Abstract: Methods and apparatuses for controlling a trajectory of a borehole being drilled into the earth are provided. The apparatus includes a drilling system including a drill tubular, a disintegrating device, and a steering system coupled to the drill tubular configured to steer the drilling system, the drilling system configured to drill the borehole by receiving control outputs from at least one control unit for controlling parameters of the drilling system, the at least one control unit configured to provide the control outputs to the steering system, the at least one control unit being configured to provide a depth-based control output.

Abstract: Methods, systems, and storage media are presented for operating a drill string within a well. Exemplary implementations may: detect, using one or more sensors, data representing an analog control command sequence; analyze the analog control command sequence; determine that the control command sequence represents a command to change an operational mode of the drill string from a first operational mode to a second operational mode; and transmit a signal to an actuator of the drill string, the signal representing an electronic command to activate the actuator in such a way as to change the drill string from the first operational mode to the second operational mode. In some embodiments, the analog control sequence may comprise a predetermined sequence of rotational inputs, vibrational inputs, pressure inputs, or a combination thereof.

Abstract: A drill bit subsystem can include a drill bit, a processor, and a non-transitory computer-readable medium for storing instructions and for being positioned downhole with the drill bit. The instructions of the non-transitory computer-readable medium can include a machine-teachable module and a control module that are executable by the processor. The machine-teachable module can receive depth data and rate of drill bit penetration from one or more sensors in a drilling operation, and determine an estimated lithology of a formation at which the drill bit subsystem is located. The control module can use the estimated lithology to determine an updated location of the drill bit subsystem, and control a direction of the drill bit using the updated location and a drill plan.

Abstract: A directional drilling device includes a housing, a drive shaft extending through the housing, a plurality of magnetic field sensors positioned in the housing and in signal communication with a control device also positioned in the housing, wherein the magnetic field sensors are configured to determine a magnetic interference declination influenced by a magnetic interference field as a magnetic interference flux density and to transmit a magnetic interference declination value corresponding to a magnetic interference flux density to the control device, and a directional control device coupled to the housing and controllable by the control device to control a position of the directional drilling device, wherein the control device is configured to generate a correction value based on the magnetic interference declination value, and wherein the correction value corresponds to a deviation of the magnetic interference flux density from a reference magnetic flux density measured at a reference standard.

Abstract: Systems are provided for management of a geomechanical workflow of a geomechanics application in a computer system. The systems can include a client computer system can be communicatively coupled via a computer network to a geomechanical data source including one or more sensors configured to measure geomechanical data characterizing one or more aspects of a geomechanical feature. The systems can further include sets of program codes for instantiating a Calculation Manager object, a Calculation Manager Extension object, and a Workflow Run object for reconstructing a geomechanical workflow in response to a changed event in the geomechanical data.

Abstract: A system can determine properties associated with a plurality of wellbore zones extending radially outward from a wellbore of a drilling operation. The system can determine an operating window for a drilling pressure of the drilling operation based on the properties associated with the plurality of wellbore zones. The system can access real-time data for the plurality of wellbore zones during the drilling operation. The system can determine an adjusted operating window for the drilling pressure based on the real-time data. The system can output a command to adjust, in real time, at least one drilling parameter of the drilling operation based on the adjusted operating window.

Abstract: An embodiment of a method of predicting a location of one or more features of an earth formation during a downhole operation includes acquiring reference data and identifying one or more reference data sections, each reference data section corresponding to a feature of interest and having an associated depth or depth interval, deploying a drilling assembly and drilling a target borehole in the earth formation, and performing measurements during the operation by a downhole measurement device to generate measurement data. The method also includes performing one or more correlations of the one or more measurement data sections with one or more reference data sections; and predicting at least one of a depth of a subsequent feature of interest located beyond a current carrier depth and a point in time of a future event associated with the subsequent feature of interest based on the correlation.

