A mechanical-model based earthquake-induced landslide hazard assessment method in earthquake-prone mountainous area includes: obtaining the cohesion and internal friction angle through a geological map of the study area and a geotechnical physical parameter; obtaining simulated ground motions by combining a pulse-like ground motion effect model and a pulse-like ground motion response model; calculating slope permanent displacement according to the simulated ground motions, the cohesion, the internal friction angle and other parameters; obtaining a statistical relationship between the permanent displacement and a landslide probability according to permanent displacement data derived from historical earthquake-induced landslides and historical strong earthquake records; and predicting earthquake-induced landslide probability according to the slope permanent displacement and the statistical relationship between the permanent displacement and the landslide probability, and quantitatively evaluating earthquake-induced landslide hazard through the earthquake-induced landslide probability.

Provided is a method of first arrival picking of multi-channel seismic survey data considering sound source-receiver array that can increase the reliability of a first arrival selected from land seismic survey data or marine seismic survey data that includes background noise. Further, provided is a method of first arrival picking of multi-channel seismic survey data considering source-receiver array, which can improve the reliability of a first arrival or a micro earthquake occurrence location selected from measurement data of a micro earthquake seismic survey.

A method for determining a favorable time window of an infill well of an unconventional oil and gas reservoir, which comprises the following steps: S1, establishing a three-dimensional geological model with physical properties and geomechanical parameters; S2, establishing a natural fracture network model in combination with indoor core-logging-seismic monitoring; S3, calculating complex fractures in hydraulic fracturing of parent wells; S4, establishing an unconventional oil and gas reservoir model and calculating a current pore pressure field; S5, establishing a dynamic geomechanical model and calculating a dynamic geostress field; S6, calculating complex fractures in horizontal fractures of the infill well in different production times of the parent wells based on pre-stage complex fractures and the current geostress field; S7, analyzing a microseismic event barrier region and its dynamic changes in infill well fracturing; and S8, analyzing the productivity in different infill times, and determining an infill time window.

Seismic based fracking fluid disposal can in an example embodiment include selecting a first disposal site of a plurality of disposal sites to receive fracking fluid from a fracking site; measuring, via a seismic sensor, seismic waves associated with the first disposal site; and assigning at least some of the fracking fluid from the first disposal site to a second disposal site of the plurality of disposal sites based on the measured seismic waves.

A distributed seismic system, MyShake, which collectively harnesses sensor data from smartphones to determine earthquake onset, and generate warnings through the self-same phone network. The system can record magnitude 2.5 or larger earthquakes, and provides on-phone detection capability to separate earthquake shake data from other every-day shakes of the phone. The earthquake data is collected at a central site where a network detection algorithm confirms that an earthquake is underway and estimates the location and magnitude in real-time. This information is used to issue an alert of forthcoming ground shaking, such as through the network of phones for an early earthquake warning system.

A valve controller device for controlling a set of one or more solenoid valves is provided. The valve controller comprises an accelerometer for making acceleration measurements in three directions comprising acceleration measurements in a vertical direction. The valve controller comprises a processing unit that determines the arrival of seismic P-waves when the ratio of vibrations' power in the vertical direction with respect to a sum of the vibrations' power in the three directions exceeds a first threshold. The processing unit then determines the arrival of seismic S-waves when the vector sum of the vibrations' power in the three directions exceeds a second threshold. The processing unit then determines the arrival of seismic surface waves when the vector sum of the vibrations' power in the three directions exceeds a third threshold. The processing unit then sends one or more signals to close the set of solenoid valves.

A seismic warning system comprises: a plurality of sensors, each sensor sensitive to a physical phenomenon associated with seismic events and operative to output an electronic signal representative of the sensed physical phenomenon; a data acquisition unit communicatively coupled to receive the electronic signal from each of the plurality of sensors, the data acquisition unit comprising a processor configured to estimate characteristics of a seismic event based on the electronic signal associated with a P-wave from each of the plurality of sensors; and a local device communicatively coupled to the data acquisition unit. The plurality of sensors, the data acquisition unit and the local device are local to one another.

A fracture network mapping system can include a sensor, a repeater, an acoustic signal generator, and a distributed acoustic sensing system. The sensor and the repeater can be positioned in a fracture of a well. The acoustic signal generator can be positioned in a wellbore of the well. The distributed acoustic sensing system can communicate location data of the sensor from the repeater and the acoustic signal generator to a processing device for mapping the fracture.

Systems and methods of performing a seismic survey are described. The system can receive seismic data in a first domain, and transform the seismic data into a tau-p domain. The system can identify a value on an envelope in the tau-p domain, select several values on the tau-p envelope using a threshold, and then generate a masking function. The system can combine the masking function with the tau-p transformed seismic data, and then perform an inverse tau-p transform on the combined seismic data. The system can adjust amplitudes in the inverse tau-p transformed combined seismic data, and identify one or more coherent events corresponding to subsea lithologic formations or hydrocarbon deposits.

A method of identifying hydrocarbon production information is disclosed. In in a first hydrocarbon management environment, a first audio signal is detected and a characteristic acoustic fingerprint is identified therefrom. The fingerprint is stored in a memory, along with identifying information associated with the first signal. A second audio signal is detected and a characteristic acoustic fingerprint is identified therefrom. The fingerprints are compared, and if the fingerprints match the identifying information of the first audio signal is assigned to the second audio signal. A notification regarding the matching of the characteristic acoustic fingerprints of the first and second audio signals is issued.