.
As used herein, “borehole feature” may refer to a physical feature present or detected in the borehole. For example, a borehole feature may be a crack or fracture detected in a portion of the borehole. A borehole feature may correspond to or may be identified based on a data feature, for example, oriented with respect to a local reference frame of the borehole. For example, a borehole feature may be an indication of a crack in the borehole at an angle of 95° within the borehole. In this way, a borehole feature may be a local indication of a physical feature present or detected in the borehole (e.g., as opposed to a global indication of a physical feature of the earth formation at large).
As used herein, “geological feature” may refer to a physical feature present or detected in the earth formation in which the borehole is located. For example, a geological feature may be a crack or fracture detected in relation to or associated with the greater earth formation. A geological feature may correspond to or may be identified based on data features and/or borehole features, for example, oriented with respect to a global reference frame of the earth formation at large. For example, a geological feature may be an indication of a crack in the earth formation that runs cast to west. In this way, a geological feature may be a global indication of a physical feature present and/or detected in the earth formation generally.
As used herein, “borehole image” may refer to an image that is associated with a borehole in an earth formation or associated with the removal of material from the earth formation to form a borehole. In some situations, a borehole image may correspond to a borehole of a finished or completed diameter such that the image substantially resembles or represents a view of, for example, an inner wall or circumference of the finished borehole. In some situations, a borehole image may correspond to an intermediate or temporary diameter of a borehole that may be further expanded to a completed diameter. In this way, the borehole image may represent or may substantially resemble a borehole wall of a reduced diameter that may no longer exist within the borehole or may correspond to formation material that has been removed downhole such that it may no longer be visible, for example, upon physical inspection.
The drill string 105 may include several joints of drill pipe 108 connected end-to-end through tool joints 109. The drill string 105 transmits drilling fluid through a central bore and transmits rotational power from the drill rig 103 to the BHA 106. In some embodiments, rotational power is transmitted by one or more mud motors located in the borehole 102. In some embodiments, the drill string 105 further includes additional components such as subs, pup joints, etc. The drill pipe 108 provides a hydraulic passage through which drilling fluid is pumped from the surface. The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit 110 for the purposes of cooling the bit 110 and cutting structures thereon, and for lifting cuttings out of the borehole 102 as it is being drilled.
The BHA 106 may include the bit 110 or other components. An example BHA 106 may include additional or other components (e.g., coupled between to the drill string 105 and the bit 110). Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (“MWD”) tools, logging-while-drilling (“LWD”) tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing. The BHA 106 may further include a rotary steerable system (RSS). The RSS may include directional drilling tools that change a direction of the bit 110, and thereby the trajectory of the borehole 102. At least a portion of the RSS may maintain a geostationary position relative to an absolute reference frame, such as gravity, magnetic north, and/or true north. Using measurements obtained with the geostationary position, the RSS may locate the bit 110, change the course of the bit 110, and direct the directional drilling tools on a projected trajectory.
In general, the drilling system 100 may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves). Additional components included in the drilling system 100 may be considered a part of the drilling tool assembly 104, the drill string 105, or a part of the BHA 106 depending on their locations in the drilling system 100.
The drilling system 100 may include a sensor 111. For example, the sensor 111 may be located in a downhole tool of the drilling system 100, such as the bit 110, a reamer, a stabilizer, or any other downhole tool. The sensor 111 may be an engagement sensor. For example, the sensor 111 may take one or more engagement measurements corresponding with an engagement with the borehole. The sensor 111 may be included in an instrumented engagement element implemented in the bit 110. The sensor 111 may be a force sensor for measuring a force associated with the instrumented engagement element engaging the borehole 102. The bit 110 in the BHA 106 may be any type of bit suitable for degrading downhole materials. For instance, the bit 110 may be a drill bit suitable for drilling the earth formation 101. Example types of drill bits used for drilling earth formations are fixed-cutter or drag bits. In other embodiments, the bit 110 may be a mill used for removing metal, composite, elastomer, other materials downhole, or combinations thereof. For instance, the bit 110 may be used with a whipstock to mill into casing 107 lining the borehole 102. The bit 110 may also be a junk mill used to mill away tools, plugs, cement, other materials within the borehole 102, or combinations thereof. Swarf or other cuttings formed by use of a mill may be lifted to surface or may be allowed to fall downhole.
The drilling system 100 may include a computing device 112. The computing device may be in data communication with the sensor 111 for receiving one or more signals from the sensor 111. In some embodiments, the computing device 112 is located at the surface of the borehole 102. For example, the computing device 112 may be a drilling computer or any other user equipment at the surface of the borehole 102 (e.g., located at or associated with the drill rig 103). In some embodiments, the computing device 112 is located in the borehole 102. For example, the computing device may be associated with and/or located in a component of the drilling tool assembly such as at a downhole tool (e.g., the bit 110). The computing device 112 may be located in close proximity to the sensor 111 in the borehole 102 or may be located at another location within the borehole 102. In this way the sensor 111 may transmit one or more signals to the computing device 112, such as one or more measurements taken in the borehole 102.
The computing device 112 may include a downhole imaging system 120 for performing one or more of the downhole imaging techniques described herein. For example, the computing device may include a processor and memory. The memory may contain one or more instructions which, when executed, cause the processor to perform one or more functions of the downhole imaging system 120, as will be described herein in detail.
In some embodiments, the bit 210 includes an instrumented engagement element 216. The instrumented engagement element 216 may include instrumentation (e.g., a sensor) for taking one or more downhole measurements with the bit 210. For example, the instrumented engagement element 216 may include one or more sensors for measuring force, pressure, temperature, etc.
In accordance with at least one embodiment of the present disclosure, the instrumented engagement element 216 includes a sensor engagement element and an engagement sensor. The instrumented engagement element 216 may engage (e.g., contact, press against, degrade) a borehole, and the sensor may take measurements, for example, corresponding to forces on the instrumented engagement element 216. For example, the instrumented engagement element 216 may contact or engage the borehole as the bit 210 rotates, and the instrumented engagement element 216 may experience changing dynamics (e.g., forces) as it passes over and/or past physical features of the borehole. These changes may be measured by the engagement sensor. The instrumented engagement element 216 may be in data communication with a computing device (such as the computing device 112 of
Although
The embodiments shown herein illustrate downhole tools (e.g., bits) having instrument assemblies with various components having specific configurations and/or orientations. It should be understood, however, that the instrument assembly of the present disclosure is not limited to implementation in only a bit of a drilling system. Rather, the techniques described herein may be employed in connection with any downhole tool. For example, one or more instrumented engagement elements 216 as described herein may be implemented in a reamer, a stabilizer, or any other downhole tool (e.g., downhole tools that contact and/or engage an inner wall of the borehole).
Additionally, it should be understood that the instrumented engagement elements 216 described herein in various embodiments are not limited to engagement elements that cut, or configurations where the borehole is being cut, lengthened, widened, etc. To this end, the instrumented engagement elements 216 may be any type of engagement elements for engaging or interfacing with the borehole. For example, one or more downhole tools may implement an instrumented engagement element 216 with an ultrahard (e.g., diamond) tip or coating that is not necessarily intended to or limited to cutting the formation. For example, a stabilizer may include one or more instrumented engagement elements 216 (such as a stabilizer pad) for engaging the borehole for the purpose of stabilizing or centering one or more components of the drilling tool assembly, as opposed to cutting. Such instrumented engagement elements 216 may be implemented in order to perform the techniques described herein. Other downhole tools may implement other engagement elements for the purpose of engaging the borehole that may not necessarily be limited to cutting. In other words, the instrumented engagement elements 216 described herein may be any engagement elements implemented in connection with any downhole tool.
Further, it should be understood that the instrumented engagement elements 216 of the present disclosure are not limited to only the configurations and/or orientations illustrated and described herein. For example, an instrumented engagement element 216 may be oriented at an angle from vertical, in a radial or outward direction, or any other orientation for engaging the borehole as described herein. In this way, any type of downhole tool may include an instrument assembly (including an engagement element) having any configuration for taking downhole measurements, and the instrument assembly may be configured, oriented, and adapted to function in accordance with the manner in which a given downhole tool engages the borehole.
By way of example, as will be discussed below, one or more features of the downhole imaging system 320 may be delegated to other components of the downhole imaging system 320. As another example, while mapping of sensor data may be performed by a mapping engine 322, in some instances some or all of these features may be performed by a feature detection manager 323 (or other component of the downhole imaging system 320). Indeed, it will be appreciated that some or all of the specific components may be combined into other components and specific functions may be performed by one or across multiple of the components 321-325 of the downhole imaging system 320.
