4433 results about "Fracturing fluid" patented technology

Providing pressurized fracturing fluid with a fracturing pump transport comprising a first fracturing pump and a second fracturing pump that are coupled on opposite sides of a dual shaft electric motor. A first drive line assembly comprising a first engagement coupling that allows for selective engagement and / or disengagement of the first fracturing pump with the dual shaft electric motor. A second drive line assembly comprising a second engagement coupling that allows for selective engagement and / or disengagement of the second fracturing pump with the dual shaft electric motor. The fracturing pump transport also comprising an engagement panel that allows for selective engagement or disengagement at the first engagement coupling based on receiving a remote command.

Surface modified oil and gas well hydraulic fracturing proppants for improving wettability, altering chemical reactivity, altering surface topography, imparting lubricity or controlling relative permeability to flow of fluids of such proppants. The use and preparation of such coated proppants in hydraulic fracturing of subterranean formations is also described.

Method of treating a portion of a subterranean formation comprising: placing a pre-pad fluid into a portion of a subterranean formation wherein the pre-pad fluid comprises a low-viscosity aqueous tackifying composition that comprises an aqueous tackifier compound and an aqueous fluid; placing a fracturing fluid into the portion of the subterranean formation at a pressure sufficient to create or extend at least one fracture therein; and, activating the aqueous tackifier compound with an activator so as to consolidate the unconsolidated particulates. Method of consolidating unconsolidated particulates within a portion of a subterranean formation comprising: placing a foamed low-viscosity aqueous tackifying composition into a portion of a subterranean formation comprising unconsolidated particulates wherein the aqueous tackifying composition comprises an aqueous fluid, a foaming agent, and an aqueous tackifier compound; and, activating the aqueous tackifier compound with an activator so as to consolidate the unconsolidated particulates.

A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular. Alternatively, the tubular can be in open hole and simply have openings for passage of fracture fluid and external isolators to allow fracturing in any desired order.

A hydraulic fracture design model that simulates the complex physical process of fracture propagation in the earth driven by the injected fluid through a wellbore. An objective in the model is to adhere with the laws of physics governing the surface deformation of the created fracture subjected to the fluid pressure, the fluid flow in the gap formed by the opposing fracture surfaces, the propagation of the fracture front, the transport of the proppant in the fracture carried by the fluid, and the leakoff of the fracturing fluid into the permeable rock. The models used in accordance with methods of the invention are typically based on the assumptions and the mathematical equations for the conventional 2D or P3D models, and further take into account the network of jointed fracture segments. For each fracture segment, the mathematical equations governing the fracture deformation and fluid flow apply. For each time step, the model predicts the incremental growth of the branch tips and the pressure and flow rate distribution in the system by solving the governing equations and satisfying the boundary conditions at the fracture tips, wellbore and connected branch joints. An iterative technique is used to obtain the solution of this highly nonlinear and complex problem.

Liquefied natural gas is used as a fracturing fluid to stimulate production of hydrocarbons from and / or injectability of fluids into subterranean formations. Proppants may be blended with the LNG prior to pumping the liquefied natural gas into the well. Optionally, the liquefied natural gas is heated after it is pumped and before it is introduced into the subterranean formation.

A system and a method for producing fracturing fluid, comprising: engaging an engagement coupling attached to one end of a gear box dual shaft to a gear box connector of an external gear box, wherein the external gear box is part of a pump; rotating the gear box dual shaft to drive the pump after engaging the engagement coupling with the gear box connector; disengaging the engagement coupling from the gear box connector; and rotating the gear box dual shaft without driving the pump after disengaging the engagement coupling with the gear box connector.

An electrically powered hydraulic fracturing system includes pumps for pressurizing fracturing fluid, piping for carrying fracturing fluid, and field connections in obliquely oriented segments of the piping. The connections are between lead lines that couple directly to the pumps and lines carrying fluid to and from the pump; and are assembled and disassembled in the field. Operations personnel can more easily manipulate connections that are obliquely oriented than those that are horizontal or vertical.

A system for hydraulically fracturing an underground formation in an oil or gas well to extract oil or gas from the formation, the oil or gas well having a wellbore that permits passage of fluid from the wellbore into the formation. The system includes a plurality of electric pumps fluidly connected to the well, and configured to pump fluid into the wellbore at high pressure so that the fluid passes from the wellbore into the and fractures the formation. The system can also include a plurality of natural gas powered generators electrically connected to the plurality of electric pumps to provide electrical power to the pumps.

A service tool string (34) is releasably attached to a bottom hole assembly (18) and forms a production string as well as a work string. The tool (35) has a mandrel (102) and a slide valve assembly (68) mounted on the mandrel for relative sliding movement. Crossover ports (114, 124) are provided in the mandrel (102) and the slide valve assembly (68). Slide valve assembly (68) moves by gravity and spring action when not contacted by the bottom hole assembly (18) to a position in which ports (114, 124) are blocked as shown in FIG. 7B. Upon contact of slidable valve assembly (68) with the bottom hole assembly (18), slide valve assembly is moved upwardly for alignment of ports (114, 124) as shown in FIGS. 5B and 6B. An equalizing valve (29) as shown in FIGS. 10-12 is effective to equalize the fluid pressure within the bottom hole assembly (18) with the fluid pressure outside the perforated casing section (23) so that in a reverse position as shown in FIG. 7B, the service tool (35) can be lifted to a position above the upper packer assembly (26) and above the bottom hole assembly (18). A diverter ball (132) seated on a ball catcher (134) is effective to divert the fracturing fluid outwardly through crossover ports (114, 124) as shown in FIG. 6B for downward flow through the annulus (27) into the formation adjacent the perforated casing section (23).

