Abstract: A sequential hydraulic well control system provides actuator selection and operation utilizing pressure applied to hydraulic lines in a sequence. In a disclosed embodiment, an actuation control device of a well control system includes multiple pistons, at least one of which is included in a latch for selectively permitting and preventing displacement of another of the pistons. When one of the pistons displaces in response to pressure applied sequentially to hydraulic inputs of the control device, an associated actuator is placed in fluid communication with the inputs.

Abstract: A hydraulic actuator system includes a power source, a controller in communication with the power source, a piezoelectric stack comprising a plurality of piezoelectric elements disposed within a sleeve to define a chamber at one end of the sleeve, pressure accumulators in fluid communication with the chamber, a flow control valve in communication with the accumulators, and a hydraulic piston in fluid communication with the flow control valve. The communication between the power source and the controller may be electrical or photo communication, and the power source is preferably remotely located relative to the other elements of the hydraulic actuator system. The method for controlling a remotely located hydraulic actuator includes communicating a signal to the hydraulic actuator, pressurizing a hydraulic fluid in the hydraulic actuator, and directing the hydraulic fluid to a cylinder in the hydraulic actuator to bias a piston either into or away from the cylinder.

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: 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 method and apparatus for collecting data downhole in a well bore, even during drilling operations, are disclosed. The apparatus generally comprises an antenna and some associated electronic circuitry. The antenna includes a plurality of arrayed transceiver elements and the electronic circuitry steers transmission or reception through the antenna by controlling the application of power to the array elements. In operation, a transceiver unit containing such an antenna is positioned proximate a remote sensor placed into a formation. An electromagnetic signal is then steered to communicate with the remote sensor over a wireless link.

Abstract: A very high data rate telemetry system is provided for use in a wellbore. In a described embodiment, a telemetry system includes multiple nodes positioned in the wellbore and distributed over a substantial length of the wellbore. The nodes simultaneously communicate with a remote location at a very high combined data transmission rate. A method of communicating data in a wellbore is also provided. The method includes the steps of installing multiple modems in the wellbore, installing a remote modem at a location remote from the downhole modems, and simultaneously communicating data from each of the downhole modems to the remote location. Each downhole modem communicates with the remote modem using a unique set of frequency subchannels.

Abstract: The present invention provides a production well control system for controlling multiple downhole devices individually, or as a group, based upon user command or real time downhole parameters. In accordance with a first embodiment of the present invention, a surface control unit, a downhole control module and an interface unit are provided for selectively controlling multiple downhole devices and transmitting real time data to the surface. An important feature of this invention is the ability to access the multiple devices (e.g., valves) individually, or as a group arranged in a distributed scheme. The number of downhole devices that can be controlled by this apparatus is only limited by the data address sizes, the power delivery capacity or the power consumption requirements. Another embodiment of the invention provides downhole sensors and a control module to automatically control the downhole devices based upon a sensed downhole parameter or event.

Abstract: A downhole telemetry system that transmits a burst-QAM uplink signal to the surface of the well is disclosed. In a preferred embodiment, a downhole instrument coupled to a pair of conductors in a wireline or composite tubing string transmits a burst-QAM uplink signal to a surface system. The burst-QAM signal preferably comprises a series of data frames carrying telemetry data. Each data frame is preferably preceded by a quiet interval (when no signal is present), a timing synchronization sequence, and a training sequence. The timing synchronization sequence is designed for easy timing recovery at the surface, and the training sequence is designed to aid the adaptation of the equalizer. The data frame itself preferably includes a synchronization field, a data count, and a checksum in addition to the data. Direct digital synthesis is preferably employed to modulate the uplink signal.

Abstract: An apparatus and method for determining a location and an orientation of an underground boring tool by employment of a radar-like probe and detection technique. The boring tool is provided with a device which generates a specific signature signal in response to a probe signal transmitted from above the ground. Cooperation between the probe signal transmitter at ground level and the signature signal generating device provided at the underground boring tool results in accurate detection of the boring tool location and, if desired, orientation, despite the presence of a large background signal. Precision detection of the boring tool location and orientation enables the operator to accurately locate the boring tool during operation and, if provided with a directional capacity, avoid buried obstacles such as utilities and other hazards. The signature signal produced by the boring tool may be generated either passively or actively, and may be a microwave or an acoustic signal.

Abstract: The systems and the methods relating to process control optimizations systems useful to manage oilfield hydrocarbon production. The systems and the methods utilize intelligent software objects which exhibit automatic adaptive optimization behavior. The systems and the methods can be used to automatically manage hydrocarbon production in accordance with one or more production management goals using one or more adaptable software models of the production processes.

Abstract: A method for mapping a bore below a ground surface is provided. A boring rod head configured to transmit a signal indicating the pitch angle of the boring rod head with respect to a horizontal plane is disposed within a bore. The boring rod head is advanced within the bore in predetermined linear increments. The pitch angle is measured at each increment. The change in depth is determined at each increment from a prior increment based on the length of the increment and the measured pitch angle at the increment. For each increment, the changes of depth determined in the prior step are added, including the change of depth for the most recent increment. Thus, the depth of the bore at each increment with respect to a predetermined horizontal plane is determined.

