Abstract: A method of recycling a direct emulsion wellbore fluid may include disrupting a direct emulsion comprising an aqueous external phase and an oleaginous internal phase, wherein the direct emulsion is stabilized by a surfactant composition; and separating the aqueous phase and the oleaginous phase.

Abstract: A device includes a housing having a bore formed axially therethrough. The housing includes a stop that protrudes radially inward proximate to a lower end of the housing. The device also includes a lower piston positioned in the bore. The lower piston is configured to move axially within the bore in response to a pressure differential across the lower piston. The lower piston is prevented from passing out through the lower end of the housing by the stop. The lower piston has a lower piston hole formed therethrough. The device also includes an upper piston positioned in the bore. The upper piston is configured to move axially within the bore in response to a pressure differential across the upper piston. The upper piston has an upper piston hole formed therethrough. The device is configured to receive a fluid in the bore, between the upper and lower pistons.

Abstract: A device includes a housing having a bore formed axially therethrough. The housing includes a stop that protrudes radially inward proximate to a lower end of the housing. The device also includes a lower piston positioned in the bore. The lower piston is configured to move axially within the bore in response to a pressure differential across the lower piston. The lower piston is prevented from passing out through the lower end of the housing by the stop. The lower piston has a lower piston hole formed therethrough. The device also includes an upper piston positioned in the bore. The upper piston is configured to move axially within the bore in response to a pressure differential across the upper piston. The upper piston has an upper piston hole formed therethrough. The device is configured to receive a fluid in the bore, between the upper and lower pistons.

Abstract: A fluid may include an aqueous based continuous phase, a pH adjusting additive, wherein the pH adjusting additive is formic acid, and a clay hydration suppressant agent having the formula H2NCH(CH3)CH2(OCH(CH3)CH2)xNH2, wherein x is a value less than 15.

Abstract: A method of recycling a direct emulsion wellbore fluid may include disrupting a direct emulsion comprising an aqueous external phase and an oleaginous internal phase, wherein the direct emulsion is stabilized by a surfactant composition; and separating the aqueous phase and the oleaginous phase.

Abstract: Wellbore fluid compositions containing a base fluid; at least one synthetic fiber; and a particulate solid are provided. In another aspect, methods of reducing loss of wellbore fluid into and strengthening of a formation are provided, including: introducing into the wellbore a fluid composition comprising one or more synthetic fibers and one or more particulate solids.

Abstract: A fluid may include an aqueous based continuous phase, a pH adjusting additive, wherein the pH adjusting additive is formic acid, and a clay hydration suppressant agent having the formula H2NCH(CH3)CH2(OCH(CH3)CH2)xNH2, wherein x is a value less than 15.

Abstract: Wellbore fluid compositions containing a base fluid; at least one synthetic fiber; and a particulate solid; where one or more of the at least one synthetic fiber and the particulate solid are completely or substantially acid soluble are provided. In another aspect, methods of reducing loss of wellbore fluid in a wellbore to a formation are provided, including: introducing into the wellbore a fluid composition comprising one or more synthetic fibers and one or more particulate solids.

Abstract: An acid soluble defluidizing pill for reducing fluid loss in a wellbore is provided that includes an oleaginous or non-oleaginous base fluid; at least one synthetic fiber; and at least one inorganic crystalline fiber; in which one or more of the synthetic fiber and the inorganic crystalline fiber are at least substantially acid soluble.

Abstract: A method of triggering heating within a subterranean formation, that includes introducting a wellbore fluid containing a dispersed carbon nanomaterial into a wellbore through the subterranean formation; lowering a microwave or ultraviolet radiation source into the wellbore; and irradiating the wellbore with microwave or ultraviolet radiation, thereby increasing the temperature of the wellbore fluid and/or wellbore is disclosed.

Abstract: A method may include adding a dry carrier powder loaded with a liquid additive into a wellbore fluid, thereby releasing at least a portion of the liquid additive into the wellbore fluid; and pumping the wellbore fluid with the liquid additive therein into a wellbore.

Abstract: Wellbore fluid compositions containing a base fluid; at least one synthetic fiber; and a particulate solid are provided. In another aspect, methods of reducing loss of wellbore fluid into and strengthening of a formation are provided, including: introducing into the wellbore a fluid composition comprising one or more synthetic fibers and one or more particulate solids.

Abstract: Wellbore fluid compositions containing a base fluid; at least one synthetic fiber; and a particulate solid; where one or more of the at least one synthetic fiber and the particulate solid are completely or substantially acid soluble are provided. In another aspect, methods of reducing loss of wellbore fluid in a wellbore to a formation are provided, including: introducing into the wellbore a fluid composition comprising one or more synthetic fibers and one or more particulate solids.

Abstract: An acid soluble defluidizing pill for reducing fluid loss in a wellbore is provided that includes an oleaginous or non-oleaginous base fluid; at least one synthetic fiber; and at least one inorganic crystalline fiber; in which one or more of the synthetic fiber and the inorganic crystalline fiber are at least substantially acid soluble.

Abstract: A method of triggering heating within a subterranean formation, that includes introducting a wellbore fluid containing a dispersed carbon nanomaterial into a wellbore through the subterranean formation; lowering a microwave or ultraviolet radiation source into the wellbore; and irradiating the wellbore with microwave or ultraviolet radiation, thereby increasing the temperature of the wellbore fluid and/or wellbore is disclosed.