As just mentioned, the downhole imaging system 320 includes a sensor data manager 321. The sensor data manager 321 may receive downhole measurements 317 from one or more sensors 311. For example, the sensors 311 may include an engagement sensor and/or a rotation sensor which may communicate engagement measurements and/or rotation measurements to the sensor data manager 321. The downhole measurements 317 may be measurements that are taken, for example, in the borehole. The downhole measurements 317 may be measurements taken at the surface, or at any other location. In this way, the downhole measurements are not limited to measurements taken downhole, but rather may include any measurement relevant to downhole drilling or a drilling system, as described herein. In some embodiments, the sensor data manager 321 receives the downhole measurements 317 and records or stores the downhole measurements 317 to the data storage 326 as sensor data 327. For example, the sensor data manager 321 may store, as sensor data 327, one or more raw signals associated with the downhole measurements 317. In another example, the sensor data manager 321 may perform one or more operations on the downhole measurements 317 (e.g., the raw signal) to one or more of alter, adjust, filter, compress, amplify, segment, and combine the downhole measurements 317. This may be prior to storing the downhole measurements 317 as sensor data 327 or may be in addition to storing the raw signals of the downhole measurements 317 as sensor data 327. In some embodiments, the sensor data manager 321 transmits or communicates the sensor data 327 to one or more components of the downhole imaging system 320, such as the mapping engine 322. In this way, the downhole imaging system 320 may receive and/or store one or more downhole measurements 317 from the sensors 311.
As mentioned above, the downhole imaging system 320 includes a mapping engine 322. In some embodiments, the mapping engine 322 receives data, such as sensor data 327, from the sensor data manager 321. The mapping engine 322 may also accesses the data storage 326 to receive data. The mapping engine 322 may map any of the data accessible to the downhole imaging system 320. For example, the mapping engine 322 may associate one or more specific instances of data with one or more other specific instances of data. In this way, the mapping engine 322 may generate mapped data 328. The mapping engine 322 may store the mapped data 328 to the data storage 326.
As mentioned above, the downhole imaging system 320 includes a feature detection manager 323. In some embodiments, the feature detection manager 323 detects and/or facilitates detecting data features, borehole features, geological features, other downhole features, or combinations thereof. For example, the feature detection manager 323 may analyze (e.g., perform one or more operations on) data it receives to determine data features and/or corresponding geological features of the earth formation. The feature detection manager 323 may detect features in any data and/or may incorporate any type of data in order to determine features, such as incorporating user input or incorporating image data. The feature detection manager 323 may generate and/or store an indication of the detected features as feature data 329. In this way, the downhole imaging system 320 may identify data features, borehole features, geological features, other downhole features, or combinations thereof.
As mentioned above, the downhole imaging system 320 includes an image generation engine 324. In some embodiments, the image generation engine 324 generates image data 330 which may include one or more plots, graphs, images, pictures, maps, any other visual representations, or combinations thereof based on any of the data discussed herein. For example, the image data 330 may present engagement measurements (e.g., force) with respect to rotation measurements. The image generation engine 324 may apply a color scale and/or color spectrum to data and in this way generate a photograph-like representation of the borehole. The color scale/color spectra as described herein may include grayscale scales/spectra. The image generation engine 324 may incorporate lithology data with the image and in this way generate a virtual representation of a core sample of the earth formation including an illustration of one or more physical properties of the earth formation. In some embodiments, the image data 330 illustrates one or more borehole features and/or geological features. This may facilitate identifying the geological features, such as by the feature detection manager 323. In this way, the downhole imaging system 320 may generate image data 330.
As mentioned above, the downhole imaging system 320 includes a communication module 325. The communication module 325 may be configured to communicate with one or more drilling devices. The communication module 325 may communicate any of the data described herein. The communication module 325 may communicate with one or more drilling devices located at the surface and/or located in the borehole. In this way, the data collected and/or processed and/or generated by the downhole imaging system 320 may be transmitted to one or more devices associated with the drilling system.
In some embodiments, the downhole imaging system 320 includes data storage 326 with a variety of data and/or types of data stored thereon. For example, the data storage 326 may store one or more of the sensor data 327, the mapped data 328, the feature data 329, and the image data 330. In some embodiments, the data storage 326 stores borehole data 331. The borehole data 331 may include and/or identify information about the borehole with respect to the earth formation, or with respect to a global reference frame of the earth formation. For example, the borehole data may include an azimuth, inclination, and a geographic location of the borehole with respect to the global reference frame of the earth formation. The borehole data 331 may include any other information relevant to globally orienting the borehole.
The techniques discussed herein (the various embodiments of the downhole imaging system described herein) may be discussed in some instances with respect to a flow of information, or with respect to one or more components of the downhole imaging system transmitting and/or passing data to one or more other components of the downhole imaging system. It should be understood, however, that in some situations, such a flow of information may be an illustrative tool useful for describing one or more aspects of the present invention, and not meant as a limit or a requirement that information be transmitted from one component to another. For example, in some situations, one or more components of a downhole imaging system may access a data storage to access and/or retrieve data rather than receiving the data directly from another component. In this way, one or more data elements may be transmitted between the various components of a downhole imaging system and/or the various components may access a data storage to access one or more data elements.
As just mentioned, the downhole imaging system 420 includes a sensor data manager 421. The sensor data manager 421 may be in data communication with one or more sensors 411. The sensor data manager 421 may receive one or more downhole measurements 417 from the one or more sensors 411.
In some embodiments, the sensors 411 include an engagement sensor 432. The sensor data manager 421 may receive one or more signals from the engagement sensor 432 as engagement data 433. The engagement data 433 may include one or more engagement measurements taken by the engagement sensor 432, for example, corresponding with an engagement of a downhole tool (e.g., a bit) with a borehole. For example, a bit may include an instrumented engagement element, and the instrumented engagement element may include the engagement sensor 432. The instrumented engagement element may be configured to engage a borehole, for example, during drilling with the bit. The instrumented engagement element may experience dynamics (e.g., axial forces) due to its engagement with the borehole. These dynamics may change as the instrumented engagement element passes over and/or past physical features of the borehole (e.g., due to the rotation of the bit). The engagement sensor 432 may measure the corresponding dynamics and/or changes in dynamics and may transmit these measurements to the sensor data manager 421 as the engagement data 433. In some embodiments, the sensor data manager 421 stores the engagement data 433 to a data storage 426 of the downhole imaging system 420. For example, the sensor data manager 421 may store the engagement data 433 as part of sensor data 427. In this way, the downhole imaging system 420 may receive the engagement data 433, and the engagement data 433 may be accessible to one or more components of the downhole imaging system 420.
In some embodiments, the engagement data 433 is based on or associated with one or more forces experienced or exhibited by the instrumented engagement element. For example, the engagement sensor 432 may measure force, strain, stress, pressure, deformation, deflection, displacement, any other parameter associated with an engagement of the instrumented engagement element with the borehole, and combinations thereof. In some embodiments, the engagement sensor 432 measures force, either directly or through one or more other parameters calibrated for force (e.g., used to calculate force). The engagement sensor 432 may include a strain gauge, hall effect sensor, magnet, capacitive sensor, spring sensor, any other sensor for sensing dynamics related to an engagement with the borehole, and combinations thereof.
In some embodiments, the sensors 411 include a rotation sensor 434. The sensor data manager 421 may receive one or more signals from the rotation sensor 434 as rotation data 435. The rotation data 435 may include one or more rotation measurements taken by the rotation sensor 434, for example, corresponding to a rotational orientation of the engagement data 433. In some embodiments, the rotation data 435 measures a rotational movement of one or more of the sensors 411, such as the engagement sensor 432. For example, a BHA component implementing the engagement sensor 432 may rotate within, or with respect to the borehole. The rotation of the BHA (e.g., including a bit, a reamer, a stabilizer, an RSS, other BHA components, or combinations thereof) may facilitate and/or may correspond with the engagement sensor 432 taking and/or measuring the engagement data 433. In some embodiments, the rotation data 435 is not measuring a rotational movement of the engagement sensor 432 but may instead measure a rotational orientation of the engagement data 433 with respect to the borehole. For example, the rotation data 435 may be a measurement of one or more (e.g., static) aspects and/or features of the borehole, and the rotation data 435 may be used to orient the engagement data 433 by associating or mapping one or more data features in the engagement data 433 with the borehole features of the rotation data 435. Aspects and features may be, for example, correlated to assemble the downhole data to reflect the actual orientation of the characteristics of the borehole. For example, as shown in
In some embodiments, the sensor data manager 421 stores the rotation data to the data storage 426. For example, the sensor data manager 421 may store the rotation data 435 as part of the sensor data 427. In this way, the downhole imaging system 420 may receive the rotation data 435 and the rotation data 435 may be accessible to one or more components of the downhole imaging system 420, for example, to facilitate mapping or orienting the engagement data 433.
In some embodiments, the sensors 411 include a depth sensor 436. The sensor data manager 421 may receive one or more signals from the depth sensor 436 as depth data 437. The depth data 437 may include one or more depth measurement taken by the depth sensor 436, for example, corresponding to a depth of the downhole tool. The depth data 437 may correspond to a depth at which the engagement data 433 (or any other downhole measurements 417) were taken. For example, the depth data 437 may indicate a depth of the downhole tool at all instances of the engagement data 433. In another example, the depth data 437 may indicate a depth of the downhole tool at some of the instances of the engagement data 433, such as at instances of interest in the engagement data 433. The depth data 437 may be taken based on a timing and/or a duration of one or more downhole operations. In some embodiments, the depth data 437 is associated with the rotation data 435. For example, the rotation data 435 may identify and/or track each revolution of the downhole tool, and the depth data 437 may indicate a depth corresponding to each revolution. In this way, the depth data 437 may facilitate mapping a depth associated with one or more portions of the sensor data 427. In some embodiments, the sensor data manager 421 stores the depth data 437 as part of the sensor data 427. In this way, the downhole imaging system 420 may receive the depth data 437 and the depth data 437 may be accessible to one or more components of the downhole imaging system 420.
