Abstract: Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.

Abstract: A wellbore fluid may include a non-oleaginous internal phase, an oleaginous external phase, and an emulsifier having a molecular weight of at least 700 daltons, whereby the emulsifier may include at least one tertiary amine. A method of completing a wellbore operation may include injecting a wellbore fluid downhole, the wellbore fluid including a non-oleaginous internal phase, an oleaginous external phase, and an emulsifier having a molecular weight of at least 700 daltons. The emulsifier may include at least one tertiary amine. The method may further include injecting a wash fluid comprising a protonating agent downhole.

Abstract: A brine viscosifier includes at least one monomer and triethoxyvinylsilane (TEVS) to provide crosslinking among the at least one monomer. A method includes admixing a composition comprising a brine, a thermal stabilizer, a pH buffer, and a polymer. The polymer may include a monomer, an organic crosslinker, an inorganic crosslinker; and an initiator.

Abstract: A wellbore fluid may include a non-oleaginous internal phase, an oleaginous external phase, and an emulsifier having a molecular weight of at least 700 daltons, whereby the emulsifier may include at least one tertiary amine. A method of completing a wellbore operation may include injecting a wellbore fluid downhole, the wellbore fluid including a non-oleaginous internal phase, an oleaginous external phase, and an emulsifier having a molecular weight of at least 700 daltons. The emulsifier may include at least one tertiary amine. The method may further include injecting a wash fluid comprising a protonating agent downhole.

Abstract: Emulsion-preventing compositions may contain one or more sorbitan esters; and one or more non-ionic surfactants; where the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants is in the range of 1:1 to 1:5. Methods may include contacting an emulsion with a treatment fluid, the treatment fluid containing one or more sorbitan esters and one or more non-ionic surfactants, where the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants is in the range of 1:1 to 1:5; and separating the emulsion into an aqueous phase and an oleaginous phase.

Abstract: A insulating annular fluid for reducing convective currents in the annular region a wellbore is provided that includes an oleaginous fluid, a silica, and, in some embodiments, organoclay.

Abstract: An insulating packer fluid including an oleaginous fluid and a styrenic thermoplastic block copolymer and methods of preparing the packer fluid are provided. Also provided are methods of using the insulating packer fluid that include pumping an insulating packer fluid into an annulus formed between two concentric strings of pipe extending into a wellbore.

Abstract: Insulating packer fluids containing colloidal silica inorganic additives may be used in methods that reduce convective currents in a packer fluid. In other aspects, packer fluids containing colloidal silica inorganic additives may be used in methods of insulating production wells and methods for stimulating production of hydrocarbons.

Abstract: Non-emulsifying compositions may contain one or more sorbitan esters; one or more non-ionic surfactants; and one or more amphoteric surfactants, wherein the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants to the one or more amphoteric surfactants is in the range of 1:1:1 to 1:5:3. Methods may include contacting an emulsion with a treatment fluid, the treatment fluid containing one or more sorbitan esters, one or more non-ionic surfactants, and one or more amphoteric surfactants, wherein the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants to the one or more amphoteric surfactants is in the range of 1:1:1 to 1:5:3; and separating the emulsion into an aqueous phase and an oleaginous phase.

Abstract: Compositions may include a monomer, an organic crosslinker, an inorganic crosslinker, and an initiator. Furthermore, compositions may include at least one monomer and triethoxyvinylsilane (TEVS) to provide crosslinking among the at least one monomer.

Abstract: Non-emulsifying compositions may contain one or more sorbitan esters; one or more non-ionic surfactants; and one or more amphoteric surfactants, wherein the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants to the one or more amphoteric surfactants is in the range of 1:1:1 to 1:5:3. Methods may include contacting an emulsion with a treatment fluid, the treatment fluid containing one or more sorbitan esters, one or more non-ionic surfactants, and one or more amphoteric surfactants, wherein the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants to the one or more amphoteric surfactants is in the range of 1:1:1 to 1:5:3; and separating the emulsion into an aqueous phase and an oleaginous phase.

Abstract: Emulsion-preventing compositions may contain one or more sorbitan esters; and one or more non-ionic surfactants; where the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants is in the range of 1:1 to 1:5. Methods may include contacting an emulsion with a treatment fluid, the treatment fluid containing one or more sorbitan esters and one or more non-ionic surfactants, where the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants is in the range of 1:1 to 1:5; and separating the emulsion into an aqueous phase and an oleaginous phase.

Abstract: Methods may include circulating a first wellbore fluid into a wellbore, wherein the first wellbore fluid contains: a non-aqueous continuous phase, and a polyester internal breaker; wherein the first wellbore fluid generates a filter cake in at least a section of the wellbore; circulating a second wellbore fluid into the wellbore, wherein the second wellbore fluid contains an acid source and a surfactant; and allowing the second wellbore fluid to degrade at least a portion of the filter cake. Other methods may include circulating a wellbore fluid into a wellbore drilled with an oil-based mud containing a polyester fluid loss additive, wherein the wellbore fluid comprises one or more surfactants and an acid source.

Abstract: A brine viscosifier includes at least one monomer and triethoxyvinylsilane (TEVS) to provide crosslinking among the at least one monomer. A method includes admixing a composition comprising a brine, a thermal stabilizer, a pH buffer, and a polymer. The polymer may include a monomer, an organic crosslinker, an inorganic crosslinker; and an initiator.

Abstract: Compositions may include a monomer, an organic crosslinker, an inorganic crosslinker, and an initiator. Furthermore, compositions may include at least one monomer and triethoxyvinylsilane (TEVS) to provide crosslinking among the at least one monomer.

Abstract: An insulating packer fluid including an oleaginous fluid and a styrenic thermoplastic block copolymer and methods of preparing the packer fluid are provided. Also provided are methods of using the insulating packer fluid that include pumping an insulating packer fluid into an annulus formed between two concentric strings of pipe extending into a wellbore.

Abstract: Insulating packer fluids containing colloidal silica inorganic additives may be used in methods that reduce convective currents in a packer fluid. In other aspects, packer fluids containing colloidal silica inorganic additives may be used in methods of insulating production wells and methods for stimulating production of hydrocarbons.

Abstract: A insulating annular fluid for reducing convective currents in the annular region a wellbore is provided that includes an oleaginous fluid, a silica, and, in some embodiments, organoclay.