Abstract: Acoustic telemetry devices and methods that provide directional detection. In one embodiment, a disclosed acoustic telemetry device comprises at least two acoustic sensors and an electronics module. The electronics module combines the detection signals from the acoustic sensors to obtain a combined signal that substantially excludes signals propagating in a direction opposite to the communication signal. The disclosed systems and methods can be trained in the field and will readily accommodate an irregular and unknown signal transmission medium between the two acoustic sensors.

Abstract: A subsea production system adapted for wireless communication so that production tree operation can be controlled locally wirelessly from a workover umbilical or remotely controlled vehicle. The production system includes a wellhead assembly and an umbilical termination connected to an umbilical that extends to above the sea surface. Dedicated wireless communication devices can be attached to one or both of the wellhead assembly and the umbilical termination. The wireless communication devices can include a radio frequency modem, a sonar device, an infrared communication device, a light emitting diode, an optical modem, and combinations thereof; the wireless communication can include radio frequency waves, acoustic waves, and electromagnetic waves. A subsea control module can be included for controlling/actuating devices in or associated with the production system. The subsea control module can be adapted for wireless communication.

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 drill string component includes a box-end and a pin-end. Each end includes a signal transceiver, which are operably coupled together. Each signal transceiver communicates with another signal transceiver in another component to form a communication network in the drillstring. An end-cap may be placed in the central bore of the pin-end of a component to form an annular chamber between a side of the end-cap and a wall of the central bore of the pin-end when the end-cap is disposed in the central bore. In some embodiments, an electronics module may be placed in the annular chamber and configured to communicate with one of the signal transceivers. Accelerometer data, as well as other sensor data, at various locations along the drillstring may be sampled by the electronics module and communicated to a remote computer. Drillstring motion dynamics, such as vibration, may be determined based on the accelerometer data.

Abstract: An apparatus for use in deployment of downhole tools is disclosed. Preferably, the apparatus includes at least an in-ground well casing, a housing providing a hermetically sealed electronics compartment, a tool attachment portion, and a first flow through core. The housing is preferably configured for sliding communication with the well casing. The hermetically sealed electronics compartment secures a processor and a location sensing system, which communicates with the processor while interacting exclusively with features of the well casing to determine the location of the housing within the well casing. A preferred embodiment further includes a well plug affixed to the tool attachment portion, the well plug includes a second flow through core capped with a core plug with a core plug release mechanism, which upon activation provides separation between the second flow through core and the core plug, allowing material to flow through said first and second flow through cores.

Abstract: Methods and apparatus for downhole monitoring are provided by interrogating an unmodified optic fibre (102) arranged along the path of a well bore (106) to provide a distributed acoustic sensor and sampling data gathered from a plurality of contiguous sensing portions of the fibre. The sampled data is processed to determine one or more well bore parameters. The well bore parameters may comprise a well condition profile, and may be obtained in response to an acoustic stimulus.

Abstract: A system for communicating between a first location and a second location comprises a jointed tubular string having a first section and a second section connected at a connection joint, with the tubular string having a fluid in an internal passage thereof. A first acoustic transducer is mounted in the internal passage of the first section proximate the connection joint, and a second acoustic transducer is mounted in the internal passage of the second section proximate the connection joint. A signal transmitted from the first location to the second location is transmitted across the connection joint as an acoustic signal in the fluid from the first acoustic transducer to the second acoustic transducer.

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: Purging of fiber optic conduits in subterranean wells. A downhole optical sensing system includes an optical line, at least two tubular conduits, one conduit being positioned within the other conduit, and the optical line being positioned within at least one of the conduits, and a purging medium flowed in one direction through one conduit, and flowed in an opposite direction between the conduits. A method of purging a downhole optical sensing system includes the steps of: installing at least two conduits and an optical line in a well as part of the sensing system, one conduit being positioned within the other conduit, and the optical line being positioned within at least one of the conduits; and flowing a purging medium through the conduits in the well, so that the purging medium flows in one direction through one conduit and in an opposite direction between the conduits.

Abstract: An acoustic logging while drilling tool includes an acoustic transmitter and a linear array of acoustic receivers. At least one of the transmitter and the linear array of receivers is deployed on a blade having an outer diameter greater than that of the tool body. In preferred embodiments the transmitter and linear array are each deployed on a distinct blade. Deployment of the transmitter and/or the receivers on a blade reduces the standoff distance to the borehole wall which tends to improve the signal strength of received guided waves without an increase in transmitter power or receiver sensitivity.

