Abstract: Embodiments of an adapter, a system including the adapter, and methods of using the adapter may be for mixing a first substance and a second substance. The adapter may include a body having a first port configured to connect with a first container to receive a first substance, a second port configured to connect with a second container to receive a second substance, a third port configured to connect with a recipient container to output a mixture of the first substance and the second substance, and a mixing chamber having a first portion in communication with the first port and the second port and a second portion in communication with the third port. The adapter may further include a mixing pin inserted into the mixing chamber. In some embodiments, the mixing pin at least partially defines at least one microfluidic path for mixing the first substance and the second substance. In some embodiments, at least one of the first channel and the second channel are oriented offset of a central plane of the body.

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: The present invention is related to the field of detection of operational failures, more specifically with the monitoring of head loss in equipment such as reactors, heat exchangers and adsorption vessels. The invention uses a method for continuous monitoring of equipment head loss, in order to assist in the early identification and action on this type of problem, avoiding or reducing losses resulting from its occurrence.

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: The present invention addresses to obtaining a support of hydrorefining catalysts by an innovative preparation route that reduces the problem of loss (or leaching) of boron over the operating time of industrial units. As the presence of boron in catalysts contributes to increased activity (hydrogenating and acidic) and stability for the hydrorefining reactions (hydrotreating and hydrocracking), its maintenance in the catalyst guarantees the preservation of the properties in operation, throughout the entire cycle of campaign of industrial units.

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.