Methods of and systems for forming an image of a subterranean region of interest are disclosed. The method includes obtaining an observed seismic dataset and a seismic velocity model for the subterranean region of interest and generating a simulated seismic dataset based on the seismic velocity model and the source and receiver geometry of the observed seismic dataset. The method also includes forming a plurality of time-windowed trace pairs from the simulated and the observed seismic datasets, and forming an objective function based on a penalty function and a cross-correlation between the members of each pair. The method further includes determining a seismic velocity increment based on the extremum of the objective function and forming an updated seismic velocity model by combining the seismic velocity increment and the seismic velocity model, and forming the image of the subterranean region of interest based on the updated seismic velocity model.

A process for drilling a well into a subsurface formation includes receiving data representing depth maps for a given subsurface region, each depth map being generated from seismic data acquired in a seismic survey at a subsurface region. The process includes determining, for depth maps of the plurality, respective weight values; generating data representing a combination of the depth maps based on the respective weight values; generating a cumulative distribution function (CDF) for a particular location in the subsurface region based on the data representing a combination of the depth maps; determining, based on the CDF for that particular location, a probability value representing a depth at which a geological layer occurs in the subsurface region at the particular location; and drilling the well into the subsurface formation at the particular location to a target depth based on the probability value.

This disclosure presents processes and systems for generating an image of a subterranean formation from seismic data recorded in a seismic survey of the subterranean formation. The seismic data is contaminated with low frequency noise in a low frequency band. Processes and systems reconstruct seismic data in the low frequency band of the seismic data to obtain low frequency reconstructed seismic data that is free of the low frequency noise. The low frequency reconstructed seismic data is used to construct a velocity model of the subterranean formation. The velocity model and the low frequency reconstructed seismic data are used to generate an image of the subterranean formation that reveals structures of the subterranean formation without contamination from the low frequency noise.

In a first step, a defined scope value is selected for each of a plurality of hydrodynamic input parameters. A simulated topographical result is generated using the selected scope values and a forward model. A detailed seismic interpretation is generated to represent specific seismic features or observed topography. A calculated a misfit value representing a distance between the simulated topographical result and a detailed seismic interpretation is minimized. An estimated optimized sand ratio and optimized hydrodynamic input parameters are generated. In a second step, a genetic algorithm is used to determine a proportion of each grain size in the estimated optimized sand ratio. A misfit value is used that is calculated from thickness and porosity data extracted from well data and a simulation result generated by the forward model to generate optimized components of different grain sizes. Optimized hydrodynamic input parameters and optimized components of different grain sizes are generated.

Systems and methods are discussed to image lithological data within the strata beneath the earth surface, including a subterranean object detection system. The system may further comprise a pipeline operable to conduct a working fluid and an instrumented pig operable to travel within the pipeline and operable to image lithological strata and voids within the strata beneath and around the pipeline. The instrumented pig may comprise an outer case, a battery coupled to the outer case, a ground imaging unit operable to send a signal to image the lithological strata and voids within the strata beneath and around the pipeline and may be operable to receive a reflected signal indicating lithology data, wherein the ground imaging unit may be operably coupled to the battery.

This disclosure presents a system, method, and apparatus for preventing fracture communication between wells, the system comprising: a sensor coupled to a fracking wellhead, circulating fluid line, or standpipe of a well and configured to convert acoustic vibrations in fracking fluid in the well into an electrical signal; a memory configured to store the electrical signal; a machine-learning system configured to analyze current frequency components of the electrical signal in a window of time and to identify impending fracture communication between the well and an offset well, the machine-learning system having been trained on previous frequency components of electrical signals measured during previous instances of fracture communication between wells; and a user interface configured to return a notification of the impending fracture communication to an operator of the well.

Disclosed herein are system, apparatus, article of manufacture, method and/or computer program product embodiments, and/or combinations and sub-combinations thereof, for using direction-angles to identify geologic features and geologic attributes for use in geothermal, oil and gas, mining, and other applications. An example embodiment operates by receiving a discrete three-dimensional (3D) representation of a geologic volume comprising a set of 3D orientations, where each 3D orientation is represented as a set of direction-angles measured relative to a set of coordinate axes. The example embodiment further operates by receiving a set of other measurements of properties of the geologic volume, In response, the example embodiment operates by correlating the set of 3D orientations with the set of other measurements to generate a geologic correlation data structure. Subsequently, the example embodiment operates by identifying a geologic attribute or a geologic feature associated with the geologic volume based on the geologic correlation data structure.

A DAS VSP technique is used to determine the induced fracture height and fracture density of an induced fracture region. The DAS VSP technique obtains pre-hydraulic fracturing DAS VSP survey time-lapse data to establish a baseline reference for the direct acoustic wave travel time. The DAS VSP technique obtains one or more time-lapse data corresponding to the subsequent monitor surveys conducted after each hydraulic fracturing stage along the well. Forward modeling is used to determine a theoretical acoustic wave travel time difference. The forward modeling uses seismic anisotropy to describe the behavior of seismic waves traveling through the induced fracture regions. An inversion scheme is then used to invert for the induced fracture height and the fracture density using the forward modeling. The two extracted induced fracture characteristics may then be used to determine optimal hydraulic fracturing parameters.

A process for drilling a well into a subsurface formation includes receiving data representing depth maps for a given subsurface region, each depth map being generated from seismic data acquired in a seismic survey at a subsurface region. The process includes determining, for depth maps of the plurality, respective weight values; generating data representing a combination of the depth maps based on the respective weight values; generating a cumulative distribution function (CDF) for a particular location in the subsurface region based on the data representing a combination of the depth maps; determining, based on the CDF for that particular location, a probability value representing a depth at which a geological layer occurs in the subsurface region at the particular location; and drilling the well into the subsurface formation at the particular location to a target depth based on the probability value.

The present disclosure belongs to the technical field of seismic exploration imaging, and relates to an interpretive-guided velocity modeling seismic imaging method and system, a medium and a device. The method comprises the following steps: S1. performing first imaging on a given initial velocity model to obtain a first imaging result; S2. performing relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile; S3. performing Curvelet filtering on the relative wave impedance profile to obtain a first interpretation scheme; S4. superposing the first interpretation scheme and the initial velocity model to obtain a new migration velocity field; S5. performing second imaging on a new migration velocity field to obtain a second imaging result; and S6. repeating steps S2-S4 for the obtained second imaging result until a final seismic imaging result is obtained.