Abstract: A measuring device for a drilling apparatus which comprises a series of drilling rods, rotary and axially mobile. The measuring device comprises sensors, disposed on the series of rods, and feed devices of the electromagnetic induction type, able to feed the sensors electrically. Each of the devices is connected to a feed source and comprises a rotary element and a stator. A guide unit is mounted on the apparatus, and a slider, on which the stator is supported, is able to slide on the guide unit with an axial motion corresponding to that of the series of rods.

Abstract: Systems and methods for wellbore operations using a dual top drive system with two top drives.

Abstract: A method and apparatus for estimating a change in length of a wellbore conveyance device in a wellbore. A reference signal is sent along a first path and a wellbore signal having a phase relationship with the reference signal is sent along a wellbore path. A change in length of the wellbore conveyance device is estimated from a phase shift between the reference signal and the wellbore signal. The frequency of the wellbore signal may be changed downhole. The wellbore conveyance device may have at least one conductor under a maintained tension. A length of the wellbore conveyance device is estimated from the estimated change in the length. For a drill string composed of a plurality of wellbore tubulars, a phase shift of the drill sting is determined upon adding a wellbore tubular to the drill string.

Abstract: An apparatus for use in deployment of downhole tools is disclosed. Preferably, the apparatus includes at least an in-ground well casing, a housing providing a hermetically sealed electronics compartment, a tool attachment portion, and a first flow through core. The housing is preferably configured for sliding communication with the well casing. The hermetically sealed electronics compartment secures a processor and a location sensing system, which communicates with the processor while interacting exclusively with features of the well casing to determine the location of the housing within the well casing. A preferred embodiment further includes a well plug affixed to the tool attachment portion, the well plug includes a second flow through core capped with a core plug with a core plug release mechanism, which upon activation provides separation between the second flow through core and the core plug, allowing material to flow through said first and second flow through cores.

Abstract: One embodiment includes an apparatus that includes a piezoelectric transducer to generate an acoustic signal that is to modulate along a mandrel, wherein the piezoelectric transducer includes at least one piezoelectric element and at least one electrode that is without non-permanent joints.

Abstract: Presently, existing completion tools have not been designed to couple with wired drill pipe. As such, present completions operations and tools have not been able to take advantage of the expanded bandwidth in wire drill pipe. Instead of designing new completions tools with wired pipe connections, the disclosed system and methods propose use of a short-hop or wireless system to transmit data from a completions tool to an upper receiver module coupled to the wired drill pipe. Various measurements from the region around the completions tool may be transmitted from one or more lower wireless modules to the upper wireless module and then transmitted through the wired drill pipe to the surface. Likewise, signals may be transmitted from the surface through the wired drill pipe to the upper module and then to the lower wireless module.

Abstract: A method for enhancing downhole telemetry performance comprising enhancing a signal in order to offset signal-to-noise ratio reduction with increasing measured depth, wherein the signal is modified at specified measured depths which are inferred from acoustic wave velocity determination.

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: Apparatuses and methods to power and communicate with downhole sensors are presented. Preferred embodiments of the present invention includes energizing a downhole sensor with a surface pressure wave generator and a downhole mechanical to electrical energy converter. Preferred embodiments of the present invention also include transmitting data measured from a downhole sensor to a surface unit through modulation of surface-generated pressure waves.

Abstract: Apparatus and method for transmitting data in a borehole (10) between a downhole installation including one or more tools (20) (for example downhole testing tools) and a surface installation (62), wherein the downhole installation is connected to the surface installation by means of a tubular conduit (such as a drill string or production tubing 14)). The apparatus comprises: an acoustic modem (26) associated with each tool, the modem acting to convert tool signals such as electrical tool signals into acoustic signals; and a hub (90) forming part of the downhole installation to which the tools and tubular conduit are connected and comprising an acoustic receiver (74) and an electromagnetic transmitter (80).

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: An acoustic telemetry apparatus and methods for communicating digital data from a down-hole location through a borehole to the surface or between locations within the borehole are described including a receiver and a transmitter linked by an acoustic channel (210) wherein acoustic channel has a cross-sectional area of 58 cm2 or less and the transmitter comprises an electro-active transducer generating a modulated continuous waveform.

Abstract: A bi-directional acoustic telemetry system is presented for communicating data and/or control signals between a first modem and a second modem along tubing. The system includes a communication channel defined by the tubing, a transducer of the first modem, and a transducer of the second modem. The transducer of each modem are configured to transmit and receive data and/or control signals, and are further configured to electrically communicate with a power amplifier characterized by an output impedance Zs and a signal conditioning amplifier characterized by an input impedance Zr. The system also includes a reciprocal response along the communication channel between the output impedance Zs and the input impedance Zr.