In some embodiments, the sensors 411 include a lithology sensor 438. The sensor data manager 421 may receive one or more signals from the lithology sensor 438 as lithology data 439. The lithology data 439 may include one or more measurements corresponding to the lithology and/or minerology of the earth formation. For example, the lithology data 439 may include one or more measurements corresponding to a physical property of the earth formation. The measurements may be taken based on density, resistivity, gamma ray, nuclear spectroscopy, size and shape of portions of the formation, any other physical property, and combinations thereof. The lithology data 439 may facilitate creating or generating an image of the borehole, such as a virtual core image, as will be discussed herein in detail.
In some embodiments, the lithology data 439 is taken in the borehole. For example, the lithology sensor 438 may be included as part of the BHA. In some embodiments, the lithology sensor 438 is not part of the BHA, such as a wireline tool. In some embodiments, the lithology data 439 is not taken in the borehole. For example, the lithology data 439 may be taken by analyzing cuttings that are brought to the surface. In some embodiments, the lithology data 439 is taken while drilling. In some embodiments the lithology data 439 is taken after stopping or pausing drilling operations. In some embodiments, the sensor data manager 421 stores the lithology data 439 as part of the sensor data 427. In this way, the downhole imaging system 420 may receive the lithology data 439 and the lithology data 439 may be accessible to one or more components of the downhole imaging system 420.
In some embodiments, the downhole imaging system 420 (more specifically the sensor data manager 421) is in data communication with one or more sensors 411 in addition to those shown in
As mentioned above, the downhole imaging system 420 includes data storage 426. The data storage may include a variety of data and/or types of data stored thereon, such as the sensor data 427. In some embodiments, the data storage 426 includes borehole data 431. The borehole data 431 may include and/or identify information about the borehole and/or the earth formation. For example, the borehole data 431 may include and/or identify an orientation, length, angle, azimuth, inclination, size, other characteristic of the borehole, or combinations thereof. In some embodiments, the borehole data 431 identifies one or more aspects of the borehole with respect to the earth formation. For example, the borehole data 431 may identify geographic information associated with the borehole such as GPS coordinates, latitude and longitude, elevation, geographic location and/or orientation relative to other boreholes or geographic features, cardinal orientation of the borehole, any other borehole information, or combinations thereof. In this way, the borehole data 431 may facilitate associating and/or orienting one or more portions of the sensor data 427 with respect to the earth formation or with respect to a geographic and/or global reference frame. For example, one or more techniques describe herein may associate and/or orient data with respect to the borehole. The borehole data 431 (e.g., the geographic and/or global nature of the borehole data 431) may facilitate associating that data with respect to the earth formation or orienting the data with respect to a global frame. This may, for example, facilitate associating one or more data features and/or borehole features to geological features of the earth formation in which the borehole is located.
In some embodiments, at least a portion of the borehole data 431 is input into the downhole imaging system 420. For example, geographic information associated with the borehole may be provided to the downhole imaging system 420 (e.g., by a user). In some embodiments, one or more portions of the borehole data 431 may be identified by the downhole imaging system 420. For example, the downhole imaging system 420 may be in data communication with (e.g., via the sensor data manager 421) to one or more sensors that may detect and/or measure one or more portions of the borehole data 431. In another example, the downhole imaging system 420 may be in data communication with (e.g., via the communication module 425) one or more computing devices (e.g., drilling devices), and may receive one or more portions of the borehole data 431 from these computing devices. In this way the borehole data 431 may include any data relevant to a global reference frame of the earth formation.
As mentioned above, the downhole imaging system 420 includes a mapping engine 422. The mapping engine 422 may receive one or more portions of the sensor data 427 from the sensor data manager 421. For example, the sensor data manager 421 may transmit the engagement data 433 and/or the rotation data 435 to the mapping engine 422. The mapping engine 422 may receive any other data accessible to the downhole imaging system 420. The mapping engine 422 may map one or more portions of data to one or more other portions of data to generate mapped data 428. For example, the mapping engine 422 may associate specific instances in the engagement data 433 to a specific angle or rotational position within the borehole based on the rotation data 435 (e.g., to generate oriented engagement data as described herein). In another example, the mapping engine 422 may map oriented engagement data to a geographic or global reference frame based on the borehole data 431. In another example, the mapping engine 422 may associate specific instances in the engagement data 433 to a specific depth in the borehole based on the depth data 437. In some embodiments, the mapping engine 422 may map data by generating or quantifying one or more relationships between data sets. For example, the mapping engine 422 may fit a line of best fit to one or more sets of data, fit one or more sets of data to line or curve, compensate and/or adjust one or more sets of data to correlate to other data sets, any other technique to relate one or more sets of data to other data, and combinations thereof. The mapping engine 422 may map any combination of the sensor data 427 (or any other data accessible to the downhole imaging system 420) as described herein. In this way, the mapping engine may generate the mapped data 428 which may facilitate one or more of the imaging and/or feature detection techniques described herein.
In some embodiments, the mapping engine 422 transmits and/or passes data to one or more components of the downhole imaging system 420. For example, the mapping engine 422 may transmit data to a feature detection manager 423. In another example, the mapping engine 422 may transmit data to an image generation engine 424. In another example, the mapping engine 422 may transmit data to a communication module 425. In some embodiments, the mapping engine transmits the mapped data 428. In some embodiments, the mapping engine transmits the sensor data 427, for example, without mapping one or more portions and/or combinations of the sensor data 427. The mapping engine 422 may transmit any other data and/or combination of data.
In accordance with at least one embodiment of the present disclosure, the sensor data manager 521 transmits engagement data 533 and rotation data 535 to the mapping engine 522. In some embodiments, the mapping engine 522 maps the engagement data 533 to the rotation data 535 and generates oriented engagement data 542. For example, one or more specific instances in the oriented engagement data 542 may correspond to one or more angles of rotation within the borehole (e.g., 95° in the borehole).
In some embodiments, the rotation data 535 measures a rotational movement of the downhole tool. For example, a rotation sensor associated with the rotation data 535 may include a gyroscope, accelerometer, magnetometer, RPM sensor, any other sensor for measuring rotational movement, and combinations thereof. The engagement data 533 may be time-domain engagement data, and the mapping engine 522 may map the time-domain engagement data to the rotation data 535 in order to generate the oriented engagement data 542 (e.g., force or other dynamics with respect to rotational position and/or angle). The rotation data 535 being measurements of the movement of the downhole tool in this way may facilitate taking the rotation data 535 during downhole activities, such as during drilling with a bit, reaming with a reamer, stabilizing with a stabilizer, steering with an RSS.
In some embodiments, the rotation data 535 measures a rotational position of the downhole tool, or measures one or more aspects of the borehole (e.g., static aspects) associated with rotation position of the engagement data 533. For example, a rotation sensor may measure and/or detect one or more (e.g., static) aspects of the borehole (including an orientation and/or angular position of theses aspects) and the mapping engine 522 may correlate these aspects with one or more instances in the engagement data 533 in order to orient the engagement data 533 (e.g., to generate the oriented engagement data 542). In some embodiments, the rotation sensor measures the aspects of the borehole after the engagement sensor (e.g., the instrumented engagement element) has passed over or past a given location of the borehole. For example, the rotation sensor may be located at a distinct location of a drilling tool assembly from the engagement sensor. In another example, the rotation sensor may be implemented downhole (e.g., on a wireline tool) after stopping or pausing drilling operations, such as when a drill string is tripped from the borehole.
In this way, the mapping engine 522 may generate the oriented engagement data 542 by mapping the engagement data 533 to the rotation data 535, in at least one embodiment. In some embodiments, the mapping engine 522 transmits the oriented engagement data 542 to one or more components of the downhole imaging system 520. In some embodiments, the mapping engine stores the oriented engagement data 542 to a data storage of the downhole imaging system 520 (e.g., as mapped data 328 of
In accordance with at least one embodiment of the present disclosure, the mapping engine 622 transmits oriented engagement data 642. The oriented engagement data 642 may be engagement data mapped to rotation data in order to locally orient the engagement data with respect to an angle or rotational position within the borehole. In some embodiments, the mapping engine 622 transmits the oriented engagement data 642 to the image generation engine 624.
In some embodiments, the image generation engine 624 generates image data 630. The image data 630 may include one or more of a plot, graph, image, picture, map, or any other visual representation. The image generation engine 624 may generate the image data 630 based on data received from the mapping engine 622. For example, the image data 630 may be generated based on the oriented engagement data 642. The image data 630 may illustrate a visual representation of the oriented engagement data 642. For example, the image data 630 may illustrate specific instances of engagement of the oriented engagement data 642 with respect to a rotational position or local angle of the engagement data within the borehole. The image data 630 may substantially resemble a picture or photograph of the borehole, or more specifically, a portion of the borehole engaged by or removed by an instrumented engagement element of a downhole tool. For example, discreet intervals, instances, or groupings of the oriented engagement data 642 may be represented by individual pixels which, when compiled together, present a photographic-like representation of the borehole.
