Abstract: A method comprising determining a concentration of one or more components of a wellbore servicing fluid during a wellbore servicing operation; and adjusting or maintaining a composition of the wellbore servicing fluid being introduced into a wellbore and/or an operational parameter of the wellbore servicing operation based on the determining of the concentration of the one or more components, wherein the determining of the concentration of the one or more components comprises contacting a sample of the wellbore servicing fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: It can sometimes be difficult to quantify the amount of polymer present in a subterranean treatment fluid, particularly at a job site. Methods for analyzing a treatment fluid for a polymer can comprise: receiving a sample of a treatment fluid comprising a nitrogen-containing polymer; placing the sample of the treatment fluid and an aqueous base in an oilfield retort; heating the sample of the treatment fluid and the aqueous base together in the oilfield retort at least until the nitrogen-containing polymer has been substantially hydrolyzed to one or more volatile nitrogen compounds; distilling the one or more volatile nitrogen compounds from the oilfield retort; and determining a quantity of the nitrogen-containing polymer in the sample of the treatment fluid based upon a quantity of the one or more volatile nitrogen compounds distilled from the oilfield retort. Analyses of other nitrogen-containing compounds may take place similarly.

Abstract: Core-shell particles for treatment of subterranean formations are provided. A method may include placing in the subterranean formation a composition including a core-shell particle including a hydrophilic core and a hydrophobic shell.

Abstract: A method of servicing a wellbore penetrating a subterranean formation, comprising placing into the wellbore a wellbore servicing fluid comprising a sterically-hindered ester having a general formula R1COOR2 and an aqueous fluid, wherein R1, R2 or both have A-values greater than about 1.76 kcal/mol.

Abstract: Embodiments of the present disclosure provide optical methods and systems to evaluate the performance of a demulsifying agent in wellbore fluid. The present embodiments provide an optical system which scans wellbore fluid in order to detect the phase separation caused by a demulsifying agent. Using spectral data, the optical system quantifies the opacity and/or transparency of the different phases in the wellbore fluid in order to evaluate the demulsifying agent.

Abstract: A method comprises flowing a mud into a wellbore, wherein the mud has a mud composition and has a weight in a defined range. The method includes introducing a fluid pill into the mud flowing into the wellbore, wherein the fluid pill has an injection fluid with an injection composition that is different from the mud composition. A particulate has been added to the injection fluid to increase the weight of the fluid pill to be in the defined range. After flowing the mud into the wellbore such that the fluid pill is positioned in a zone of the wellbore: filtering out the particulate from the injection fluid; injecting, after the filtering, the injection fluid into the zone; measuring a downhole parameter that changes in response to injecting the injection fluid into the zone; and determining a property of the formation of the zone based on the measured downhole parameter.

Abstract: A method of detecting an amine-based shale inhibitor in a wellbore servicing fluid (WSF) comprising contacting an aliquot of the WSF with an amine detector compound to form a detection solution; wherein the WSF comprises the amine-based shale inhibitor; and wherein the detection solution is characterized by at least one absorption peak wavelength in the range of from about 380 nm to about 760 nm; detecting an absorption intensity for the detection solution at a wavelength within about ±20% of the at least one absorption peak wavelength; comparing the absorption intensity of the detection solution at the wavelength within about ±20% of the at least one absorption peak wavelength with a target absorption intensity of the amine-based shale inhibitor to determine the amount of amine-based shale inhibitor in the WSF; and comparing the amount of amine-based shale inhibitor in the WSF with a target amount of the amine-based shale inhibitor.

Abstract: The present disclosure provides methods, compositions, and systems directed to filter cake removal embodying a delayed breaker fluid for oil-based drill-in fluids. A wellbore treatment method comprising: introducing a delayed breaker fluid into a wellbore, wherein the delayed breaker fluid comprises an aqueous base fluid, an acid precursor, and a carbodiimide; and contacting a filter cake in the wellbore with the delayed breaker fluid such that the filter cake is at least partially degraded by acid released from the acid precursor.

Abstract: Methods and compositions for modifying the rheological properties of non-aqueous fluids for treating subterranean formation are provided. In one or mom embodiment, the compositions comprise a non-aqueous fluid; a weighting agent; and one or more associative polymers that are capable of associating to form one or more supramolecular assemblies. In one or more embodiments, the methods comprise introducing a treatment fluid into a wellbore penetrating at least a portion of a subterranean formation, wherein the treatment fluid comprises a non-aqueous fluid and one or more associative polymers.

