HK40001271A - Horizontal directional drilling area network and methods - Google Patents

Description

Horizontal directional drilling area network and method

The application is a divisional application of a Chinese patent application with application number 201380006984.8, entitled "horizontal directional drilling area network and method", which is filed on 7/1/2013.

RELATED APPLICATIONS

Priority of U.S. provisional patent application serial No. 61/584,231, filed on 7/1/2012, of this application, is hereby incorporated by reference herein in its entirety. This application also claims priority from U.S. patent application serial No. 13/734,841, filed 2013, month 1, and day 4, which is hereby incorporated by reference in its entirety.

Background

The present application relates generally to at least horizontal directional drilling operations, and more particularly to systems, devices, and methods involving horizontal directional drilling area networks.

Conventional horizontal directional drilling systems typically use many components such as an underground transmitter, a drilling rig, and a hand-held locator. Applicants have recognized that communication between these components is generally limited to the minimum functionality required to successfully complete a particular subterranean operation, such as constructing a borehole trajectory and then back reaming to install a facility underground.

Due to the complexity of the equipment making up the entire current horizontal directional drilling system, the operator may be responsible for many aspects of the system operation, usually with little or no external or remote supervision. Applicants have had many considerations in this regard. One aspect of the consideration relates to maintenance of components and systems. In some cases, component or system failures are due to failure to follow manufacturer specified maintenance procedures. Another aspect of consideration is the need to carefully monitor certain operating parameters when performing subterranean operations, to ensure that installed facilities are not damaged by the subterranean operation, to ensure that performance of the subterranean operation is within acceptable limits, or to simply provide remote supervisory supervision, for example to allow a supervisor to monitor multiple drilling projects simultaneously.

Furthermore, it is becoming increasingly common practice to record operating parameters of subterranean operations to "as built" drawings, and in some cases now to be imposed on contractors as conditions for giving a project, or as conditions for paying for the project. Applicants have recognized that the means to record such data and generate such as-built drawings in horizontal directional drilling projects are currently very limited and do not allow for remote data storage.

As will be discussed further, another aspect of consideration relates to wide regulations imposed by government agencies for performing subterranean operations in a specified area.

Finally, applicants recognized that due to increased competition in the horizontal directional drilling industry, current systems would limit the ability of companies in the industry to offer products and services to increase sales opportunities and to provide better services to their customers.

The above examples of related art and related limitations are for illustrative purposes and are not intended to be exhaustive. Other limitations of the related art will become apparent to those of skill in the art upon a reading of the specification and a study of the drawings.

Disclosure of Invention

The following embodiments and aspects thereof are described and illustrated in conjunction with systems, tools, and methods, which are meant to be exemplary and illustrative, not limiting in scope. In several embodiments, at least attempts are made to solve one or more of the above-described problems in order to mitigate or eliminate these problems, while other embodiments are directed to other problems.

In general, an arrangement, apparatus, and associated method are described for use in connection with a system for performing horizontal directional drilling that includes a drilling rig and a subsystem for monitoring the position of an inground tool along an underground borehole trajectory and other operating parameters associated with the underground borehole trajectory. A downhole transceiver supported in proximity to the inground tool for two-way communication including receiving operational instructions and transmitting positioning and operational data from the surface. A drilling area network hub locatable on a drilling rig, comprising: an uphole transceiver for data communication with the downhole transceiver for bidirectional communication between the inground tool and the drill rig using the drill string as an electrical conductor; a data communication device that monitors at least at the drilling rig to generate specific information, the specific information including at least one of location information and rig-based information; a processor for collecting specific data to generate at least one site report from specific information, the site report relating to at least one of a subterranean operation, an operational status of a downhole transceiver, an operational status of an uphole transceiver, an operational status of a drilling rig; an internet connection means for at least intermittent data communication with the internet for transmitting the site report to a remote location.

In another aspect of the disclosure, a drilling area network hub is located proximate to the drilling rig for collecting at least system-generated borehole trajectory data and system-related operational data characterizing the borehole trajectory to generate at least one field report and one or more suggested actions based on the borehole trajectory data and the operational data to characterize at least one of the subterranean operation and the rig operational state. An internet connection device, which may form part of the drilling area network hub, is used to at least intermittently communicate data with the internet to transmit the site report to a remote location. A drilling area network server receives a site report from a remote location over the internet and generates a custom report based on the site report.

In another aspect of the disclosure, an apparatus and associated method monitor a horizontal directional drilling system for performing an underground operation, the system including a drilling rig and a subsystem for monitoring a position of an inground tool along an underground borehole trajectory and other operating parameters associated with the underground borehole trajectory. The application receives system-generated borehole trajectory data characterizing a subsurface borehole trajectory and system-related operational data received via remote electronic data transmission at a location remote from the subsurface borehole trajectory, and generates at least one of a custom report and one or more suggested actions based on the borehole trajectory data and the operational data.

In another aspect of the disclosure, an apparatus and associated method for customizing one or more configurable components of a horizontal directional drilling system according to zone specific parameters. A horizontal directional drilling system includes a drilling rig and a subsystem for monitoring the position of an inground tool along an underground borehole trajectory and other operating parameters associated with the underground borehole trajectory. The geographic database of region-specific parameters specifies operating parameters based on the location of one or more components of the horizontal directional drilling system. An apparatus is provided for identifying a current location of at least one locatable system component of the system in an area and associating the current location with a geographic database to identify a set of local requirements for the current location. The controller customizes at least one operating parameter of the one or more configurable components based on the current location to meet the set of local requirements. The operating parameters as a result of these requirements may include, without limitation, transmit frequency and maximum transmit power. As one feature, the system may be automatically configured to conform to the region-specifying parameters.

In another aspect of the disclosure, an apparatus and associated method monitors a system for performing horizontal directional drilling that includes a drilling rig and a subsystem for monitoring a position of an inground tool along an underground borehole trajectory and other operating parameters associated with the underground borehole trajectory. A drilling area network hub located proximate to the drilling rig location is used to generate a plurality of different types of data logs characterizing a subterranean operation as it is performed along the borehole trajectory, the drilling area network hub in at least intermittent data communication with the remote location. The priority table imposes priority levels on the different types of data logs, thereby enabling the drilling area network hub to transmit the data logs to a remote location according to the priority table.

Drawings

Exemplary embodiments are shown in the referenced figures. The embodiments and figures disclosed herein are meant to be illustrative, not limiting.

Fig. 1 is a schematic elevation view of a drilling area network and its components operating as part of a horizontal directional drilling system according to the present disclosure.

FIG. 2 is a block diagram illustrating one embodiment of components of a drilling area network according to the present disclosure.

FIG. 3 is a flow chart illustrating one embodiment of a method for performing a drilling area network update.

Fig. 4 is a block diagram illustrating one embodiment of a Drilling Area Network (DAN) hub according to the present disclosure.

Figure 5 is a flow chart illustrating one embodiment of a method of operating the drilling area network hub of figure 4.

