Abstract: In various embodiments, seismic receivers may detect seismic energy and transmit digital signals representative of the seismic energy to an S-line interface module (SLIM) and/or a smart antenna module (SAM) for collection. A SLIM may be used to connect two or more seismic receivers together. A SAM may include a memory medium for storing digital signals from seismic receivers (e.g., received directly from the seismic receivers or received through a connection to a SLIM) and a wireless transmitter to transmit data stored on the memory medium. The SAM may further include a Global Positioning System (GPS) receiver for receiving and storing timestamps, clock data, and/or positional data relative to the seismic receivers. The timestamps, clock data, and/or positional data may be transmitted along with the digital signal data to an external source (e.g., a laptop) for analysis to detect characteristics of subterranean formations.

Abstract: Method for transforming geologic data relating to a subsurface region between a geophysical depth domain and a geologic age domain. A set of topologically consistent surfaces (252a) is obtained that correspond to seismic data (252). The surfaces are enumerated in the depth domain. An age is assigned to each surface in the depth domain (255). The age corresponds to an estimated time of deposition of the respective surface. An age mapping volume is generated (256). An extent of the age domain is chosen. A depth mapping volume is generated (260). Both the age mapping volume and the depth mapping volume are used to transform geophysical, geologic, or engineering data or interpretations (258, 263) between the depth domain and the age domain (268) and vice versa (269). The geophysical, geologic, or engineering data or interpretations transformed by at least one of the age or depth mapping volume are outputted.

Abstract: A method for fault and fracture identification based on seismic data representing a geological section using dispersion properties of reflected and diffracted waves. The method includes scanning N parameters associated with the seismic data. The array includes the coordinate axes of the angle of emergence (?), the radius of curvature of the wave front (R) and either time or depth samples. The method also includes processing the N parameters, generating a new image having a cross-sectional shape associated with one of the reflected and diffracted waves, calculating parameters DS and LS, evaluating DS for the case of fracture characterization, and comparing, for the case of fault identification, parameter LS with a threshold value defining the type of wave as one of the reflected and diffracted wave, the cross-sectional shape being substantially circular for the reflected wave, and being elliptical for the diffracted wave.

Abstract: A seismic sensor module includes sensing elements arranged in a plurality of axes to detect seismic signals in a plurality of respective directions, and a processor to receive data from the sensing elements and to determine inclinations of the axes with respect to a particular orientation. The determined inclinations are used to combine the data received from the sensing elements to derive tilt-corrected seismic data for the particular orientation.

Abstract: The invention relates to acquiring seismic data in either land or marine environments, but typically marine environments where a pulse-type source is fired in a distinctive composite pulse like a distinctive rumble. In a preferred embodiment, a number of pulse-type seismic sources, sometimes called an array, are fired in a distinctive composite pulse to be able to identify within the returning wavefield the energy resulting from the composite pulse. Firing the pulse-type sources creates an identifiable signature so that two or more marine seismic acquisition systems with source arrays can be acquiring seismic data concurrently and the peak energy delivered into the water will be less, which will reduce the irritation of seismic data acquisition to marine life.

Abstract: A technique includes receiving requests from mobile seismic sources and organizing the requests in a queue. The seismic sources are associated with respective paths of a survey plan, and each request indicates that one of the seismic sources is ready for an action to be performed by the seismic source. The technique includes regulating an ordering associated with the requests based on survey parameters and responding to the requests according to the ordering.

Abstract: A system includes a subterranean survey data acquisition network and a processor. The network has first nodes that are distributed along a length of the network between a first end of the network and a second end of the network. Each of the first nodes is capable of being either in a state in which the first node is transparent to the network or in a state in which the first node is visible to the network. The processor is adapted to communicate with the closest visible first node relative to the first end, and the processor is adapted to, based on the communication, determine whether the closest visible first node is the closest first node of all of the first nodes relative to the first end.

