Abstract: A method of performing notch compensation and a system to perform notch compensation for a first seismic streamer are described. The method includes disposing the first seismic streamer at a first depth, where the seismic streamer includes a first set of sensors to receive reflections resulting from a seismic source, the reflections indicating a notch at a frequency. The method also includes disposing a second seismic streamer at a second depth, the second depth being less than the first depth and the second seismic streamer including a second set of sensors to receive reflections resulting from the seismic source. The method further includes processing the reflections received by the first set of sensors and the second set of sensors together to derive the match filter, and applying the match filter to the reflections received by the first set of sensors of the first seismic streamer to compensate for the notch.

Abstract: Systems and methods compute dysfunctions via mapping of tri-axial accelerations of drill pipe into drill-string motions. The methods remove gravitational and centripetal accelerations to yield corrected acceleration data due to the vibration only, transform the corrected acceleration data, and maps resulting transformed acceleration data into continuous drill-string positions. The maps provide 2D/3D visualization of drill-string motions to enable real-time optimization and control of well drilling operations and other scenarios where proactive detection of temporal events in automated systems may aid in avoiding failures.

Abstract: Method for characterizing a subterranean formation includes: obtaining azimuth-dependent observed travel-times from measured seismic data; inverting observed travel-times to calculate a fracture attribute selected from the group consisting of: magnitude and orientation; identifying presence of fracture based on calculated fracture magnitude; identifying fracture direction based on calculated fracture orientation; calculating predicted travel-times; calculating differences or residual errors between observed travel-times and predicted travel-times; identifying potential fault locations based on residual errors; inverting fracture magnitude and orientation using travel-time differences between a shallower horizon to a deeper horizon of interest to minimize overburden artifacts.

Abstract: Systems and methods compute dysfunctions via mapping of tri-axial accelerations of drill pipe into drill-string motions. The methods remove gravitational and centripetal accelerations to yield corrected acceleration data due to the vibration only, transform the corrected acceleration data, and maps resulting transformed acceleration data into continuous drill-string positions. The maps provide 2D/3D visualization of drill-string motions to enable real-time optimization and control of well drilling operations and other scenarios where proactive detection of temporal events in automated systems may aid in avoiding failures.

Abstract: Systems and methods compute dysfunctions via mapping of tri-axial accelerations of drill pipe into drill-string motions. The methods remove gravitational and centripetal accelerations to yield corrected acceleration data due to the vibration only, transform the corrected acceleration data, and maps resulting transformed acceleration data into continuous drill-string positions. The maps provide 2D/3D visualization of drill-string motions to enable real-time optimization and control of well drilling operations and other scenarios where proactive detection of temporal events in automated systems may aid in avoiding failures.

Abstract: A method of performing notch compensation and a system to perform notch compensation for a first seismic streamer are described. The method includes disposing the first seismic streamer at a first depth, where the seismic streamer includes a first set of sensors to receive reflections resulting from a seismic source, the reflections indicating a notch at a frequency. The method also includes disposing a second seismic streamer at a second depth, the second depth being less than the first depth and the second seismic streamer including a second set of sensors to receive reflections resulting from the seismic source. The method further includes processing the reflections received by the first set of sensors and the second set of sensors together to derive the match filter, and applying the match filter to the reflections received by the first set of sensors of the first seismic streamer to compensate for the notch.

Abstract: The invention relates to a method, system and apparatus for synchronizing the time of time series data acquired from a wellbore sensor relative to a reference time series. This comprises acquiring a first time series from a sensor in a wellbore, acquiring a reference time series and determining a linear moveout time correction to apply to the first time series. The linear moveout time correction is equal to the depth of the wellbore sensor divided by the signal propagation velocity. The linear moveout correction is applied to the first time series. The first time series is cross-correlated with the reference time series to determine a cross-correlation time correction to apply to the first time series and the cross-correlation time correction is applied to the first time series to obtain a cross-correlation corrected time series. Dynamic time warping and dynamic cross-correlation may be used to adjust for clock drift.

Abstract: Improved methods of gather high fidelity vibratory seismic surveys for ZenSeis® systems wherein at least one optimal phase encoding schemes for surveys having 2-8 vibratory sources are disclosed. These encoding schemes can be hard coded into the source controller and will allow for quality data to be obtained on each survey. Further, the data will also have the best separation during inversion processing steps, leading to an optimal seismic survey.

Abstract: A method of performing notch compensation and a system to perform notch compensation for a first seismic streamer are described. The method includes disposing the first seismic streamer at a first depth, where the seismic streamer includes a first set of sensors to receive reflections resulting from a seismic source, the reflections indicating a notch at a frequency. The method also includes disposing a second seismic streamer at a second depth, the second depth being less than the first depth and the second seismic streamer including a second set of sensors to receive reflections resulting from the seismic source. The method further includes processing the reflections received by the first set of sensors and the second set of sensors together to derive the match filter, and applying the match filter to the reflections received by the first set of sensors of the first seismic streamer to compensate for the notch.