Fig. 6 is a block diagram illustrating one embodiment of a Drilling Area Network (DAN) server according to the present disclosure.

FIG. 7 is a flow chart illustrating one embodiment of a method of operation of the drilling area network server of FIG. 7.

Detailed Description

The following description is presented to enable one of ordinary skill in the art to make and use the invention and is provided in the context of a patent application and its requirements. It will be apparent that various modifications to the described embodiments will be readily apparent to those skilled in the art, and the generic principles taught herein may be applied to other embodiments. Thus, the present invention is not intended to be limited to the embodiments shown, but is to be accorded the widest scope consistent with the principles and features described herein (including modifications and equivalents). It should be noted that the drawings are not to scale but are diagrammatic and are drawn in a manner that is believed to best illustrate the subject features. The described technology, as well as the various views provided in the drawings, are provided for the purpose of enhancing the reader's understanding and are in no way intended to be limiting.

Turning now to the drawings, wherein like items may be designated by like reference numerals throughout the various views, attention is now directed to FIG. 1, which illustrates one embodiment of a drilling area network, designated generally by reference numeral 10, for use in connection with a system 12 for performing subterranean operations. The system includes a handheld device 20 that may be carried by an operator 22. The apparatus 20 is used to receive electromagnetic locating signals 30 from subsurface equipment such as a drilling tool 32. The locating signal may be a dipole signal. In this example, the handheld device may be consistent with a handheld device such as described in any of U.S. Pat. Nos. 6,496,008, 6,737,867, 6,727,704, and published U.S. patent application No.2011-0001633, which are incorporated herein by reference in their entirety. In view of these patents, it should be appreciated that these handheld devices may operate in a simple positioning mode, as shown in FIG. 1, or in a home reset mode, which places the handheld device on the ground, as shown in U.S. Pat. No.6,727,704. Although the present disclosure shows a dipole localization field emanating from a drilling tool that rotates about an axis of symmetry of the field, the present disclosure is not intended to be so limited. Many suitable system configurations may be implemented. For example, the localization field may emanate from the handheld device itself, as seen at least in fig. 18a and 18b of U.S. patent No.7,425,829 and fig. 3b of U.S. patent No.7,775,301, which are incorporated herein by reference. It should be noted that in the latter patent, the magnetic dipole field is rotated about an axis transverse to the field symmetry axis. In such a system, the receiver in the drilling tool can detect the rotating magnetic field emitted by the handheld device, so that the receiver in the drilling tool generates position-related data, which is transmitted to the drilling machine in a suitable manner. Another type of system does not require a handheld device to track the inground tool or transmit a locating signal. For example, certain prior art systems may track the position of an inground tool by integrating orientation parameters that are transmitted from the inground tool to the drill rig through the drill string and/or using an inertial navigation system supported by the inground tool. Accordingly, applicants contemplate that the systems and related methods described herein may be used because it enables the use of any information generated by any system component, so long as the information is related to the operation being performed. The handheld device or any other system component on the ground may include a GPS (global positioning system) receiver for determining the position of the component at any suitable time during operation. The GPS component may be survey-grade, providing enhanced positioning accuracy.

Returning to continuing with discussion of FIG. 1, the positioning signal 30 may be modulated using information generated in the drill tool, including (but not limited to) positional orientation parameters based on readings of the positioning sensors, temperature values, pressure values, battery status, tension readings in a pullback operation, and the like. In this regard, the handheld device 20 includes a telemetry arrangement having a telemetry antenna 40 that transmits telemetry signals 42. It is sufficient to now recognize that the telemetry signal can be used to convey any information modulated onto the locating signal to other locations on the ground, such as the drilling rig. It should be understood that the subterranean device is not limited to drilling tools, as other types of subterranean devices can transmit the locating signal. For example, another suitable type of underground equipment is a drill used in pullback operations to install a utility line in a pre-formed above-ground gouge. It should be noted that as an alternative to modulating the positioning signal, the information may be transmitted from the drill string to the drilling rig using a conductor (e.g., an in-pipe cable). In another embodiment, bidirectional data transfer may be achieved using the drill string itself as the electrical conductor. As an example, the current transformer 50 may be in electronic communication with the console 120 and in electromagnetic communication with the drill string 100. It is noted by guidance that such current transformers on the drill string are well known to those skilled in the art and typically use a toroid core around the drill string. The toroid supports a toroid, which is coupled to the conductive drill bit through the toroid, thereby making the drill string a single turn winding to implement a current transformer. An improved embodiment of a drill string communication system is described in commonly owned U.S. application serial No. 13/733,097, filed on 1/2/2013, which is hereby incorporated by reference in its entirety. Either of which, the console 120 at the rig, can obtain all of the information.

With continued reference to fig. 1, system 12 further includes a drill 80, drill 80 having a carriage 82 receiving movement of carriage 82 along the length of an oppositely disposed pair of rails 83. The drilling tool 26 includes an asymmetric surface 84 and is attached at the other end to a drill string 86. Typically, the drill string 86 is made up of a number of removably attachable drill pipe pieces, such that the drill rig can press the drill string into the ground with movement in the direction of arrow 88 and pull the drill string back with reverse movement. Joints 90 between adjacent drill pipe sections in the drill string are shown schematically in vertical lines. The drill pipe components may define a through passage for the transport of drilling mud or fluid 92 that is emitted from the drilling device under pressure to aid in cutting into the ground and cooling the drill bit. Typically, the drilling mud also serves to retain and transport the cuttings to the surface along the outer length of the drill string. Steering can be accomplished in a well-known manner by orienting the asymmetric face 84 so that the drill is deflected in the desired direction in the ground in response to a forward, pushing movement (which may be referred to as a "push mode"). Turning or rotating the drill string by the drill rig typically results in forward or straight advancement of the drill tool, which may be referred to as a "spin" or "go" mode.

This example assumes that the movement of the drill is in a standard (master) XYZ coordinate system. For purposes of simplicity, the X-axis may be at least generally coextensive with the ground and generally above the intended tool path in this example, however, any other suitable coordinate axis configuration may be adopted. The origin of the standard coordinate system is designated by reference numeral 100 and may coincide with the point at which the drill enters the ground, although the coordinate axes are offset in this view for purposes of clarity of illustration. Although a cartesian coordinate system is used as the basis for the standard coordinate system in the several embodiments disclosed herein, it should be understood that this term is used for illustrative purposes and any suitable coordinate system may be used. As mentioned, the X axis extends forward, while the Y axis extends to the right facing forward along the X axis, and the Z axis is directed downward.

The drilling operation may be controlled by an operator (not shown) at a console 120, the console 120 itself comprising a telemetry transceiver 122 connected to a telemetry antenna 124 for transmitting telemetry signals 125, a display screen 126, input devices (such as a keyboard 130), and a processing apparatus 132 which may include appropriate interfaces and memory and one or more processors. A plurality of control rods 134, for example, control movement of the carrier 82 and other functions of the drilling rig. In one embodiment, the screen 126 may be a touch screen, thereby making the keyboard 130 optional. It should be noted that telemetry systems such as those formed between the equipment 20 using the signal 42 and the drilling rig using the signal 125 are typically subject to regulatory control at least in terms of transmitted power and transmitted frequency. The telemetry system may be considered a system component since it may be configured in real time according to the transmission power and transmission frequency.

