Abstract: A system for synchronizing components of a downhole system includes: a source assembly including a source clock; an electromagnetic source associated with the source assembly and configured to emit an electromagnetic signal into an earth formation at a transmission time; a receiver assembly including a receiver clock; an electromagnetic receiver associated with the receiver clock and configured to detect the electromagnetic signal; and a processor configured to identify a receipt time of the electromagnetic signal based on the receiver clock and adjust the receiver clock by comparing the transmission time to the receipt time.

Abstract: A mobile work machine includes a chassis that has a traveling gear and a bracing device that is arranged on the chassis and can be braced on a support such as to raise the chassis. The traveling gear includes at least one traveling gear part, the relative position and/or inclination of which with respect to the chassis can be varied during the bracing process. At least one position or inclination sensor is arranged on the traveling gear part, the output signal of the sensor being an actual measure of the position or the inclination of the traveling gear part relative to a reference system that is stationary on the chassis or stationary on the ground. In addition, an evaluation unit is provided, which responds to the output signal of the at least one position or inclination sensor.

Abstract: The invention relates to a distributing boom (14) for stationary or mobile concrete pumps. The distributing boom (14) consists substantially of a rotary head (22), which can be rotated about an axis of rotation (18) in the form of a vertical axis, and of an arm assembly (24), which is made up of a plurality of boom arms which can be telescoped or pivoted relative to one another. The arm assembly (24) has the one end of its first boom arm (1) articulated on the rotary head (22) and, by means of a first cylinder/piston unit (32), which has its ends articulated at points of articulation (28, 30) of the rotary head (22) and of the first boom arm (1), can be pivoted, about a horizontal axis of inflection (A), between a substantially horizontally oriented retracted position and an operating position. It is an aim of the invention to provide measures which make it possible for the cylinder/piston unit (32), which acts on the first boom arm (1), to be reduced in size.

Abstract: The invention relates to a mobile work machine, comprising a chassis (10) that has a traveling gear (11) and a bracing device that is arranged on the chassis (10) and can be braced on a support (28) such as to raise the chassis (10). The invention is further based on the realization that the traveling gear (11) comprises at least one traveling gear part (38, 38?), the relative position and/or inclination of which with respect to the chassis (10) can be varied during the bracing process. According to the invention, at least one position or inclination sensor (36) is arranged on the traveling gear part (38, 38?), the output signal of the sensor being an actual measure of the position or the inclination of the traveling gear part (38, 38?) relative to a reference system that is stationary on the chassis or stationary on the ground. In addition, an evaluation unit is provided, which responds to the output signal of the at least one position or inclination sensor.

Abstract: A system for synchronizing components of a downhole system includes: a source assembly including a source clock; an electromagnetic source associated with the source assembly and configured to emit an electromagnetic signal into an earth formation at a transmission time; a receiver assembly including a receiver clock; an electromagnetic receiver associated with the receiver clock and configured to detect the electromagnetic signal; and a processor configured to identify a receipt time of the electromagnetic signal based on the receiver clock and adjust the receiver clock by comparing the transmission time to the receipt time.

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 mobile implement, particularly an automatic concrete pump, with stability monitoring system includes an undercarriage supportable on a subsurface by two front and two rear outriggers. A respective measuring element is disposed in the telescoping support legs of the outriggers for determining the supporting force. Each support leg has an upper telescoping element connected to the associated outrigger at an upper connection point, and a support base displaceable relative to the upper element and supported on the subsurface at the lower end thereof at a lower connection point. The measuring element is disposed either directly at the upper connection point between the outrigger and the upper telescoping element, or in the region of the lower connection point between the lower telescoping element and the support base.

Abstract: A downhole tool starts recording seismic energy. During the recording time, a surface seismic source is activated a specified number of times with a nominally defined separation between successive. The downhole sensor receives seismic waves resulting from the activation, but the time of the shooting sequence is not known downhole. The recorded data stream is processed and converted in real-time into seismic traces. A predefined number of traces are stacked and the quality of this sliding stack is used to detect time of the shooting sequence. The method could be used to detect one or several shooting sequences during a measurement window.

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 drilling system includes a control unit and a bottomhole assembly (BHA) coupled to a drill string. The control unit uses measurements from sensors distributed throughout the drill string and BHA to determine the physical condition of the drill string and BHA and to determine whether drilling can be optimized. The drill string sensors are housed in receiver subs and optionally can be positioned on extensible members. The receiver sub also can include a short-hop telemetry module, a processor module, and a clock module. In one embodiment, the receiver subs include seismic sensors for enabling vertical seismic profiling. During operation, the processor visually presents to the operator via one or more graphical user interfaces a dynamically updated pictorial image representing the drilling system. The image is annotated with an appropriate visual signal to indicate a determined physical condition at a given location or component.

Abstract: A seismic and/or acoustic while drilling configuration includes a high speed telemetry arrangement; at least one seismic and/or acoustic energy sensor in communication with the high speed telemetry arrangement; at least one seismic and/or acoustic energy source capable of producing at least one seismic and/or acoustic energy signal receivable by the at least one seismic and/or acoustic energy sensor and methods.

Abstract: A system for drilling a well comprises a tubular member having a bottomhole assembly at a bottom end thereof disposed in a wellbore. A first sensor is disposed in the bottomhole assembly at a predetermined axial location for detecting bending in a first axis and generating a first bending signal in response thereto, where the first axis is substantially orthogonal to a longitudinal axis of the bottomhole assembly. A second sensor is disposed in the bottomhole assembly at the predetermined axial location for detecting bending in a second axis and generating a second bending signal in response thereto, where the second axis is substantially orthogonal to the longitudinal axis. A processor receives the first bending signal and the second bending signal and relates the first bending signal and the second bending signal to a borehole curvature according to programmed instructions.

Abstract: Separation of telemetry and noise signals in a telemetry system is accomplished by modeling the system as one in which two sources are operating simultaneously. Direct and indirect implementations by IIR and FIR filters are discussed.

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

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

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

Abstract: A drilling system includes a control unit and a bottomhole assembly (BHA) coupled to a drill string. The control unit uses measurements from sensors distributed throughout the drill string and BHA to determine the physical condition of the drill string and BHA and to determine whether drilling can be optimized. The drill string sensors are housed in receiver subs and optionally can be positioned on extensible members. The receiver sub also can include a short-hop telemetry module, a processor module, and a clock module. In one embodiment, the receiver subs include seismic sensors for enabling vertical seismic profiling. During operation, the processor visually presents to the operator via one or more graphical user interfaces a dynamically updated pictorial image representing the drilling system. The image is annotated with an appropriate visual signal to indicate a determined physical condition at a given location or component.

Abstract: A system for drilling a well comprises a tubular member having a bottomhole assembly at a bottom end thereof disposed in a wellbore. A first sensor is disposed in the bottomhole assembly at a predetermined axial location for detecting bending in a first axis and generating a first bending signal in response thereto, where the first axis is substantially orthogonal to a longitudinal axis of the bottomhole assembly. A second sensor is disposed in the bottomhole assembly at the predetermined axial location for detecting bending in a second axis and generating a second bending signal in response thereto, where the second axis is substantially orthogonal to the longitudinal axis. A processor receives the first bending signal and the second bending signal and relates the first bending signal and the second bending signal to a borehole curvature according to programmed instructions.