Abstract: A method for generating a synthetic seismogram. In one implementation, a ray tracing may be performed on a subsurface. The ray tracing may generate a plurality of rays. A first seismic wavefront may be reconstructed by triangulating a first plurality of control points that correspond to the plurality of rays. Each control point may represent an end point of a ray at the first seismic wavefront. The plurality of rays may be propagated to a second seismic wavefront. The second seismic wavefront may have a hole associated with at least one missing ray at the second seismic wavefront. A plurality of points on a circle may be defined that correspond to a second plurality of control points defining the hole. The second seismic wavefront may be reconstructed based on the plurality of points on the circle.

Abstract: Methods and systems for digital control utilizing oversampling.

Abstract: The invention comprises a synergy of technology integrations including an acoustic device and method of using said device(s)—to initiate avalanche release as a non-explosive control alternative. The invention is an integration of technologies incorporating an acoustic device, power supply and amplification, inverter, digital signal processor, GPS, and RF receiver all housed in a rugged weather resistant enclosure with necessary gantry and rigging. The combination of these technologies allows control personnel to safely operate the equipment from a remote location. The invention is deployed remotely via a cable or network of cables to predetermined avalanche starting zone(s). The device can be rotated, panned the full length or range of the cable(s), and tilted offering the user comprehensive coverage of any topography.

Abstract: A method for passive seismic surveying includes deploying seismic sensors in a plurality of spatially distributed wellbores disposed above a volume of subsurface formations to be evaluated. The sensors in each wellbore form a line of sensors. Each sensor generate optical or electrical signals in response to seismic amplitude. The seismic signals from each sensor are recorded for a selected period of time. The response of the seismic sensor recordings is beam steered to at least one of a selected point and a selected volume in the subsurface. At least one microseismic event is identified in the beam steered response.

Abstract: A system and method for using orthogonally-coded active source signals for reflected signal analysis, such as in seismic exploration, sonar, and/or ultrasound applications. One method comprises inputting an orthogonally-coded active source signal to a target site, where the orthogonally-coded active source signal is sufficiently random to not interfere with a delayed version of itself. A reflected signal is received from the target site, and based at least in part on the sufficiently random orthogonal coding of the active source signal, a determination is made whether the received signal is a reflection of the input active source signal.

Abstract: The presently disclosed technique includes a method for geophysical survey having at least one source and one receiver, wherein the survey has two sets of survey locations within the survey area, one set of survey locations for the source(s) and the other set of survey locations for the receiver(s), wherein the survey locations in one set are randomized.

Abstract: Stoneley-wave data acquired in the LWD environment are used to characterize/estimate formation permeability. Real-time Stoneley-wave time-delay/slowness and center-frequency/attenuation data are used to indicate/characterize formation permeability even during drilling. The use of stabilizers mounted at the tool ends helps maintain the tool position from severe decentralization, reducing ambiguities in the permeability characterization/estimation.

Abstract: Joint processing of seismic and controlled source electromagnetic (CSEM) surface data is performed by using a common rock physics model which relates reservoir properties (such as porosity, lithology, saturation, and shaliness) to surface seismic AVO (or AVA) data. This allows one to determine how perturbations in the reservoir properties affect surface data. This can be carried out by systematically changing the reservoir properties and examining the effect on the synthetic data. This allows the hydrocarbon type of a reservoir to be established, e.g. oil or gas, as well as the saturation level of the hydrocarbon in the reservoir, which is useful for determining whether the reservoir has a non-commercial, low hydrocarbon saturation or a commercial, high hydrocarbon saturation.

Abstract: The invention generally relates a method of determining completion criteria for a coal bed methane reservoir having a plurality of coal seams.

Abstract: A combined probe includes a dilatometer probe, a gas conduit coupled to the dilatometer probe for providing a gas connection between the dilatometer probe and an external gas source, a wire located in the gas conduit for providing an electrical connection between the dilatometer probe and an external circuit, and a seismic module coupled to the wire located in the gas conduit to provide an electrical connection between the seismic module and the external circuit.