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: Compositions and methods of using such compositions to treat subterranean formations are provided. In one embodiment, the methods include providing a drilling fluid including an aqueous base fluid and a low molecular mass organic gelator; and using the drilling fluid to drill at least a portion of a wellbore that penetrates at least a portion of a subterranean formation. In certain embodiments, the methods include providing a drilling fluid including an aqueous base fluid and a low molecular mass organic gelator; and using the drilling fluid to drill at least a portion of a wellbore that penetrates at least a portion of a subterranean formation.

Abstract: The present disclosure provides methods, compositions, and systems directed to filter cake removal embodying a delayed breaker fluid for oil-based drill-in fluids. A wellbore treatment method comprising: introducing a delayed breaker fluid into a wellbore, wherein the delayed breaker fluid comprises an aqueous base fluid, an acid precursor, and a carbodiimide; and contacting a filter cake in the wellbore with the delayed breaker fluid such that the filter cake is at least partially degraded by acid released from the acid precursor.

Abstract: A method comprising determining a concentration of one or more components of a wellbore servicing fluid during a wellbore servicing operation; and adjusting or maintaining a composition of the wellbore servicing fluid being introduced into a wellbore and/or an operational parameter of the wellbore servicing operation based on the determining of the concentration of the one or more components, wherein the determining of the concentration of the one or more components comprises contacting a sample of the wellbore servicing fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A method includes determining a concentration of one or more components of a subterranean fluid, and adjusting or maintaining at least one operating parameter of a wellbore servicing operation based on the determining of the concentration of the one or more components. The subterranean fluid includes a fluid obtained from a subterranean formation during the wellbore servicing operation, and the determining of the concentration of the one or more components includes contacting a sample of the subterranean fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A method of servicing a wellbore penetrating a subterranean formation, comprising placing into the wellbore a wellbore servicing fluid comprising a superabsorbent starch hydrogel (SSH) and an aqueous fluid, wherein the SSH is formed from an SSH reaction mixture comprising a starch, a crosslinker, a base, and water.

Abstract: A method of drilling may include mixing, at the surface, a base fluid, a polyvalent cation reactive polymer, and a delayed source of polyvalent cation so as to form a treatment fluid; placing the treatment fluid in a subterranean formation to form a solid plug including the polyvalent cation reactive polymer crosslinked with the polyvalent cation; contacting the solid plug with a breaker so as to transform the solid plug into a reclaimed treatment fluid; and removing the reclaimed treatment fluid. A system for drilling may include a treatment fluid, at the surface, including a polyvalent cation reactive polymer, and a delayed source of a polyvalent cation, where the treatment fluid is settable in the formation to form a solid plug including the polyvalent cation reactive polymer and the polyvalent cation; and a breaker, separate from the treatment fluid at the surface, capable of liquefying the solid plug.

Abstract: Described herein are methods to determine an amount of shale inhibitor in drilling fluids used in wellbore operations. In some cases, methods include receiving a sample of a drilling fluid, removing solids from the sample to produce a solids-free fluid, contacting the solids-free fluid with an anion to produce a precipitate in a test solution, and determining an amount of an amine-based shale inhibitor within the sample by measuring the amount of the precipitate in the test solution.

Abstract: Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

Abstract: Compositions and methods of using such compositions to treat subterranean formations are provided. In one embodiment, the methods include providing a drilling fluid including an aqueous base fluid and a low molecular mass organic gelator; and using the drilling fluid to drill at least a portion of a wellbore that penetrates at least a portion of a subterranean formation. In certain embodiments, the methods include providing a drilling fluid including an aqueous base fluid and a low molecular mass organic gelator; and using the drilling fluid to drill at least a portion of a wellbore that penetrates at least a portion of a subterranean formation.

Abstract: Methods and systems for using an invert emulsion fluid that is beneficial in the drilling, completing and working over of subterranean wells are provided. In some embodiments, the method includes: preparing a treatment fluid including an invert emulsion, wherein the invert emulsion further includes an aqueous dispersed phase, an oleaginous continuous phase, and an amine surfactant emulsifier and placing the treatment fluid in a wellbore penetrating at least portion of a subterranean formation.