Method for producing an hydrophobically associative polymer is provided which is characterized by forming a monomer solution comprising a surfactant, at least one hydrophobic ethylenically unsaturated monomer, at least one hydrophilic monomer selected from nonionic ethylenically monomers, cationic ethylenically unsaturated monomers, anionic ethylenically unsaturated monomers or mixtures thereof, and water; forming a salt solution comprising a multivalent salt and water; mixing the monomer solution and salt solution to form a mixed solution; and charging the mixed solution with an initiator, thereby polymerizing the monomers to form the hydrophobically associative polymer in a dispersion. Aqueous dispersion containing the hydrophobically associative polymer formed by the method. The aqueous dispersion containing the hydrophobically associative polymer may be used in a paint formulation, in a mobility control fluid useful in enhanced oil recovery, in a secondary or tertiary oil recovery system, in an enhanced oil recovery method, in a cementious composition, in an oil well drilling mud formulation, in a fracturing fluid formulation, in a wastewater treatment system, or in a dewatering sludge system.

A fluid can be tracked in a wellbore utilizing at least one WID tag, such as an LW tag or an RFID tag, entrained in the fluid. A WID tag reader can be disposed and / or displaced in the wellbore, for example, on a drill string or a casing string. A reader can be utilized to locate the at least one WID tag in the wellbore. A reader can be housed in a drill string sub. A fluid entrained with at least one WID tag can be utilized as a tracer fluid. A WID tag can be entrained in cement or a drilling or fracture fluid.

Hydraulic fracturing of wells by injecting a degradable polymer phase as a fracturing fluid is provided. Composition and degree of polymerization of the degradable polymer and the selection of additives may be varied to adjust the viscosity, degradation time and other properties of the fracturing fluid. Viscous degradable fluid or pellets of degradable polymer may be placed in a wellbore as an internal phase in a low viscosity carrier fluid. A polymer-continuous liquid phase may be formed at a selected location in the wellbore, usually near perforations, before the polymer phase is pressured into a formation to form a hydraulic fracture.

An apparatus and method according to which a fluid, such as a fracturing fluid, is pressurized. The apparatus includes a motor that produces a first rotational output including a first angular velocity, a pump operably coupled to the motor, the pump comprising a fluid end and a power end operably coupled to the fluid end, and a transmission operably coupled between the motor and the pump. The transmission receives the first rotational output as a first rotational input, the first rotational input including the first angular velocity, and converts the first rotational input into a second rotational output, the second rotational output including a second angular velocity. The power end receives the second rotational output as a second rotational input, the second rotational input including the second angular velocity. In some embodiments, the transmission is directly connected to, or part of, the pump and the motor.

The invention provides a fracturing sand mixing device used for mixing fracturing fluid. The fracturing sand mixing device comprises a solid-liquid mixing device, and the solid-liquid mixing device is a pressure container. The solid-liquid mixing device comprises a solid lead-in port capable of leading in solid particles of the fracturing fluid, a base fluid lead-in port for leading in base fluid of the fracturing fluid, a mixing inner cavity for accommodating the solid particles and the base fluid and a solid-liquid lead-out port for leading out the fracturing fluid formed by mixing. Substances such as carbon dioxide or petroleum gas which are in a gas state under normal temperature can be kept in a liquid state by high pressure through the fracturing sand mixing device and are mixed with the solid particles to form the fracturing fluid, and the goal of preparing the fracturing fluid with liquid carbon dioxide or liquefied petroleum gas (propane) serving as the base fluid is achieved.

A method of treating a subterranean formation penetrated by a well bore including:(a) preparing a fracturing fluid containing a mixture resulting from:(I) providing a water-in-oil emulsion composition that includes:(i) 5% to 99% by weight of a water-in-oil emulsion polymer comprising a polymer or copolymer containing repeat units from an acrylamide monomer;(ii) 0.5% to 90% by weight of a carrier solvent; and(iii) 0 to 90% by weight of a fluidizing agent; and adding(iv) 0.1% to 10% by weight of one or more inorganic microparticles, where the total of all components is 100% by weight; and(II) adding the water-in-oil emulsion composition to water; and(b) contacting the subterranean formation with the fracturing fluid.

A system for fracturing a formation in a bore at a worksite is disclosed. The system includes a turbine. The system also includes a pump coupled to the turbine. The pump includes a housing member that is adapted to receive a fracturing fluid. The pump also includes an auger rotatably disposed within the housing member. The auger pressurizes the fracturing fluid at a desired pressure based on a speed of the turbine to supply a pressurized fracturing fluid to the bore. The auger includes a shaft coupled to the turbine and rotatable about a rotational axis. The auger also includes a helical blade disposed around the shaft.