Abstract: The present invention provides a method and system in which signals from the surface are sent by changing flow rate of the drilling fluid supplied to the drill string during drilling of a wellbore. The signals are sent based on a fixed or dynamic time period schemes so that the sent signals cross a dynamic threshold value in a known manner. A controller downhole sets the dynamic threshold and determines the number of times a parameter, such as voltage, relating to the changes in the flow rate crosses the set dynamic threshold. Based on the number of the number of crossings and/or the number of crossings and the timing of such crossings, the controller ascertains the signal sent from the surface for use downhole.

Abstract: Transmitting acoustic signals from a wellbore. At least some of the illustrative embodiments are methods including transmitting an acoustic signal comprising downhole data, receiving the acoustic signal (the receiving by a receiver disposed within the internal diameter of a casing in the wellbore) converting the acoustic signal to a corresponding first electromagnetic signal, and inducing a second electromagnetic signal in a tubing responsive to the first electromagnetic signal.

Abstract: An acoustic transceiver assembly including a housing, an oscillator, and at least one membrane. The housing has at least one inner wall defining a cavity. The housing also has a first end and a second end defining an axis of the acoustic transceiver assembly. The oscillator is provided in the cavity. The oscillator is provided with a transducer element, and a backing mass acoustically coupled to the transducer element. The at least one membrane extends outward from the backing mass to support at least the backing mass within the cavity. The at least one membrane is flexible in an axial direction parallel to the axis of the acoustic transceiver assembly to permit the backing mass to oscillate in the axial direction, and rigid in a transverse direction to restrict lateral movement of the backing mass relative to the housing.

Abstract: A system and method of optimizing air hammer performance in a well drilling rig whereby an electronic acoustic receiver (EAR) is used to monitor the effects of changing any of the operating parameters under his or her control. The signals are visually presented to the drill operator based on an EAR's output, along with current settings, allowing the drill operator to dial in the parameters of his or her choice until the optimal frequency of the air hammer is regained. The visual output displays the amplitude response of acoustic waves being detected and decoded at the surface by the EAR. The drill operator can observe and use this information to determine the changes necessary in the operating parameters to return the hammer to optimal frequency, and thus optimal performance.

Abstract: A casing sensor and methods for sensing using a casing sensor are disclosed. The casing sensor includes a casing shoe and a sensor coupled to the casing shoe. A casing data relay includes a downhole receiver coupled to a well casing and a transmitter coupled to the receiver. The casing sensor may be coupled to the transmitter. A drill string actuator may be controllable through the downhole receiver.

Abstract: A bottom-hole assembly (202), BHA, for drilling a borehole (204, 301) in an earth formation (208, 300), comprising a percussion drill bit (208), a percussion mechanism adapted to strike the drill bit (208), at least one sensor (226, 228, 230, 232, 234) for measuring a physical quantity and converting it into an electrical signal, and converting means (237) for converting the electrical signal into a digital signal, and a method for transmitting data from such a bottom-hole assembly (202) positioned in a borehole (204, 301), the bottom-hole assembly (202) and the method being characterized by encoding the digital signal by controlling the percussion mechanism and time periods between two impacts delivered by the percussion mechanism on the drill bit (208) during drilling, and transmitting the encoded digital signal by waves generated by the impacts delivered by the percussion mechanism on the drill bit (208). A system which comprises said bottom-hole assembly (202).

Abstract: An invention is claimed wherein the signal loss along steel drill pipe walls can be estimated in the absence of a loss mechanism due to the formation debris at various positions in the well bore; the signal loss in excess of the calculated attenuation is generally and directly attributable to the build-up of said formation debris and an estimation of the amount can be determined. Furthermore, by use of distributed acoustic nodes positioned in the well between the transmitter in the BHA and the surface receiver—configured as repeaters—the formation debris build-up can be determined in each section so defined. This new information enables the driller to implement hole cleaning means in a timely manner and as appropriate, thus avoiding the problems of getting stuck in the hole, and possible well abandonment. An extension of the method enables the hole cleaning process to be automated, thereby improving efficiency.

Abstract: A method of acoustic telemetry in a drill string in a wellbore, comprises; transmitting an acoustic signal related to a parameter of interest from a transmitting location into the drill string; detecting signals propagated through the drill string at a receiving location, where the detected signals including noise; determining a drill string transfer matrix defining the propagation of signals through a transfer interval between the receiving location and the transmitting location; and using the detected signals and the drill string transfer matrix for obtaining an estimate of the acoustic signal.