The image data 630 may include or may illustrate or visually distinguish one or more data features of the oriented engagement data 642. For example, the data features may be represented in the image data 630 by different colors and/or different shades of color. In some embodiments, the data features correspond to one or more revolutions of the downhole tool (e.g., successive revolutions). The data features may correspond to one or more borehole features. For example, the data features may be identifiable in the image data 630 as one or more cracks, fractures, veins, etc. oriented locally with respect to the borehole.
In some embodiments the borehole features correspond to and/or may facilitate identifying one or more geological features of an earth formation in which the borehole is located. For example, the mapping engine may map global geographic data (e.g., borehole data 431 of
The image generation engine 624 is not limited to generating image data 630 based on the oriented engagement data 642 but may generate image data 630 based on any data. For example, the image data 630 (and the techniques described related to the image data 630) may illustrate any combination of the sensor data described herein (whether mapped or not mapped). For example, the image data 630 may illustrate engagement data with respect to depth data. The image data 630 may illustrate any combination of the sensor data with respect to the borehole data described herein. In this way, the image generation engine 624 may generate image data 630 including any number of images illustrating any number and/or combinations of data accessible to the downhole imaging system 620.
In some embodiments, the image generation engine generates an image based on oriented engagement data, for example, engagement data locally oriented with respect to a borehole (e.g., based on rotation data). As shown in
In some embodiments, the pixels 744 are positioned and/or oriented adjacent one another based on a rotational position and/or borehole angle 741-1 associated with the pixels 744. For example, each line of resolution of the image data 730-1 may be made of up sequential pixels corresponding to sequential engagement measurements from the same revolution of a downhole tool. In this way, the image data 730-1 may span from a borehole angle 741-1 of 0° on a first side 745 of the image to a borehole angle 741-1 of 360° on a second (opposite) side 746 of the image. The borehole angles 741-1 from 0° to 360° may represent a local reference frame of a borehole. Accordingly, adjacent (horizontal) lines of resolution in the image data 730-1 may represent sequential revolutions of the downhole tool within the borehole. For example, as shown in
The image data 730-1 may represent or illustrate one or more borehole features. For example, some borehole features may correspond with a higher or lower engagement measurement by the engagement sensor. These differences in magnitude (or changes in magnitude) may be illustrated in the image data 730-1. More specifically, the image data 730-1 may illustrate one or more fractures of cracks 747 (e.g., voids) as areas of lower magnitude. The image data 730-1 may illustrate a substrate 748 (e.g., formation material) as an area of higher magnitude. The borehole features illustrated in the image data 730-1 may facilitate identifying one or more borehole features of interest, as described herein (and one or more geological features of interest once oriented to a global reference frame).
In some embodiments, the image generation engine incorporates and/or illustrates other data and/or combinations of data in addition to (or in place of) the oriented engagement data. For example, the image data 730-1 may illustrate or may indicate a depth of the downhole tool, or a depth associated with the oriented engagement data. The depth may be illustrated or indicated, for example, in place of (or in addition to) the quantity of revolutions in the image data 730-1. In this way, the image data 730-1 may indicate a depth (e.g., a depth below the surface) where one or more borehole features are located.
In some embodiments, the image generation engine generates image data based on borehole data (e.g., geographic data relating to a global reference frame of the borehole). For example, as shown in
The various image data described herein may facilitate characterizing one or more aspects of the earth formation in which the borehole is located. For example, certain geological features may be of interest for determining where underground resources are likely to be located, such as hydrocarbons or geothermal energy. Certain geological features may be of interest in determining well completion strategies. In this way, the image data generated by the image generation engine may be advantageous for the effective and efficient operation of a drilling system, as described herein, in at least one embodiment.
In some embodiments, the image generation engine generates image data having one or more 3-dimensional aspects (or partial 3-dimensional aspects). For example, as shown in
In some embodiments, the image generation engine generates image data illustrating or incorporating two or more images. As shown in
In some embodiments, supplemental data is interpolated between the two or more images of image data 730-4. Spaces between the images or gaps between the data of the two images may be filled or populated with supplemental (interpolated) data in order to generate a solid, 3-dimensional representation of the borehole. For example, two sets of oriented engagement data may be the basis of two images, and supplemental oriented engagement data may be interpolated from the two sets of oriented engagement data, or from the two images. In this way, the image data 730-4 may be more robust by providing and/or illustrating more engagement data through a solid, 3-dimensional representation. This may help to better identify borehole and/or geological features in the image data 730-4 by, for example, increasing a confidence that a borehole feature identified in the image data 730-4 is actually a borehole feature present in the borehole. For example, a borehole feature that appears on more than one image of the multiple images of image data 730-4 may correspond to an increased probability of the illustrated borehole feature actually being present in the borehole (e.g., as opposed to an error with the sensor). In this way, a variety of types of images may be generated from the sensor data to represent one or more aspects of the borehole and/or the earth formation.
In some embodiments, the image generation engine generates a virtual core of the borehole. For example, as shown in
The virtual core of image data 730-5 may provide numerous benefits. For example, the virtual core providing an illustration of the lithology data may inform decisions about drilling technique, equipment selection, well completion strategies, etc. based on one or more physical properties of the earth formation indicated by the virtual core. For example, knowing information about the material makeup of the formation may facilitate determining that some formations are more prone to collapse or erosion during drilling, determining that some formations are more likely to have high oil and gas yields, determining the permeability of the earth formation, determining other formation characteristics, or combinations thereof. In this way, the virtual core may facilitate making critical decisions regarding the operation of a drilling system.
The feature detection manager 823 may receive and/or access any data accessible to the downhole imaging system 820. For example, the feature detection manager 823 may receive sensor data, mapped data (e.g., oriented engagement data), image data, borehole data, any other type or form of data, and combinations thereof. In accordance with at least one embodiment of the present disclosure, the feature detection manager 823 receives mapped data 828. The feature detection manager 823 may receive the mapped data 828 from the mapping engine 822 or may access a data storage of the downhole imaging system 820 to receive data. The mapped data 828 may be any data (e.g., sensor data) that has been mapped, at least in part, to any other data. For example, the mapped data may be oriented engagement data as described herein. In some embodiments, the mapped data 828 is oriented engagement data that has been mapped to a global reference frame, for example, based on borehole data as described herein.
In some embodiments, the feature detection manager 823 detects data features data in the data it receives. For example, the feature detection manager may perform one or more operations on data of the downhole imaging system 820 to analyze the data and detect data features. As described herein, the data features may be one or more instances of interest in the data (e.g., instances of force or changes in force at a threshold level). In some embodiments, the data features may be instances of interest in the data due to a periodic nature of the instances. For example, one or more data features may occur periodically with respect to a rotational orientation of the data, or with respect to a rotation of a downhole tool. The data feature may occur in substantially the same or similar or an adjacent location with respect to each period or rotation. In this way, multiple and/or successive revolutions of the data (e.g., of the downhole tool) may together form a data feature, or a data feature may be of interest due to the repetitive and/or periodic nature of the data feature. In this way, frequently-occurring and/or periodic data features may correspond to and/or indicate one or more borehole features and/or geological features.
The feature detection manager 823 may detect data features in any of the data and/or combinations (e.g., mappings) of data it receives. For example, the feature detection manager 823 may detect features in the mapped data 828. In another example, the feature detection manager 823 may detect data features in oriented engagement data as described herein. The feature detection manager may detect data features in image data that it receives, for example, from an image generation engine of the downhole imaging system 820.
In accordance with at least one embodiment of the present disclosure, the feature detection manager 823 detects data features in oriented engagement data mapped to and/or oriented to the global reference frame of the earth formation. In this way, the detected data features may correspond to geological features of the earth formation, as described herein. Also in this way, the determining of the geological features of the earth formation may be based on mapping the oriented engagement data to the global reference frame, in at least one embodiment.
In some embodiments, the feature detection manager 823 provides an indication of the detected data features. For example, the feature detection manager 823 may generate feature data 829. The feature data 829 may include one or more flags, tags, labels, or alerts indicating the detected data features, or combinations thereof. In some embodiments, the feature data 829 indicates the detected data features, for example, on or with respect to the data received and/or input to the feature detection manager 823. In some embodiments, the feature data 829 indicates the detected data features separate from the input data. The feature detection manager 823 may store the feature data 829 to a data storage of the downhole imaging system 820.
In some embodiments, the feature detection manager 823 facilitates detecting one or more data features. For example, the feature detection manager 823 may incorporate one or more inputs from a user in order to identify, detect, validate, or authenticate data features, or combinations thereof. The feature detection manager 823 may present data and/or may facilitate presenting data to a user (e.g., through a printout, readout, graphical user interface, or combinations thereof) in order to receive user input associated with detecting data features. In this way, user interaction with the downhole imaging system 820 may be incorporated into the detecting of data features by or with the feature detection manager 823.
