A variety of systems, methods and compositions are disclosed, including, in one method, a method may comprise providing a proppant-free fracturing fluid; providing a proppant composition, wherein the proppant composition comprises proppant particulates and degradable thermoplastic particulates; introducing the proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation; introducing the proppant composition into the at least one fracture; and allowing the proppant composition to form a proppant pack in the fracture, wherein the degradable thermoplastic particulates are degradable to generate voids in the proppant pack.

Methods of treating a subterranean formation. A pad fluid is introduced into a wellbore penetrating the subterranean formation to create or enhance one or more fractures in the subterranean formation. A fracturing fluid is introduced into the wellbore. The fracturing fluid includes a polymer having a hydrophobic monomer and a hydrophilic monomer. The fracturing fluid further includes a proppant and a second aqueous base fluid. The fracturing fluid does not include a crosslinker or an oxidative breaker. The fracturing fluid is broken thereby settling the proppant in the fracture.

The flow of a fluid may be diverted from a high permeability zone to a low permeability zone of a subterranean formation or well sections may be temporarily isolated by use of particles comprising a mixture of (i) at least one bi-phenyl compound of Compound I, (ii) one mellitic derivative of Compound II, (iii) one chelating agent of Compound III, (iv) one polymer of Compound IV, and (v) an internal breaker for the diverting agents and other additives like gels, foams, acids, brines and various other treatment chemicals.

A method of servicing a wellbore penetrating a subterranean formation, comprising: placing a wellbore servicing fluid (WSF) into the wellbore, wherein the WSF comprises a first polymer, a second polymer, and water, wherein the first polymer is formed by polymerizing monomers comprising three of 2-Acrylamido-2-methyl propane sulfonic acid (AMPS), N,N-dimethylacrylamide (NNDMA), acrylamide, N-vinylacetamide, allyloxy-2-hydroxy propane sulfonic acid (AHPS), acrylic acid (AA), 2-acrylamido-2-tert.-butyl sulfonic acid (ATBS), or N,N-Dimethylaniline, and the second polymer is formed by polymerizing monomers and/or crosslinkers comprising AMPS, vinylpyrrolidinone, pentaerythritol allyl ether, and methylenebisacrylamide, wherein in the vinylpyrrolidinone, the 2-Pyrrolidone group can be substituted by a heterocyclic group, comprising one or more Z membered rings with Y heteroatoms, wherein Z is equal to or greater than three, and wherein Y is equal to or greater than one.

This invention describes and claims the stimulation of several Wolfcamp and Bone Springs targeted wells in the northern Delaware Basin using fracturing treatments and a new method employing relatively small pre-pad pill volumes of Brine Resistant Silicon Dioxide Nanoparticle Dispersions ahead of each stage of treatment have been successfully performed. The invention includes a method of extending an oil and gas system ESRV comprising the steps of adding a Brine Resistant Silicon Dioxide Nanoparticle Dispersion (BRINE RESISTANT SDND) to conventional oil well treatment fluids. The invention also includes a method of increasing initial production rates of an oil well by over 20.0% as compared to wells either not treated with the BRINE RESISTANT SDND technology or treated by conventional nano-emulsion surfactants. The Method focuses on the steps of adding a Brine Resistant Silicon Dioxide Nanoparticle Dispersion to conventional oil well treatment fluids.

This invention describes and claims the stimulation of several Wolfcamp and Bone Springs targeted wells in the northern Delaware Basin using fracturing treatments and a new method employing relatively small pre-pad pill volumes of Brine Resistant Silicon Dioxide Nanoparticle Dispersions ahead of each stage of treatment have been successfully performed. The invention includes a method of extending an oil and gas system ESRV comprising the steps of adding a Brine Resistant Silicon Dioxide Nanoparticle Dispersion (BRINE RESISTANT SDND) to conventional oil well treatment fluids. The invention also includes a method of increasing initial production rates of an oil well by over 20.0% as compared to wells either not treated with the BRINE RESISTANT SDND technology or treated by conventional nano-emulsion surfactants. The Method focuses on the steps of adding a Brine Resistant Silicon Dioxide Nanoparticle Dispersion to conventional oil well treatment fluids.

Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

Unconventional hydrocarbon source rock reservoirs can contain the organic material kerogen, intertwined with the rock matrix. The kerogen can alter the tensile strength of the rock and contribute to higher fracture energy needs. To degrade kerogen and other organic materials, oxidizing gasses are dissolved in carbon dioxide (CO.sub.2) which is then used as part of a fracturing fluid. The oxidizing gasses can be dissolved directly in the CO.sub.2 or generated in situ using precursors.

Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

The invention includes a method of extending an oil and gas system effective stimulated reservoir volume by performing the steps of adding a brine resistant silicon dioxide nanoparticle dispersion to oil well treatment fluids. This method is found to increase initial production rates of an oil well by over 20.0% as compared to wells either not treated with the brine resistant silicon dioxide nanoparticle dispersion technology or treated by conventional nano-emulsion surfactants.