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System and method for managing and/or using data for tools in a wellbore

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System and method for managing and/or using data for tools in a wellbore


A system and a method manage and use data related to a wellbore or a drill string. The system and the method may provide remote access to tools in a drill string using a network. In addition, the tools have access to the data. In a disclosed embodiment, the tools are able to automatically access the data needed to optimize or improve function of the tools.

Browse recent Schlumberger Technology Corporation patents - Sugar Land, TX, US
USPTO Applicaton #: #20140131099 - Class: 175 27 (USPTO) -
Boring Or Penetrating The Earth > Automatic Control >Of Advance Or Applied Tool Weight

Inventors: Geoffrey C. Downton, Clinton D. Chapman, Shyam B. Mehta

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The Patent Description & Claims data below is from USPTO Patent Application 20140131099, System and method for managing and/or using data for tools in a wellbore.

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CROSS-REFERENCE TO RELATED APPLICATION

The present document is a divisional application of and claims priority to currently pending U.S. patent application Ser. No. 12/535,793, filed on Aug. 5, 2009, incorporated herein by reference in its entirety.

BACKGROUND OF THE INVENTION

The present invention generally relates to a system and a method for managing and/or using data for tools in a wellbore. More specifically, the present invention provides one or more tools located downhole or at the surface with access to data and intelligence to perform actions based on the data. For example, one or more of the tools may utilize measurement data to adjust drilling operations, tool operations and/or the like without instructions from a surface location. As another example, one or more of the tools may connect to a network and/or a database to access information and to perform an action, such as, for example, to improve performance of the tool or improve performance of the drilling process. The tools may automatically perform diagnostics and report a status of the diagnostics to the network and/or the database without instructions from the network.

To obtain hydrocarbons, a drilling tool is driven into the ground surface to create a borehole through which the hydrocarbons are extracted. Typically, a drill string is suspended within the borehole. The drill string has a drill bit at a lower end of the drill string. The drill string extends from the surface to the drill bit. The drill string has a bottom hole assembly (BHA) located proximate to the drill bit.

Drilling operations may be conducted in a vertical, horizontal or directional orientation of the drill string. Vertical drilling refers to drilling in which the trajectory of the drill string is inclined approximately ten degrees or less. Horizontal drilling refers to drilling in which the drill string is approximately perpendicular to the ground surface. Directional drilling refers to drilling in which the trajectory of the drill string is inclined between ten degrees and ninety degrees. Directional drilling may be advantageous in that directional drilling may enable several wells to be drilled from one drilling platform.

Drilling operations typically require monitoring to determine the trajectory of the borehole. Measurements of drilling conditions, such as, for example, drift of the drill bit, inclination, azimuth and the like, may be necessary for determining the trajectory of the borehole, especially for directional drilling.

The BHA may have tools that may generate and/or may obtain information regarding the wellbore, a surrounding formation and the drilling conditions. Technology for transmitting information within a wellbore, known as telemetry technology, is used to transmit the information from the tools of the BHA to a surface location for analysis. The information may be used to control the tools. Accurate real-time information regarding the tools, the wellbore, the surrounding formation and the drilling conditions may enable prevention and/or detection of a drilling problem, such as, for example, a hazard region which the drilling tool must avoid, a blowout, casing wear and/or the like. Moreover, adjustment of the drilling operations in response to accurate real-time information may enable optimization of the drilling process to increase a rate of penetration of the drill bit, reduce a drilling time and/or optimize a placement of the wellbore.

Wired drill pipe, such as the wired drill pipe infrastructure described in U.S. Pat. No. 6,641,434, enables high-speed transmission of the information from the tools to the surface location. The wired drill pipe infrastructure may have communication cables embedded in the drill pipe for transmittal of the information. In addition, the communication cables may be connected to coupling devices located at each joint of the drill pipe to enable transmission of the information and transmission of fluid through the drill pipe. In an embodiment, a tubular sleeve may secure the communication cables and/or protect the communication lines from damage.

The high-speed transmission by the wired drill pipe may provide a data transmission rate that may be orders of magnitude greater then a data transmission rate of other telemetry technologies, such as, for example, mud pulse telemetry or electronic pulse telemetry. The high-speed transmission by the wired drill pipe may also provide data transmission from relatively distant drilling depths.