With continued reference to FIG. 1, a Drilling Area Network (DAN)10 may be considered to contain the components of the field telemetry system described above, which may provide wireless two-way communication between the handheld device 20 and the telemetry transceiver 122 at the drilling rig. The DAN also includes a DAN hub 210, which may be located at any suitable physical location, such as on the console 120 at the rig. The DAN hub is in data communication with the drill rig 80 and the handheld device 20 via the telemetry transceiver 122. In one embodiment, the drilling rig 80 may be equipped with a controller area network bus (CAN bus) for providing and facilitating data communication. The CAN bus operates according to a message-based protocol, which was originally designed for automation applications, but which is rapidly expanding to applications in other fields, such as industrial and medical equipment. Although the specific details of the operation of the CAN bus are beyond the scope of this disclosure, it should be understood that the CAN bus CAN be readily implemented to function as a practical monitor of any aspect of the operation of the drilling rig 80, at least some of which will be described in detail at one or more appropriate points below. Further, it should be noted that the DAN hub may be used to facilitate information exchange with any device used to monitor and control a drilling rig, and is not limited to a CAN bus.

The DAN hub 210 may be configured for connection to the internet 212, for example using a wireless connection as indicated by arrow 214. The connection may be made in any suitable manner, such as using a cellular data connection, a satellite data connection, a WiFi connection based on the well-known IEEE802.11 standard protocols, or any other suitable form of wireless connection, currently available or not yet in use. In this regard, a great deal of flexibility may be given to the system operator. It should be understood that the particular type of internet connection or connections available changes from one location of a subterranean operation to the next, such that a given DAN may be implemented to accommodate more than one internet connection. Furthermore, the system operator may even choose to connect to a mobile phone for acting as a WiFi hotspot over WiFi, which may provide significant data bandwidth. DAN server 220 may communicate with DAN hub 210 via the internet. For example, as will be further described, the DAN hub may use a web service to send operational data to the DAN server. The DAN server may be connected to the internet in any suitable manner, as illustrated by connection 222. The user may connect to the DAN in any suitable manner. A first user computer 226 is shown connected directly to the DAN server through a local area network 230, while a second user computer 232 is shown connected to the internet through a connection 234 for remote or wide area network connection to the DAN server 220. The user may access the DAN server through a standard internet connection. Although two users are shown for purposes of simplicity, it should be understood that a large number of users may be supported by the DAN server.

Fig. 2 is a block diagram illustrating an embodiment of the DAN 10 in a manner consistent with fig. 1. In this regard, it should be understood that the locating signal may be transmitted from a transceiver 32 ', and the transceiver 32' may be movably mounted in the drilling tool 32 of FIG. 1. In one embodiment, the above-ground data communication with the transceiver 32' may be facilitated by an infrared connection (IrDA)240 between the transceiver and the handheld device. As an example, such an infrared connection may be used to program a transceiver prior to a particular subterranean operation. Characteristics of the programmable transceiver include, but are not limited to, carrier frequency, signal strength, and baud rate of the positioning signal. It should be understood that the connection to the drill bit transceiver may be in any suitable manner and is not limited to infrared. The connection may be implemented, for example, by bluetooth. In another embodiment, subsurface communication (shown in phantom) with bit transceiver 32' may be achieved using communication link 241, which communication link 241 may couple data signals onto the drill string as electronic signals for bi-directional transmission with the drill string as an electrical conductor. Applicants have developed an improved drill string communication system such as the above-described U.S. patent serial No. 13/733,097, which is incorporated herein. In one embodiment, the bit transceiver 32 '(which may alternatively be referred to as a downhole transceiver) may be in electrical communication with a downhole current transformer 50' to implement the link 241, thereby enabling bidirectional communication with the underground lower end of the drill string in the same manner as the current transformer 50 described above. Another suitable type of coupling device adjacent the underground end of the drill string may form an electrically insulating space in the electrical connection of the drill string, across which the transceiver 32' bridges. While such electrical isolation intervals are well known in the art, an improved approach is described, by way of example, in U.S. patent application serial No. 13/593,439, filed on 8/23/2012, which is commonly owned with the present application and incorporated herein by reference. The CAN bus 242 is expressly shown as extending between the DAN hub 210 and the rig 80. It should be understood that the CAN bus may be implemented as part of the processing device 132 at the drilling rig. The telemetry signal 42 may be implemented in the ultra high frequency band, for example at 464.5MHz, and is therefore specified accordingly. Any suitable set of parameters, including the combination of parameters shown in fig. 2, may be monitored for operation of the drilling rig, such as water pressure, mud flow rate, drill bit rpm, drill string length, and drill string grip.

Referring to fig. 1 and 2 concurrently, the DAN hub 210 may serve data flow in a drilling area network in the manner of a central controller. The DAN hub may collect data from the handheld device 20, the transceiver 32', the drill 80, and any required system components. The collected data may be transmitted to the DAN server for further processing and viewing by the DAN service, as will be described below. The DAN hub may receive remote data from the DAN server for further processing, viewing, and/or transmission to the handset 20, bit transceiver 32', or drill 80. Data that may be collected and stored remotely by the DAN hub include, but are not limited to:

data logs created during drilling operations, including information such as:

o depth of drill bit at several points during drilling

o wheelbase of the drill bit at several points during drilling (pitch)

o temperature of the drill bit at several points during drilling

o annular fluid pressure of drill bit at several points during drilling

Tension of the pull-back facility at several points during the pull-back process

GPS coordinates of handheld devices, drills, and any other system components

o state of the handheld device or locator

o state of bit transmitter or transceiver

With respect to data logs, different types of data logs may be handled differently. As one example, tension data in a pullback operation may be considered a high priority, such that the transfer of tension data precedes other types of data logs. The data logs may be transmitted with priority, for example, based on predetermined threshold limits for each data log type. For example, the fluid pressure log may be associated with a maximum pressure value. If the maximum pressure is exceeded, the pressure log may be identified and transmitted to the DAN server in an appropriate manner. In instances in which the predetermined threshold is exceeded, the associated data log may be incrementally transferred. When the threshold is exceeded, the designated user may be notified, for example, by e-mail. Table 1 illustrates one embodiment of a priority system, although any suitable embodiment may be used without limitation.

