Systems and methods for harvesting geothermal energy use temperature-based flow control to optimize the extraction of thermal energy from a geothermal reservoir. In one example, a thermal transport fluid is flowed into a wellbore traversing a thermal reservoir of a formation. Flow of the thermal transport fluid into and out of the thermal reservoir is dynamically controlled at each of a plurality of injection and/or return locations in response to a downhole parameter such as temperature. For example, flow may be controlled so that the flow into the thermal reservoir is greater at the injection locations where the temperature is hotter and that the flow out of the thermal reservoir is greater at the return locations where the temperature is hotter. The thermal transport fluid produced from the return locations is then conveyed to surface to extra the thermal energy.

A completion section includes a base pipe defining a central flow passage, an injection port, and a production port. A fracturing assembly includes a frac sleeve positioned within the central flow passage adjacent the injection port, a sensor that detects a wireless signal, a first frac actuator actuatable in response to the wireless signal to move the frac sleeve and expose the injection port, and a second frac actuator actuatable based on the wireless signal to move the frac sleeve to occlude the injection port. A production assembly is axially offset from the fracturing assembly and includes a production sleeve positioned within the central flow passage adjacent the production port, a filtration device arranged about the base pipe, and a production actuator actuatable based on the wireless signal or an additional wireless signal to move the production sleeve to an open position where the production ports are exposed.

A completion section includes a base pipe defining a central flow passage, an injection port, and a production port. A fracturing assembly includes a frac sleeve positioned within the central flow passage adjacent the injection port, a sensor that detects a wireless signal, a first frac actuator actuatable in response to the wireless signal to move the frac sleeve and expose the injection port, and a second frac actuator actuatable based on the wireless signal to move the frac sleeve to occlude the injection port. A production assembly is axially offset from the fracturing assembly and includes a production sleeve positioned within the central flow passage adjacent the production port, a filtration device arranged about the base pipe, and a production actuator actuatable based on the wireless signal or an additional wireless signal to move the production sleeve to an open position where the production ports are exposed.

A technique facilitates hydrocarbon fluid production. A well is formed in a subterranean region by drilling a borehole, e.g. a generally vertical wellbore. At least one tunnel is formed and oriented to extend outwardly from the borehole at least 10 feet into a formation surrounding the borehole. The orientation of the at least one tunnel is selected such that it extends at a desired angle with respect to a direction of horizontal stress in the formation. A fracture stimulation of the at least one tunnel is performed to create a network of fractures. The orientation of the at least one tunnel ensures that the network of fractures extends through a target zone in a hydrocarbon bearing region of the formation.

A technique facilitates hydrocarbon fluid production. A well is formed in a subterranean region by drilling a borehole, e.g. a generally vertical wellbore. At least one tunnel is formed and oriented to extend outwardly from the borehole at least 10 feet into a formation surrounding the borehole. The orientation of the at least one tunnel is selected such that it extends at a desired angle with respect to a direction of horizontal stress in the formation. A fracture stimulation of the at least one tunnel is performed to create a network of fractures. The orientation of the at least one tunnel ensures that the network of fractures extends through a target zone in a hydrocarbon bearing region of the formation.

Techniques for determining a fracture driven interaction include identifying pressure response data from one or more pressure sensors that are in direct fluid communication with a fluid at least partially enclosed within one or more monitor wellbores formed from a terranean surface to one or more subterranean formations; calculating at least one pressure response value from the pressure response data; determining the fracture driven interaction between the treatment wellbore and at least one of the one or more monitor wellbores based at least in part on the calculated at least one pressure response value; and preparing a graphic representation of the determined FDI for display on a graphical user interface.

A hydraulic fracturing system includes a support structure having a first area at a first height and a second area at a second height, the first and second areas adjacent one another. The system also includes an electric powered, multi-plunger pump with an odd number of plungers, arranged in the first area, the electric powered pump coupled to a well, via outlet piping, and powered by at least one electric motor, also arranged in the first area. The system further includes a variable frequency drive (VFD), arranged in the second area, connected to the at least one electric motor, the VFD configured to control at least a speed of the at least one electric motor. The system also includes a transformer, arranged in the second area, the transformer positioned within an enclosure with the VFD, the transformer distributing power to the electric pump.

A hydraulic fracturing system includes a support structure having a first area at a first height and a second area at a second height, the first and second areas adjacent one another. The system also includes an electric powered, multi-plunger pump with an odd number of plungers, arranged in the first area, the electric powered pump coupled to a well, via outlet piping, and powered by at least one electric motor, also arranged in the first area. The system further includes a variable frequency drive (VFD), arranged in the second area, connected to the at least one electric motor, the VFD configured to control at least a speed of the at least one electric motor. The system also includes a transformer, arranged in the second area, the transformer positioned within an enclosure with the VFD, the transformer distributing power to the electric pump.

The invention provides a carbon dioxide-resistant hydraulic cement composition. The inventive composition comprises a Portland cement, Class C fly ash and water. The Class C fly ash is present in the composition in an amount in the range of from about 5% to less than about 30% by weight based on the total weight of the cementitious components in the composition. In another aspect, the invention provides a method of cementing in a carbon dioxide environment. In yet another aspect, the invention provides a method of enhancing the recovery of a hydrocarbon fluid from a subterranean formation.

Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations.