A fracturing fluid system for increasing hydrocarbon production in a subterranean reservoir formation comprising a fluid composition and a base fluid, the fluid composition comprising a nano-crosslinker, and a base polymer; and the base fluid operable to suspend the fluid composition, the base fluid comprising water; wherein the fluid composition and the base fluid are combined to produce the fracturing fluid system, wherein the fracturing fluid system is operable to stimulate the subterranean reservoir formation. In certain embodiments, the nano-crosslinker is an amine-containing nano-crosslinker and the base polymer is an acrylamide-based polymer. In certain embodiments, the fracturing fluid systems comprise proppants for enhancing hydraulic fracturing stimulation in a subterranean hydrocarbon reservoir.

A process for forming a particle carrier system includes supplying a particle carrier, the particle carrier having a surface and modifying the particle carrier surface to include a first ionic functional group. The process also includes chemically binding the first ionic functional group on the particle carrier surface to a first ionic molecule.

A method includes injecting an injection fluid through a well and to a depth of a formation, where the injection fluid includes phase-changing nanodroplets having a liquid core and a shell. The method also includes exposing the phase-changing nanodroplets to an external stimulus at the depth of the formation, wherein the liquid core of the phase-changing nanodroplets undergoes a liquid-to-vapor phase change causing the phase-changing nanodroplets to expand, and stimulating the formation at a near wellbore region by expansion of the phase-changing nanodroplets.

Methods of fracturing a subterranean formation include introducing a fracturing fluid containing an aqueous medium, a viscosifying agent and a polyethylene oxide alkyl ether through a wellbore and into the subterranean formation, pressurizing the fracturing fluid to fracture the subterranean formation, and allowing the fracturing fluid to flow back into the wellbore from the subterranean formation. The polyethylene oxide alkyl ether useful in some embodiments is defined according to the formula:

##STR00001##

where R.sub.1 and R.sub.2 are independently selected from linear or branched alkyl groups having from 2 to 16 carbon atoms, and n may be a value selected from within a range of from 1 to 100.

A supramolecular star-shaped polymer with -CD as a core and a preparation method thereof. The supramolecular star-shaped polymer with -CD as a core has a -cyclodextrin-modified branched monomer F--CD that serves as a core and is grafted with acrylamide, acrylic acid, hydrophobic monomers and surface-active macromolecular monomers to form a supramolecular star-shaped polymer. The hydrophobic monomer is one or more of N-benzyl-N alkyl (meth) acrylamide and N-phenethyl-N alkyl (meth) acrylamide; the surface-active macromolecular monomer is one or more of allyl polyoxyethylene ether, alkylphenol polyoxyethylene ether (meth)acrylate, allyl alkylphenol polyoxyethylene ether, alkyl alcohol polyoxyethylene ether (meth)acrylate and allyl alkyl alcohol polyoxyethylene ether. The method has cheapness and easiness to obtain raw materials, ease to control synthesis conditions, and high yield. The present invention has excellent tackifying performance, temperature resistance, salt resistance and hydrolysis resistance, so that it shows good application prospects in the aspect of enhancing recovery ratios and hydraulic fracturing in oilfields.

A hydraulic fracturing method for recovering oil from a low-temperature subterranean oil formation is disclosed. Before, during, or after inducing hydraulic fracturing within the formation, a particulate, degradable polyester diverting agent is introduced into the formation in an amount effective to improve oil production from the formation. The diverting agent is allowed to degrade, and oil is recovered. The diverting agent has a melting point greater than the average temperature of the formation and is selected from: (i) ethylene glycol succinates; (ii) acid-terminated ethylene glycol succinates; (iii) acid-terminated polyglycolic acids; (iv) acid-terminated polylactic acids; (v) mixtures of any of (i) through (iv) with a half acid ester; and (vi) mixtures of polylactic acids or polyglycolic acids with a half acid ester. These easily synthesized classes of particulate polyester diverting agents degrade more effectively than polylactides under the conditions present in low-temperature wells and should help to enhance well productivity.

Friction reducers, fracturing fluid compositions and methods for treating subterranean formations, wherein friction reducer is a blend of natural gum and polyacrylamide having a molecular weight between 300,000 and 30,000,000.

A proppant includes a particle present in an amount of from 90 to 99.5 percent by weight based on the total weight of the proppant, and a polyurethane coating disposed about the particle and present in an amount of from 0.5 to 10 percent by weight based on the total weight of the proppant. The polyurethane coating comprises the reaction product of an isocyanate component and an isocyanate-reactive component comprising a polydiene polyol.

Disclosed is a composition and use thereof for the recovery of hydrocarbon fluids from a subterranean reservoir. More particularly, this invention concerns sulfonated epoxy resin polymers comprising an epoxide-containing compound, a primary amino sulfonate, and optionally one or more of a primary monoamine alkylene oxide oligomer, that modify the permeability of subterranean formations and increase the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid ranging from 50-100 ppt so as to adjust pH and delay said cross linking agent.