Abstract: A hydrocarbon production system comprises a topside installation connected to a underwater distribution unit 4 by an umbilical 3. The unit 4 is connected to Christmas Trees 8, 9 and 10 by respective ones of jumper interconnects 11, 12 and 13. Each Christmas Tree may comprise one or more of an electrical actuator 14, flow rate control choke 16, pressure and/or temperature transducers 18, down hole measurement transducers 18a and/or a down hole safety valve 21. Electrical power is transmitted to the unit 4 by a high voltage transmission cable forming part of the umbilical 3. A transformer forming part of the unit 4 steps down the voltage transmitted over the umbilical 3 to a level suitable for use by the electrical devices 14, 16 and 21. Power and control of the devices 14, 16, 18, 18a, 21 is effected by an underwater controller 5, 6, 7 associated with its respective Christmas Tree 8, 9, 10.

Abstract: A closed-loop system is used to complete oil and gas wells. The term “to complete a well” means “to finish work on a well and bring it into productive status”. A closed-loop system to complete an oil and gas well is an automated system under computer control that executes a sequence of programmed steps, but those steps depend in part upon information obtained from at least one downhole sensor that is communicated to the surface to optimize and/or change the steps executed by the computer to complete the well. The closed-loop system executes the steps during at least one significant portion of the well completion process. The completed well is comprised of at least a borehole in a geological formation surrounding a pipe located within the borehole.

Abstract: The invention relates to a data transmission or telemetry system and a method for communicating information axially along a drill string. The method includes the step of conducting an axial electrical signal embodying the information between a first axial position in the drill string and a second axial position in the drill string through an axial conducting loop formed by the drill string, which axial conducting loop extends between the first and second axial positions. The system includes the axial conducting loop for conducting the axial electrical signal embodying the information between the first and second axial positions and a transmitter for transmitting the information to the axial conducting loop. The system further preferably includes a receiver for receiving the information from the axial conducting loop. Finally, the portion of the drill string forming the axial conducting loop is preferably comprised of a downhole motor drilling assembly.

Abstract: A method for operating a downhole tool. The method includes moving an instrument through a wellbore, and the instrument includes a first non-acoustic transponder that is adapted to detect identification codes. An identification code detected from at least one second non-acoustic transponder is compared to a reference code. The at least one second non-acoustic transponder is attached to an emplaced structure in the wellbore, and the comparison is performed when the instrument moves by the at least one second non-acoustic transponder. The downhole tool is then operated if the identification code matches the reference code.

Abstract: A method and apparatus for implementing a communication network for well monitoring and control applications where a twisted pair cable bus is used to connect well-related locations. The twisted pair cable bus will exhibit high parallel impedance when used in differential mode and low series impedance in common mode. A bus supervisor and devices connected at nodes can exchange signal transmission. Communication, including data and control, signals and power signals can circulate along the twisted pair cable bus among and between the connected devices.

Abstract: A monitoring system determines characteristics of a fluid in a well. The system comprises a well module adapted to be disposed in a well, where the module comprises a probe and at least one sensor that senses characteristics of the fluid. The well module is capable of transmitting information concerning fluid characteristics. The system further comprises a data collection center, which is capable of receiving well information from the well module and generating information concerning characteristics of the fluid, a monitoring site, and a communication link that enables a user at the monitoring site to obtain information such as, but not limited to, real-time, historical, and a combination of real-time and historical concerning the characteristics.

Abstract: A method for actuating or installing downhole equipment in a wellbore employs non-acoustic signals (e.g., radio frequency signals) to locate, inventory, install, or actuate one downhole structure in relation to another downhole structure. The method comprises the steps of: (a) providing a first downhole structure that comprises a non-acoustic (e.g.

Abstract: A method and apparatus for acoustically actuating wellbore tools using two-way acoustic communication is disclosed.

Abstract: Distributed selectable fiber optic sensing system include a plurality of fiber grating sensors 12 connected to an optical fiber 10 and installed in an oil/gas well 15 and an instrumentation box 20 at the surface which selects which of the sensors 12 to activate, or provide output data from to a display 26 or to a remote link 32, such as the internet. The box 20 has a transceiver/converter 22 which provides a source optical signal 14 and receives a return optical signal 16,18 and which converts the return signal 16,18 to a signal indicative of the parameters being measured by the sensors 12. A sensor selection signal is provided from the remote link 32, the keyboard 28 to the converter 22 which is indicative of which of the sensors 12 to be selected to provide output data for. The end user only pays for the sensors 12 that are selected.

Abstract: This invention is a method of conducting seismic prospecting operations using a drilling tool (1) acting at the bottom of a well (2), which creates very powerful seismic vibrations, transmitting reference signals representing the vibrations of the tool in real time or later, and correlating the seismic signals picked up by a receiving assembly (12) with the reference signals. The reference signals are furnished by sensors (7) in contact with the drill string and at a distance from the down-hole assembly constituted by tool (1) and associated drill collars (4). In order for these reference signals to be truly representative, a damping means (8, 19) and at least one filtering element (20) designed to attenuate to a great degree the multiple reflections in a frequency range useful for seismic prospecting are interposed into the drill string. The invention has application to the making of seismic recordings.

Abstract: The method of remotely actuating a downhole device provides the initiation of an acoustic signal. The acoustic signal is amplified within a resonance chamber and is transmitted down a fluid column in the tubing string or in the annulus around the tubing string. The signal can be coded to allow activation of multiple downhole devices. The use of a resonance chamber allows for the amplification of the actuation signal to ensure that a downhole receiver can detect it. The receiver can be either a transducer or a hydrophone. The apparatus and method allow for remote actuation without the need for intervention into the well.