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.

A method of controlling lost circulation includes introducing into a wellbore a lost circulation fluid comprising: an external oil phase, an internal aqueous phase, an emulsifier, a wetting agent, a magnesia sealant, and a; retarder; contacting the lost circulation fluid with a lost circulation zone; and forming a plug adjacent the lost circulation zone by reacting the magnesia sealant with water at a wellbore temperature, thereby reducing fluid loss into the lost circulation zone.

A method of reducing a density of a density of a stable emulsion drilling fluid may comprise providing a stable emulsion drilling fluid comprising: an aqueous liquid; a biopolymer; an emulsifier; solid particulates; and an oil; wherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 70° F. and atmospheric pressure without phase separation for about 8 hours or longer; circulating the stable emulsion drilling fluid though a drill string and annulus; adding additional oil to the stable emulsion drilling fluid to decrease the density of the stable emulsion drilling fluid and produce a reduced density stable emulsion drilling fluid; and circulating the reduced density stable emulsion drilling fluid though the drill string and the annulus.

A method of reducing a density of a density of a stable emulsion drilling fluid may comprise providing a stable emulsion drilling fluid comprising: an aqueous liquid; a biopolymer; an emulsifier; solid particulates; and an oil; wherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 70° F. and atmospheric pressure without phase separation for about 8 hours or longer; circulating the stable emulsion drilling fluid though a drill string and annulus; adding additional oil to the stable emulsion drilling fluid to decrease the density of the stable emulsion drilling fluid and produce a reduced density stable emulsion drilling fluid; and circulating the reduced density stable emulsion drilling fluid though the drill string and the annulus.

A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore into the subterranean geological formation thereby producing a formation fluid including hydrogen sulfide (H.sub.2S). The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid composition includes 0.25 to 2 wt.% of a primary H.sub.2S scavenger which is potassium permanganate. The drilling fluid composition includes an invert emulsion includes a continuous phase including palm oil and a dispersive phase including water. The potassium permanganate present in the drilling fluid composition reacts with the H.sub.2S present in the formation fluid to produce a dispersion of manganese-containing particles which are at least one selected from the group consisting of manganese sulfide and manganese sulfate.

The present invention addresses to a wireline logging method using an aqueous based drilling fluid with xanthan gum and polyols in order to improve the quality of the acquisition of geological data from wireline logging (final logging) in open hole and reducing the risk of the tool getting stuck. It can also be applied in well control situations and used in the integral drilling of the reservoir, but with different application bias of the multifunctional fluid.

Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, one or more ethoxylated amine compounds and optionally, one or more organic or inorganic salts. The emulsions are particularly suitable for use in harsh brine conditions.

Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, one or more ethoxylated amine compounds and optionally, one or more organic or inorganic salts. The emulsions are particularly suitable for use in harsh brine conditions.

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, wherein the particulate material comprises sand, and the macromolecular surfactant comprises a hydrophobically modified polyethyleneimine, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, wherein the particulate material comprises sand, and the macromolecular surfactant comprises a hydrophobically modified polyethyleneimine, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.