In some embodiments, the feature data 829 indicates and/or facilitates detecting one or more borehole features. For example, detected data features may correspond to one or more physical features (e.g., cracks) present and/or detected in the borehole. The detected data features may be oriented locally with respect to the borehole (e.g., based on oriented engagement data) and in this way correspond to borehole features. Thus, the feature data 829 may indicate, for example, that a crack is present (or detected) in the borehole at a given angle (e.g., 95°) of the borehole.
In some embodiments, the feature data 829 indicates and/or facilitates detecting one or more geological features. For example, detected data features may correspond to one or more physical features (e.g., cracks) with respect to the greater earth formation in which the borehole is located. The detected data features may be oriented globally with respect to the earth formation (e.g., based on mapping-oriented engagement data to a global reference frame) and in this way may correspond to geological features. Thus, the feature data 829 may indicate, for example, that the earth formation has a crack that is oriented in a given direction (e.g., cast to west), in at least one embodiment.
In some embodiments, the feature detection manager 823 includes and/or implements one or more machine learning models to generate the feature data 829 and/or to detect one or more features. For example, the machine learning model may receive one or more inputs such as sensor data, mapped data, image data, borehole data, any other data of the downhole imaging system 820, or combinations thereof and may generate one or more outputs such as data features, borehole features, and geological features, or combinations thereof. In an example, the machine learning model may be trained to detect one or more geological features of the earth formation based on receiving globally oriented engagement data. The machine learning model may implement one or more of a classification model, regression model, decision tree model, clustering model, association model, any other model, and combinations thereof.
The machine learning model may be trained with training data. For example, sensor data, mapped data, image data, etc. corresponding with a known borehole or portion of a borehole may be provided as training characteristics, and an indication of one or more geological features (or lack of geological features) may be provided as a ground truth. The machine learning model may implement one or more machine learning network layers (e.g., neural network layers). For example, the machine learning model may include input layers, hidden layers, output layers, and combinations thereof. The input layers may encode input data features corresponding to the input data into a numerical representation. The hidden layers may map and/or encode the input data to feature vectors. The output layers may process the feature vectors to decode geological feature information from the input data to determine and/or predict geological features. A loss model may determine an error and/or loss amount corresponding to the predicted indication of geological features (or lack of geological features) that the machine learning model outputs (e.g., by comparing to the ground truth). The loss model may provide feedback to the machine learning model to tune the machine learning model (e.g., tune the one or more layers). In this manner, the machine learning model may be iteratively tuned or trained to learn a set of best-fit parameters that accurately generates the indication of geological features (or lack of geological features) in the earth formation. In this way, geological features of the earth formation may be determined based on any of the data of the downhole imaging system 820.
In some embodiments, the feature detection manager 823 performs one or more operations on image data it received (e.g., image data 730-1 to 730-5). For example, the feature detection manager 823 may alter, filter, smooth, reduce noise, or segment the image data. This may facilitate detecting one or more features in the data (e.g., data feature, borehole features, or geological features). For example, the feature detection manager 823 may alter the image data to locate discrete data objects in the image data which may facilitate identifying data features. In some embodiments, the feature detection manager 823 stores the altered image data to a data storage of the downhole imaging system 820 as feature data 829.
In some embodiments, the feature detection manager 823 morphologically opens the image data. For example, erosion and dilation operations may be applied to the image data to remove small data objects and/or smooth object boundaries while preserving larger structures in the image data. In another example, objects may be separated which may be touching and/or overlapping in the image data while preserving their size and/or shape. In this way, unwanted structures may be removed from the image data and/or image noise may be reduced, in at least one embodiment. This may facilitate identifying, for example, geological features of interest in the data. For example, the image data may include one or more geological features of one or more different types. Geological features of a first type may be identified in the image, and through morphologically opening the image, these features may be removed while geological features of a second type are preserved in the image data. In another example, geological features of a first type may be highlighted or distinguished from geological features of a second type through morphologically opening the image data. In this way, the image data may be filtered to remove unwanted features, and/or to separate and/or distinguish features of interest, in at least one embodiment.
In some embodiments, a first portion of the image data is morphologically opened based on a first type of geological feature (e.g., based on a first structuring element), and a second portion of the image data may be morphologically opened based on a second type of geological feature (e.g., based on a second structuring element). In some embodiments, the first and second portions of the image data are combined after morphologically opening in order to illustrate the first and second types of geological features together. This may facilitate different types of geological features and/or removing unwanted geological features from the image data. The image data may be morphologically opened 2, 3, 4, 5, or more times based on 2, 3, 4, 5, or more types of geological features. In this way, any number of types of geological features may be identified, removed, highlighted, distinguished, etc.
In some embodiments, the feature detection manager 823 extracts summary statistics from the image data. For example, the summary statistics maybe associated with a dimension, orientation, dynamic such as force, number of occurrences, any other characteristic of objects identified in the image data (e.g., geological features), or combinations thereof. The feature detection manager 823 may calculate and/or generate means, medians, percentiles, standard deviations, ranges, quartiles, other statistical values, or combinations thereof of one or more characteristics of the discrete objects identified in the image data. The summary statistics may be presented in the form of a histogram, curve, table, plot, graph, any other representation, or combinations thereof. The summary statistics may be stored in the data storage of the downhole imaging system as feature data 829.
In some embodiments, the communication module 925 receives data. For example, the communication module 925 may receive sensor data, mapped data, image data, feature data, borehole data, any other data accessible to the downhole imaging system 920, or combinations thereof. In some embodiments, the communication module 925 receives the data from the mapping engine 922. In some embodiments, the communication module 925 receives the data by accessing a data storage of the downhole imaging system 920. In accordance with at least one embodiment of the present disclosure, the communication module may receive oriented engagement data 942 (e.g., from the mapping engine 922). The oriented engagement data 942 may include engagement data locally oriented with respect to a borehole based on rotation data, as described herein. The communication module 925 may transmit any of the data it receives.
The communication module 925 may be configured to communicate with one or more downhole devices 919 (e.g., drilling devices, milling devices, reaming devices, stabilizing devices, steering devices, other downhole devices, or combinations thereof). In some embodiments, the communication module 925 is configured to communicate with the downhole devices 919 over a physical data connection. For example, the communication module 925 may include or be in data communication with one or more physical data ports for electronically transferring information over a cable and/or a wired connection. In some embodiments, the communication module 925 is configured to communicate with the downhole devices 919 wirelessly. For example, the communication module 925. May be configured to wirelessly communicate using Bluetooth, near field communication (“NFC”), Wi-Fi, LoRa, an Industrial Internet of Things (“IoT”) protocol, or any other form of wireless communication. In some embodiments, the communication module 925 is configured for long range wireless communication such as GPS, radio, cellular network, etc. Wireless communication in this regard may have the benefit of communicating and/or transferring data faster, more efficiently, or more conveniently.
In some embodiments, the downhole devices 919 include computing devices located at the surface of the borehole. For example, the downhole devices 919 may include a computing device associated with a drill rig of a drilling system, a mobile device, or any other type of computing device, and the communication module 925 may transmit data to the computing device at the surface. In some embodiments, the downhole devices 919 include computing devices located in the borehole. For example, one or more components of the drilling system located in the borehole may include a computing device and the communication module 925 may transmit data to the computing device in the borehole. One or more components of the downhole imaging system 920 may be located in the borehole or at the surface. For example, a computing device implementing the downhole imaging system 920 may include a computing device located on a downhole tool and/or may include a surface computing device. In this way, the communication module 925 may transmit data to any number of downhole devices 919 located at any location in relation to the drilling system.
The method 1060 may include an act 1061 of identifying engagement data from an engagement sensor. The engagement data may correspond to an engagement with a borehole. For example, a downhole tool may include an instrumented engagement element having an engagement sensor. The instrumented engagement element may be located and/or positioned in the downhole tool to engage the borehole wall. The engagement data may correspond to an engagement of the instrumented engagement element with a borehole in the earth formation. In some embodiments, the engagement data is taken or measured during an operation of the downhole tool. For example, the engagement data may be taken while drilling with a bit. In some embodiments, the instrumented engagement element is in a blade of the downhole tool. in some embodiments, the engagement sensor is a force sensor and the engagement data is force data.
The method 1060 may include an act 1062 of identifying rotation data from a rotation sensor. For example, the rotation data may correspond to a rotational orientation of the engagement data with respect to the borehole. A rotation sensor may take or measure the rotation data. For example, the rotation sensor may include one or more of a magnetometer, an inclinometer, a gyroscope, other rotation sensors, or combinations thereof. In some embodiments, the rotation data is taken during an operation of the downhole tool (e.g., while drilling).
The method 1060 may include an act 1063 of mapping the engagement data to the rotation data to generate oriented engagement data. For example, one or more instances of the engagement data may be mapped to or associated with one or more instances of a rotational position or angle of the rotation data. In this way, the engagement data may be oriented (e.g., locally) with respect to the borehole. In some embodiments, the oriented engagement data is mapped to a global reference frame. For example, the oriented engagement data may be mapped to one or more of an azimuth, an inclination, a latitude and longitude of the borehole, other reference frames, or combinations thereof.