Abstract: The present invention relates to a method and system for processing multi-dimensional signal data to determine frequency dependent features therefrom. The multi-dimensional signal data are transformed into space-frequency or time-space-frequency domain, providing second signal data. At predetermined locations of at least a portion of the one of space and time-space of the second signal data a dominant feature corresponding to a largest value of the second signal data is determined. This is followed by the determination of a wave-vector corresponding to the dominant feature at each of the predetermined locations. Finally, a dip map, a frequency map, and an amplitude map are generated using the wave-vectors.

Abstract: Techniques or mechanisms are provided to improve accuracy in determining headings and/or shapes of carrier structures based on measurements made by one or more compasses that are attached to or provided with the carrier structures. The carrier structures are used to carry survey receivers that detect survey signals affected by a subterranean structure.

Abstract: A method of predicting subsurface properties of a geologic formation includes acquiring seismic data for a subsurface region including the geologic formation of interest, computing seismic attributes of the measured seismic data over at least part of this geologic formation, determining internally consistent rock properties representative of the geologic formation, generating models of the same part of the geologic formation with these rock properties, computing synthetic seismic data from the models, computing the same attributes from these synthetic seismic data, and using Bayesian analysis to predict, from the probability of modeled attributes given the models, the probability of the actual subsurface properties given the measured attributes.

Abstract: A synchronous recording system is configured with a first seismograph and a second seismograph. The first seismograph includes a sensor, a GPS receiver, a data buffer, and a synchronous information transmission program that transmits synchronous information to the second seismograph, the information designating recording start time. The second seismograph includes a sensor, a GPS receiver, a data buffer, a recorder, a synchronous information reception program that receives the synchronous information, and a recording control program that starts, based on the synchronous information, recording in the recorder of oscillation data, which is recorded in the data buffer, from the designated recording start time.

Abstract: The present invention provides a method and apparatus for providing simplified seismological surveys with increased accuracy and ease of use. The present invention uses data received from satellite positioning systems to obtain time and position information. The information is used to determine transmission times of pressure waves between a seismic source and a seismic sensor.

Abstract: A Laplace transform system comprising a processor, a measured time domain wavefield, a velocity model, and Laplace damping constants, wherein the processor is programmed to calculate a substantially about zero frequency component of a Fourier transform of a time domain damped wavefield, wherein the time domain damped wavefield is damped by the Laplace damping constants to obtain long wavelength velocity information for deeper subsurface regions.

Abstract: A system for determining the position and/or orientation of electromagnetic receivers in a network of receiver instruments at a remote location, a first receiver instrument including one or more electromagnetic sensors, the system comprising transmitting means to send a characteristic signal, detecting means to detect transmitted signals from a plurality of receiver instruments, depth measurement means to measure the depth of the first instrument, recording means to store data from the transmitting means, the detecting means and the depth measurement means, and processing means for processing data from the receiver instruments.

Abstract: A technique includes providing seismic data that is indicative of energy that is sensed in response to a first operation of at least one seismic source in a first seismic survey and a second operation of at least one seismic source in a second seismic survey. The technique includes processing the seismic data to determine a timing of the second operation relative to the first operation, and the technique includes based at least in part of the determined timing, processing the seismic data to generate a dataset, which is indicative of the sensed energy that is attributable to the first operation and is not attributable to the second operation.

Abstract: Seismic sensor systems and sensor station topologies, as well as corresponding cable and sensor station components, manufacturing and deployment techniques are provided. For some embodiments, networks of optical ocean bottom seismic (OBS) stations are provided, in which sensor stations are efficiently deployed in a modular fashion as series of array cable modules deployed along a multi-fiber cable.

Abstract: Method for subsurface exploration. In one implementation, the method may include receiving a gamma value at a subsurface interface, wherein the gamma value is a ratio of Vp/Vs at the subsurface interface. Vp is the average P wave velocity and Vs is the average S wave velocity. The method may further include receiving a converted wave reflection coefficient at the subsurface interface. The converted wave reflection coefficient is a function of a density contrast at the subsurface interface and a shear velocity contrast at the subsurface interface. The method may further include determining a P wave incident angle such that the converted wave reflection coefficient is a function of substantially only the density contrast at the P wave incident angle. The P wave incident angle is referred to herein as ?. The method may further include calculating the density contrast based on the converted wave reflection coefficient at ?.

