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: Systems, methods, and compositions for creating microfractures within subterranean formations and delivering microproppant particles into microfractures within subterranean formations are provided. In some embodiments, the methods include: providing a treatment fluid that comprises an aqueous base fluid, a surfactant, and a plurality of microproppant particles having a mean particle diameter of about 100 microns or less; introducing the treatment fluid into a subterranean formation at or above a pressure sufficient to initiate the formation of at least one microfracture within the subterranean formation; and allowing at least a portion of the microproppant particles to enter the at least one microfracture within the subterranean formation.

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 method may include: preparing or providing an aqueous fluid containing iron ions; screening at least one iron control agent against the aqueous fluid; selecting at least one iron control agent and iron control agent concentration based at least in part on the step of screening; and preparing a fracturing fluid comprising an aqueous base fluid and the at least one iron control agent wherein a concentration of the iron control agent in the fracturing fluid is greater than or equal to the selected iron control agent concentration.

Abstract: A method of preparing a fracturing fluid comprising: preparing or providing an aqueous fluid containing iron ions; screening a plurality of friction reducers against the aqueous fluid wherein the plurality of friction reducers are anionic, cationic, nonionic, amphoteric, or combinations thereof; selecting at least one friction reducer from the plurality of friction reducers based at least in part on the step of screening; and preparing a fracturing fluid including the at least one friction reducer.

Abstract: An apparatus may include: a body defining a flow path; an inlet to the flow path; an outlet to the flow path; a test coupon at least partially disposed within the flow path; a sealing element disposed between the test coupon and the body; and a current source electrically coupled to the test coupon, wherein the inlet and the outlet are in fluid communication through the flow path, and wherein the sealing element electrically insulates the body and the test coupon.

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: 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.