In some embodiments mapping the engagement data includes generating an image of the borehole. Generating the image of the borehole may be based on the oriented engagement data. The image may present and/or illustrate the oriented engagement data. In other words, the image may present and/or illustrate the engagement data with respect to the rotation data. The image may illustrate geological features of the earth formation. In some embodiments, generating the image is based on mapping the oriented engagement data to the depth data. For example, the image may illustrate the oriented engagement data with respect to the depth data. In some embodiments, generating the image includes applying a color scale, as described above, to represent a magnitude of the oriented engagement data. In some embodiments, the image may be generated while performing downhole operations, such as drilling (e.g., with the downhole tool).
In some embodiments, mapping the engagement data includes determining a geological feature of an earth formation. For example, the geological feature may be a crack or fracture in the earth formation. The geological feature may be determined based on mapping the oriented engagement data to a global reference frame. For example, mapping the oriented engagement data to the global reference frame may include mapping the oriented engagement data to one or more of an azimuth of the borehole, an inclination of the borehole, a latitude and longitude of the borehole, other reference frames, or combinations thereof. In some embodiments, determining the geological feature includes defining a data feature and identifying one or more instances of the data feature associated with a plurality of successive revolutions of the downhole tool. For example, the data feature may correspond to a threshold change in magnitude of the oriented engagement data. In some embodiments the method includes transmitting the oriented engagement data to a drilling device.
The method 1160 may include an act 1161 of identifying engagement data from an engagement sensor. The engagement data may correspond to an engagement with a borehole. For example, a downhole tool may include an instrumented engagement element having an engagement sensor. The instrumented engagement element may be located and/or positioned in the downhole tool to engage the borehole wall. The engagement data may correspond to an engagement of the instrumented engagement element with a borehole in the earth formation. In some embodiments, the engagement data is taken or measured during an operation of the downhole tool. For example, the engagement data may be taken while drilling with a bit. In some embodiments, the instrumented engagement element is in a blade of the downhole tool. In some embodiments, the engagement sensor is a force sensor, and the engagement data is force data.
The method 1160 may include an act 1162 of identifying depth data from a depth sensor. The depth data may correspond to a depth of the engagement data with respect to the borehole. In some embodiments, the depth data is taken during an operation of the downhole tool (e.g., while drilling).
The method 1160 may include an act 1163 of mapping the engagement data to the depth data to generate mapped engagement data. In some embodiments, the mapped engagement data is transmitted to a drilling device. In some embodiments, mapping the engagement data includes generating an image of the borehole based on the mapped data. For example, the image may present the engagement data with respect to the depth data. The image may illustrate one or more geological features of the earth formation. In some embodiments, mapping the engagement data includes determining a borehole feature of the borehole based on mapping the engagement data to the depth data.
The method 1260 may include an act 1261 of identifying engagement data from an engagement sensor. The engagement data may correspond to an engagement with a borehole. For example, a downhole tool may include an instrumented engagement element having an engagement sensor. The instrumented engagement element may be located and/or positioned in a blade of the downhole tool. The engagement data may correspond to an engagement of the instrumented engagement element with a borehole in the earth formation. In some embodiments, the engagement data is taken or measured during an operation of the downhole tool. For example, the engagement data may be taken while drilling with a bit. In some embodiments, the engagement sensor is a force sensor, and the engagement data is force data.
The method 1260 may proceed optionally from act 1261 to either one or both of act 1262 and act 1263. For example, the method 1260 may proceed to act 1262 of identifying rotation data from a rotation sensor. For example, the rotation data may correspond to a rotational orientation of the engagement data with respect to the borehole. Alternatively, the method 1260 may proceed to act 1263 of identifying depth data from a depth sensor. For example, the depth data may correspond to a depth of the engagement data with respect to the borehole. In this way, the method 1260 may include either act 1262 or act 1263.
The method 1260 may include an act 1264 of identifying lithology data from a lithology sensor. For example, the lithology data may correspond to one or more physical properties of the earth formation.
The method 1260 may include an act 1265 of mapping the engagement data. For example, the engagement data may be mapped to the lithology data. Additionally, the engagement data may be mapped to either (or both) the rotation data or the depth data depending on which of the acts 1262 or 1263 is implemented in the method. In this way, mapped engagement data may be generated. In some embodiments, mapping the engagement data includes generating a virtual core image of the borehole based on the mapped engagement data. For example, the virtual core image may illustrate the lithology data with respect to the engagement data. The virtual core image may illustrate geological features of the earth formation. In some embodiments, mapping the engagement data includes determining a geological feature of the earth formation based on the mapped engagement data.
The method 1360 may include an act 1361 of identifying engagement data from an engagement sensor. The engagement data may correspond to an engagement with a borehole. For example, a downhole tool may include an instrumented engagement element having an engagement sensor. The instrumented engagement element may be located and/or positioned in a blade of the downhole tool. The engagement data may correspond to an engagement of the instrumented engagement element with a borehole in the earth formation. In some embodiments, the engagement data is taken or measured during an operation of the downhole tool. For example, the engagement data may be taken while drilling with a bit. In some embodiments, the engagement sensor is a force sensor, and the engagement data is force data.
The method 1360 may include an act 1362 of defining a data feature in the engagement data. For example, the data feature may correspond with one or more instances of interest in the engagement data, such as a measurement past a threshold level or a change in a measurement past a threshold level.
The method 1360 may include an act 1363 of determining a geological feature of the earth formation. Determining the geological feature may be based on identifying a plurality of instances of the data feature that each occur periodically with respect to a rotation of the downhole tool. For example, a data feature may occur in a plurality of revolutions (e.g., successive) of the downhole tool. The data feature may occur at the same or similar (or adjacent) locations with respect to the revolutions of the downhole tool. This may indicate or may be associated with the engagement sensor repeatedly sensing a physical feature of the borehole, and in this way the engagement data may correspond or may be attributed to a geological feature in the earth formation.
The method 1460 may include an act 1461 of identifying first engagement data from a first engagement sensor. The first engagement data may correspond to a first engagement with a borehole. For example, a downhole tool may include a first instrumented engagement element having the first engagement sensor. The first instrumented engagement element may be located and/or positioned in a blade of the downhole tool. The first engagement data may correspond to a first engagement of the first instrumented engagement element with a borehole in the earth formation. In some embodiments, the first engagement data is taken or measured during an operation of the downhole tool. For example, the first engagement data may be taken while drilling with a bit. In some embodiments, the first engagement sensor is a first force sensor, and the first engagement data is first force data.
The method 1460 may include an act 1462 of identifying second engagement data from a second engagement sensor. The second engagement data may correspond to a second engagement with a borehole. For example, the second engagement sensor may be included on a second instrumented engagement element implemented on the downhole tool (or on a second downhole tool).
In another example, the second engagement sensor may be included on the first instrumented engagement element. For example, the first engagement data and the second engagement data may correspond to the first instrumented engagement element engaging the borehole wall. The first engagement data and the second engagement data may each correspond to different aspects of the engagement of the first instrumented engagement element with the borehole. For example, the first and second engagement data may each represent different dynamics (e.g., force and strain). In another example, the first and second engagement data may each represent the same dynamic but in a different way, or with respect to a different axis (e.g., normal force and shear force). In this way the first and second engagement data may correspond to the engagement of the same (first) instrumented engagement element with the borehole but may correspond to a first engagement and a second engagement of the engagement element (respectively) with the borehole due to the difference in nature of the data.
In some embodiments, the second engagement data is taken or measured during an operation of the downhole tool. For example, the second engagement data may be taken while drilling with a bit. In some embodiments, the second engagement sensor is a second force sensor, and the second engagement data is second force data.
The method 1460 may include an act 1463 of mapping the first engagement data to the second engagement data. This may generate mapped engagement data. For example, one or more instances of the first engagement data may be mapped or associated with one or more instances of the second engagement data. In some embodiments, mapping the first and second engagement data may be based on a relationship of the first engagement data to the second engagement data. For example, mapping may include fitting a line of best fit to the first and second engagement data. Mapping may include fitting the first and second engagement data to a curve or line. Mapping may include adjusting and/or compensating the first and/or second engagement data to correlate with the other set of data (or any other data). Mapping may include any other technique to relate the first engagement data to the second engagement data, and combinations of the techniques discussed herein.
The computer system 1500 includes a processor 1501. The processor 1501 may be a general-purpose single- or multi-chip microprocessor (e.g., an Advanced RISC (Reduced Instruction Set Computer) Machine (ARM)), a special purpose microprocessor (e.g., a digital signal processor (DSP)), a microcontroller, a programmable gate array, etc. The processor 1501 may be referred to as a central processing unit (CPU). Although just a single processor 1501 is shown in the computer system 1500 of
The computer system 1500 also includes memory 1503 in electronic communication with the processor 1501. The memory 1503 may be any electronic component capable of storing electronic information. For example, the memory 1503 may be embodied as random-access memory (RAM), read-only memory (ROM), magnetic disk storage media, optical storage media, flash memory devices in RAM, on-board memory included with the processor, erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM) memory, registers, and so forth, including combinations thereof.
Instructions 1505 and data 1507 may be stored in the memory 1503. The instructions 1505 may be executable by the processor 1501 to implement some or all of the functionality disclosed herein. Executing the instructions 1505 may involve the use of the data 1507 that is stored in the memory 1503. Any of the various examples of modules and components described herein may be implemented, partially or wholly, as instructions 1505 stored in memory 1503 and executed by the processor 1501. Any of the various examples of data described herein may be among the data 1507 that is stored in memory 1503 and used during execution of the instructions 1505 by the processor 1501.