Abstract: A method for data processing includes transforming measurement data acquired in the time domain during an oilfield operation into a second domain to produce transformed data; identifying distortions in the transformed data; removing the distortions from the transformed data; and transforming back from the second domain to the time domain to produce cleaned-up data. The transforming measurement data may use a Fourier transform or a wavelet transform. The method may further include compressing the cleaned-up data or reconstructing signals from the cleaned-up data. A method for data processing includes decomposing measurement data, which are acquired in an oilfield operation, using a low pass filter to produce a first dataset; decomposing the measurement data using a high pass filter to produce a second dataset; removing distortions from the second dataset to yield a corrected second dataset; and reconstructing a corrected dataset from the first dataset and the corrected second dataset.

Abstract: A method of characterizing a fractured reservoir in a field includes measuring seismic reflection coefficient of the fractured reservoir as a function of angle of incidence and azimuth, predicting seismic reflection coefficient of the fractured reservoir as a function of angle of incidence and azimuth using an elastic stiffness tensor and an elastic compliance tensor of the fractured reservoir, determining components of an excess compliance tensor due to the presence of fractures in the fractured reservoir by matching the predicted seismic reflection coefficient to the measured seismic reflection coefficient, and characterizing one or more properties of the fractured reservoir using the excess compliance tensor.

Abstract: A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data.

Abstract: The present invention provides a seismic exploration and imaging system for producing seismic survey reports of subsea geological structures. The exploration system provides a method in which both P-waves and S-waves are detected without the need for placing detection apparatus in contact the seabed. A seismic event is applied (12) to the earth's surface (13), and the detected response including P-waves and S-waves in the earth's. The detecting apparatus comprises a means for monitoring and recording the response to the seismic event in the form of movements of particles at the earth's surface, from a position spaced from the earth's surface. Particles at the surface will respond both to P-wave and S-wave stimulation and so their movements will be representative of the two waves. These movements are detected from a distance.

Abstract: Methods and systems for determining coil eccentricity of seismic sensors configured or designed for use in seismic signal detection. A direct electrical current is applied to a moving coil of a seismic sensor such that the moving coil is dislocated from a neutral position relative to the magnetic field in the seismic sensor. A predetermined indicator is measured and eccentricity of the coil (?) relative to the center of the magnetic filed is determined using the predetermined indicator.

Abstract: A technique includes determining at least one parameter that characterizes a seismic survey in which multiple interfering seismic sources are fired and seismic sensors sense energy that is produced by the seismic sources. The determination of the parameter(s) includes optimizing the seismic survey for separation of the sensed energy according to the seismic sources.

Abstract: A method of controlling distributed devices includes configuring the devices to respond to a controlled signal; positioning the devices in an area of interest; and transmitting the controlled signal into the earth. The earth acts as the signal transmission medium. The method may include controlling a signal generator with a controller to transmit the controlled signal. An illustrative controlled signal may have a fixed frequency, a fixed amplitude, a fixed wave form, a modulated frequency, a modulated amplitude, a modulated wave form, and/or a predetermined duration. In aspects, the method may include connecting the signal generator to the earth and transmitting the controlled signal into the earth using the signal generator. Afterwards, the signal generator may be operated to impart seismic energy into the earth. The devices may be used to detect and record seismic energy that has reflected from underground formations.

Abstract: The present invention relates to a method and system for processing seismic data. Seismic data indicative of at least a time-dependent seismic trace are transformed into time-frequency domain using the S-transform. The transformed seismic data are processed for determining at predetermined time instances an instantaneous amplitude and a dominant instantaneous frequency. Based on a quotient of the instantaneous amplitude to the dominant instantaneous frequency seismic data indicative of a likelihood of a presence of hydrocarbons are then determined which are then graphically displayed. The method and system for processing seismic data provides a powerful tool for determining the likelihood of a presence of hydrocarbons based on a double peak hydrocarbon signature in the quotient of the instantaneous amplitude to the dominant instantaneous frequency.