TABLE 1

During normal operation of the system, the transfer of data logs may be performed according to fig. 1. If the thresholds for two or more different types of data logs are exceeded simultaneously, or at least in an overlapping manner, arbitration may be performed according to the priority assignment of Table 1. In one embodiment, the threshold value may be determined as a function of the product specification of the facility being installed during the pullback operation. For example, when a plastic pipe is stretched, the pull-back tension threshold will be significantly different than the threshold for stretching a steel pipe. Accordingly, table 1 indicates that the pullback tension threshold may be based on the facility. Given the manufacturer's specifications for the facility, a maximum pull-back tension Tmax will be specified. Either alone or in combination with Tmax, a maximum rate of change of the tension Δ Tmax may be specified. Also, the resistance to annular fluid pressure can vary greatly depending on the type of raw material making up the facility. Thus, table 1 indicates that the threshold value for the annular fluid pressure may be based on the type of facility and/or the type of subterranean operation being performed. Further, a maximum annular fluid pressure value and/or a maximum rate of change of the annular pressure may be specified.

It will further be appreciated that the annular pressures for drilling a pilot hole to form a drilling trajectory and for performing a pullback operation to install a facility along the drilling trajectory may have different thresholds. In one embodiment, at least some thresholds may be provided based on multiple copies of Table 1, which may be retrieved based on different types of subterranean operations and types of facilities installed. Taking the bit temperature as an example, the threshold value may be based on a maximum temperature tmax and/or a maximum rate of temperature change Δ tmax. By way of non-limiting example, a maximum temperature of 45 ℃ may be beneficial depending on the temperature limit of any electronics carried by the inground tool. Such a fixed threshold is beneficial for indicating a slow rise in temperature. The operator may take action such as reducing the rate of ripping/rotational speed of the drill string and/or increasing the amount of drilling mud to provide cooling while drilling or back reaming. Another example of Δ tmax is a temperature rise from 30 ℃ to 60 ℃ in a one minute interval, which may be a useful threshold. This type of threshold is useful, for example, when rock is encountered and the temperature rises rapidly. With respect to GPS coordinates, many GPS systems can provide an indication of the accuracy of a currently specified location. That is, the GPS gives a positive or negative distance from the current designated location. Thus, a minimum accuracy may be specified, as represented by (+/-) Dmin in Table 1.

The status of the handheld device.

In this regard, a large amount of data may be transmitted by telemetry from the handheld device to the DAN hub, and then stored and made available on the DAN server. Such data may include, but is not limited to, battery status, number of hours of operation remaining based on current battery status, software version, number of hours of operation, serial number of equipment, customer asset number, optional parts already installed, fault log, current latitude/longitude location, and the like. The DAN hub may process the data before it is transferred to the DAN server, but this is not mandatory. Such pre-processing may be based at least in part on available bandwidth for internet access or on priority needs of data on the DAN server. For example, when the progress of an underground operation needs to be monitored remotely in real time, the drill hole trajectory-related data used to establish an as built map of drill hole trajectories may be of high priority. As another example, the preprocessing may be performed based on identifying that a preset threshold is exceeded, as described above.

State of the bit transceiver 32

Almost the same information referenced above regarding the hand-held instrument may be transmitted through the drill bit transceiver 32' and remotely monitored or stored, including but not limited to battery status, number of operating hours remaining based on current battery status.

State of the drilling machine

Through the CAN bus interface, the DAN hub CAN compile rig usage statistics, alarms, and other information critical to proper maintenance of the rig.

Status of DAN hub

DAN service

DAN server 220 may process data collected by DAN hub 210 to provide DAN services, such as:

accessing data logs collected during drilling operations for generating "as built" drawings

Remote monitoring of the progress of a particular drilling operation

Access to the status of all devices in the DAN, including the DAN hub, one or more handheld devices, a drill bit transceiver, and a drill rig

The DAN server 220 may push data to the DAN device, including:

software update of the hand-held device 20

Software update of the bit transceiver 32

Software updates of the rig 220

Software updates to the DAN hub 210, including, for example, purchasing applications that can be loaded and executed in real-time

Map data from the geographic information service displayed on the screen 126

Other data, e.g. information and advertising

Fig. 3 is a flow diagram illustrating an embodiment of a method for performing a DAN component update, the method being generally illustrated by reference numeral 300. The method starts at 302 and proceeds to 304 (loading update data to the DAN server 220 (fig. 1 and 2)). The update data may be placed on the DAN server, for example, through LAN users 226 or WAN users 234. The update data may then be transmitted to DAN hub 210. Of course, the update data may be communicated to any number of DAN hubs, as the update data may be directed to any number of similar DAN components distributed globally. Step 308 determines whether the update data is directed to handheld device 20. If so, operation proceeds to 310 where the update data is transmitted to the handheld device at step 310 via telemetry transceiver 122, for example, over a very high frequency band. The handheld device may then execute the update data. If step 308 determines that the update data is not directed to the handset, operation proceeds to 312 where it is determined if the update data is targeted to the drill bit transceiver 32' at step 312. If so, operation proceeds to 314 where the update data is transmitted to the drill bit transceiver over the IrDA link. Of course, if the drill bit transceiver is currently participating in some subterranean operation, it cannot be data updated until the drill bit transceiver is available at the surface. If step 312 determines that the update data is not directed to the drill bit transceiver, operation proceeds to 316 where it is determined whether the update data is directed to the drill 80. If so, at step 318, the update data is transmitted over the CAN bus via the CAN bus protocol to the drill rig for installation. If step 316 determines that the updated data is not targeted for the rig, operation proceeds to 320 where it is checked whether the updated data is directed to some other DAN component, such as a tension monitoring device used in a pullback operation. If so, operation proceeds to step 322 where the update data is transferred to the other components and the update is performed in the appropriate manner. If step 320 determines that the update data is not directed to other components, then operation returns to step 304. In this regard, operation may also return to step 304 after any of steps 310, 314, 318, 322. In certain embodiments, the DAN hub may act as a controller to dynamically set certain operating parameters of the system components, as will be described immediately below.

As noted above, government agencies may impose widely varying demands on subterranean operations in a given area. The presence of a drilling area network may facilitate compliance with such regulations, such as by identifying a geographic location where an item is to be conducted and facilitating manual and/or automatic adjustment of operational parameters of associated equipment to match the regulatory requirements of such geographic location. It should be appreciated that such updating of operating parameters may be handled by the method 300 of FIG. 3.

Referring again to FIG. 1, the rig-located console 120 may include a GPS receiver 400, shown by way of non-limiting example as part of the telemetry transceiver 122, for GPS signals 402. The GPS receiver may include an updatable map that may be preloaded and/or obtain map information in real-time via the wireless connection 214. The GPS receiver 400 is able to determine the current location of the rig or other system component in which the GPS receiver is located. Any suitable system component may serve as a positionable component, such as handheld device 20. In one embodiment, the system 10 is able to identify a particular geographic region in which to perform a current operation and to customize system operation and system components to conform to region-specific parameters. The region specifying parameters may be stored and accessed in any suitable manner. In one embodiment, the region-specific parameters may be stored by one or more local DAN components (e.g., DAN hub 210 and/or handheld device 20). In another embodiment, the zone designation parameters may be stored remotely on the DAN server 220 and accessed over the internet. In another embodiment, the zone designation parameters may be stored on both the DAN server 220 and the local DAN component. The information on the DAN server may be periodically updated by a remote administrator so that the DAN hub may be periodically updated or synchronized with locally stored information. As will be further described, in some cases, the region-specifying parameters are authorized by a government agency, while in other cases, the region-specifying parameters may represent other local information. In some other cases, the local information may be provided to the operator for a wide range of purposes.