A computer system 1500 may also include one or more communication interfaces 1509 for communicating with other electronic devices. The communication interface(s) 1509 may be based on wired communication technology, wireless communication technology, or both. Some examples of communication interfaces 1509 include a Universal Serial Bus (USB), an Ethernet adapter, a wireless adapter that operates in accordance with an Institute of Electrical and Electronics Engineers (IEEE) 1102.11 wireless communication protocol, a Bluetooth® wireless communication adapter, and an infrared (IR) communication port.
A computer system 1500 may also include one or more input devices 1511 and one or more output devices 1513. Some examples of input devices 1511 include a keyboard, mouse, microphone, remote control device, button, joystick, trackball, touchpad, and lightpen. Some examples of output devices 1513 include a speaker and a printer. One specific type of output device that is typically included in a computer system 1500 is a display device 1515. Display devices 1515 used with embodiments disclosed herein may utilize any suitable image projection technology, such as liquid crystal display (LCD), light-emitting diode (LED), gas plasma, electroluminescence, or the like. A display controller 1517 may also be provided, for converting data 1507 stored in the memory 1503 into text, graphics, and/or moving images (as appropriate) shown on the display device 1515.
The various components of the computer system 1500 may be coupled together by one or more buses, which may include a power bus, a control signal bus, a status signal bus, a data bus, etc. For the sake of clarity, the various buses are illustrated in
The techniques described herein may be implemented in hardware, software, firmware, or any combination thereof, unless specifically described as being implemented in a specific manner. Any features described as modules, components, or the like may also be implemented together in an integrated logic device or separately as discrete but interoperable logic devices. If implemented in software, the techniques may be realized at least in part by a non-transitory processor-readable storage medium comprising instructions that, when executed by at least one processor, perform one or more of the methods described herein. The instructions may be organized into routines, programs, objects, components, data structures, etc., which may perform particular tasks and/or implement particular data types, and which may be combined or distributed as desired in various embodiments.
Computer-readable media can be any available media that can be accessed by a general purpose or special purpose computer system. Computer-readable media that store computer-executable instructions are non-transitory computer-readable storage media (devices). Computer-readable media that carry computer-executable instructions are transmission media. Thus, by way of example, and not limitation, embodiments of the disclosure can comprise at least two distinctly different kinds of computer-readable media: non-transitory computer-readable storage media (devices) and transmission media.
Both non-transitory computer-readable storage media (devices) and transmission media may be used temporarily to store or carry, software instructions in the form of computer readable program code that allows performance of embodiments of the present disclosure. Non-transitory computer-readable storage media may further be used to persistently or permanently store such software instructions. Examples of non-transitory computer-readable storage media include physical memory (e.g., RAM, ROM, EPROM, EEPROM, etc.), optical disk storage (e.g., CD, DVD, HDDVD, Blu-ray, etc.), storage devices (e.g., magnetic disk storage, tape storage, diskette, etc.), flash or other solid-state storage or memory, or any other non-transmission medium which can be used to store program code in the form of computer-executable instructions or data structures and which can be accessed by a general purpose or special purpose computer, whether such program code is stored as or in software, hardware, firmware, or combinations thereof.
A “network” or “communications network” may generally be defined as one or more data links that enable the transport of electronic data between computer systems and/or modules, engines, and/or other electronic devices. When information is transferred or provided over a communication network or another communications connection (either hardwired, wireless, or a combination of hardwired or wireless) to a computing device, the computing device properly views the connection as a transmission medium. Transmission media can include a communication network and/or data links, carrier waves, wireless signals, and the like, which can be used to carry desired program or template code means or instructions in the form of computer-executable instructions or data structures and which can be accessed by a general purpose or special purpose computer.
Further, upon reaching various computer system components, program code in the form of computer-executable instructions or data structures can be transferred automatically or manually from transmission media to non-transitory computer-readable storage media (or vice versa). For example, computer-executable instructions or data structures received over a network or data link can be buffered in memory (e.g., RAM) within a network interface module (NIC), and then eventually transferred to computer system RAM and/or to less volatile non-transitory computer-readable storage media at a computer system. Thus, it should be understood that non-transitory computer-readable storage media can be included in computer system components that also (or even primarily) utilize transmission media.
The present disclosure includes a number of practical applications having features described herein that provide benefits and/or solve problems associated with identifying geological features and/or characterizing an earth formation. Some example benefits are discussed herein in connection with various features and functionalities provided by a downhole imaging system implemented on one or more computing devices. It will be appreciated that benefits explicitly discussed in connection with one or more embodiments described herein are provided by way of example and are not intended to be an exhaustive list of all possible benefits of the downhole imaging system and further are not intended to limit the scope of the claims.
For example, in order to effectively plan and execute drilling operations, it can be critical to identify and/or map geological features and/or structures of an earth formation or of a reservoir. The downhole imaging techniques discussed herein may detect and/or facilitate detecting geological features of the earth formation such as cracks, fractures, formation boundaries, formation angles, etc. Identifying and/or understanding such geological features can be invaluable for determining, for example, where underground resources may be located, how to drill through and/or penetrate certain formations, well completion strategies, risk factors associated with certain formations, among other factors. Thus, implementing the downhole imaging techniques described herein to detect and/or map geological features of the earth formation may provide significant cost, time, and/or resource savings by providing a better understanding of the formations being drilled, as well as an increased confidence in the features presumed to be present in the earth formation.
In addition to generally detecting geological features, the downhole imaging techniques described herein can generate images of the borehole to facilitate determining and/or confirming geological features. For example, engagement measurements associated with geological features may be transformed into photograph-like images of the borehole which may facilitate determining the location, orientation, size, or general presence of geological features. Indeed, the downhole imaging techniques described herein may in essence provide a photograph of the borehole.
Additionally, some conventional borehole surveying and/or characterization methods require specialized tools implemented in the borehole by stopping or pausing drilling operations. In some cases, drilling tools are removed from the borehole to perform conventional imaging techniques, resulting in costly downtime of the drilling system. The borehole images described herein may be generated based on data taken during drilling operations, and in some situations the images may also be generated during drilling operations or in real time. In this way, the earth formation may be mapped and/or characterized without the downtime expenses of some conventional methods, resulting in cost and resource savings. As such, a variety and/or any number of images may be generated of the borehole, for example, at any depth and/or for any duration (e.g., length) of the borehole. In contrast, the downtime associated with some conventional borehole characterization techniques may impose practical limits to how much or how long such techniques may be implemented. Indeed, the imaging techniques described herein may realistically be implemented to image any portion (or an entirety) of a borehole with little to no operational limits on duration, detail, etc.
Some conventional borehole surveying and/or characterization methods require specialized tools implemented in the borehole as part of the drilling tool assembly and/or as part of the BHA, such as measurement-while-drilling (MWD) and/or logging-while-drilling (LWD) tools. MWD and LWD tools are often implemented above or uphole from one or more downhole (e.g., drilling) tools such as a bit or reamer. MWD and LWD tools may take measurements and/or facilitate generating images associated with the borehole. However, because these tools are located uphole of the drilling tools (e.g., up to 100 ft), any information gathered by these measurement tools can realistically only be used to make delayed decisions regarding the operation of the drilling tools located further down the borehole. In other words, MWD and LWD tools cannot practically be implemented to make real-time decisions concerning, for example, a present engagement and/or a present formation associated with one or more drilling tools. In contrast, the techniques described herein may be implemented to take measurements at a point of engagement of one or more drilling tools with the earth formation. In this way, real-time information relevant to an immediate proximity of the drilling tools may be used to inform decisions about the operation of the drilling tools.
Additionally, while conventional MWD and LWD tools may take measurements and/or facilitate generating images of the borehole, such measurements and/or images are typically of limited resolution. The imaging techniques of the present disclosure may generate images of improved resolution over, for example, conventional borehole images. MWD and LWD imaging tools are also typically quite expensive to both manufacture and to implement downhole. Exposing expensive instrumentation to the harsh downhole environment presents the possibility that the instrumentation may become damaged or lost. In contrast, the imaging techniques described herein may be implemented through simple and inexpensive instrumentation in connection with engagement elements that may already be designed and/or configured to withstand the harsh environment downhole.
Further, one technique that is conventionally used to gather and/or analyze specific information about an earth formation is the technique of taking a core sample. A special bit is implemented downhole to remove and bring to the surface a sample of the borehole in order that it may be analyzed to gather information about the earth formation. This can be costly and time consuming as it requires stopping drilling operations as well as removing downhole tools from the borehole. The imaging techniques described herein can generate a virtual core image by incorporating lithology data (e.g., data associated with physical properties of the earth formation) into the images described above. In this way, a virtual representation of a core sample may be analyzed in much the same way as is conventionally done to characterize the earth formation, but without the costly downtime. Thus, a virtual core image may provide significant cost and resource savings over conventional core sampling techniques.
The following non-limiting examples are illustrative of the various permutations contemplated herein.
