Methods of fracturing a subterranean formation containing a hydrocarbon include introducing a first fracturing fluid that includes natural gas into the formation at a rate and pressure sufficient to create a complex fracture in the formation; introducing a second fracturing fluid into the formation, wherein the second fracturing fluid comprises water, a gelling agent, a foaming agent, natural gas, and proppant particulates; and allowing the second fracturing fluid to transport a portion of the proppant particulates into the complex fracture.

A fluid control device includes a housing, a fluid channel defined within the housing, the fluid channel having an inlet, and a flow control body disposed in the fluid channel, the flow control body tapering towards the inlet. The flow control body, in use, causes a fluid flowing through the fluid channel to flow into an annular fluid flow path within the fluid channel. The annular fluid flow path has a geometry selected based on a subcool of the fluid at a pressure of the fluid entering the fluid channel, and the geometry is selected to induce cavitation of the fluid to choke fluid flow through the fluid channel.

A method of well rehabilitation using CO.sub.2 comprises a more effective distribution of effective CO.sub.2 energy throughout an entire well structure including all parts of a producing interval of a well and surrounding formation. The CO.sub.2 phase changes are controlled during CO.sub.2 injection to cause surging agitation within a well bore and surrounding formation and allow CO.sub.2 energy to reach all areas of the well, and the CO.sub.2 energy utilized includes at least one of chemical energy, thermal energy and mechanical energy.

A method of servicing a wellbore penetrating a subterranean formation, comprising placing a wellbore servicing fluid (WSF) into the wellbore proximate a permeable zone having an average fracture width of about W microns, wherein the WSF comprises a particulate blend and water, and wherein the particulate blend comprises (a) a type A particulate material characterized by a weight average particle size of equal to or greater than about W/3 microns, and (b) a type B particulate material characterized by a weight average particle size of less than about W/3 microns, wherein a weight ratio of the type A particulate material to the type B particulate material is from about 0.05 to about 5.

Systems and methods for predicting and optimizing the effects of acidizing treatment of carbonate rock are disclosed. The disclosed methods predict the conflicting effects of increased production (i.e., wormhole creation) and reduced rock compressive strength due to acid rock reactions. The mechanical stability of stimulated wellbores, such as horizontal wellbores, can be determined under different acidizing conditions, such as acid type and volume. The acidizing conditions can be optimized to maximize short and long-term production.

The present disclosure provides a reinforcement learning-based decision optimization method of an oilfield production system, including: collecting dynamic production data of an oilfield production site to establish a data cube for reservoir production optimization; training a preset machine learning model based on the data cube to obtain a reinforcement learning-based reservoir injection-production system surrogate model configured to predict oil production according to the dynamic production data available on site; constructing an evaluation function for production optimization of a gas injection reservoir; establishing, during a process of production optimization, an enforced constraint model based on input parameters and a boundary constraint condition; and with the constraint model and the boundary constraint condition as constraints, the reservoir injection-production system surrogate model as a basis, and the evaluation function as an optimization direction, searching reservoir production optimization schemes for an optimal production scheme.

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

A device for treating a bottom-hole formation of a wellbore comprises a firing head and seal block assembly at a proximal end thereof and a bullnose assembly at a distal end thereof. A carrier tube extends between the firing head and seal block assembly and the bullnose assembly. The carrier tube contains a combustible chemical composition which generates hydrochloric acid gas or hydrofluoric acid gas or a combination thereof when combusted. A dispersion tube extends from the carrier tube. The dispersion tube has a lateral opening. The lateral opening may be a slot or an aperture. There is a charge wire electrically connecting the firing head and sealing block assembly to the combustible chemical composition.

A method of servicing a wellbore penetrating a subterranean formation, comprising placing a wellbore servicing fluid (WSF) into the wellbore proximate a permeable zone having an average fracture width of about W microns, wherein the WSF comprises a particulate blend and water, and wherein the particulate blend comprises (a) a type A particulate material characterized by a weight average particle size of equal to or greater than about W/3 microns, and (b) a type B particulate material characterized by a weight average particle size of less than about W/3 microns, wherein a weight ratio of the type A particulate material to the type B particulate material is from about 0.05 to about 5.

Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. The methods can include injecting a gas into the existing wellbore in fluid communication with an unconventional subterranean formation prior to and/or during fracturing of the new wellbore in fluid communication with the unconventional subterranean formation.