Abstract: A control system with probes for generating and utilizing at least one or more addressed datagrams that communicate information to and from devices along piping assemblies comprising; one or more transmitters, one or more receivers, and one or more controllers, wherein the transmitters transmit information via one or more addressed datagrams encoded within a working medium to one or more receivers among the piping assemblies, is described. Transmitters convert datagrams into signals that are transmitted within the working medium and the receivers receive signals from the transmitters and also convert signals from the working medium which is converted back into datagrams. The controllers receive and decode the datagrams so that the controllers selectively communicate and perform logical operations on piping assembly devices according to directions received from the addressed datagrams.

Abstract: A method for directing borehole drilling in a target earth formation includes the following steps: providing drilling equipment having a bottom hole assembly that includes a controllable directional drilling subsystem, and a logging-while-drilling directional measurement tool with a look-around and look-ahead capability; determining the presence of a predetermined type of formation characteristic in the target formation; and navigating a drill path in the target formation with the drilling equipment, including receiving measurement signals from the directional measurement tool, obtaining, from the received measurement signals, indications of formation parameters with respect to the formation characteristic in the target formation, and controlling the directional drilling subsystem to drill in a direction determined as a function of the obtained indication of formation parameters.

Abstract: Methods, apparatus, and systems are provided for collecting data from a plurality of downhole sensors located in a wellbore utilizing an asynchronous direct-sequence code division multiple access (DS-CDMA)-based communication scheme. One example method includes receiving a superposed signal comprising asynchronous signals from the downhole sensors, wherein a spreading sequence has been applied to data generated by each of the downhole sensors to form each of the asynchronous signals; sampling the received superposed signal; and processing the sampled superposed signal using decorrelation to determine the data from at least one of the downhole sensors before the spreading sequence was applied.

Abstract: A system, method and computer-readable medium for acquiring seismic data, which includes activating a seismic source at a surface location; defining a seismic trace of a seismic wave received at a downhole location on a bottomhole assembly in a borehole in response to the activation of the seismic source; compressing the seismic trace; and recording the compressed seismic trace to a storage medium.

Abstract: A downlinking signal is transmitted downhole from the surface using drilling fluid as the communications medium. The downlinking signal includes at least a synchronization phase and a command phase. The downlinking signal is differentiated upon reception such that attributes of the synchronization phase may be used to determine corresponding attributes of the command phase. Commands may be transmitted downhole while drilling and simultaneously while using mud-pulse telemetry uplinking techniques.

Abstract: A downlinking signal is transmitted downhole from the surface using drilling fluid as the communications medium. The downlinking signal includes at least a synchronization phase and a command phase. Attributes of the synchronization phase are used upon reception of the signal to determine corresponding attributes of the command phase. Commands may be transmitted downhole while drilling and simultaneously while using mud-pulse telemetry uplinking techniques.

Abstract: In electric equipment that has a digital interface, an operation that is normally performed by an output terminal during authentication processing is executed on equipment connected to an input terminal of the digital interface by the input terminal as an erroneous connection detection operation. When there is a proper response from the equipment connected to the input terminal of the digital interface in response to the erroneous connection detection operation, the electric equipment detects that the connected equipment has been erroneously connected. When an erroneous connection is detected, the electric equipment gives notice of the detection of the erroneous connection.

Abstract: A downhole communication device comprises a first energy harvesting device; a downhole transceiver in communication with the first energy harvesting device; an accumulator in communication with the energy harvesting device; and a microcontroller. The microcontroller manages communication between the first energy harvesting device, transceiver, and accumulator.

Abstract: A method of signal processing includes providing at least a first pressure sensor and a second pressure sensor spaced in a drilling system and using an algorithm to separate the downwardly propagating waves from the upwardly propagating waves. In one or more examples, an algorithm may include determining a velocity of pressure signals in a wellbore, time-shifting and stacking pressure signals from at least the first pressure sensor and the second pressure sensor to determine a downwardly propagating noise signal, and subtracting the downwardly propagating noise signal from at least the signal from the first pressure sensor.