Abstract: The invention relates to a seismic warning system comprising of two or more sensors for detecting shock signals and electronic signal processing elements for processing and analyzing said signals. According to the invention, the system has at least two detection units, each comprising a shock sensor and electronic signal processing elements. The signal processing elements of each detection unit are configured in such a way that they detect the primary waves of earthquakes using the signals of the shock sensors. The detection units are interconnected via an electronic data bus.

Abstract: A combined probe includes a dilatometer probe, a gas conduit coupled to the dilatometer probe for providing a gas connection between the dilatometer probe and an external gas source, a wire located in the gas conduit for providing an electrical connection between the dilatometer probe and an external circuit, and a seismic module coupled to the wire located in the gas conduit to provide an electrical connection between the seismic module and the external circuit.

Abstract: Seismic data may be imaged using or recognizing substantially only primary reflections. Imaging seismic data may include for example integrating a plurality of seismic data points that have substantially similar arrival directions, for example, to a modeled primary ray. Seismic data points may be imaged that for example substantially meet a set of predetermined conditions, for example, conditions substantially unique to primaries, which may include for example arrival direction and angle of reflection.

Abstract: Methods, systems, and computer program products for determining a property of construction material. According to one aspect, a material property gauge operable to determine a property of construction material is disclosed. The gauge may include an electromagnetic sensor operable to measure a response of construction material to an electromagnetic field. Further, the electromagnetic sensor may be operable to produce a signal representing the measured response by the construction material to the electromagnetic field. An acoustic detector may be operable to detect a response of the construction material to the acoustical energy. Further, the acoustic detector may be operable to produce a signal representing the detected response by the construction material to the acoustical energy. A material property calculation function may be configured to calculate a property value associated with the construction material based upon the signals produced by the electromagnetic sensor and the acoustic detector.

Abstract: Method for survey design including configuring electrodes to reduce near-surface noise in the seismic response from an electroseismic survey of a subterranean formation. Different embodiments of the invention include (1) selective measurement of the surface noise to remove it from the data; (2) suppressing surface noise generation by reducing electric fields in the vicinity of some of the electrodes; (3) creating source signature differences between the near-surface seismic response and the deep response enabling the near surface response to be removed in data processing; (4) applying an external near-surface magnetic field to modulate the near-surface seismic response, enabling it to be removed in processing; and (5) constructing a partial Faraday cage to shield a near-surface region from fields generated by the electrodes.

Abstract: Systems and methods for acquiring seismic data are described, one system comprising one or more seismic sources, a plurality of sensor modules each comprising a seismic sensor configured to sample analog seismic data, each module comprising a comparing unit comprising software; wherein the software in each module tests clock quality by running a sigma-delta modulator from two different clock sources in the node and compares a noise-floor of the modulator when using the different clocks.

Abstract: A method of analyzing results from an underwater controlled source electromagnetic (CSEM) survey of an area that is thought or known to contain a subterranean hydrocarbon reservoir is described. The method is based on a wavefield extrapolation of narrow-band electromagnetic field data obtained from pairs of source and receiver locations. The data comprise a plurality of discrete frequencies between 0.01 Hz and 60 Hz. The wavefield extrapolation is performed for each of these discrete frequencies to provide distributions of electromagnetic scattering coefficient as a function of position and depth beneath the survey area. These distributions may then be combined to provide a displayable image of electromagnetic scattering coefficient. The method is able to quickly provide a displayable image that is readily interpretable.