Abstract: Methods and systems output at least one drill string whirl attribute, such as magnitude, orientation, velocity and type, without requiring determination of whirl frequency. Transforming acceleration data into drill string motions provides a path of one point along the drill string. Fitting these motions throughout one complete revolution of the drill string to a revolution ellipse, for example, provides revolution ellipse centers defining centers of rotation for each revolution fitted. A whirl ellipse, for example, derives from another fitting using a plurality of the revolution ellipse centers. Coefficients from the whirl ellipse and/or vector direction of the centers provide at least one whirl attribute for output.

Abstract: Methods and systems output at least one drill string whirl attribute, such as magnitude, orientation, velocity and type, without requiring determination of whirl frequency. Transforming acceleration data into drill string motions provides a path of one point along the drill string. Fitting these motions throughout one complete revolution of the drill string to a revolution ellipse, for example, provides revolution ellipse centers defining centers of rotation for each revolution fitted. A whirl ellipse, for example, derives from another fitting using a plurality of the revolution ellipse centers. Coefficients from the whirl ellipse and/or vector direction of the centers provide at least one whirl attribute for output.

Abstract: The invention relates to a method, system and apparatus for synchronizing the time of time series data acquired from a wellbore sensor relative to a reference time series. This comprises acquiring a first time series from a sensor in a wellbore, acquiring a reference time series and determining a linear moveout time correction to apply to the first time series. The linear moveout time correction is equal to the depth of the wellbore sensor divided by the signal propagation velocity. The linear moveout correction is applied to the first time series. The first time series is cross-correlated with the reference time series to determine a cross-correlation time correction to apply to the first time series and the cross-correlation time correction is applied to the first time series to obtain a cross-correlation corrected time series. Dynamic time warping and dynamic cross-correlation may be used to adjust for clock drift.

Abstract: Systems and methods compute dysfunctions via mapping of tri-axial accelerations of drill pipe into drill-string motions. The methods remove gravitational and centripetal accelerations to yield corrected acceleration data due to the vibration only, transform the corrected acceleration data, and maps resulting transformed acceleration data into continuous drill-string positions. The maps provide 2D/3D visualization of drill-string motions to enable real-time optimization and control of well drilling operations and other scenarios where proactive detection of temporal events in automated systems may aid in avoiding failures.

Abstract: Improved methods of gather high fidelity vibratory seismic surveys for ZenSeis® systems wherein at least one optimal phase encoding schemes for surveys having 2-8 vibratory sources are disclosed. These encoding schemes can be hard coded into the source controller and will allow for quality data to be obtained on each survey. Further, the data will also have the best separation during inversion processing steps, leading to an optimal seismic survey.

Abstract: The invention relates to a seismic acquisition process where multiple seismic sources are used to acquire seismic energy using encoding so that all of the sources may deliver seismic energy at the same time where the sweeps are arranged to be back to back with no listen time and wherein a pseudo listen time that is uncontaminated is created in the composite data record. After the listen time is created, the composite data may be source separated for further processing and analysis.

Abstract: Interpolation of seismic data of a subterranean formation includes: obtaining input seismic data; constructing an initial model by interpolation operation along dominant dips in time domain, wherein the initial model includes structural features of the subterranean formation; interpolating seismic data missing from the input seismic data via model-constrained minimum weighted norm interpolation (MWNI) to generate interpolated data; computing difference between the input seismic data and the interpolated data, wherein the difference is residual data; replacing the initial model using difference between the initial model and the interpolated data to generate an updated-initial model; performing model-constrained MWNI method using the residual data and the updated-initial model; adding the interpolated data from residual data to a previously generated interpolated data.

Abstract: A method of performing notch compensation and a system to perform notch compensation for a first seismic streamer are described. The method includes disposing the first seismic streamer at a first depth, where the seismic streamer includes a first set of sensors to receive reflections resulting from a seismic source, the reflections indicating a notch at a frequency. The method also includes disposing a second seismic streamer at a second depth, the second depth being less than the first depth and the second seismic streamer including a second set of sensors to receive reflections resulting from the seismic source. The method further includes processing the reflections received by the first set of sensors and the second set of sensors together to derive the match filter, and applying the match filter to the reflections received by the first set of sensors of the first seismic streamer to compensate for the notch.

Abstract: The invention relates to a process for two separate seismic crews to work in proximity to one another that would otherwise require expensive time sharing where one crew is a conventional seismic acquisition system and the other is a phase encoded seismic acquisition system. Typically, each recording system would receive seismic energy from the other that neither data set would be very useful. The invention primarily envisions some collaboration between the crews where each adjusts its sweeps to comprise a different time duration so that the energy the other crew's sources are distinguishable in the data set and easily eliminated therefrom. Distinctions may be further enhanced when the two crews use construct their sweeps so that each crew has a distinctly different start frequency and a distinctly different end frequency.

Abstract: Method for characterizing a subterranean formation includes: obtaining azimuth-dependent observed travel-times from measured seismic data; inverting observed travel-times to calculate a fracture attribute selected from the group consisting of: magnitude and orientation; identifying presence of fracture based on calculated fracture magnitude; identifying fracture direction based on calculated fracture orientation; calculating predicted travel-times; calculating differences or residual errors between observed travel-times and predicted travel-times; identifying potential fault locations based on residual errors; inverting fracture magnitude and orientation using travel-time differences between a shallower horizon to a deeper horizon of interest to minimize overburden artifacts.

Abstract: A method of conducting multiple source, multiple signal seismic surveys in a marine environment are provided.