Abstract: Example wellbore telemetry systems and methods for transmitting signals between a surface unit and a downhole tool are disclosed. One example method transmits data between a downhole location in a wellbore and a surface location associated with the wellbore by measuring downhole data via at least one downhole component and generating a data frame containing at least a portion of the downhole data. The example method varies a telemetry bandwidth allocated to the at least one downhole component in response to the at least some of the downhole data corresponding to a special event and transmits the at least some of the downhole data to the surface location via the telemetry bandwidth allocated to the at least one downhole component.

Abstract: Measurements made with at least two sensors (flow rate or pressure) during generation of a message concurrently with operation of a noise source are used to estimate a channel transfer function. The estimated transfer function is then used to attenuate pump noise in a mud pulse telemetry system. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

Abstract: A method of signal processing includes providing at least a first pressure sensor and a second pressure sensor spaced in a drilling system and using an algorithm to separate the downwardly propagating waves from the upwardly propagating waves. In one or more examples, an algorithm may include determining a velocity of pressure signals in a wellbore, time-shifting and stacking pressure signals from at least the first pressure sensor and the second pressure sensor to determine a downwardly propagating noise signal, and subtracting the downwardly propagating noise signal from at least the signal from the first pressure sensor.

Abstract: A method and apparatus for controlling oil well drilling equipment is disclosed. One or more sensors are distributed in the oil well drilling equipment. Each sensor produces a signal. A surface processor coupled to the one or more sensors via a high speed communications medium receives the signals from the one or more sensors via the high speed communications medium. The surface processor is situated on or near the earth's surface. The surface processor includes a program to process the received signals and to produce one or more control signals. The system includes one or more controllable elements distributed in the oil well drilling equipment. The one or more controllable elements respond to the one or more control signals.

Abstract: An improved energy efficient intelligent rotary pulser for generating a mud pulse in a MWD (measurement while drilling) application. In the rotary pulser, a control circuit activates a brushless motor that rotates a windowed restrictor relative to a fixed housing to act as a shutter and window respectively. Opening of the windowed restrictor allows generally unrestricted mud flow. Closing of the windowed restrictor generally restricts mud flow. The windowed restrictor is powered both in opening and closing operations by the motor.

Abstract: A communications system includes a first wireless communications system configured to provide wireless communications over a first frequency band, and a second wireless communications system configured to provide wireless communications using at least a portion of the first frequency band. The system includes an inter-system communications link between the first wireless communications system and the second wireless communications system. The inters-system communications link is used to coordinate the use of the first frequency band. The system further includes an interference reducer configured to reduce interference between the first wireless communications system and the second wireless communications system. Related methods are also disclosed.

Abstract: A communication module for use in wellbore logging operations. The module is attachable around a wireline, slickline, tubing or coiled tubing having a logging tool on its end. The module includes a drive means for transporting it down the line, a controller for controlling its operation, and communications for communicating with the logging tool. Communication between the module and the logging tool includes the transfer of data and operational instructions.

Abstract: Methods and apparatus for conserving battery energy used in transmitting signals carrying data from a downhole location, using a transmission system where a predetermined set of data is to be transmitted once during a predetermined period. The method can comprise the steps of: transmitting at least one signal during said period to transmit the set of data; selecting the time of transmission of said at least one signal; and representing at least some of the data to be transmitted in terms of the time of transmission of said at least one signal.

Abstract: Measurements made with dual sensors (flow rate or pressure) are used to attenuate pump noise in a mud pulse telemetry system.

Abstract: A method and apparatus for communicating between downhole tools without the necessity of routing the communication through a surface module. Communications sent by downhole tools are examined and extracted downhole. If the communications are intended for other downhole tools, the communications are copied to a downlink and send to a specific intended tool, a group of tools, or all the tools. This is all done downhole, significantly reducing the latency between command and response.

Abstract: A method of and system for rapidly locating all passive underground electronic marker types in an area under survey may locate various marker types simultaneously. In accordance with one aspect of the present invention, a marker locator may sequentially transmit and receive multiple frequencies very quickly; alternatively, the transmitter may transmit a broadband signal on multiple frequencies.