However, communication with downhole tools is generally limited to providing commands and receiving measurement information. In addition, downhole tools are incapable of diagnostic control within the borehole. Typically, a problem associated with a downhole tool requires removing the tool from the wellbore prior to analyzing the tool for defects. As a result, considerable drilling time is lost in the event of a tool failure. Moreover, determination of whether the problem associated with the tool may cause failure of the tool is difficult, if not impossible. Frequently, an operator or other like individual does not determine that the tool has a problem until the tool completely fails or repeatedly fails. Accordingly, tools usually fail prior to any recognition of potential problems.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a drill string in an embodiment of the present invention.

FIG. 2 illustrates a black box diagram of a system for managing and/or using data for tools in a wellbore in an embodiment of the present invention.

FIG. 3 illustrates a flowchart of a method for managing and/or using data for tools in a wellbore in an embodiment of the present invention.

FIG. 4 illustrates a flowchart of a method for managing and/or using data for tools in a wellbore in an embodiment of the present invention.

DETAILED DESCRIPTION

OF THE PRESENTLY PREFERRED EMBODIMENTS

The present invention generally relates to a system and a method for managing and/or using data for tools in a wellbore. More specifically, the present invention provides one or more tools located downhole or at the surface with access to data and intelligence to perform actions based on the data. The tools may automatically perform diagnostics and report a status of the diagnostics to the network and/or the database without instructions from the network.

The system and the method may be used in oil well drilling to obtain, organize, display and/or analyze data regarding drilling conditions, wellbore conditions and/or tool operating conditions. The system and the method may utilize the data to adjust drilling operations, tool operations and/or the like without instructions from a surface location. The tools may be programmed and/or may be designed to prepare a report and/or determine whether to transmit the report. The tools may generate an updated model of drilling operations and a state of one or more of the tools and/or any component of an associated drill string. The tools may connect to a network so that the tools may be monitored and/or controlled by an application. The system and the method may provide an application and/or a linking tool that enable control of the tools and/or any component of the drill string.

Referring now to the drawings wherein like numerals refer to like parts, FIG. 1 generally illustrates a wellbore system 1 in an embodiment of the present invention. A platform assembly 5 may be positioned over a borehole 11 that may penetrate a drilling surface. A drill string 12 may have a drill bit 15 and/or may be suspended within the borehole 11. The drill bit 15 may be rotated by imparting rotation on the drill string 12, and/or a motor or other device (not shown) may be provided within the drill string 12 to rotate the drill bit 15.

The drill string 12 may have a bottom hole assembly (BHA) 20 that may be located adjacent to the drill bit 15. The drill string 12 may have a telemetry system 100 that may be one or more known telemetry systems. For example, the telemetry system 100 may use electromagnetic telemetry, acoustic telemetry, mud pulse telemetry, wired drill pulse telemetry and/or a combination of these technologies. While the present invention may be discussed primarily with respect to a wired drill pipe telemetry system, the invention should not be deemed as limited to only the use of wired drill pipe. Any one or combination of these telemetry systems may be used. For example, the telemetry system 100 may consist of wired drill pipe that extends from the drilling surface to a position within the wellbore and a mud pulse telemetry system that extends from the position within the wellbore to the BHA 20. In the case of wired drill pipe, the telemetry system 100 may consist of one or more wired drill pipe (WDP) joints 210.

A tool 10 may be associated with the telemetry system 100, the BHA 20 and/or the drill string 12. The tool 10 may provide measurements regarding the borehole 11, a formation that may surround the borehole 11, the drill string 12 and/or any component of the drill string 12. For example, the tool 10 may be and/or may have a measurement-while-drilling (“MWD”) tool, a logging-while-drilling (“LWD”) tool, a strain measuring device, a torque measuring device, a temperature measuring device, a seismic tool, a resistivity tool, a direction measuring device, an inclination measuring device, a weight-on-bit measuring device, a vibration measuring device, a shock measuring device, a stick-slip measuring device, a drilling tool used to create the borehole 11 and/or the like. In an embodiment, the tool 10 may be a wireline configurable tool, such as a tool commonly conveyed by wireline cable as known to one having ordinary skill in the art. The present invention is not limited to a specific embodiment of the tool 10. FIG. 1 depicts the tool 10 in association with the BHA 20, but the present invention is not limited to a specific location of the tool 10 within the drill string 12.

