Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, and an inverting surfactant composition comprising one or more surfactants selected from the group consisting of ethoxylated alcohol compounds, ethoxylated fatty acid compounds, and alkyl polyethyleneglycol ether carboxylic acid compounds, and salts or esters thereof. The emulsions are particularly suitable for use in brine.

Coated proppants include a proppant particle, a surface copolymer layer surrounding the proppant particle, and a resin layer surrounding the surface copolymer layer. The surface copolymer layer includes a copolymer of at least two monomers chosen from styrene, methyl methacrylate, ethylene, propylene, butylene, imides, urethanes, sulfones, carbonates, and acrylamides, where the copolymer is crosslinked by divinyl benzene. The resin layer includes a cured resin. Methods of preparing the coated proppants include preparing a first mixture including at least one polymerizable material, an initiator, and a crosslinker including divinyl benzene; contacting the first mixture to a proppant particle to form a polymerization mixture; heating the polymerization mixture to cure the polymerizable material and form a polymer-coated particulate; preparing a second mixture including the polymer-coated substrate, an uncured resin, and a solvent; and adding a curing agent to the second mixture to cure the uncured resin and form the coated proppant.

A method of stimulating petroleum production includes introducing a fracturing fluid into a petroleum bearing carbonate formation, thereby creating at least one fracture to stimulate the petroleum production. The fracturing fluid is introduced into the petroleum bearing carbonate formation at a pressure above the breakdown pressure of the formation. The fracturing fluid includes a plurality of proppants where from 1 to 50 wt. % of the plurality of proppants includes micro proppants having a particle size ranging from 0.5 to 150 μm, and from 50 to 99 wt. % of the plurality of proppants includes macro proppants having a particle size greater than 100 mesh.

A method of stimulating petroleum production includes introducing a fracturing fluid into a petroleum bearing carbonate formation, thereby creating at least one fracture to stimulate the petroleum production. The fracturing fluid is introduced into the petroleum bearing carbonate formation at a pressure above the breakdown pressure of the formation. The fracturing fluid includes a plurality of proppants where from 1 to 50 wt. % of the plurality of proppants includes micro proppants having a particle size ranging from 0.5 to 150 μm, and from 50 to 99 wt. % of the plurality of proppants includes macro proppants having a particle size greater than 100 mesh.

The present invention relates to a reagent for exploiting natural gas hydrates, which includes a regent A and a regent B. The reagent A is PEG400-polyurethane prepolymer; the reagent B includes PEG400 and an initiator; and a volume ratio of the PEG400-polyurethane prepolymer, the PEG400 and the initiator is (1-3000):(1-1000):(1-2000). The reagent of the present invention has excellent performance and high stability, and can effectively “replace” the “water” of the natural gas hydrate; and moreover, the reaction is exothermic reaction to effectively increase the reaction rate, which reduces the energy loss on the one hand, and reduces the blockage of a gas passage caused by the secondary generation of the natural gas hydrates in a low-temperature high-pressure pipeline during transferring on the other hand.

The present invention relates to a reagent for exploiting natural gas hydrates, which includes a regent A and a regent B. The reagent A is PEG400-polyurethane prepolymer; the reagent B includes PEG400 and an initiator; and a volume ratio of the PEG400-polyurethane prepolymer, the PEG400 and the initiator is (1-3000):(1-1000):(1-2000). The reagent of the present invention has excellent performance and high stability, and can effectively “replace” the “water” of the natural gas hydrate; and moreover, the reaction is exothermic reaction to effectively increase the reaction rate, which reduces the energy loss on the one hand, and reduces the blockage of a gas passage caused by the secondary generation of the natural gas hydrates in a low-temperature high-pressure pipeline during transferring on the other hand.

A system for utilizing oolitic aragonite as a proppant in hydraulic fracking is provided. The system includes a proppant storage tank including a stockpile of the oolitic aragonite. The system further includes a proppant pumping unit operable to pump the oolitic aragonite from the proppant storage tank, through an underground shaft, and into an underground fracture proximate to the underground shaft.

A system for utilizing oolitic aragonite as a proppant in hydraulic fracking is provided. The system includes a proppant storage tank including a stockpile of the oolitic aragonite. The system further includes a proppant pumping unit operable to pump the oolitic aragonite from the proppant storage tank, through an underground shaft, and into an underground fracture proximate to the underground shaft.

A method comprising: introducing a first fluid into a wellbore above a fracture gradient of a subterranean formation penetrated by the wellbore to create a first plurality of fractures within a first portion of the subterranean formation; introducing a second fluid comprising at least one acid component into the wellbore above the fracture gradient of the subterranean formation penetrated by the wellbore to create a second plurality of fractures within a second portion of the subterranean formation; allowing the second fluid to enter at least one natural fracture in the first or second portion of the subterranean formation allowing the acid component to dissolve at least a portion of the subterranean formation to form one or more induced fractures in fluidic communication with the natural fracture, at least some of the first plurality of fractures, and at least some of the second plurality of fractures.

A method comprising: introducing a first fluid into a wellbore above a fracture gradient of a subterranean formation penetrated by the wellbore to create a first plurality of fractures within a first portion of the subterranean formation; introducing a second fluid comprising at least one acid component into the wellbore above the fracture gradient of the subterranean formation penetrated by the wellbore to create a second plurality of fractures within a second portion of the subterranean formation; allowing the second fluid to enter at least one natural fracture in the first or second portion of the subterranean formation allowing the acid component to dissolve at least a portion of the subterranean formation to form one or more induced fractures in fluidic communication with the natural fracture, at least some of the first plurality of fractures, and at least some of the second plurality of fractures.