Systems and methods of placing wells in a hydrocarbon field based on seismic attributes and quality indicators associated with a subterranean formation of the hydrocarbon field can include receiving seismic attributes representing the subterranean formation and seismic data quality indicators. A cutoff is generated for each seismic attribute and seismic data quality indicator. A weight is assigned to each seismic attribute and seismic data quality indicator. The weighted seismic attributes and data quality indicators are aggregated for each location in the hydrocarbon field. A risk ranking is assigned based on the weighted seismic attributes and data quality indicators associated with each location in the hydrocarbon field based on the cutoffs. A map is generated with each location on the surface of the subterranean formation color-coded based on its assigned risk ranking.

According to an example aspect of the present invention, there is provided an apparatus comprising a memory configured to store seismic data, at least one processing core configured to perform a geographic determination, based on the seismic data and reference data, the geographic determination relating to a geographical location of a device that produced the seismic data. In some embodiments, the device that produced the seismic data is comprised in a cloud computing server. In other embodiments, the device that produced the seismic data is integrated in a secure computing element on a motherboard of a computer. In further embodiments, the reference data originates in a trusted seismographic source.

According to an example aspect of the present invention, there is provided an apparatus comprising a memory configured to store seismic data, at least one processing core configured to perform a geographic determination, based on the seismic data and reference data, the geographic determination relating to a geographical location of a device that produced the seismic data. In some embodiments, the device that produced the seismic data is comprised in a cloud computing server. In other embodiments, the device that produced the seismic data is integrated in a secure computing element on a motherboard of a computer. In further embodiments, the reference data originates in a trusted seismographic source.

A method which includes obtaining an initial velocity model and perturbing the initial velocity model to form a first plurality of velocity models. The method includes using a forward model to simulate seismic data sets from the first plurality of velocity models and transforming the seismic data sets to the wavenumber-time domain. The method includes training a machine-learned model using the first plurality of velocity models and the transformed seismic data sets, wherein the machine-learned model is configured to accept transformed seismic data. The method includes obtaining a second seismic data set for a subsurface region of interest, wherein the second seismic data set is acquired according to a second survey configuration and transforming the second seismic data set to the wavenumber-time domain. The method further includes processing the second transformed data set with the trained machine-learned model to predict a second velocity model for the subsurface region of interest.

A method which includes obtaining an initial velocity model and perturbing the initial velocity model to form a first plurality of velocity models. The method includes using a forward model to simulate seismic data sets from the first plurality of velocity models and transforming the seismic data sets to the wavenumber-time domain. The method includes training a machine-learned model using the first plurality of velocity models and the transformed seismic data sets, wherein the machine-learned model is configured to accept transformed seismic data. The method includes obtaining a second seismic data set for a subsurface region of interest, wherein the second seismic data set is acquired according to a second survey configuration and transforming the second seismic data set to the wavenumber-time domain. The method further includes processing the second transformed data set with the trained machine-learned model to predict a second velocity model for the subsurface region of interest.

Methods for generating boreholes used for generating geothermal energy or other purposes include forming the borehole by accelerating a projectile into contact with geologic material. Interaction between the projectile and the geologic material generates an acoustic signal, such as vibrations within the formation, that is detected using acoustic sensors along a drilling conduit, at the surface, or within a separate borehole. Characteristics of the geologic material, such as hardness, porosity, or the presence of fractures, may be determined based on characteristics of the acoustic signal. The direction in which the borehole is extended may be modified based on the characteristics of the geologic material, such as to create a borehole that intersects one or more fractures for generation of geothermal energy.

Methods for generating boreholes used for generating geothermal energy or other purposes include forming the borehole by accelerating a projectile into contact with geologic material. Interaction between the projectile and the geologic material generates an acoustic signal, such as vibrations within the formation, that is detected using acoustic sensors along a drilling conduit, at the surface, or within a separate borehole. Characteristics of the geologic material, such as hardness, porosity, or the presence of fractures, may be determined based on characteristics of the acoustic signal. The direction in which the borehole is extended may be modified based on the characteristics of the geologic material, such as to create a borehole that intersects one or more fractures for generation of geothermal energy.

A pneumatic actuator (4b), in particular for use in a pressure wave generator (1) comprises: a first piston surface (91) which acts counter to a gaseous working medium in a first volume (41), wherein a pressure in the first volume (41) effects an actuator force in a first direction upon the first piston surface (91); a second piston surface (92) which acts counter to the working medium in a second volume (42), wherein a pressure in the second volume (42) effects an actuator force in a second direction opposite to the first direction, upon the second piston surface (92); a throttle between the first volume (41) and the second volume (42); an inlet/outlet opening (45) of the first volume (41) for bringing the working medium into and discharging it out of, the first volume; wherein the first piston surface (91) is larger than the second piston surface (92).

A method, system and apparatus for plasma blasting comprises a solid object having a borehole, a blast probe comprising a high voltage electrode and a ground electrode separated by a dielectric separator, wherein the high voltage electrode and the dielectric separator constitute an adjustable probe tip, and an adjustment unit coupled to the adjustable probe tip, wherein the adjustment unit is configured to selectively extend or retract the adjustable probe tip relative to the ground electrode and a blasting media, wherein at least a portion of the high voltage electrode and the ground electrode are submerged in the blast media. The blasting media comprises water. The adjustable tip permits fine-tuning of the blast. The blast can be used to fracture solids and/or to create a shockwave to mapping underground structures.

Methods and systems for characterizing fractures in a subterranean formation are provided. The method includes introducing an encapsulated explosive unit into a casing located in a wellbore within the subterranean formation and maintaining the encapsulated explosive unit in a stage of the casing. The method also includes detonating the encapsulated explosive unit within the stage to generate a pressure wave that passes through a group of perforations and into the fractures and measuring a reflected pressure wave using a pressure sensor coupled to the bridge plug to produce a pressure measurement. The method further includes converting the pressure measurement into an acoustic signal correlated with the pressure measurement by an acoustic signal generator contained in the bridge plug and transmitting the acoustic signal to apply acoustic pressure on a fiber optic cable coupled to an exterior surface of the casing.