The tool 10 may have capabilities for measuring, processing and/or storing information, as well as for communicating with a surface location. The tool 10 may have a sensor, such as, for example, a gauge, a temperature sensor, a pressure sensor, a flow rate measurement device, an oil/water/gas ratio measurement device, a scale detector, a vibration sensor, a sand detection sensor, a water detection sensor, a viscosity sensor, a density sensor, a bubble point sensor, a composition sensor, a resistivity array sensor, an acoustic sensor, a near infrared sensor, a gamma ray detector, a H2S detector, a CO2 detector and/or the like.

An example of a communication apparatus that may be used in and/or with the telemetry system 100, the BHA 20 and/or the tool 10 is described in detail in U.S. Pat. No. 5,339,037. The present invention is not limited to a specific embodiment of the telemetry system 100, the communication apparatus or the BHA 20.

For example, the tool 10 may measure, may record and/or may transmit data acquired from and/or through the borehole 11 (hereinafter “the data”). The data may relate to the borehole 11 and/or the formation that may surround the borehole 11. For example, the data may relate to one or more characteristics of the formation and/or the borehole 11, such as, for example, a temperature, a pressure, a depth, a composition, a density and/or the like. The data may relate to one or more characteristics of the drill string 12, such as, for example, an amount of stretch, an amount of strain, an angle, a direction, a characteristic of fluid flowing through the drill string 12, a dog-leg severity and/or the like. For example, the data may indicate a trajectory of the borehole 11, a depth of the borehole 11, a width of the borehole 11 and/or the like. Further, the data may be and/or may indicate, for example, a location of the drill bit 15, an orientation of the drill bit 15, a weight applied to the drill bit 15, a rate of penetration, properties of an earth formation being drilled, properties of an earth formation and/or a hydrocarbon reservoir located proximate to the drill bit 15, fluid conditions, fluids collected and/or the like. Still further, the data may be, for example, resistivity measurements, neutron porosity measurements, azimuthal gamma ray measurements, density measurements, elemental capture spectroscopy measurements, neutron gamma density measurements that measure gamma rays generated from neutron formation interactions, sigma measurements and/or the like. The data may be and/or may indicate an inclination of the borehole 11 and/or an azimuth of the borehole 11, for example. The data may indicate annular pressure, three-axis shock and/or vibration, for example. The data may be measured and/or obtain at predetermined time intervals, at predetermined depths, at request by a user and/or the like. The present invention is not limited to a specific embodiment of the data. The data may be any data as known to one having ordinary skill in the art.

The WDP joints 210 may be interconnected to form the drill string 12. The telemetry system 100 and/or the plurality of WDP joints 210 may transmit the data from the tool 10. An example of a WDP joint that may be used in the telemetry system 100 is described in detail in U.S. Pat. No. 6,641,434 by Boyle et al. Again, the present invention is not limited to a specific embodiment of the telemetry system 100, and reference to the wired drill pipe is merely an example of one embodiment of the telemetry system 100.

The telemetry system 100 may be connected to a first network 200 that may be remote with respect to the borehole 11 and/or the drill string 12. The first network 200 may connect to one or more terminals, such as, for example, a first terminal 211, a second terminal 212 and/or a third terminal 213 (collectively hereinafter “the terminals 211-213”). The first network 200 may connect the terminals 211-213 to the telemetry system 100. The terminals 211-213 may be, for example, a desktop computer, a laptop computer, a mobile cellular telephone, a personal digital assistant (“FDA”), a 4G mobile device, a 3G mobile device, a 2.5G mobile device, an internet protocol (hereinafter “IP”) video cellular telephone, an ALL-IP electronic device, a satellite radio receiver, a portable digital audio player, a portable digital video player and/or the like. The terminals 211-233 may be any device that has a capability to communicate with the network. The terminals 211-213 may be remote relative to the drill string 12, the borehole 11 and/or the first network 200. The present invention is not limited to a specific embodiment of the terminals 211-213. Any number of terminals may be connected to the first network 200, and the present invention is not limited to a specific number of terminals.

In an embodiment, the first network 200 may be the Internet wherein the telemetry system 100 and/or the terminals 211-213 may be connected and/or in communication via a telephone network, a broadband network, a wireless network and/or other like network. The first network 200 may be a fixed network, such as, for example, a cabled network, a permanent network and/or the like. In an embodiment, the first network 200 may be a temporary network, such as, for example, a modem network, a null modem network and/or the like. The first network 200 may be, for example, a personal area network, a local area network, a campus area network, a metropolitan area network, a wide area network and/or the like. In an embodiment, the first network 200 may be a wireless network, such as, for example, a wireless metropolitan area network, a wireless local area network, a wireless personal area network, a global standard network, a personal communication system network, a pager-based service network, a general packet radio service, a universal mobile telephone service network, a radio access network and/or the like.

The present invention is not limited to a specific embodiment of the first network 200. It should be understood that the first network 200 may be any network capable of transferring and/or of transmitting the data between the telemetry system 100 and the terminals 211-213 as known to one having ordinary skill in the art. The first network 200 may be any data communication network known to one having ordinary skill in the art.

The first network 200 may connect to a server 220 that may be in communication with a database 229. The server 220 and/or the database 229 may be remote relative to the terminals 211-213. The database 299 may store any information related to the borehole 11, the drill string 12, the BHA 20, the telemetry system 100, the terminals 211-213, the server 200, the first network 200, the formation that may surround the borehole 11 and/or the tool 10. In an embodiment, the database 229 may store the data obtained from the tool 10 and/or the BHA 20, information from the surface location related to the borehole 11, information obtained from the drill string 12 and/or any other information known to one having ordinary skill in the art. For example, the database 229 may store information related to equipment being used at or in the borehole 11, such as, for example, limitations of the equipment, capabilities of the equipment, requirements of the equipment and/or the like.

For example, the database 229 may store well plan information for an area where drilling operations will occur, are occurring and/or have previously occurred. The well plan information may indicate a planned path of the borehole 11 and/or formation locations and/or depths. The well plan information may indicate a time and/or a location for occurrence of planned events, such as, for example, a change in the trajectory, a change in the rate of penetration, a change in the weight-on-bit, a change in drilling fluid rate and/or weight, a replacement of the drill bit 15, a setting of a casing and/or the like. The present invention is not limited to a specific embodiment of the well plan information.

The database 229 may be accessible via a control application 230 associated with the database 229. The tool 10 may transmit the data to the database 229 and/or the control application 230 using the telemetry system 100 and/or the first network 200. The database 229 and/or the control application 230 may store the data. The control application 230 may be provided by and/or stored by a computer readable medium, such as, for example, a compact disc, a DVD, a computer memory, a hard drive and/or the like. The computer readable medium may enable the first network 200 and/or the terminals 211-213 to execute the control application 230.

The control application 230 may enable one or more users to communicate with the tool 10 using the terminals 211-213 as described in more detail hereafter. For example, the control application 230 may have a graphic user interface provided and/or displayed by a standard web browser. Users may use, may access and/or may retrieve the control application 230 using the first network 200. For example, the users may use, may access and/or may retrieve the control application 230 using a web browser provided by any of the terminals 211-213 connected to the first network 200. The database 229 may be accessed by a single application or by multiple applications that may be linked to the database 229.

The tool 10 may be programmed and/or may be designed to generate and/or transmit a report. The tool 10 may be directed to transmit the report by the first network 200, the terminals 211-213 and/or the control application 230. The report may be generated and/or may be transmitted automatically by the tool 10 without instructions from the first network 200, the terminals and/or the control application 230. In such an embodiment, the report may be generated and/or may be transmitted based on operating conditions of the tool 10, conditions of the borehole 11, conditions of the drill string 12 and/or the like. In addition, the report may be generated and/or may be transmitted at predetermined time intervals, such as, for example, daily, hourly and/or the like.

In an embodiment, the report may relate to diagnostic and/or performance information for the tool 10, such as, for example, a potential problem, an operating failure, a potential operating failure, a predicted operating failure and/or the like. The report may have an account of operational activities of the drill string 12 and/or may have information regarding the borehole 11. The report may have and/or may be based on the data. For example, the report may indicate temperature, shock, rotating bending, oil levels, remaining battery life, flow rates and/or the like for various points in time and/or various locations of the tool 10, the drill bit 15, the BHA 20 and/or the drill string 12. The report may provide a detailed view of the borehole 11. For example, the report may have a two-dimensional visual representation of the borehole 11 and/or a three-dimensional visual representation of the borehole 11. In an embodiment, the report may provide analysis regarding data obtained by the tool 10.