Regional specific parameters imposed by a governmental agency, such as regulatory agencies and/or laws or regulations, may include specifications of acceptable transmission frequency and power (i.e., signal strength) limits in a region (as non-limiting examples). In response to this specification, the DAN hub 210 may implement appropriate settings for the configurable components, including, but not limited to, setting the telemetry signals 125 and 42 for use by the telemetry transceiver 122 and the handheld device 20 located at the drilling rig, respectively, and may further set the subsurface transceiver 32' and the handheld device 20, respectively, to transmit and receive the locating signal 30 at the appropriate frequency and power level. In one embodiment, the system may be configured such that the operator cannot exceed a specified frequency, power, or other parameter for the area. In another embodiment, the local government may provide options such as explanations of different frequencies and frequency bandwidths or other exceptions beyond the specified frequency, power or other parameters. Other government imposed parameters may include, for example, modulation type and data rate, all of which may be adjusted. In one embodiment, identifying desired settings, such as transmission settings for frequency and signal strength, may result in automatic reconfiguration of the system to meet the desired settings.

Other local information may include, by way of non-limiting example, language, time, date, time zone, units of temperature (e.g., degrees celsius or fahrenheit), and units of measure (e.g., meters or feet). The local information may also include any location-based service, such as a local weather forecast and/or weather alert or local advertisement, as non-limiting examples.

Regional profiles representing specific geographic regions may be provided, including but not limited to a federation of countries, such as the european union, individual countries, counties, cities. Each profile may provide a customized version of any combination of national and/or regional government requirements, standard practice requirements, and local information. Profile information representative of operational requirements, such as frequency and power settings, may trigger automatic setting of specified values.

With continued reference to fig. 1, the system 10 may provide remote tracking of the operation and/or configuration of any DAN component. For example, the usage of system components such as the locator 20 and the drilling rig 80 may be tracked in terms of hours of operation. The GPS location of any GPS-enabled component can be tracked. Other information may include, by way of non-limiting example, the model and serial number of the system component, a manufacturer identification of the system component, a customer's ID, contractor information. In addition, the target information of any of the data logs described above may be monitored. The fault status of any component can be tracked. For example, the DAN component may be set to issue a fault code to the DAN hub 210. Using the locator 20 as an example, the locator may issue a fault code for the state where the internal battery reaches an end-of-life condition. Another fault code may be about a need to update an installed software version. The CAN bus CAN be used for monitoring and recording specified parameters of the drilling machine. All collected information may be stored locally by DAN hub 210 and uploaded to DAN server 220 in the form of a field report when an internet connection is available. In some instances, the site report may actually be merely an update or notification of the site, where no processing is performed, nor is it necessary (e.g., formatting) to transmit the substantially raw, raw data to the remote location. Such a transfer of raw data may be useful when sufficient bandwidth is available for remote transfer. As non-limiting examples, the raw data may include measurements related to the inground tool including, for example, direction, temperature, fluid pressure, thrust pressure, and the like. In such embodiments, the DAN server or other remote component may perform any desired and/or required subsequent data processing, analysis, and operations. In other examples, the field report may be generated locally through the DAN hub to impose any degree of processing and analysis necessary and that may generate appropriate recommendations.

Such locally generated field reports may be generated by the DAN hub alone, by an application running on the DAN hub, or in conjunction with an application running on the DAN hub. In any case, the application may be a third party application. The DAN hub may use any locally available components and resources that are believed to be relevant to the task of generating a field report in conjunction with the DAN hub. Of course, the DAN hub may identify the available bandwidth of the internet connection and create the data transfer according to a pre-set priority. Essentially, substantially any aspect of system components and/or operations that are sensitive to data characterization can be monitored by the system. Accordingly, the field report may include locator-based and/or drill-rig based information to characterize at least one of the subterranean operation, the operational status of the transceiver in the well, the operational status of the drill rig, and the operational status of the hand-held device 20.

The information stored at the DAN hub and/or transmitted to the DAN server may be used in a number of different ways. For example, a notification may be provided to a system operator based on the uploaded information. Again taking the locator 20 as an example, the operator may be notified via email that the locator battery is nearing end of life and should be replaced. For example, a notification may also be provided indicating that an updated software version of the operator locator is available. In one embodiment, information related to the current operating region may be compared to the current operating mode of the system and/or its components. In one embodiment, if the frequency, power, or other settings of the current operating region do not match the current system settings, a notification may be provided locally (e.g., on a component of display 126) and stored by DAN hub 210. As a feature, the notification may be communicated to the DAN server 220 so that the remote notification may be published in any suitable manner, such as by email. The suggestions may include some form of notification and may include a wide range of topics. By way of non-limiting example, steering commands (e.g., push, turn, rotate) may include a form of advice to provide an operator in a drilling operation, such as a drill bit that is to remain forward and/or return to a desired path. Another form of suggestion may warn that retraction of the drill bit should be stopped immediately, for example in response to a tension threshold being exceeded during the pullback facility. Likewise, an advisory warning may be generated to reduce or stop the flow of drilling mud in response to the fluid pressure reading exceeding the threshold. Other recommendations may inform to change carrier frequencies and/or parameters to meet zone specific requirements, replace positioner batteries, perform equipment checks based on detecting any overflow conditions of the rig (e.g., oil pressure, water pressure, mud pressure, etc.). Other recommendations may involve cross-hole or surface exposure and may include corrective steps for these conditions.

The information stored in DAN server 220 may serve as a basis for access by several different users and/or groups of users. The DAN server may include an application customized to the manufacturer and select at least a plurality of users and/or groups of users. By way of non-limiting example, a particular group of target users may include distribution partners, customers, facility operators, contractors, and any government authority, such as municipalities that manage the facility distribution system. The information may be customized and presented to the various institutions in any suitable manner and in almost unlimited number.

An application on the DAN server that is customized for the manufacturer may provide input of information related to any aspect of the user and/or group of users. For example, statistics related to a particular marketing partner may be entered.

To assist the base client, the DAN server is accessible to the manufacturer and/or marketing partners. In one embodiment, the application may monitor the servicing/maintenance of relevant information for any selected DAN component associated with the client group. For example, the application may monitor software versions of the DAN components, maintain a calendar, and fault codes. The DAN server may produce a wide range of different custom reports based on the information available on the DAN server. As another example, the application may allow a distribution partner to track the use of DAN devices, such as tracking location devices to provide updates and services to those devices. The DAN server may generate custom reports for manufacturers and/or marketing partners to provide their usage tracking. In response to detecting an expired status or a need to repair or maintain the DAN component, the application may notify the manufacturer or distributor of one or more recommended actions so that they may respond immediately. In one embodiment, the notification may be sent directly to the customer, contractor, or equipment operator. In addition, the DAN server may generate relevant custom reports for the manufacturer and/or marketing partner for follow-up.

