Abstract: The present disclosure relates to methods for adding a recirculation chemical composition to a hydrocarbon containing stream. The recirculation chemical composition may be an emulsion breaker. The hydrocarbon containing stream may be separated into a stream containing water and a stream containing oil. The stream containing oil may be contacted in a water wash unit, and the residual emulsion breaker may be removed from the stream containing oil.

Abstract: A method is disclosed comprising determining a concentration of one or more compounds of a fluid in an industrial water operation in real time. The determining of the concentration of the one or more components comprises contacting an array of sensors of a microelectromechanical system (MEMS) device with a sample of the fluid to provide a sample response indicative of the concentration of the one or more components. The method further provides adjusting or maintaining at least one operating parameter of the industrial water operation based on the concentration of the one or more components of the fluid.

Abstract: A method may include: drawing a slip stream sample from a cooling fluid stream, the cooling fluid stream being fluidically coupled to an outlet of a heat exchanger and an inlet of a cooling tower; introducing the slip stream sample into an expansion chamber; and measuring a concentration of hydrogen gas within a headspace of the expansion chamber.

Abstract: A method may include: providing a fracturing fluid including, but not limited to, an aqueous base fluid, a friction reducer, and a friction reduction booster; and introducing the fracturing fluid into the subterranean formation.

Abstract: A method is disclosed that includes introducing one or more dual function inhibitor compounds through an umbilical into a deepwater environment such that the one or more dual function inhibitor compounds are introduced into a fluid in the deepwater environment. The dual function inhibitor is a corrosion inhibitor and a hydrate inhibitor.

Abstract: Included are compositions, methods, and systems for producing and using winterized paraffin inhibitor solutions. An example composition comprises a paraffin inhibitor solution; and an additive comprising a first portion and a second portion; wherein the first portion is selected from the functional groups consisting of sulfo, phosphate, phosphonate, ester, carboxyl, hydroxyl, and any combination thereof; wherein the second portion is selected from the functional groups consisting of linear alkyl, branched alkyl, alkyl phenyl, ethoxylated branched alkyl, propoxylated branched alkyl, and any combination thereof.

Abstract: A method may comprise: determining a total dissolved solids (TDS) concentration of a water source; correlating the TDS concentration to an ion concentration; and selecting at least one friction reducing polymer for a hydraulic fracturing operation based at least in part on the ion concentration.

Abstract: Systems and methods having friction reducer compositions for use in subterranean treatment fluids are presented. An embodiment is a method comprising: (A) forming a treatment fluid comprising: an aqueous base fluid, a friction reducer, and an alkaline buffering agent, wherein the treatment fluid has a pH in the range of about 7 to about 10; and (B) injecting the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation.

Abstract: A method of wax treatment in subsea well may comprise providing a treatment fluid comprising a base fluid and a hyperbranched polymeric additive. The method may further comprise introducing the treatment fluid into the subsea well through an umbilical line.

Abstract: A method, comprising contacting a proppant, water, and a water external emulsion to form a mixture, wherein the water external emulsion has an organic internal phase comprising a surface modifying agent; contacting the mixture with an emulsion breaker to form a wellbore servicing fluid comprising a proppant coated with the surface modifying agent; an placing the wellbore servicing fluid in a wellbore penetrating a subterranean formation. A method comprising contacting a proppant, water, and a water external emulsion to form a first mixture, wherein the water external emulsion has an organic internal phase comprising a surface modifying agent; contacting the first mixture with an emulsion breaker to form second mixture comprising a proppant coated with the surface modifying agent; and recovering a coated proppant from the second mixture.

Abstract: Methods for treating subterranean formations are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid and a surfactant comprising an ethoxylated amine or derivative thereof; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and producing fluids from the wellbore during or subsequent to introducing the treatment fluid into the wellbore.

Abstract: A method may include: determining a total dissolved solids (TDS) concentration of a water source; correlating the TDS concentration to an ion concentration; and selecting at least one friction reducing polymer for a hydraulic fracturing operation based at least in part on the ion concentration.

Abstract: A method may comprise introducing a first traceable solid particulate into a first formation zone of one or more subterranean formations, wherein the first traceable solid particulate may comprise a first soluble tracer coated onto a first solid particulate. The method may also comprise introducing a second traceable solid particulate into a second formation zone of the one or more subterranean formations, wherein the second traceable solid particulate may comprise a second soluble tracer coated onto a second solid particulate, wherein the second tracer and the first tracer may have a different chemical identity. The method may further comprise recovering produced fluid from the one or more subterranean formations and monitoring concentrations of at least the first soluble tracer and the second soluble tracer in the produced fluid.

Abstract: A system may include: a crude oil desalter; one or more sample points fluidically coupled to the crude oil desalter; and one or more fluid characterization units coupled to each of the one or more sample points, the one or more fluid characterization units being operable to measure at least one of density or flow rate of fluid from the sample points.

Abstract: A system may include: a crude oil desalter; one or more sample points fluidically coupled to the crude oil desalter; and one or more fluid characterization units coupled to each of the one or more sample points, the one or more fluid characterization units being operable to measure at least one of density or flow rate of fluid from the sample points.

Abstract: A method may include: generating a signal in a conduit; measuring the signal; generating data representing a deposit in the conduit, the data being generated by a deposition identification model, wherein the deposition identification model utilizes the signal as an input; generating a treatment plan based at least in part on the data representing the deposit; and applying a chemical additive to the conduit based at least in part on the treatment plan.

Abstract: Compositions and methods of using of such compositions to, for example, inhibit of the formation of gas hydrate agglomerates are provided. In one embodiment, the methods comprise: introducing a low-dosage hydrate inhibitor additive into a fluid, wherein the low-dosage hydrate inhibitor additive comprises a quaternary or tertiary ammonium cation moiety, a lipophilic tail, and a sulfonate anion moiety; and exposing the low-dosage hydrate inhibitor additive to a temperature above about 200° F.

Abstract: A method is disclosed that includes adding a recirculation chemical composition to a hydrocarbon containing stream, wherein the recirculation chemical composition may be an emulsion breaker. The method may also include separating the hydrocarbon containing stream into a stream containing water and a stream containing oil; contacting the stream containing oil in a water wash unit; and removing residual emulsion breaker from the stream containing oil.

Abstract: A method for inhibiting erosion (wear)-corrosion of downhole components in a secondary lift system, the method comprising: introducing a corrosion inhibitor and a lubricating agent into a wellbore; allowing the corrosion inhibitor and the lubricating agent to mix with a produced fluid to form a mixture; and recovering the mixture from the wellbore through a production tubing, wherein the corrosion inhibitor and/or the lubricating agent contact one or more of the downhole components of the secondary lift system. A system for inhibiting wear in secondary recovery comprising: a casing disposed in a producing wellbore; a production tubing extending into the casing; a downhole equipment disposed in the production tubing, wherein the downhole equipment comprises at least one equipment selected from the group consisting of a sucker rod, a plunger, and an electrical submersible pump; a treatment fluid for introduction into an annulus disposed between the casing and the production tubing.

Abstract: Compositions and methods of using of such compositions to, for example, inhibit of the formation of gas hydrate agglomerates are provided. In one embodiment, the methods comprise: introducing a hydrate inhibitor composition comprising a compound into a fluid, wherein the compound comprises two hydrophobic cation moieties, a lipophilic tail, and two linking moieties.