Abstract: A 4D seismic source comprising a series of sub-arrays of guns on flotation devices. Each flotation device has a GPS device. For firing, the guns in the e.g. three sub-arrays identified as being closest to the desired firing location are selected.

Abstract: A method and system for seismic data processing utilizes azimuthal variations in the velocity of seismic signals. The system and method utilizes a plurality of seismic energy sources that are located at known positions at the surface of the earth. The seismic energy sources generate seismic signals that propagate downward into the earth. Some of the seismic signals are reflected and diffracted by various sub-surface layers and are returned to the surface of the earth. The returned seismic signals are received by a plurality of receivers. The method includes the step of determining the distance from an energy source to an image point. A fast travel time of the seismic signal from the energy source to the image point is determined, and a slow travel time of the seismic signal from the energy source to the image point is determined. The azimuth angle between the energy source and the surface location of the image point is calculated.

Abstract: A seismic streamer includes a jacket covering an exterior of the streamer. At least one strength member extends along the length of the streamer and is disposed inside the jacket. At least one seismic sensor is disposed in a sensor spacer affixed to the at least one strength member. An encapsulant is disposed between the sensor and the sensor spacer. The encapsulant is a substantially solid material that is soluble upon contact with a void filling material. A void filling material is disposed in the interior of the jacket and fills substantially all void space therein. The void filling material is introduced to the interior of the jacket in liquid form and undergoing state change to substantially solid thereafter.

Abstract: Acoustic transducers configured with transducer elements disposed on an arch or arcuate shaped member adapted to fit in juxtaposition around a tubular. The arcuate shaped member is adapted with conductors to provide a voltage to the transducer elements. One embodiment uses a metallic arcuate shaped member. Embodiments implemented as sources are used to excite borehole acoustic modes. Some embodiments provide phased array acoustic energy excitation/signal reception. The transducers are covered with a sealer in a liquid-free configuration and shields are used to protect the transducers.

Abstract: Data processing means are described for calculating an estimated time of arrival of a seismic or microseismic P or S wave at a sensor station, based on a P to S wave velocity ratio, a calculated estimated time of origin of the event and, where the estimated arrival time of a P wave is to be calculated, a picked arrival time of the S wave at the sensor station or, where the estimated arrival time of a S wave is to be calculated, a picked arrival time of the P wave at the sensor station.

Abstract: In one aspect of the invention, a high-speed measurement system has a first and a second well bore. A first and second plurality of network nodes is integrated into and spaced at intervals along the first and second well bore, respectively. A communications channel connects each plurality of network nodes forming a first and second downhole network. A signal source is in communication with the first downhole network and a signal receiver is in communication with the second downhole network; and a common clock source is in communication with both the signal source and the signal receiver over the first and second downhole networks, respectively. The signal source and signal receiver are synchronized with the clock source and the signal source is adapted to send a signal to the signal receiver through a subterranean formation.

Abstract: A method of determining and analyzing spatial changes in the earth's subsurface. The method includes obtaining seismic attribute data as a 3D data volume and obtaining corresponding 3D dip and azimuth as a 3D volume and obtain corresponding 3D reliability volumes or 3D censor volumes which are representative of portions of the volume within in which a reliable dip and azimuth can be determined. The gradient of the seismic attribute data in the direction of structural dip is formed using either a dot product methodology or a derivative methodology after interpolation onto the direction of structural dip. At non-reliability locations or locations where no gradient could be meaningfully computed null values are stored. High gradient values in narrow time or depth ranges which are both statistically significant relative to a background level and contiguous designate regions likely to be proximal to a fluid contact or seismic flat spot.

Abstract: A method of determining and analyzing spatial changes in the earth's subsurface. The method includes obtaining seismic attribute data as a 3D data volume and obtaining corresponding 3D dip and azimuth as a 3D volume and obtain corresponding 3D reliability volumes or 3D censor volumes which are representative of portions of the volume within in which a reliable dip and azimuth can be determined. A focused subvolume of interest within the 3D data volume is additionally selected. An average for the plurality of vector dips is computed and a flat spot direction vector for each structural dip and a flat spot direction vector dip magnitude is determined. Sequences of distances from each reliability location is defined and interpolated onto the direction of the flat pot direction vector. The sequences of interpolated seismic attribute data is summed and the summed sequences of interpolated seismic attributed data values are stored.

Abstract: A method of imaging in an underground formation one or more steep-sloping geologic interfaces, which are not necessarily in a plane, by forming with primary reflectors, which are not necessarily in a plane, dihedra giving rise to prismatic seismic reflections (double reflections). The geometry of the steep-sloping interface is determined from choosing seismic records of one or more events corresponding to prismatic reflections for different source-pickup pairs of an acquisition device. A new reflection tomography technique is used, wherein introduction of specific constraints guarantees the convergence of the algorithm. The velocity distribution in the geologic formation and/or the geometry of the interface(s) between the sedimentary layers can be known otherwise or determined by means of the method. The method can apply to a formation comprising several different sloping interfaces.

Abstract: Methods, systems, and computer readable media are provided for interactively determining optimum deghosting parameter values for suppressing ghost reflections. Seismic data are obtained from various hydrophone/geophone receiver locations. Energy traces are generated which include measures of the deghosting parameter values from the seismic data obtained from each of the hydrophone/geophone receiver locations. The energy traces are displayed. A set of seed values is provided by the user. In response to receiving the user seed values, deghosting parameter values are picked based on the energy traces. The picked deghosting parameter values are displayed. A user then interactively edits and/or smooths the picks to obtain optimum deghosting parameter values. The optimum deghosting parameter values are utilized for suppressing ghost reflections in the seismic data.