Abstract: A method and a downhole telemetry system a downhole telemetry system using discrete multitone modulation for transmitting a data stream over a plurality of transmission modes is provided. The downhole telemetry system includes a downhole transmitter, a cable, and a surface receiver. The downhole transmitter is configured to transmit the data stream over the plurality of transmission modes. The surface receiver is coupled to the downhole transmitter via the cable and is configured to combine signals from each of the plurality of transmission modes to obtain the data stream transmitted by the downhole receiver. The method includes receiving a plurality of signals over the plurality of transmission modes from a downhole package, and may further include combining the plurality of signals to form at least one data stream.

Abstract: A drill pipe forms an acoustic transmission channel for data to be transmitted from a downhole transceiver to a surface transceiver. By positioning a first low frequency acoustic attenuator between a drill bit and the downhole transceiver, acoustic noise generated by the drill bit is attenuated. Similarly, by positioning the surface transceiver between the top of the drill pipe and a second low frequency acoustic attenuator, acoustic noise generated by surface equipment is attenuated. In this manner, the first and second low frequency acoustic attenuators serve as terminators for the acoustic transmission channel.

Abstract: An improved data telemetry system for multi-conductor wirelines to achieve satisfactory transmission of analog and digital signals with frequency content up to 100 kHz by assigning at least two conductors to a first terminal of a data transmittal means and to a first terminal of a data receiver means and connecting at least one additional conductor to a second terminal of a data transmittal means and to a second terminal of a data receiver means. Pairing conductors reduces attenuation and crosstalk and permits the signal to contain multiple frequency modulated carrier bands with individual channel bandwidths of up to 3 kHz or higher.

Abstract: In an illustrative embodiment, a desired signal processing transfer function is implemented using a generic pipelined data processor having variable latency followed by a variable latency multistage FIFO. The delay of the multistage FIFO is varied dynamically to keep the number of outstanding samples (and thus the overall latency) a constant. The present invention enables an abstract approach to the design of higher-level signal processing transfer functions while the design of the underlying low-level circuitry is driven solely by target implementation technology issues. Thus, the higher-level design of signal processing transfer functions is decoupled from the low-level (logic and physical) design. Furthermore, test bench modules and vectors for testing the transfer function can also be to be prepared independent of the specifics of the low-level circuitry associated with the target implementation technology.

Abstract: A reprogrammable data communications system for use in a gas or oil well borehole is disclosed. The borehole includes a casing and a piping structure therein and at least one downhole equipment module located therein. The system provides for data and control signals to be coupled to the casing and piping structure by a surface modem and transmitted to the downhole equipment located in the downhole equipment modules. The downhole equipment modules include a downhole modem that is coupled to the casing and piping structure and receives the transmitted data and command signals and recovers the transmitted data and commands therefrom. A downhole processor is coupled to the downhole modem and receives the data and commands from the downhole modem and stores the data and commands in retentive memory that is coupled to the downhole processor. In this way, the downhole processor can be reprogrammed with new algorithms and communications parameters.

Abstract: An architecture for use in controlling and managing optical functions and optical devices. A common microprocessor based control layer coordinates commands between optical devices and a user station. The control layer executes an operating system which handles data flow in the control layer. Generic commands from the user station causes the operating system to call specific subroutines the produce digital commands. These digital commands are then passed to a digital layer that interfaces with an analog layer. The analog layer is specifically developed to interface and work with a specific optical device. The analog layer thus directly controls the optical device including changing its settings based on input from the digital layer.

Abstract: A synchronous CDMA telemetry system is provided for use in a wellbore. In one described embodiment, each data bit of digital outputs of multiple downhole data sources is multiplied by an orthogonal code unique to each data source. The resulting encoded outputs are modulated on a carrier frequency and summed on a transmission channel. The resulting signal is demodulated at a remote location and separately multiplied by each of the codes to separate out the contributions to the signal from each data source. The individual demodulated and decoded outputs are then integrated over the length of each data bit.

