Abstract: An embodiment in accordance with the present invention includes an EGS configured to allow the commercial production of electrical energy. One criteria of an EGS according to the present invention is that the temperature and volume of the fluids extracted are sufficiently high and large enough as to allow the commercial production of electrical energy. The system is able to operate for at least N years before the extracted fluid falls below the minimum temperature needed for energy production. Additionally, fractures are separated from each other by a sufficiently large volume of rock (Vcrit) relative to the fractures surface area such that the ratio of the rate of heat extraction to the rate of heat supply controlled by the thermal conductivity of the rock is such that the intervening rock is cooled at a rate that is sufficiently slow to be economic.

Abstract: An embodiment in accordance with the present invention includes an EGS configured to allow the commercial production of electrical energy. One criteria of an EGS according to the present invention is that the temperature and volume of the fluids extracted are sufficiently high and large enough as to allow the commercial production of electrical energy. The system is able to operate for at least N years before the extracted fluid falls below the minimum temperature needed for energy production. Additionally, fractures are separated from each other by a sufficiently large volume of rock (Vcrit) relative to the fractures surface area such that the ratio of the rate of heat extraction to the rate of heat supply controlled by the thermal conductivity of the rock is such that the intervening rock is cooled at a rate that is sufficiently slow to be economic.

Abstract: An embodiment in accordance with the present invention includes a method for estimating the permeability of fractured rock formations from the analysis of a slow fluid pressure wave, which is generated by pressurization of a borehole. Wave propagation in the rock is recorded with TFI™. Poroelastic theory is used to estimate the permeability from the measured wave speed. The present invention offers the opportunity of measuring the reservoir-scale permeability of fractured rock, because the method relies on imaging a wave, which propagates through a large rock volume, on the order of kilometers in size. Traditional methods yield permeability for much smaller rock volumes: well logging tools only measure permeability in the vicinity of a borehole. Pressure transient testing accesses larger rock volumes; however, these volumes are much smaller than for the proposed method, particularly in low-permeability rock formations.

Abstract: A radiator (RAD) enhanced geothermal system (EGS) may comprise a radiator vane heat exchanger (RVHE). The RVHE may be configured to be located in a plane defined by an injector well and a production well that is defined by a principal stress direction (S1) of a plurality of principal stress directions and a maximum horizontal stress component (SHmax). The RVHE may include one or more stacked laterals oriented along SHmax. Each stacked lateral, of the one or more stacked laterals, may include one or more vertical branches oriented along Si. The RVHE may be configured to extract energy from a non-hydrothermal source of energy.

Abstract: An embodiment in accordance with the present invention includes a method for estimating the permeability of fractured rock formations from the analysis of a slow fluid pressure wave, which is generated by pressurization of a borehole. Wave propagation in the rock is recorded with TFI™. Poroelastic theory is used to estimate the permeability from the measured wave speed. The present invention offers the opportunity of measuring the reservoir-scale permeability of fractured rock, because the method relies on imaging a wave, which propagates through a large rock volume, on the order of kilometers in size. Traditional methods yield permeability for much smaller rock volumes: well logging tools only measure permeability in the vicinity of a borehole. Pressure transient testing accesses larger rock volumes; however, these volumes are much smaller than for the proposed method, particularly in low-permeability rock formations.

Abstract: An embodiment in accordance with the present invention includes a method for estimating the permeability of fractured rock formations from the analysis of a slow fluid pressure wave, which is generated by pressurization of a borehole. Wave propagation in the rock is recorded with TFI™. Poroelastic theory is used to estimate the permeability from the measured wave speed. The present invention offers the opportunity of measuring the reservoir-scale permeability of fractured rock, because the method relies on imaging a wave, which propagates through a large rock volume, on the order of kilometers in size. Traditional methods yield permeability for much smaller rock volumes: well logging tools only measure permeability in the vicinity of a borehole. Pressure transient testing accesses larger rock volumes; however, these volumes are much smaller than for the proposed method, particularly in low-permeability rock formations.

Abstract: The invention comprises a method for mapping a volume of the Earth's subsurface encompassing a selected path within said volume, comprising dividing the volume of the Earth's subsurface into a three-dimensional grid of voxels and transforming detected seismic signals representing seismic energy originating from said volume of the Earth's subsurface when no induced fracturing activity is occurring along said selected path and conducted to a recording unit for recording into signals representing energy originating from the voxels included in said grid of voxels, and utilizing said transformed seismic signals to estimate spatially continuous flow paths for reservoir fluids through said volume of the Earth's subsurface to said selected path.

Abstract: An embodiment in accordance with the present invention includes a method for estimating the permeability of fractured rock formations from the analysis of a slow fluid pressure wave, which is generated by pressurization of a borehole. Wave propagation in the rock is recorded with TFI™. Poroelastic theory is used to estimate the permeability from the measured wave speed. The present invention offers the opportunity of measuring the reservoir-scale permeability of fractured rock, because the method relies on imaging a wave, which propagates through a large rock volume, on the order of kilometers in size. Traditional methods yield permeability for much smaller rock volumes: well logging tools only measure permeability in the vicinity of a borehole. Pressure transient testing accesses larger rock volumes; however, these volumes are much smaller than for the proposed method, particularly in low-permeability rock formations.

Abstract: Disclosed herein are various embodiments of methods and systems for providing a graphical skeletonization representation of fractures and faults in a subsurface of the earth. According to some embodiments, as fracturing fluid is pumped into a target geologic formation through a well bore, and as the formation fractures or faults in response to the fracturing fluid being pumped under high pressure therein, seismic wavefronts are generated at points of fracture related to movement of a fluid pressure wave induced by fracturing or other fluids moving through the formation, or the extraction of fluids such as gas and/or oil from the formation, which are detected by surface and/or downhole sensors. Data corresponding to signals generated by the surface and/or downhole sensors are recorded and subsequently analyzed to determine in near real-time the locations of the fractures or faults using skeletonization data processing techniques and methods.

Abstract: Described herein are various embodiments of methods and corresponding hardware and software that are configured to illuminate or image the permeability field around or near a well that is to be fracked, both prior to fracking and after various fracking stages. The methods and corresponding hardware and software disclosed herein permit the progress of the fracking operation to be monitored at different stages.

Abstract: Disclosed are various embodiments of methods for identifying faults and fractures, and other permeable features, within geologic layers during a drilling operation comprising; recording microseismic data during a drilling operation; recording times and positions of a drill bit in a well bore during the drilling operation; processing microseismic data at a plurality of selected times and locations to image microseismic events and identifying faults and fractures, and other permeable features, from corresponding images of microseismic events.

Abstract: Described herein are various embodiments of methods and corresponding hardware and software configured to permit the vicinity around and/or near a well to be imaged, where the well is being subjected to, or has been subjected to, fracking operations. The methods and corresponding hardware and software permit the generation of images of near-well fractures or faults resulting from the fracking.

Abstract: An embodiment in accordance with the present invention includes an EGS configured to allow the commercial production of electrical energy. One criteria of an EGS according to the present invention is that the temperature and volume of the fluids extracted are sufficiently high and large enough as to allow the commercial production of electrical energy. The system is able to operate for at least N years before the extracted fluid falls below the minimum temperature needed for energy production. Additionally, fractures are separated from each other by a sufficiently large volume of rock (Vcrit) relative to the fractures surface area such that the ratio of the rate of heat extraction to the rate of heat supply controlled by the thermal conductivity of the rock is such that the intervening rock is cooled at a rate that is sufficiently slow to be economic.

Abstract: Disclosed are various embodiments of methods for identifying faults and fractures, and other permeable features, within geologic layers during a drilling operation comprising; recording microseismic data during a drilling operation; recording times and positions of a drill bit in a well bore during the drilling operation; processing microseismic data at a plurality of selected times and locations to image microseismic events and identifying faults and fractures, and other permeable features, from corresponding images of microseismic events.

Abstract: Disclosed are various embodiments of methods for determining the velocity of seismic energy in geologic layers using Seismic Emission Tomography (SET) imaging of drill bit noise, by recording microseismic data during a drilling operation, recording the time and the position of a drill bit in a well bore during the drilling operation, processing the microseismic data using SET software to image microseismic events proximate a known time and position of the drill bit using an estimated velocity model, computing the difference between the known time and position of the drill bit and the time and position of the microseismic event determined from the SET data, varying the estimated velocity model to minimize the difference between the known time and position of the drill bit and the time and time and position of the microseismic event determined from the SET data.

Abstract: The invention comprises a method for mapping a volume of the Earth's subsurface encompassing a selected path within said volume, comprising dividing the volume of the Earth's subsurface into a three-dimensional grid of voxels and transforming detected seismic signals representing seismic energy originating from said volume of the Earth's subsurface when no induced fracturing activity is occurring along said selected path and conducted to a recording unit for recording into signals representing energy originating from the voxels included in said grid of voxels, and utilizing said transformed seismic signals to estimate spatially continuous flow paths for reservoir fluids through said volume of the Earth's subsurface to said selected path.

Abstract: Disclosed are various embodiments of methods for determining the velocity of seismic energy in geologic layers using Seismic Emission Tomography (SET) imaging of drill bit noise, by recording microseismic data during a drilling operation, recording the time and the position of a drill bit in a well bore during the drilling operation, processing the microseismic data using SET software to image microseismic events proximate a known time and position of the drill bit using an estimated velocity model, computing the difference between the known time and position of the drill bit and the time and position of the microseismic event determined from the SET data, varying the estimated velocity model to minimize the difference between the known time and position of the drill bit and the time and time and position of the microseismic event determined from the SET data.

Abstract: Disclosed are various embodiments of methods for identifying faults and fractures, and other permeable features, within geologic layers during a drilling operation comprising; recording microseismic data during a drilling operation; recording times and positions of a drill bit in a well bore during the drilling operation; processing microseismic data at a plurality of selected times and locations to image microseismic events and identifying faults and fractures, and other permeable features, from corresponding images of microseismic events.

Abstract: Disclosed herein are various embodiments of methods and systems for providing a graphical skeletonization representation of fractures and faults in a subsurface of the earth. According to some embodiments, as fracturing fluid is pumped into a target geologic formation through a well bore, and as the formation fractures or faults in response to the fracturing fluid being pumped under high pressure therein, seismic wavefronts are generated at points of fracture related to movement of a fluid pressure wave induced by fracturing or other fluids moving through the formation, or the extraction of fluids such as gas and/or oil from the formation, which are detected by surface and/or downhole sensors. Data corresponding to signals generated by the surface and/or downhole sensors are recorded and subsequently analyzed to determine in near real-time the locations of the fractures or faults using skeletonization data processing techniques and methods.

Abstract: The application of SET for the imaging and analysis of seismic energy emission induced during production of fluid resources from their reservoirs allows 4 dimensional measurements of the components of the permeability field of the reservoir. The seismic energy emission associated with the permeability field is identified by its spatial and temporal location with respect to a well or plurality of wells in which fluid pressure is being changed. Changing fluid pressure causes seismicity to rapidly migrate outward from the points of fluid pressure change and will alter the characteristics of the seismic energy emission. Monitoring the changes in seismic energy emission in response to pressure changes in the active well and altering the values of the processing parameters permits measurement of components of the permeability tensor. The placement of subsequent infill, development and injection wells may be selected based on the analysis.