In some embodiments, a method of imaging an earth formation includes identifying engagement data from an engagement sensor, the engagement data corresponding to an engagement with a borehole in the earth formation. In some embodiments, the engagement sensor is on an instrumented engagement element of a downhole tool, and the engagement data corresponds to an engagement of the instrumented engagement element with the borehole. In some embodiments, the engagement sensor is a force sensor, and the engagement data is force data. In some embodiments, the engagement data is transmitted to a drilling device. In some embodiments, the engagement measurements are taking while drilling. In some embodiments, rotation data is identified from a rotation sensor, the rotation data corresponding to a rotational orientation of the engagement data with respect to the borehole. In some embodiments, the rotation data is transmitted to a drilling device. In some embodiments, the rotation data is taken while drilling. In some embodiments, the engagement data is mapped to the rotation data to generate oriented engagement data. In some embodiments, the oriented engagement data is transmitted to a drilling device. In some embodiments, a borehole feature is determined based on the oriented engagement data. In some embodiments, an image of the borehole is generated based on the oriented engagement data, wherein the image presents the engagement data with respect to the rotation data and wherein the image illustrates one or more geological features of the earth formation. In some embodiments, depth data is identified from a depth sensor, the depth data corresponding to a depth of the engagement data with respect to the borehole. In some embodiments, the depth data is taken while drilling. In some embodiments, the depth data is transmitted to a drilling device. In some embodiments, the engagement data is mapped to the depth data to generate mapped engagement data. In some embodiments, the mapped engagement data is transmitted to a drilling device. In some embodiments, a borehole feature is determined based on the mapped engagement data. In some embodiments, an image of the borehole is generated based on the mapped engagement data, wherein the image presents the engagement data with respect to the depth data and wherein the image illustrates one or more geological features of the earth formation. In some embodiments, lithology data is identified from a lithology sensor, wherein the lithology data is associated with one or more physical properties of the earth formation. In some embodiments, the lithology data is taken while drilling. In some embodiments, the method further comprises transmitting the lithology data. In some embodiments, the engagement data is mapped to the lithology data based on a depth associated with the lithology data to generate mapped engagement data. In some embodiments, the mapped engagement data is transmitted to a drilling device. In some embodiments, an image is generated of the borehole based on the mapped engagement data, wherein the image presents the engagement data with respect to the lithology data and wherein the image illustrates one or more geological features of the earth formation. In some embodiments, the image is a virtual core image of the borehole. In some embodiments, the borehole data is identified corresponding to a global reference frame of the earth formation in which the borehole is located. In some embodiments, the borehole information is transmitted to a drilling device. In some embodiments, the engagement data is mapped to the borehole data to orient the engagement data with respect to the global reference frame of the earth formation, and wherein the mapping generates globally oriented engagement data. In some embodiments, the globally oriented engagement data is transmitted. In some embodiments, the engagement data is mapped to one or more of an azimuth of the borehole, an inclination of the borehole, and a latitude and longitude of the borehole. In some embodiments, a geological feature is determined of the earth formation based on the globally oriented engagement data. In some embodiments, an image is generated of the borehole based on the globally oriented engagement data, wherein the image presents the engagement data with respect to the global reference frame of the earth formation, and wherein the image illustrates one or more geological features of the earth formation. In some embodiments, an image of the borehole is generated based, at least in part, on the engagement data. In some embodiments, generating the image includes applying a color scale to represent a magnitude of the engagement data. In some embodiments, the image is generated while drilling with the downhole tool. In some embodiments, each line of resolution of the image corresponds to a revolution of the downhole tool. In some embodiments, a geological feature is determined of the earth formation based, at least in part, on the engagement data. In some embodiments, determining the geological feature of the earth formation includes defining a data feature corresponding to a threshold change in a magnitude of the engagement data; and identifying one or more instance of the data feature associated with a plurality of successive revolutions of the downhole tool. In some embodiments, the geological feature is a crack or fracture in the earth formation. In some embodiments, the instrumented engagement element is on a blade of the downhole tool.
In some embodiments, a method of imaging an earth formation includes identifying engagement data from an instrumented engagement element of a downhole tool having an engagement sensor, the engagement data corresponding to an engagement of the instrumented engagement element with a borehole in the earth formation; identifying rotation data from a rotation sensor, the rotation data corresponding to a rotational orientation of the engagement data with respect to the borehole; mapping the engagement data to the rotation data to generate oriented engagement data; and generating an image of the borehole based on the oriented engagement data, wherein the image presents the engagement data with respect to the rotation data and wherein the image illustrates one or more geological features of the earth formation. In some embodiments, depth data is identified from a depth sensor corresponding to a depth of the engagement data with respect to a surface of the borehole, wherein generating the image is further based on mapping the oriented engagement data to the depth data, and wherein the image illustrates the oriented engagement data with respect to the depth data. In some embodiments, second engagement data is identified from a second engagement sensor, the second engagement data corresponding to an engagement with the borehole; second rotation data is identified from the rotation sensor, the second rotation data corresponding to a second rotational orientation of the second engagement data with respect the borehole; and the second engagement data is mapped to the second rotation data to generate second oriented engagement data, wherein generating the image of the borehole is based on the oriented engagement data and the second oriented engagement data. In some embodiments, generating the image includes generating supplemental oriented engagement data by interpolating from the oriented engagement data and the second oriented engagement data. In some embodiments, the instrumented engagement element corresponds to a first radius of the downhole tool and the second instrumented engagement element corresponds to a second radius of the downhole tool.
In some embodiments, a method of mapping an earth formation includes identifying engagement data from an instrumented engagement element of a downhole tool having an engagement sensor, the engagement data corresponding to an engagement of the instrumented engagement element with a borehole in the earth formation; identifying rotation data from a rotation sensor, the rotation data corresponding to a rotational orientation of the engagement data with respect to the borehole; mapping the engagement data to the rotation data to generate oriented engagement data; and determining a geological feature of the earth formation based on mapping the oriented engagement data to a global reference frame. In some embodiments, depth data is identified from a depth sensor, the depth data corresponding to a depth of the engagement data with respect to a surface of the borehole, wherein determining the geological feature is further based on mapping the oriented engagement data to the depth data. In some embodiments, the rotation sensor includes one or more of a magnetometer, an inclinometer, and a gyroscope.
In a downhole drilling environment, a computer-implemented method of mapping an earth formation for the downhole drilling environment is described. The computer-implemented method includes identifying engagement data from an instrumented engagement element of a downhole tool having an engagement sensor, the engagement data corresponding to an engagement of the instrumented engagement element with a borehole in the earth formation; identifying rotation data from a rotation sensor, the rotation data corresponding to a rotational orientation of the engagement data with respect to the borehole; mapping the engagement data to the rotation data to generate oriented engagement data; and transmitting the oriented engagement data to a drilling device.
In some embodiments, a method of determining a geological feature of an earth formation includes receiving sensor data from a downhole sensor implemented on an instrumented engagement element of a downhole tool, wherein the sensor data corresponds to an engagement of the instrumented engagement element with a borehole of the earth formation; defining a data feature in the sensor data; and determining a geological feature of the earth formation based on identifying a plurality of instances of the data feature that each occur periodically with respect to a rotation of the downhole tool. In some embodiments, the downhole sensor is implemented on an instrumented engagement element of a downhole tool and wherein the engagement data corresponds to an engagement of the instrumented engagement element with the borehole. In some embodiments, the downhole sensor is an engagement sensor and wherein the sensor data is engagement data.
In some embodiments, a method of mapping an earth formation includes identifying first engagement data from a first engagement sensor, the first engagement data corresponding to an engagement with a borehole in the earth formation; identifying second engagement data from a second engagement sensor, the second engagement data corresponding to an engagement with the borehole; and mapping the first engagement data to the second engagement data to generate mapped engagement data. In some embodiments, the first engagement sensor is included on a first instrumented engagement element implemented on a downhole tool. In some embodiments, the second engagement sensor is included on a second instrumented engagement element implemented on a downhole tool. In some embodiments, the second engagement sensor is included on the first instrumented engagement. In some embodiments, the first engagement data is first engagement data and wherein the second engagement data is second engagement data.
The embodiments of the borehole imaging techniques have been primarily described with reference to wellbore drilling operations; the borehole imaging techniques described herein may be used in applications other than the drilling of a wellbore. In other embodiments, the borehole imaging techniques according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources. For instance, the borehole imaging techniques of the present disclosure may be used in a borehole used for placement of utility lines. Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.
One or more specific embodiments of the present disclosure are described herein. These described embodiments are examples of the presently disclosed techniques. Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.
The articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements in the preceding descriptions. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements. Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein. Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure. A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result. The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.
A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure. Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function. It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function. Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.
The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that still performs a desired function or achieves a desired result. For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount. Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements. For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.
The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics. The described embodiments are to be considered as illustrative and not restrictive. The scope of the disclosure is, therefore, indicated by the appended claims rather than by the foregoing description. Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.
The present disclosure claims priority from U.S. Prov. Appl. No. 63/502,148, filed on 15 May 2023, herein incorporated by reference in its entirety.
| Number | Date | Country | |
|---|---|---|---|
| 63502148 | May 2023 | US |