Abstract: A system for sensing subterranean acoustic waves emitted from an acoustic source includes a plurality of laser sources, a plurality of subterranean optical sensors, at least one optical detector, and electronics. The laser sources each emit light at a different frequency. The subterranean optical sensors receive the light and alter the light in response to the acoustic waves. The optical detector receives the altered light and outputs an electrical signal. The electronics receives the electrical signal and converts it into seismic data format. The hydrophone for sensing the acoustic signals is able to operate at pressures of at least 5,000 psi and temperatures of at least 130 degrees Celsius. A hydrophone may be housed in a cable having a diameter of less than about 1.5 inches. The hydrophone's sensor preferably includes a reference mandrel, two sensing mandrels, and a telemetry can, all of which are aligned in a coaxial, end-to-end configuration to reduce the profile of the hydrophone.

Abstract: A well control system and associated method of controlling well tools provides downhole well tool control without requiring the use of electricity or complex pressure pulse decoding mechanisms. In a described embodiment, a digital hydraulic well control system includes multiple well tool assemblies, with each assembly including a well tool, an actuator and an addressable actuation control device. Multiple hydraulic lines are interconnected to each control device. The hydraulic lines transmit addresses or codes to respective selected ones of the control devices, thereby selecting corresponding respective ones of the well tools for actuation thereof. Hydraulic lines are also used to actuate the selected well tools.

Abstract: The present invention provides a self-contained sensor module for use in a subterranean well that has a well transmitter or a well receiver associated therewith. In one embodiment, the sensor module comprises a housing, a signal receiver, a parameter sensor, an electronic control assembly, and a parameter transmitter; the receiver, sensor, control assembly and transmitter are all contained within the housing. The housing has a size that allows the module to be positioned within a formation about the well or in an annulus between a casing positioned within the well and an outer diameter of the well. The signal receiver is configured to receive a signal from the well transmitter, while the parameter sensor is configured to sense a physical parameter of an environment surrounding the sensor module within the well. The electronic control assembly is coupled to both the signal receiver and the parameter sensor, and is configured to convert the physical parameter to a data signal.

Abstract: A system and method for connecting a computer terminal (e.g., a personal computer) to a data transmission network with the appropriate settings for connection obtained from the network if the terminal has been moved and the settings are not appropriate for the new location. The system and method involve detecting that the terminal has been removed from the data transmission network, and, if the terminal has been moved, checking to determine whether the previous settings are appropriate for use in the new location. If the settings are appropriate, then the previous settings are used; if not, new settings for the terminal are obtained from the network, using a program such as the IBM's Dynamic Host Connection Program (DHCP), with the details on the settings (or connection) maintained at both the network and the computer terminal and updated when a new or changed connection to the data transmission network is made.

Abstract: Communicating relative to a subterranean well includes encoding information in an amplitude and a duration for a pulse. A detectable change in response to both the amplitude and duration communicates the information. Two distinct items of information can be encoded wherein the information encoded in the amplitude is distinct from the information encoded in the duration. A single, more highly resolved, item of information can be defined in that the amplitude and the duration can together represent one aspect of the information to be communicated. Particular application is found in a subterranean well having three-phase power conductors connected to a three-phase motor in the well with the amplitude and duration being communicated through the power conductors.

Abstract: A system for use with a well includes a surface device, a communications link coupled to the surface device and extending into the well, and a plurality of downhole devices coupled to different points on the communications link in the well. The surface device and the plurality of devices are adapted to determine distortions of different portions of the communications link coupling the surface device and downhole devices and to compensate for the distortions when communicating. Transfer characteristics of the communications link portions may be determined, from which equalization parameters may be determined to compensate for distortions caused by communications link portions.

Abstract: The method and apparatus of the invention determines earth formation resistivity at extended depths into the formation by the use of telemetry transmission signals to measure the formation resistivity. The telemetry transmission signals carry measurement data from downhole sensors through the formation to an uphole receiver. The signal transmission is by means of induction telemetry. At the receiver, the signal is demodulated to obtain the transmitted measurement data. During the detection of the signal at the receiver, the signal amplitude is also extracted and is used to determine the formation resistivity. In addition, changes in the signal amplitude are also used to indicate formation boundaries for determining well location during directional drilling.