Abstract: A method and apparatus for seismic trace matching to well logs.

Abstract: A method is disclosed for migrating seismic data which includes determining travel time of a compressional wave from a source location to a scatter point, taking into account ray bending. Travel time of a shear wave from the scatter point to a receiver location is determined, taking into account ray bending at the interfaces between subsurface strata. The determined travel times are then used to migrate the seismic data. In one embodiment, the travel times take account of vertically transversely isotropic media with a vertical symmetry axis.

Abstract: A method of seismic processing for obtaining information on the geophysics of the subsoil includes acquiring seismic traces at at least one point on the surface of the subsoil or in the subsoil, the seismic traces corresponding on each occasion to two perpendicular components of a shear wave emitted into the subsoil and reflected by different interfaces therein; applying a succession of transformations (?) at least to a temporal portion of the traces for each of these assumptions, determining the value of a parameter representative of the coherence/similarity between the result traces obtained in this way; and election as a function of the values obtained in this way that one of the hypotheses which is considered as being most representative of the subsoil, the two result traces obtained for said hypothesis being compensated traces of the subsoil birefringency.

Abstract: Coherent wave noise energy is removed from seismic data by modeling both the P-wave primary energy and the coherent wave noise energy. The P-wave primary energy is modeled first and then subtracted from the input data. The data with the P-wave primary energy removed is used as the input for coherent wave energy removal. The coherent wave energy is modeled and subtracted from the original input data, i.e. the data input into P-wave primary removal. This leaves a dataset with P-wave primary energy and noise energy not related to coherent waves. This method can be utilized to remove all types of coherent noise with a velocity difference to the desired P-wave primary energy or with a different type of moveout (change of time of arrival with source-receiver distance) such as, for example, linear moveout.

Abstract: Methods and systems for determining position of seismic sources and receivers are disclosed. Signals received by a first antenna are processed to determine its 3D coordinate position. Signals received by the first antenna and a second antenna are combined and processed to estimate a spatial vector between the first and second antennas. The spatial vector is added to the 3D coordinate position of the first antenna to provide a 3D coordinate position of the second antenna. Using the 3D coordinate position of the second antenna, a 3D coordinate position of a seismic source unit or receiver may be calculated, as well as a vertical correction for reflected seismic signals received by the receiver. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b).

Abstract: Methods and systems for taking measurements related to subterranean formations. The methods and systems provide robust, reliable first arrival data for component signals of interest, which may be used to estimate formation slowness, characterize formation slowness zones, or act as an input to other processes. The methods and systems are capable of automatically providing good first arrival data based on signals received without any human interaction, and without setting or changing any parameters.

Abstract: A longitudinally segmented acoustic transducer for a cement bond logging (CBL) tool having a plurality of adjoining PZT ring-like segments driven synchronously in parallel by one or more pulses and caused to vibrate in an anti-resonant mode, substantially below the resonant frequency of an individual segment when used in a transmitting application. When used in a receiving application, each of the plurality of transducer rings are caused to vibrate by acoustic signals detected by the transducer array, also in an anti-resonant mode. High speed digital signal processing enables on-depth, high quality data for all azimuths at each depth to be obtained, processed, normalized and either sent to the surface in real time for each 20 Hz firing cycle, as the CBL tool is pulled toward the surface, or stored in a memory module in digital form for later retrieval. Built-in calibration factors used for normalizing the output signals to the operating conditions of use may be accessed at any time.

Abstract: A method for improving the seismic resolution in the field of petroleum exploration and development, using the steps of: (1) ensuring the depth and the velocity of the low-velocity layer and the high-velocity layer and the characteristic of the frequency spectrum of the seismic wave at the near-surface using the borehole seismic survey; (2) separating the ghost wave from the seismic record in the high-velocity layer using the processing method of the vertical seismic profiling, and improving the SNR of the seismic record of the direct wave at the high-velocity layer using the uphole stacking of the vertical seismic profiling; (3) evaluating the de-convolution operator of the near-surface by the convolution math-physics equation; (4) evaluating the seismic record with high resolution by the de-convolution math-physics equation; (5) providing the band-pass filtering and geologic interpretation to the seismic record with high resolution.

Abstract: A method of and apparatus for processing seismic data. A method of processing seismic data comprising the steps acquiring seismic data in at least two shots that have different source-receiver azimuths from one another, and selecting events arising from interface seismic waves in each shot. The interface wave events are processed to provide information about azimuthal dependence of the velocity of seismic energy in the near-surface of the earth's interior. The invention may be used to process events arising from Scholte waves in marine seismic data, or to processing events arising from Love waves or Rayleigh waves in land seismic data. The method may be applied to seismic data acquired specifically to provide information about the near-surface or to seismic data acquired to provide information about the underlying geological structure.

Abstract: A method for seismic exploration using conversions between electromagnetic and seismic energy, with particular attention to the electromagnetic source waveform used. According to the invention, source waveforms are correlated with reference waveforms selected to minimize correlation side lobes. Line power at 60 Hz may be used to provide a waveform element which may be sequenced by a binary code to generate an extended source waveform segment with minimal correlation side lobes. Preferred binary codes include Golay complementary pairs and maximal length shift-register sequences.