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: 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: 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: 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.

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 system includes a neutron source positionable within a wellbore to emit one or more neutrons toward a formation surrounding the wellbore. The system also includes a gamma ray detector positionable within the wellbore to detect gamma rays. Further, the system includes a gamma ray analyzer that can perform operations. The operations can include receiving data indicating detected gamma rays from the gamma ray detector. Additionally, the operations include determining, from the data indicating the detected gamma rays, an amount of activated tracer material present within the wellbore originating from non-radioactive tracer material of drill-in fluid. The operations also include determining, from the amount of activated tracer material, an amount of filtercake buildup in a wellbore, a depth of fluid-loss filtrate into the formation surrounding the wellbore, or a combination thereof.

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: A method of treating a subterranean formation penetrated by a wellbore, wherein the subterranean formation comprises one or more permeable zones, comprising introducing a superabsorbent polymer (SAP) fluid into the wellbore, wherein the SAP fluid comprises an aqueous fluid and an SAP material comprising a reaction product of a reaction mixture comprising one or more viscosifying polymeric materials, one or more crosslinking agents, and water, allowing the SAP fluid to flow into at least a portion of the one or more permeable zones in the subterranean formation, and allowing the SAP material to absorb water and form a swollen SAP material, wherein the swollen SAP material impedes fluid flow through at least a portion of the one or more permeable zones.

Abstract: A system includes a neutron source positionable within a wellbore to emit one or more neutrons toward a formation surrounding the wellbore. The system also includes a gamma ray detector positionable within the wellbore to detect gamma rays. Further, the system includes a gamma ray analyzer that can perform operations. The operations can include receiving data indicating detected gamma rays from the gamma ray detector. Additionally, the operations include determining, from the data indicating the detected gamma rays, an amount of activated tracer material present within the wellbore originating from non-radioactive tracer material of drill-in fluid. The operations also include determining, from the amount of activated tracer material, an amount of filtercake buildup in a wellbore, a depth of fluid-loss filtrate into the formation surrounding the wellbore, or a combination thereof.

Abstract: A method including determining a concentration of one or more components of a fluid during a wellbore servicing operation of a wellbore, and providing a trigger signal to actuate mechanical operation of a tool based on the determining of the concentration of the one or more components. The determining of the concentration of the one or more components includes contacting a sample of the fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A variety of systems, methods and compositions are disclosed for a treatment fluid comprising a nano-cellulose and a gum. An example method may comprise providing a treatment fluid wherein the treatment fluid comprises: a base fluid; a nano-cellulose; and a gum; and introducing the treatment fluid into a well bore penetrating a subterranean formation.

Abstract: A composition of a treatment fluid having an aqueous base fluid and a true crystallization temperature reduction additive. A method includes providing a treatment fluid having an aqueous base fluid, adding a true crystallization temperature reduction additive and placing the treatment fluid in a subterranean wellbore.

Abstract: A method of treating a subterranean formation penetrated by a wellbore, wherein the subterranean formation comprises one or more permeable zones, comprising introducing a superabsorbent polymer (SAP) fluid into the wellbore, wherein the SAP fluid comprises an aqueous fluid and an SAP material comprising a reaction product of a reaction mixture comprising one or more viscosifying polymeric materials, one or more crosslinking agents, and water, allowing the SAP fluid to flow into at least a portion of the one or more permeable zones in the subterranean formation, and allowing the SAP material to absorb water and form a swollen SAP material, wherein the swollen SAP material impedes fluid flow through at least a portion of the one or more permeable zones.

Abstract: A composition for servicing a borehole in a subterranean formation by removing a filter cake along a wall of the borehole includes a biopolymer, the composition including a carrier fluid effective to act as a transport medium; an enzymatic breaker having activity to degrade the biopolymer in the filter cake upon contact with the filter cake so as to break up the biopolymer for removal; and an enzyme inhibitor effective to slow down the activity of the enzymatic breaker; where the composition may exclude the biopolymer. A method of servicing a borehole includes contacting the filter cake with the composition; degrading the biopolymer with the enzymatic breaker to produce degraded biopolymer; slowing down the degrading activity of the breaker with the enzyme inhibitor sufficiently that the degrading comprises degrading biopolymer along a length of the wall of the borehole; and removing the filter cake from the wall of the borehole.

Abstract: A method of inhibiting gas hydrate formation in downhole fluids, including providing a downhole fluid and mixing the downhole fluid with an aqueous gas thermodynamic hydrate inhibitor formulation to form a downhole fluid mixture. A concentration of lithium chloride in the downhole fluid mixture is at least about 1 wt % and a density of the downhole fluid mixture is in a range of about 1.08 to 1.3 gm/cm3 at a downhole temperature of about 50° F. or less and a downhole differential pressure of about 500 psi or higher. An aqueous gas thermodynamic hydrate inhibitor formulation and oil and gas well drilling system including such a formulation are also disclosed.

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 fluid, a brine-soluble weak base, and an acid precursor; and contacting a filter cake in the well bore with the delayed breaker fluid such that the filter cake is at least partially degraded by acid released from the acid precursor.

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 use in the inhibition of the formation of gas hydrate agglomerates are provided. In some embodiments, a method is provided that includes: providing an emulsion drilling fluid including: a continuous phase including a non-oleaginous fluid; an internal phase including an oleaginous fluid; and a thermodynamic hydrate inhibitor; and drilling at least a portion of a wellbore penetrating a subterranean formation.

Abstract: Particulate additives that may be useful in mitigating fluid loss and/or as bridging agents or diverting agents in subterranean treatment fluids such as drilling fluids. In some embodiments, the particulate additives include a polymeric material and calcium carbonate disposed on at least a portion of the outer surface of the polymer core wherein the particulates have a particle size (d50) of from about 2 ?m to about 1600 ?m in diameter. In some embodiments, the methods include providing a treatment fluid that includes the base fluid and the particulate additives and introducing the treatment fluid into at least a portion of a subterranean formation.