Abstract: The present disclosure relates to a telemetry system for use in developing a field of wells. The telemetry system has a first downhole device capable of transmitting and/or receiving signals disposed in an appraisal well, an electronics control system located at or near the top of the appraisal, a cable disposed in the appraisal well that provides signal communication between the first downhole device and the electronics control system, and a second downhole device capable of transmitting and/or receiving signals disposed in a second wellbore. The signal is passed through the cable between the first downhole device and the electronics control system. From there, the signal may be re-transmitted to a desired location.

Abstract: This invention applies to the means whereby capacitance changes due to varying temperature and/or pressure in a piezoelectric transducer used for acoustic telemetry in a drilling environment is dynamically offset by modifying one or more parameters associated with the drive or control circuitry of said transducer. The object of the invention is to closely maintain the transducer in a resonant mode, thereby ensuring optimum energy consumption.

Abstract: A coaxial transmission line for an electromagnetic wellbore telemetry system is disclosed. An inner conductive pipe is disposed inside an axial bore of the outer conductive pipe. An insulator is positioned between the outer conductive pipe and the inner conductive pipe. In a specific embodiment, the inner conductive pipe is perforated or slotted.

Abstract: A cycleable downhole tool such as a Jar, a hydraulic hammer, and a shock absorber adapted for telemetry. This invention applies to other tools where the active components of the tool are displaced when the tool is rotationally or translationally cycled. The invention consists of inductive or contact transmission rings that are connected by an extensible conductor. The extensible conductor permits the transmission of the signal before, after, and during the cycling of the tool. The signal may be continuous or intermittent during cycling. The invention also applies to downhole tools that do not cycle, but in operation are under such stress that an extensible conductor is beneficial. The extensible conductor may also consist of an extensible portion and a fixed portion. The extensible conductor also features clamps that maintain the conductor under stresses greater than that seen by the tool, and seals that are capable of protecting against downhole pressure and contamination.

Abstract: An assembly for passive detection of features at known locations of a conduit. The assembly is a sensor assembly particularly well suited for detection of casing collars at known locations of cased wells, such as segmented hydrocarbon wells. Thus, the assembly is able to provide real time positioning information relative to any tool coupled thereto which is being advanced in the well pursuant to a well application. Given that the detection takes place in a passive manner via the combination of a magneto-responsive sensor and voltage responsive device, no separate dedicated power source or additional electronics are required.

Abstract: A downhole pulse stimulation tool for use within a production or injection string including a tubing string, a rotating or reciprocating rod string and a downhole pump. The tool is formed by a resonance chamber defined by a cylindrical outer tubular member connected to the tubing string and having pulse emitting openings, a pulse generator rotatably disposed within the resonance chamber having longitudinal channels and defining pulse generating openings, wherein the pulse generating openings periodically align with the pulse emitting openings as the pulse generator rotates or reciprocates within the resonance chamber.

Abstract: Methods and systems may be provided for simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material.

Abstract: A method for enhancing downhole telemetry performance comprising enhancing a signal in order to offset signal-to-noise ratio reduction with increasing measured depth, wherein the signal is modified at specified measured depths which are inferred from acoustic wave velocity determination.

Abstract: Methods and systems are described for communicating with downhole locations and transmitting power to downhole locations. Use is made of a cable passing someway down into the well. This cable may be connected to a downhole sensor and may be used primarily for communicating with that sensor, but also used in the current techniques described herein. Electrical connection is achieved between the cable and the metallic structure of the well to allow signals to be transferred between the communications tool and the surface via the cable.

Abstract: Systems and methods in which data compression techniques are utilized to fill a predetermined channel capacity are shown. According to one configuration, event data points within test data are selected for communication via the data communication channel and a data decimator is utilized to identify other data points within the test data to fill or substantially fill the predetermined channel capacity. The foregoing data decimator may employ one or more variables for selecting data for communication, wherein one or more of the variables are preferably adjusted in decimator iterations to select an optimum or otherwise desirable subset of data for communication. Data decimators may additionally or alternatively implement a suitable “growth” function to select the particular data for communication and/or the amount of data communicated.

Abstract: A stacked-ring, slow-wave acoustic telemetry isolation system and method for use with tubular assemblies such as drillpipe or production tubing comprising an acoustic wave transmitter, the acoustic isolator behaving such that a “down” wave propagated toward the isolator is reflected back substantially in phase with an “up” wave propagated from the acoustic wave source away from the isolator. The acoustic isolator is similarly effective in reflecting “up” propagating waves originating from below the isolator, hence further protecting the acoustic wave source from possible deleterious interference. It causes substantially all of the emitted wave energy to travel in a chosen direction along the drill pipe, thus aiding the efficiency of acoustic telemetry said pipe.