The control application 230 and/or the tool 10 may be programmed and/or may be designed to determine whether to generate and/or transmit the report and/or the data. The tool 10 may transmit the report and/or the data using the telemetry system 100. The report may be transmitted from the tool 10 to the database 229 and/or the terminals 211-213 using the telemetry system 100 and/or the first network 200. The user may be informed of generation and/or availability of the report. For example, an email, a pager message, a text message and/or the like may indicate the availability of the report.

The control application 230 may periodically obtain the data and/or the report. The tool 10 and/or the control application 230 may aggregate and/or may compile the data and/or the report at various points in time for trend analysis. For example, the trend analysis may indicate a rate of tool wear for a specific type of tool, a rate of change of temperature as a function of depth, a rate of mud flow as a function of drilling time and/or the like.

The control application 230 and/or the tool 10 may be programmed and/or may be designed to compare the data to parameters to determine whether to generate and/or transmit the report and/or the data. The parameters may be, for example, a desired inclination of the borehole 11, a desired flow rate, a desired rate of penetration, a desired fluid density, a desired viscosity and/or the like. For example, the parameters may be based on the planned path for the borehole 11. The parameters may be determined and/or may be provided by one or more of the terminals 211-213 using the first network 200, may be accessed from the database 229 using the first network 200 and/or may be calculated by the control application 230 and/or the tool 10. The parameters may be any parameters known to one having ordinary skill in the art. The present invention is not limited to a specific embodiment of the parameters.

The parameters may be determined using model matching that may utilize the well plan information, the data obtained by the tool 10, any data stored by the database 229 and/or the like. The model matching may be used to determine if the telemetry system 100 generates and/or transmits the report. For example, the parameters may be associated with the well plan information. If the data does not correspond to the parameters associated with well plan information, the tool 10 may determine that drilling conditions changed. For example, if the control application 230 and/or the tool 10 determine that the borehole 11 deviates from the planned path for the borehole 11, the control application 230 and/or the tool 10 may indicate that drilling conditions changed.

If the drilling conditions changed, the control application 230 and/or the tool 10 may transmit the report and/or the data using the telemetry system 100. If the drilling conditions changed, the control application 230, the tool 10 and/or the terminals 211-213 may calculate, may generate and/or may transmit an updated model. For example, the updated model may indicate an updated path of the borehole 11 and/or updated formation locations and/or depths. The updated model may indicate an updated time and/or an updated location for occurrence of the planned events, such as, for example, the change in the trajectory, the change in the rate of penetration, the change in the weight-on-bit, the change in drilling fluid rate and/or weight, the replacement of the drill bit 15, the setting of the casing and/or the like. The updated time and/or the updated location of the planned events in the updated model may be different than the time and/or the location of the planned events in the well plan information. As a further example, the updated model may indicate updated features of the borehole 11, such as, for example, an updated trajectory. As yet another example, the updated model may revise the planned path and/or provide the updated path for the borehole 11.

For example, the updated model may indicate revised characteristics of the area where the drilling operations occur. The revised characteristics in the updated model may be different than the characteristics in the well plan information. The characteristics of the area where the drilling operations occur may be, for example, expected values that may variate from actual values. As a further example, the characteristics of the area may have changed due to formation of the borehole 11.

The control application 230 and/or the tool 10 may adjust the drilling operations based on the updated model. The control application 230 and/or the tool 10 may adjust the drilling operations without instructions from the first network 200 and/or the terminals 211-213. For example, the control application 230 and/or the tool 10 may adjust a direction of drilling, decrease a rotational speed of the drill string 12, change a flow rate of the drilling fluid, increase the rotational speed of the drill string 12, decrease a down-hole force and/or weight on the drill bit 15, increase the down-hole force and/or weight on the drill bit 15 and/or the like based on the updated model. The control application 230 and/or the tool 10 may adjust operational parameters of the tool 10 to optimize performance, determine a characteristic of the borehole 11 and/or the drill string 12 and/or otherwise control the tool 10.

The well plan information may indicate a casing point for the borehole 11. The casing point may be a location where casing pipe is lowered into the borehole 11 and maintained in a fixed position, such as, for example, by cement. The casing pipe may be used to isolate formations having different pressure gradients. The data may be used to determine the casing point and/or a revised casing point. For example, the data may indicate the different pressure gradients of the formations located proximate to the borehole 11. The control application 230 and/or the tool 10 may use the different pressure gradients as indicated by the data to determine the casing point and/or the revised casing point. The control application 230 and/or the tool 10 may determine the casing point and/or the revised casing point without instructions from the first network 200 and/or the terminals 211-213. The updated model may indicate the pressure gradients and/or the revised casing point.

