Abstract: A method of analyzing a wellbore fluid that includes treating a wellbore fluid with an emulsifying fluid, the emulsifying fluid comprising: a hydroxylated ether; an amphoteric chemotrope; and testing the treated wellbore fluid for at least one of turbidity and total suspended solids is disclosed. Methods of cleaning wellbores are also disclosed.

Abstract: A breaker fluid may include a base fluid; and an inactive chelating agent. A process may include pumping a first wellbore fluid comprising an inactive chelating agent into a wellbore through a subterranean formation; and activating the inactive chelating agent to release an active chelating agent into the wellbore.

Abstract: A composition and method for use in drilling or completing a subterranean well comprising a solidsfree, high-density brine composed of alkali metal polytungstate and blends thereof. These high-density brines are also useful as wellbore fluids and other non-oilfield fluids requiring high density properties.

Abstract: A fluid loss pill that includes a crosslinked polymer gel, a brine, and solid salt particles disposed in said gel is described. Further, a method for reducing fluid loss that includes pumping a selected amount of a fluid loss pill into a wellbore leading to an oil-, condensate-, or gas-producing formation, the fluid loss pill including a crosslinked polymer gel, a brine, and solid salt particles disposed in said gel is described.

Abstract: The instant disclosure is directed to a method of detecting an emulsion in a turbid brine, the method comprising the steps of disposing an aliquot of the turbid brine into a sample container to produce a test sample; adding one or more drops of a dye solution comprising an oil-soluble dye dissolved in a nonaqueous base fluid to said test sample; and determining the configuration of the dye solution after a period of time on a surface of the test sample, wherein a configuration of the dye solution forming a ring around the perimeter of the sample container at the interface of a wall of the sample container and the turbid brine indicates an emulsion is present in the turbid brine, and wherein a configuration of the dye solution forming a single dot or a plurality of dots on the surface of the turbid brine indicates an emulsion is not present in the turbid brine.

Abstract: A process that includes pumping a first wellbore fluid comprising an oxidative degradable polymer into a wellbore through a subterranean formation; pumping a second wellbore fluid comprising a pH-activated oxidative breaker into the wellbore; pumping a third wellbore fluid comprising a delayed acid source into the wellbore; and allowing the delayed acid source to acidify at least a portion of the wellbore to a pH of less than 7 so as to activate the pH-activated oxidative breaker at the lower pH and degrade the oxidative degradable polymers is disclosed.

Abstract: Disclosed herein is an indicator precursor composition for determining the hardness of a wellbore fluid filtrate, where the composition includes a colorimetric indicator and a buffer, where the buffer may include a salt of a weak acid and a strong base, and where the indicator precursor may be a dry solid. Also disclosed is a method for determining the hardness of a wellbore fluid filtrate.

Abstract: An oil-in-water emulsion that includes a brine continuous phase; and an oleaginous discontinuous phase stabilized by an emulsifier blend, the emulsifier blend comprising: an emulsifier having an HLB greater than 11; and an amphoteric chemotrope is disclosed. Emulsifier blends comprising an emulsifier having an HLB greater than 11 and an amphoteric chemotrope and methods of using emulsifier blends are also disclosed.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: A method of reducing fluid loss from a wellbore that includes emplacing a fluid loss pill in the wellbore, the fluid loss pill comprising: a base fluid; a hydratable or solvatable synthetic copolymer having at least one crosslinkable comonomer; and a crosslinking agent is disclosed.

Abstract: The instant disclosure is directed to a method of detecting an emulsion in a turbid brine, the method comprising the steps of disposing an aliquot of the turbid brine into a sample container to produce a test sample; adding one or more drops of a dye solution comprising an oil-soluble dye dissolved in a nonaqueous base fluid to said test sample; and determining the configuration of the dye solution after a period of time on a surface of the test sample, wherein a configuration of the dye solution forming a ring around the perimeter of the sample container at the interface of a wall of the sample container and the turbid brine indicates an emulsion is present in the turbid brine, and wherein a configuration of the dye solution forming a single dot or a plurality of dots on the surface of the turbid brine indicates an emulsion is not present in the turbid brine.

Abstract: A method of treating a well that includes selectively emplacing a fluid loss pill into the well, wherein the fluid loss pill includes at least one of diethylene glycol, triethylene glycol, and tetraethylene glycol, and wherein the at least one of diethylene glycol, triethylene glycol, and tetraethylene glycol reacts with a calcium brine present in the well to form a plug is disclosed.

Abstract: A method of preventing fluid loss to a wellbore that includes pumping a wellbore fluid into the wellbore through a subterranean formation, the wellbore fluid comprising: a base fluid; and a plurality of particulate bridging agents comprising a solid breaking agent encapsulated by one of an inorganic solid material and an oil-soluble resin; and allowing some filtration of the wellbore fluid into the subterranean formation to produce a filter cake comprising the particulate bridging agents is disclosed.

Abstract: Disclosed herein is an indicator precursor composition for determining the hardness of a wellbore fluid filtrate comprises a colorimetric indicator and a buffer comprising a salt of a weak acid and a strong base, wherein the indicator precursor composition is a dry solid. Also disclosed is a method to determine the hardness of a wellbore fluid filtrate.

Abstract: A method of retarding the flow of water in a subterranean formation that includes injecting a gelling pill into the formation, the gelling pill comprising: brine; a crosslinkable polymer; and a crosslinkant; and allowing the crosslinkable polymer to crosslink to form a gel in the subterranean formation is disclosed. A water absorbing polymer is optionally included.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: An oil-in-water emulsion that includes a brine continuous phase; and an oleaginous discontinuous phase stabilized by an emulsifier blend, the emulsifier blend comprising: an emulsifier having an HLB greater than 11; and an amphoteric chemotrope is disclosed.

Abstract: A method of analyzing a wellbore fluid that includes treating a wellbore fluid with an emulsifying fluid, the emulsifying fluid comprising: a hydroxylated ether; an amphoteric chemotrope; and testing the treated wellbore fluid for at least one of turbidity and total suspended solids is disclosed. Methods of cleaning wellbores are also disclosed.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: A process that includes pumping a first wellbore fluid comprising an oxidative degradable polymer into a wellbore through a subterranean formation; pumping a second wellbore fluid comprising a pH-activated oxidative breaker into the wellbore; pumping a third wellbore fluid comprising a delayed acid source into the wellbore; and allowing the delayed acid source to acidify at least a portion of the wellbore to a pH of less than 7 so as to activate the pH-activated oxidative breaker at the lower pH and degrade the oxidative degradable polymers is disclosed.