Abstract: A method for wireless communication in a seismic sensor network is disclosed. The method comprises providing a first acoustic device having at least one seismic sensor with communication and control data to communicate over an acoustic energy wave on a first communications channel. The first acoustic device generates the acoustic energy wave with a first wave intensity. The first acoustic device is configured to receive a reflection of the generated wave at a prescribed signal sensitivity level based on a network configuration. If the first wave intensity is below the prescribed signal sensitivity level, the first wave intensity of the acoustic energy wave is tuned to the prescribed signal sensitivity level to interpret the communication and control data provided by the first communications channel.

Abstract: A seismic energy source includes at least a first and a second acoustic radiator operatively coupled to a non-linear medium proximate an upper limit of formations in the Earth's subsurface. The first and second acoustic radiators are configured to convert electrical energy directly into acoustic energy. The source includes means for operating the first and the second acoustic radiator at respective first and second frequencies. The first and second frequencies are selected such that substantially no acoustic energy propagates through the non-linear medium. The first and the second frequencies are selected such that a difference therebetween is swept through a range of frequencies of seismic energy capable of propagating through the Earth's subsurface to at least one acoustic impedance boundary within the Earth's subsurface.

Abstract: To attenuate a surface seismic wave, seismic sensors having a predetermined orientation with respect to a surface are provided, where the seismic sensors receive seismic waves including a seismic wave reflected from a subterranean structure and the surface seismic wave propagating in at least a first direction that is generally parallel to the surface. A signal that represents a partial derivative of a wavefield containing the surface seismic wave is provided, and the signal is integrated to obtain a response in which the surface seismic wave is attenuated.

Abstract: An apparatus for collecting geophysical information may include a geophysical information station disposed along a seismic communication cable. A bypass circuit responsive to a command signal is in communication with a switching circuit that is operable to route electrical power, commands, data or a combination to bypass the geophysical information station in response to the command signal. An exemplary method for bypassing a geophysical information station in a geophysical information collection system includes sending a command signal to a bypass circuit and activating one or more switching circuits using the bypass circuit to route electrical power, commands, data or a combination to bypass the geophysical information station in response to the command signal.

Abstract: A method and apparatus for estimating a seismic velocity field from seismic data including time-amplitude representations associated with source-receiver locations spaced apart by an offset distance and having a midpoint therebetween, the seismic data being arranged into common midpoint (CMP) gathers associated with respective CMP locations. A control plane having an edge intersecting a plurality of the CMP locations is defined, an initial velocity field for the control plane is produced, the initial velocity field including a plurality of time-velocity values for each of the CMP locations; and an optimized velocity field for the control plane is produced by adjusting the time-velocity values for each of the CMP locations in response to trends, relative to offset distance, in time values, associated with common seismic events, until said optimized velocity field satisfies a condition.

Abstract: The disclosure herein provides a method of acquiring seismic data that includes receiving seismic signals at one or more sensors; sampling the received seismic signals into a plurality of samples, each sample having a same bit length; arranging the samples into a plurality of packets; compressing the plurality of packets by varying a time interval between transmissions of at least some of the packets; and transmitting the compressed packets.

Abstract: Disclosed is a system for detecting seismic events, the system including a plurality of seismic receivers, at least one of the receivers in the plurality adapted for: monitoring seismic activity, providing an alert to at least another of the receivers in the plurality upon detection of a seismic event, and triggering the monitoring in the at least another of the receivers in the plurality. A method and computer program product for monitoring seismic events is also disclosed.

Abstract: A method for seismic exploration using nonlinear conversions between electromagnetic and seismic energy, with particular attention to the electromagnetic source waveform used. According to the invention, seismic returns from a source waveform are correlated with a reference waveform, with both waveforms custom designed to minimize both correlation side lobes and interference from linear electroseismic effects. A waveform element is selected which may be sequenced by a binary or similar digital code embodying the desired custom design to generate an input sweep with the needed depth penetration and noise suppression. Correlation of the seismic response with the reference waveform in a data processing step mathematically aggregates the seismic response from the input sweep into a single wavelet. Preferred binary digital codes include prescribed variations of maximal length shift-register sequences. Also, an apparatus for generating the desired waveforms.