Abstract: A system and a method for determining hydrocarbon production from multiple subterranean formations. Different nanotag tracers are sequentially injected into subterranean production zones fluidly coupled to a wellbore extending from a surface of the Earth through the subterranean production zones. The respective nanotag tracers are injected into a respective subterranean production zone. The different nanotag tracers and production fluids contained within the subterranean production zones are produced through the wellbore to the surface. A turbidity of the production fluids containing the different nanotag tracers is determined at the surface. A quantity of each of the one or more different nanotag tracers from each of the subterranean production zones in the production fluids is determined. Based on the turbidity of the production fluids and the quantity of the different nanotag tracers, a total oil production rate from the subterranean production zones is determined.

Abstract: A system and a method for determining hydrocarbon production from multiple subterranean formations. Different nanotag tracers are sequentially injected into subterranean production zones fluidly coupled to a wellbore extending from a surface of the Earth through the subterranean production zones. The respective nanotag tracers are injected into a respective subterranean production zone. The different nanotag tracers and production fluids contained within the subterranean production zones are produced through the wellbore to the surface. A turbidity of the production fluids containing the different nanotag tracers is determined at the surface. A quantity of each of the one or more different nanotag tracers from each of the subterranean production zones in the production fluids is determined. Based on the turbidity of the production fluids and the quantity of the different nanotag tracers, a total oil production rate from the subterranean production zones is determined.

Abstract: A method and system for controlling unwanted water production from a water-producing zone in a subterranean formation are provided. An exemplary method includes flowing an alkaline suspension of nanosilica particles into a wellbore such that it contacts the water-producing zone, and flowing a formate salt solution into the wellbore such that it contacts the alkaline suspension in the water-producing zone producing a composition. The wellbore is shut in a duration of time sufficient for the composition to form a gel that is impermeable to fluid flow.

Abstract: In a method for diverter fracturing, a water-based fracturing fluid including non-convex particles is introduced into a hydraulic fracture of a wellbore at a first location. Each non-convex particle is formed to interlock with another non-convex particle. A diverter plug is formed in the hydraulic fracture when multiple non-convex particles interlock. Flow of another water-based fracturing fluid is diverted to a second location due to the diverter plug, forming another hydraulic fracture at the second location.

Abstract: In a method for diverter fracturing, a water-based fracturing fluid including non-convex particles is introduced into a hydraulic fracture of a wellbore at a first location. Each non-convex particle is formed to interlock with another non-convex particle. A diverter plug is formed in the hydraulic fracture when multiple non-convex particles interlock. Flow of another water-based fracturing fluid is diverted to a second location due to the diverter plug, forming another hydraulic fracture at the second location.

Abstract: A monitoring system includes a spectroscopic probe in fluid connection with a fracturing fluid, reference spectra obtained from one or more fracturing fluid components, and a computer in communication with the spectroscopic probe. The computer includes a predictive model generated from the reference spectra. The computer also includes instructions to compare spectroscopic data obtained from the spectroscopic probe with the predictive model. A modified well fracturing system includes a monitoring system located at a surface location of a hydrocarbon-bearing reservoir and a surface pump in fluid connection with the fracturing fluid source and a wellbore of the hydrocarbon-bearing reservoir. A method for monitoring a fracturing fluid is also described.

Abstract: Treatment fluids for acid diversion during acid stimulation of a subterranean formation may include at least an acidizing fluid, a nanoparticle dispersion, and an activator. The treatment fluid may include from 40 weight percent to 70 weight percent acidizing fluid based on the total weight of the treatment fluid. The treatment fluid may include from 20 weight percent to 40 weight percent nanoparticle dispersion based on the total weight of the treatment fluid. The treatment fluid may include from 5 weight percent to 15 percent activator based on the total weight of the treatment fluid. Methods of treating a subterranean formation with the treatment fluids are also disclosed.

Abstract: A matrix stimulation tool includes a cylindrical tube; at least one piston disposed within the cylindrical tube and longitudinally moveable within the cylindrical tube; and at least one hollow tube coupled to the piston, the hollow tube including a distal end disposed within a hole disposed within a wall of the cylindrical tube. Movement of the piston within the cylindrical tube causes movement of the distal end of the at least one hollow tube through the hole.

Abstract: A matrix stimulation tool includes a cylindrical tube; at least one piston disposed within the cylindrical tube and longitudinally moveable within the cylindrical tube; and at least one hollow tube coupled to the piston, the hollow tube including a distal end disposed within a hole disposed within a wall of the cylindrical tube. Movement of the piston within the cylindrical tube causes movement of the distal end of the at least one hollow tube through the hole.

Abstract: Treatment fluids for acid diversion during acid stimulation of a subterranean formation may include at least an acidizing fluid, a nanoparticle dispersion, and an activator. The treatment fluid may include from 40 weight percent to 70 weight percent acidizing fluid based on the total weight of the treatment fluid. The treatment fluid may include from 20 weight percent to 40 weight percent nanoparticle dispersion based on the total weight of the treatment fluid. The treatment fluid may include from 5 weight percent to 15 percent activator based on the total weight of the treatment fluid. Methods of treating a subterranean formation with the treatment fluids are also disclosed.