The DAN server may be accessible by a group of users, such as facility operators and municipalities, for characterizing a target facility installation. In this case, the DAN server application may access log records associated with the installation of the facility and may generate relevant custom reports for transmission to one or more individuals interested in any captured information. In some cases, a manufacturer may specify whether certain custom reports and/or records are available for a particular individual and/or type of individual. The application may be arranged, for example, to generate an as built drawing of any desired view (including perspective) of the device. Other information may also be identified, which may be any suitable combination of the following: the installation date, the specific equipment used to perform the operation and installation, including the status of the DAN components during operation, any reported operation-related fault codes, identification of the installation contractor, details regarding the type of installation being installed, the maximum pull-back tension applied to the installation, statistics related to mud pressure and/or drill bit temperature during drilling operations, any available operation-related GPS coordinates, etc. It should be understood that any available, relevant information may be included without limitation. In addition, statistics or combinations of statistics for any available target may be plotted and used for display.

Turning attention now to fig. 4, fig. 4 is a block diagram of one embodiment of a DAN hub 210. The hub may include a site report and a notification generator 400 that acts as an engine for the associated processing. The generator 400 is in two-way communication with an external communication interface 404, which in turn may be connected to the internet 212 for desired external communication. The reference unit 408 may store operating parameters, a priority table, such as table 1 including priority assignments and thresholds as described previously. Any other required data may also be stored in the reference unit 408. For example, a previously generated site report may be stored in the referencing unit 408 before it is transmitted to the DAN server. The data log unit 412 may store any needed data logs 414 and may update the data logs 414 in real-time as newly incoming data is parsed among several logs. As an example, the data log may include inground tool depth 418a, inground tool wheelbase 418b, inground tool temperature 418c, ring fluid pressure 418d, pullback tension 418e, handset status 418f, inground tool transceiver status 418g, drill status 418h, GPS or other determined system component coordinates 418i, and other logs. Rig interface 422 may be in data communication with the rig for gathering any information available through various monitoring and sensing functions of the rig. Such information may be obtained, for example, via the CAN bus 242 of fig. 2. Parameters that may be sensed or monitored may include, but are not limited to, drill string clamping status, drill string tension/pull, water pressure, drilling mud status/pressure and flow rate at the drill rig, drill string thrust, drill string rotational speed, drill rig motor rpm, and the like. Of course, the rig interface data may be directed to the log 414 and retrieved by, for example, time and/or drill string length. The borehole trajectory data interface 426 may collect any information available for the ongoing subterranean operation being performed. Typically, this data will be directed to the augmentation data log 414, where the data logs 418a-418i serve as examples of a wide range of data that may be received and recorded as a response to the inground tool's movement along the borehole trajectory. It should be understood that different data may be collected during different types of subterranean operations, such as drilling operations, back reaming/pullback operations, and mapping operations. An area designation parameter/geographic database 428 is provided for referencing the location of any system components currently identified. It should be appreciated that the DAN hub provides a high degree of flexibility for the execution of DAN services. For example, the DAN hub may serve as a platform for the application 430, and the application 430 may be provided by and/or tailored to a wide variety of different user individuals, such as operators, contractors, distribution partners, and/or manufacturers. As is the case with the DAN server in one embodiment, third party applications may be supported, accessed, updated, and maintained over the internet. It should be understood that the DAN hub itself may act as a WiFi hotspot, so that the application 430 may even be provided using a smartphone or tablet for controlling system components.

Fig. 5 is a flow chart illustrating one embodiment of a method of operation of a DAN hub, generally indicated by reference numeral 500. The method begins at 504 and proceeds to 508 where it is determined which communication channel is available. For example, it may be determined whether the drill bit transceiver is located above ground or below ground. As another example, the external data communication bandwidth (if any) may be determined. At 512, the priority values, thresholds, and log data structures may be initialized. A priority system may be established according to, for example, table 1. The current location of the system and/or certain components may be determined using the region-specific parameter database 428 to determine the appropriate system configuration. The system configuration may be altered in response to an operator attempt, automatic reconfiguration, or a combination thereof. Normal operation is then entered at 516. At 520, it is determined whether new borehole trajectory data is available. If so, operation proceeds to 524 where the appropriate log characterizing the borehole trajectory and the measurements therein are supplemented. These logs may include, as non-limiting examples, borehole trajectory mapping locations, borehole trajectory wheelbases, borehole trajectory deflections, pullback tensions, subsurface transceiver states, GPS coordinates, temperature readings, pressure readings, and the like. If there is no borehole trajectory data available, operation proceeds to 528 where new rig and/or DAN assembly data is tested. In response to this step, a wide range of data may be collected, including, but not limited to, drilling mud status, battery status and temperature of the downhole transceiver, and battery status of the handset. If new data is available, operation proceeds to 532 where the appropriate log is augmented. If no new rig and/or DA assembly data is available, operation proceeds to 536 where any other form of field data update that may be generated by the drilling area network may be monitored. If update data is not available, the appropriate log is updated at 540. With a determination at 536 that no further update data is available or the augmentation of the appropriate log is completed at steps 524, 532, 540, operation proceeds to 550 where a determination is made as to whether a new field report should be generated based on the new log update. This determination may be made in any suitable manner. For example, a field report may be generated in response to detecting that any threshold is exceeded. As another example, the generation of a field report may be triggered by the data of a certain number of specific data logs that have been accumulated since the last time the field report was generated. As another example, a field report may be generated based on the amount of increase in tension of the drill string. If no field report needs to be generated, normal operation resumes at 516. On the other hand, if a site report needs to be generated, the site report can be generated and transmitted at 554. In one embodiment, the data logs may be transmitted according to a particular type of data log based on Table 1 or according to any suitable priority system. Subsequently, normal operation resumes at 516.

Fig. 6 is a block diagram of one embodiment of the DAN server 220. The processor 600 may be used to control all of the various functions of the DAN server. The LAN user interface 604 may provide local access to the server, such as by the manufacturer. WAN user interface 608 may provide access to users outside the system and may allow the server to communicate with any DAN hub operating around the world. The custom report element 612 may provide storage for previously generated custom reports and facilitate generation of new custom reports. The notification unit 616 may provide storage for previously generated notifications and facilitate generation of new notifications. The field data unit may include a global database that stores all collected field information received via the DAN server. The information may be compressed and/or compiled, indexed, or cross-indexed in any suitable manner. For example, the information may be indexed based on underground operations performed by a particular contractor. As another example, contractors may be indexed according to distribution partners that act as providers for a particular contractor base. The DAN component service unit 624 may store any information related to DAN components. For example, the operational status of any DAN component may be stored for use in determining whether the component requires any sort of maintenance and/or software update. The DAN component information may be indexed and cross-indexed in any suitable manner, for example, according to contractors who own the devices and dealership partners who sell or provide services to the contractors' devices. As-built units 628 may store any information relating to the completion, which may be or may have been constructed regarding a particular subterranean operation. Completion information may be indexed in any suitable manner, for example, by contractor and/or facility owner or government department. The region specification parameters unit 630 may include a global specification of operational parameters and other region information for reference by the remote DAN hub.