For example, the tool 10 may be and/or may be associated with a steering mechanism 50 connected to the drill string 12 and/or the drill bit 15. The steering mechanism 50 may adjust the drilling operations and/or the direction of drilling. The steering mechanism 50 may use the data to maintain the inclination of the borehole 11 and/or the azimuth of the borehole 11. For example, the steering mechanism 50 may maintain the inclination of the borehole 11 and/or the azimuth of the borehole 11 without instructions from the first network 200 and/or the terminals 211-213. As a further example, for vertical drilling, the steering mechanism 50 may maintain a vertical orientation of the borehole 11 without instructions from the first network 200 and/or the terminals 211-213. The steering mechanism 50 may use the data to maintain continuous rotation of the drill string 12. For example, the steering mechanism 50 may maintain the continuous rotation of the drill string 12 without instructions from the first network 200 and/or the terminals 211-213.

In an embodiment, the tool 10, such as, for example, the steering mechanism 50, may obtain the data, the well plan information and/or the like from the database 229 and/or the first network 200. The data, the well plan information and/or the like may be required and/or may be beneficial for operation of the tool 10. For example, the steering mechanism 50 may obtain formation-related information from the database 229, and/or the formation-related information may relate to another wellbore located near the borehole 11, another wellbore that used similar equipment as the borehole 11 and/or the like. The steering mechanism 50 may be, for example, a rotary steerable system as known to one having ordinary skill in the art. The present invention is not limited to a specific embodiment of the steering mechanism 50.

The control application 230 and/or the tool 10 may be programmed and/or may be designed to utilize the well plan information, the updated model and/or the data to calculate and/or determine a predicted state of the tool 10. The predicted state of the tool 10 may be, for example, a predicted location of the tool 10 at a specific future point in time, a predicted temperature of the tool 10 for a specific location of the tool 10, a predicted power level of the tool 10 at a specific future point in time and/or a specific location of the tool 10, a predicted level of operation relative to maximal operation at a specific future point in time and/or a specific location of the tool 10 and/or the like. The present invention is not limited to a specific embodiment of the predicted state of the tool 10.

The control application 230 and/or the tool 10 may compare the predicted state of the tool 10 to the parameters. The control application 230 and/or the tool 10 may determine whether to generate and/or transmit the report based on comparison of the predicted state of the tool 10 to the parameters. For example, the control application 230 and/or the tool 10 may determine to transmit the report based on determination that a predicted temperature of the tool 10 may exceed a threshold temperature at a specific future time. The tool 10 may transmit the report using the telemetry system 100.

The control application 230 and/or the tool 10 may adjust the drilling operations based on the predicted state of the tool 10, and/or the control application 230 and/or the tool 10 may adjust the drilling operations without instructions from the first network 200 and/or the terminals 211-213. For example, if the predicted state of the tool 10 indicates that the tool 10 may exit a target reservoir, the control application 230 and/or the tool 10 may adjust the drilling operations so that the tool 10 does not exit the target reservoir. The control application 230 and/or the tool 10 may adjust the drilling operations so that the tool 10 does not exit the target reservoir without instructions from the first network 200 and/or the terminals 211-213. For example, the steering mechanism 50 may adjust the drilling operations so that the tool 10 does not exit the target reservoir.

The control application 230 and/or the tool 10 may be programmed and/or may be designed to generate and/or transmit a recommendation. For example, the control application 230, the telemetry system 100 and/or the tool 10 may generate and/or may transmit the recommendation if the drilling conditions may have changed. The tool 10 may transmit the recommendation using the telemetry system 100. The recommendation may be, for example, a recommended adjustment of the drilling operations, a recommended request for additional data, a recommended and/or the like. The recommendation may be based on the predicted state of the tool 10, the updated model and/or the data.

The report may have the recommendation. The control application 230 may display the recommendation on the terminals 211-213. The user may be informed of generation and/or availability of the recommendation, such as, for example, by an email, a pager message, a text message and/or the like.



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stats Patent Info
Application #
US 20140131099 A1
Publish Date
05/15/2014
Document #
14157453
File Date
01/16/2014
USPTO Class
175 27
Other USPTO Classes
International Class
/
Drawings
5



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