Abstract: A wired drill pipe for a drill string of a downhole tool positioned in a wellbore penetrating a subterranean formation is provided. The wired drill pipe includes a drill pipe, a cable and a wire retainer. The drill pipe has a slot at each end thereof. The slots are adapted to receive at least one transformer. The drill pipe has an inner surface defining a passage for the flow of mud therethrough. The cable extends from the transformer into the passage of the drill pipe. The wire retainer is positioned on the inner surface of the drill pipe. The wire retainer is adapted to secure the cable therein.

Abstract: One embodiment includes an apparatus that includes a piezoelectric transducer to generate an acoustic signal that is to modulate along a mandrel, wherein the piezoelectric transducer includes at least one piezoelectric element and at least one electrode that is without non-permanent joints.

Abstract: An acoustic telemetry isolation system and method for use with tubular assemblies such as drillpipe and production tubing includes an acoustic wave transmitter and an acoustic isolator. A “down” wave propagated toward the isolator is reflected back substantially in phase with an “up” wave propagated from the acoustic wave source away from the isolator. Furthermore, the acoustic isolator is similarly effective in reflecting “up” propagating waves originating from below the isolator, hence further protecting the acoustic wave source from possible deleterious interference. The construction of the isolator utilizes a specified combination of waves traveling in parallel in materials whose properties aid the beneficial combination of reflected and transmitted waves. The design of the isolator is to generally provide a bandstop filter function, thereby aiding the frequency isolation of an acoustic transmitter over a passband that may be constrained by the geometry of drill pipe or components of production tubing.

Abstract: A method whereby a downhole drilling transmission device that communicates to the surface automatically modifies its transmission parameters in order that it substantially improves its ability to adequately communicate with a surface receiver despite increasing signal attenuation between the two as the length of drillpipe increases. This utilizes a simple measure of localized downhole pressure that then relies upon a look-up table or similar that provides a correspondence between said pressure and measured depth. Such a look-up table or similar can be readily built by incorporating appropriate features of the planned well such as drilling fluid flow rate, drilling fluid density, drilling fluid viscosity, well profile, bottom hole assembly component geometry, drillpipe geometry, and indications as to whether the fluid is flowing or stationary.

Abstract: Measurements of acoustic velocities are made through a case borehole in the absence and presence of an applied magnetic field. A formation resistivity parameter may be estimated from differences in the acoustic velocities.

Abstract: A downhole telemetry system usable with a subterranean well comprises at least one pressure pulse generator, at least one pressure transmitter located in the internal tubular annulus in the well head and at least one pressure transmitter located in the casing annulus near the well. The system comprises a packer providing hydraulic isolation of the casing annulus and at least one transmitter located below the packer and responding to at least one physical quantity characterizing the bottom-hole zone. The system also includes a data encoder located below the packer to read out the transmitter located below the packer and to respond to at least one physical quantity characterizing the bottom-hole zone, a pressure pulse modulator to modulate pressure pulses generated by the pressure pulse generator, a surface-mounted data-collection unit to converts the output data of the transmitters and to provide a surface-mounted data decoder with data for analysis.

Abstract: A system for verifying perforating gun status prior to perforating a wellbore. The system includes a perforating gun (38) having a leak sensor disposed therein that is positionable at a target location within the wellbore on a tubing string (30). A communication system (42, 44, 46, 48, 50) is integrated with the tubing string (30). The communication system (42, 44, 46, 48, 50) is operable to communicate with the leak sensor. A surface controller (40) is operable to send a first telemetry signal via the communication system (42, 44, 46, 48, 50) to interrogate the leak sensor regarding a leak status of the perforating gun (38), receive a second telemetry signal from the leak sensor via the communication system (42, 44, 46, 48, 50) including the leak status of the perforating gun (38) and determine whether to operate the perforating gun (38) based upon the leak status information.

Abstract: An apparatus for use in drilling or producing from a well bore, the apparatus comprising a downhole member such as a drilling device or a production device which is capable of being attached to a tubular such as a drill string, production string or the like, means for rotating a tubular, control means for controlling the rotation of said tubular in order to transmit information along said tubular and means for monitoring the rotation of said tubular and for decoding said information transmitted along said tubular such that a magnitude of a parameter can be determined by the drilling member from the rotation or said tubular. The invention also relates to a method for communicating with a downhole tool using the apparatus.