Attention is now directed to fig. 7 and 6. The former illustrates an embodiment of a method, generally indicated by reference numeral 700, running on a DAN server 220. The method begins at 704 and proceeds to 708, where field data 620 is accessed. At 712, it is determined from the field data, via the custom report unit 612, whether a custom report needs to be generated. The events that trigger the generation of the custom report may be based on a wide range of operating environments. For example, the accumulation of a certain amount of data about a given subterranean operation may trigger a custom report. As another example, completion of a subterranean operation can result in the generation of a custom report. As another example, any indication that a threshold exceeds a state or fault state may cause the system to generate a custom report. As described above, the customized report may be directed to any selected individual or individuals having access to the DAN server. If a custom report needs to be generated, operation proceeds to 716, where the required data is collected and a custom report is created. The latter is transmitted to the designated individual or individuals at 720. In one embodiment, the custom report may be communicated via text information and/or email. Subsequently, it is determined at 724 whether the DAN server has received new field data. If so, the field data is augmented at 728. Operation then returns to 708.

Returning to the discussion of step 712, if the custom report unit 612 determines that a custom report need not be generated, then operation proceeds to 732, where it is determined by the notification unit 616 whether a notification should be issued to a particular individual or individuals. As a non-limiting example, a notification may be provided in response to a fault condition and exceeding any threshold. In response to determining that a notification needs to be generated, operation proceeds to 738 where appropriate data is collected and a notification is created. At 742, the notification is transmitted to the appropriate individual or individuals. In one embodiment, the notification may be communicated via text information and/or email. Subsequently, operation returns to 724 where it operates as described above. If 732, it is determined that notification is not required, then operation returns to 724 to determine if new field data has been collected. If so, operation proceeds to 728, described above. Otherwise, step 724 continues to monitor for new field data acquisition. It should be appreciated that step 724 may time out after a predetermined time interval, such that operation then passes to 728, even if no new field information is collected. In this way, new custom reports and notifications may be generated, for example, indicating that there is no process for a specified subterranean operation. However, typically the method 700 will monitor multiple subterranean operations simultaneously around the world, so that new incoming data from different subterranean operations will appear in an overlapping manner and need to be properly processed. It should be appreciated that custom reports and/or notifications may be generated in response to monitoring the DAN component service unit 624 to indicate, for example, that a fault condition associated with a particular DAN component has occurred and/or that maintenance or service is required. Additionally, custom reports may be generated in response to completing subterranean operations to collect and transmit data via as built units 628 for generating as built drawings. In this regard, as built units 628 may include data in the form of logs that may be used to create as built drawings for a specified subterranean operation. In addition to transferring data after the subterranean operation is completed, data may also be transferred in an added custom report. Comparison of these added custom reports may be used to indicate potential problems that may otherwise go undetected during subterranean operations, including data tampering, for example.

In some embodiments, an individual user may customize a particular application for accessing and presenting information stored by the DAN server and/or the DAN hub. The above disclosed concepts of applications for the various users and user groups above can be readily provided as applications specific to general mobile devices, such as smartphones and tablets.

The foregoing description of the invention has been presented for the purposes of illustration and description. It is not intended to be exhaustive or to limit the invention to the precise form or forms disclosed. For example, the drilling area network of the present disclosure can have functions not mentioned above. For example, data throughout the industrial industry may be collected, analyzed, and used for various business and research purposes. A company selling equipment or providing services can remotely track equipment usage and introduce products and services and/or provide remote customer services based on such remotely collected data. Accordingly, various other modifications and variations may be made in light of the above teachings, and certain modifications, permutations, additions and sub-combinations thereof will be recognized by those skilled in the art.

Preferably comprising all of the elements, parts, steps described herein. It will be understood that any of these elements, parts, steps may be substituted for or deleted from other elements, parts, steps, as would be apparent to one of ordinary skill in the art.

Disclosed herein are at least the following:

a drilling area network hub is located proximate to a drilling rig and includes an uphole transceiver that is in bidirectional communication with a downhole transceiver using a drill string as an electrical conductor. Specific information is collected, including rig-based and/or location information. At least one field report is generated based on the specific information to characterize at least one of the subterranean operation, an operational state of the downhole transceiver, an operational state of the uphole transceiver, and an operational state of the drilling rig. A drilling area network server receives field reports at remote locations over the internet and may generate custom reports and/or suggested actions based on the field data. The zone designation parameters are applicable to operation of the drilling system. The drilling area network hub may transmit the data log to a remote location according to the assigned priority.

The conception is as follows:

presented herein are at least the following concepts:

concept 1. in a system for performing horizontal directional drilling, the system comprising a drilling rig and a subsystem for monitoring a position of an inground tool along an inground borehole trajectory and other operating parameters associated with said inground borehole trajectory, an arrangement comprising:

a downhole transceiver supported proximate to the inground tool for two-way communication including receiving operational instructions and transmitting positioning and operational data from the surface; and

a drilling area network hub located at a drilling rig, comprising:

an uphole transceiver for data communication with the downhole transceiver for bi-directional communication between the inground tool and the drill rig using the drill string as an electrical conductor.

A data communication device that collects at least specific information, the specific information including at least one of location information and rig-based information,

a processor for collecting the specific information to generate at least one site report from the specific information, the site report relating to at least one of a subterranean operation, an operational status of the downhole transceiver, an operational status of the uphole transceiver, an operational status of the drilling rig, and

an internet connection means for at least intermittent data communication with the internet for transmitting the site report to a remote location.

Concept 2. the arrangement of concept 1 wherein the field report includes raw, unprocessed data that constitutes at least a portion of the rig-based information for transmission to a remote location.

Concept 3. the configuration of concept 1 or 2, wherein the field report is based at least in part on an analysis of the rig-based information and includes at least one recommendation generated by the analysis.

Concept 4. an arrangement as claimed in any preceding concept, wherein the downhole transceiver is for transmitting an electromagnetic locating signal for reception at the surface, the arrangement further comprising a handheld locator for receiving the electromagnetic locating signal to at least characterise the position of the inground tool; and a remote sensing transceiver for at least transmitting locator-based information to the uphole transceiver.

Concept 5. the arrangement of concept 4, wherein the processor is configured to use the locator-based information in conjunction with the rig-based information to generate the site report.

Concept 6. the arrangement of concept 1, further comprising:

a drilling area network server that receives the field report at a remote location over the internet and that generates at least one custom report as at least one of: marketing partner reports, customer reports, facility operator reports, contractor reports, and government department reports.

Concept 7. an arrangement as claimed in any preceding concept, wherein the data acquisition means comprises a CAN bus for acquiring drill-based information.

Concept 8. an apparatus for monitoring a system for performing horizontal directional drilling, the system including a drilling rig and a subsystem for monitoring a position of an inground tool along an inground borehole trajectory and other operating parameters related to the inground borehole trajectory, said apparatus comprising:

a drilling area network hub located proximate to the drilling rig for at least acquiring system-generated borehole trajectory data and system-related operational data characterizing the borehole trajectory to generate at least one of a field report and one or more suggested actions based on the borehole trajectory data and operational data to characterize at least one of a subterranean operation and a rig operational state;

internet connection means for at least intermittent data communication with the internet for transmitting said report to a remote location; and

a drilling area network server that receives the field report at a remote location over the Internet and that generates a customized report from the field report.

Concept 9 the apparatus of concept 8, wherein the custom report is customized for at least one of the following users: manufacturers, distribution partners, customers, facility operators, contractors, government agencies for the components of the system.

Concept 10 the apparatus of either of concepts 8 or 9, wherein the system comprises a plurality of components including at least the drilling rig, the inground tool, and a hand held locator for collecting the borehole trajectory data as information relating to at least one of a direction and a location of the inground tool, and the drilling area network hub is for monitoring the plurality of components.

Concept 11. the apparatus of concept 10, wherein the customized report is based on service related information of the one or more selected drilling area network components.

Concept 12 the apparatus of concept 11, wherein the custom report comprises a service recommendation.

Concept 13. an apparatus for monitoring a system for performing horizontal directional drilling, the system including a drilling rig and a subsystem for monitoring a position of an inground tool along an inground borehole trajectory and other operating parameters related to the inground borehole trajectory, said apparatus comprising:

an application that receives, via remote electronic data transmission, at least one of system-generated borehole trajectory data and system-related operational data characterizing a subterranean borehole trajectory at a location remote from a location of the subterranean borehole trajectory, and generates at least one of a customized report and one or more suggested actions based on the at least one of borehole trajectory data and operational data.

Concept 14 the apparatus of concept 13, wherein the borehole trajectory data comprises at least one of: wheelbase, depth, deflection, fluid pressure, pull-back tension, cell state and temperature.

Concept 15. an apparatus for customizing one or more configurable components of a horizontal directional drilling system according to zone-specific parameters, the system comprising a drilling rig and a subsystem for monitoring a position of an inground tool along a subterranean borehole trajectory and other operating parameters related to the subterranean borehole trajectory, the apparatus comprising:

a geographic database of region-specifying parameters specifying operating parameters as a function of a location of one or more components of the horizontal directional drilling system;

means for identifying a current location of at least one locatable system component of the system in the area and associating the current location with the geographic database to identify a set of local requirements for the current location; and

a controller for customizing at least one operating parameter of the one or more configurable components to meet the set of local requirements based on the current location.

Concept 16. the apparatus of concept 15, wherein the system comprises a handheld locator as one of the configurable system components for monitoring the position and/or orientation of the inground tool on the borehole trajectory.

Concept 17 the apparatus of concept 16, wherein the handheld locator is to at least transmit a telemetry signal, the local requirement specifying at least one of a maximum transmit power and at least one transmit frequency of the telemetry signal.

Concept 18. the apparatus of concept 15, 16 or 17, wherein the inground tool is for transmitting the locating signal across the ground for receipt at the ground, the local requirement specifying at least one of a maximum transmission power and at least one transmission frequency of the locating signal.

Concept 19. the apparatus of concept 15, 16, 17, or 18, wherein a telemetry transceiver is in data communication with the drilling rig and the telemetry transceiver transmits at least a telemetry signal, the local demand specifying at least one of a maximum transmission power and at least one transmission frequency of the telemetry signal.

Concept 20. the apparatus of any of concepts 15-19, wherein the at least one positionable component is also a configurable component.

Concept 21. the apparatus of any of concepts 15-20, wherein the geographic database comprises a set of regional profiles.

Concept 22. the apparatus of concept 17, wherein the controller is to compare local requirements of the current area with a current operating mode of the system and to issue the notification in response to a difference therebetween.

Concept 23. the apparatus of concept 17, wherein the controller is to compare local requirements of the current area with a current operating mode of the one or more configurable system components and to automatically reconfigure the one or more configurable system components in response to a detected difference between the current operating mode and the local requirements to conform the current operating mode of the configurable system components to the local requirements.

Concept 24. an apparatus for monitoring a system for performing horizontal directional drilling, the system including a drilling rig and a subsystem for monitoring a position of an inground tool along an inground borehole trajectory and other operating parameters related to the inground borehole trajectory, the apparatus comprising:

a drilling area network hub located proximate to the drilling rig location for generating a plurality of different types of data logs characterizing the subterranean operation as the subterranean operation is performed, the drilling area network hub configured for at least intermittent data communication with a remote location; and

a priority table that applies priority rankings to different types of the data logs such that the drilling area network hub transmits the data logs to a remote location according to the priority table.

Concept 25 the apparatus of concept 24, wherein the priority table comprises a threshold specified for at least one particular data log, the drilling area network hub promoting a priority of the particular data log in response to exceeding the threshold.

Concept 26. the apparatus of concept 25, wherein the drilling area network hub arbitrates between two or more data logs that currently exceed an associated threshold for each data log.

Concept 27. the apparatus of concepts 24, 25, or 26, wherein the different types of data logs comprise at least a pull-back tension log, a loop fluid pressure log, and a temperature log.

Concept 28. the apparatus of concept 27, wherein a maximum threshold is associated with each of the pull-back tension log, the loop liquid pressure log, and the temperature log.

Claims (3)

1. An apparatus for customizing a horizontal directional drilling system according to zone specific parameters, the system including a drilling rig and a subsystem for monitoring a position of an inground tool along an inground borehole trajectory during an inground operation, said apparatus comprising:

a geographic database of region-specifying parameters specifying location-based operating parameters of the horizontal directional drilling system;

means for identifying a current location of the system and associating the current location with the geographic database to identify at least one local requirement for the current location; and

a controller configured to compare local requirements of a current location with a current operating mode of a system and to inhibit operation of the system from overriding the local requirements in response to a mismatch between the local requirements and the current operating mode.

2. The apparatus of claim 1, wherein the region-specifying parameters include the local requirement, the local requirement being at least one of a maximum transmission power and at least one specified transmission frequency of the telemetry signal at the current location, and the controller sets the at least one of the transmission power and the transmission frequency of the telemetry signal to coincide with the maximum transmission power and the specified transmission frequency.

3. The apparatus of claim 1, wherein the region-specifying parameters include the local requirement, the local requirement being at least one of a maximum transmission power of the positioning signal at the current location and at least one specified transmission frequency, and the controller sets at least one of a transmission power and a transmission frequency of the telemetry signal to coincide with the maximum transmission power and the specified transmission frequency.