Abstract: A method of determining wettability may include: measuring an electrical property of a drilling fluid; and correlating the electrical property to wettability.

Abstract: Compositions and methods of using of such compositions to, for example, inhibit shale are provided. In one embodiment, the methods include introducing an additive including a cationic clay stabilizer and an anionic clay stabilizer into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation. In some embodiments, the methods include introducing an additive including a cationic shale inhibitor and an anionic shale inhibitor into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating 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: Provided are compositions and methods that use a true crystallization temperature reduction additive in the aqueous internal phase. An example method may comprise providing an oil-based treatment fluid in the form of an invert emulsion comprising an aqueous internal phase and an oil external phase. The aqueous internal phase may include a bromide brine and a true crystallization temperature reduction additive, wherein the bromide brine has a density of about 14.2 lbs/gal or greater. The method may further include placing the oil-based treatment fluid into a wellbore.

Abstract: Provided are compositions and methods that use a true crystallization temperature reduction additive in the aqueous internal phase. An example method may comprise providing an oil-based treatment fluid in the form of an invert emulsion comprising an aqueous internal phase and an oil external phase. The aqueous internal phase may include a bromide brine and a true crystallization temperature reduction additive, wherein the bromide brine has a density of about 14.2 lbs/gal or greater. The method may further include placing the oil-based treatment fluid into a wellbore.

Abstract: A method may include: performing a treatment operation on at least a portion of a subterranean formation using an oil-in-water emulsion treatment fluid that comprises an oleaginous phase and an aqueous phase; recovering at least a portion of the oil-in-water emulsion treatment fluid from the portion of the subterranean formation; introducing a quaternary ammonium compound into the recovered portion of the oil-in-water emulsion treatment fluid at a well site; and mechanically separating at least a portion of the recovered portion of the oil-in-water emulsion treatment fluid into an oleaginous fluid and an aqueous fluid

Abstract: A method of drilling in a subterranean formation. A method may include providing a direct emulsion drilling fluid comprising an aqueous fluid, an oil, and a polysorbate emulsifier; circulating the direct emulsion drilling fluid from a surface, through a wellbore, and back to the surface; and extending the wellbore in the subterranean formation while circulating the direct emulsion drilling fluid.

Abstract: Quaternary ammonium compounds and methods of using such compounds to, for example, break oil-in-water emulsion treatment fluids are provided. In some embodiments, such methods include introducing a quaternary ammonium compound into an oil-in-water emulsion treatment fluid that comprises an oleaginous phase and an aqueous phase; and centrifuging at least the portion of the oil-in-water emulsion treatment fluid to separate at least a portion of the oil-in-water emulsion treatment fluid into an oleaginous fluid and an aqueous fluid.

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: 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 of drilling in a subterranean formation is disclosed. The method may include providing a direct emulsion drilling fluid comprising an aqueous-based fluid, an oil, and a poly-quaternary ammonium chloride emulsifier; circulating the direct emulsion drilling fluid from the surface, through a wellbore, and back to the surface; and extending the wellbore in the subterranean formation while circulating the direct emulsion drilling fluid.

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: 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: A method of determining wettability may include: measuring an electrical property of a drilling fluid; and correlating the electrical property to wettability.

Abstract: Compositions and methods of using of such compositions to, for example, inhibit shale are provided. In one embodiment, the methods include introducing an additive including a cationic clay stabilizer and an anionic clay stabilizer into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation. In some embodiments, the methods include introducing an additive including a cationic shale inhibitor and an anionic shale inhibitor into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: A method of using a high temperature treatment fluid containing nanocellulose including: providing a treatment fluid that includes a base fluid, a synthetic crosslinked polymer composition including a plurality of monomeric units, and at least one crosslinker, and a nanocellulose. The treatment fluid is introduced into at least a portion of a well bore penetrating at least a portion of a subterranean formation.

Abstract: Provided are compositions and methods that use a true crystallization temperature reduction additive in the aqueous internal phase. An example method may comprise providing an oil-based treatment fluid in the form of an invert emulsion comprising an aqueous internal phase and an oil external phase. The aqueous internal phase may include a bromide brine and a true crystallization temperature reduction additive, wherein the bromide brine has a density of about 14.2 lbs/gal or greater. The method may further include placing the oil-based treatment fluid into a wellbore.

Abstract: Quaternary ammonium compounds and methods of using such compounds to, for example, break oil-in-water emulsion treatment fluids are provided. In some embodiments, such methods include introducing a quaternary ammonium compound into an oil-in-water emulsion treatment fluid that comprises an oleaginous phase and an aqueous phase; and centrifuging at least the portion of the oil-in-water emulsion treatment fluid to separate at least a portion of the oil-in-water emulsion treatment fluid into an oleaginous fluid and an aqueous fluid.

Abstract: A method of drilling in a subterranean formation is disclosed. The method may include providing a direct emulsion drilling fluid comprising an aqueous-based fluid, an oil, and a poly-quaternary ammonium chloride emulsifier; circulating the direct emulsion drilling fluid from the surface, through a wellbore, and back to the surface; and extending the wellbore in the subterranean formation while circulating the direct emulsion drilling fluid.

Abstract: Methods for using treatment fluids and additives that include xanthan gum and attapulgite. In one or more embodiments, the methods of the present disclosure include providing a treatment fluid comprising an aqueous base fluid, xanthan gum, and attapulgite; and introducing the treatment fluid into at least a portion of a subterranean formation.