A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore in the subterranean geological formation thereby producing a formation fluid. The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid includes 0.05 to 1 wt. % of a rhamnolipid surfactant based on a total weight of the drilling fluid. The drilling fluid includes an invert emulsion including a continuous phase and a dispersive phase including water.

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 which includes a continuous phase including mineral 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.

A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore in the subterranean geological formation thereby producing a formation fluid. The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid includes 1 to 3 wt. % of a weighting agent which includes hydrophobic metallic zinc nanoparticles including a metallic core and organic ligands present on a surface of the metallic core, based on a total weight of the drilling fluid. The drilling fluid includes an invert emulsion including a continuous phase and a dispersive phase including water.

An aqueous solution is disclosed including water, an acid, a nitrogen-containing compound, and a functionalizing agent (FA), which can be a ketone, diketone, aldehyde, dialdehyde, organic acid, and combinations thereof. An additional aqueous solution is disclosed including water, an acid, and an acid neutralizing agent which can be a reaction product of at least a portion of the nitrogen-containing compound and the functionalizing agent. Methods of treating a formation are also disclosed including treating a formation fluidly coupled to a wellbore with an oilfield treatment fluid comprising either or both of the aqueous solutions.

This invention provides a composition comprising I. at least one reaction product between a nitrogen-free monohydric alcohol and an aldehyde or ketone, and II. at least one reaction product between a monosaccharide having 3 to 6 carbon atoms and/or an oligosaccharide being formed by oligomerization of monosaccharides having 3 to 6 carbon atoms and an aldehyde or ketone, and optionally III. at least one reaction product from III.a) formaldehyde, and III.b) an amine, selected from the group consisting of primary alkyl amines having 1 to 4 carbon atoms, and primary hydroxy alkyl amines having 2 to 4 carbon atoms, and optionally IV. at least one solid suppression agent selected from the group consisting of IV(a). alkali or alkaline earth metal hydroxides IV(b). mono-, di- or tri-hydroxy alkyl, aryl or alkylaryl amines, IV(c). mono-, di- or tri-alkyl, aryl or alkylaryl primary, secondary and tertiary amines or IV(d). multifunctional amines and IV(e). mixtures of compounds of groups IV(a) to IV(c). wherein alkyl is C.sub.1 to C.sub.15, aryl is C.sub.6 to C.sub.15 and alkylaryl is C.sub.7 to C.sub.15.

Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. Also disclosed are methods of manufacturing the corrosion inhibitors compositions. The corrosion inhibitor compositions include the reaction product of a dicarbonyl compound with thioglycolic acid. The compositions may include other components, such as a solvent, a hydrogen sulfide scavenger, or a biocide.

A method of removing a sulfate scale from a surface is provided. The method includes contacting the sulfate-comprising scale with a conversion solution including 1 to 10 wt. % of an alkali metal carbonate, 0.5 to 10 wt. % of a borate salt or hydrate thereof, and 0.5 to 2.5 wt. % of a base to produce a carbonate-comprising scale. The method further includes exposing the carbonate-comprising scale with an acid solution including 2.5 to 25 wt. % of an acid.

A modified drilling mud includes a drilling mud selected from a group consisting of water-based mud (WBM), oil-based mud (OBM) and synthetic-based mud (SBM), and a liquid treatment composition including water and collectively 35-55 weight percent of one or more hydroxide compounds, wherein a ratio of the liquid treatment composition to the drilling mud in the modified drilling mud is in a range of 10 gallons of the liquid treatment composition per 42,000 gallons of drilling mud to 100 gallons of the liquid treatment composition per 42,000 gallons of drilling mud.

Nano-sized mixed metal oxide carriers capable of delivering a well treatment additive for a sustained or extended period of time in the environment of use, methods of making the nanoparticles, and uses thereof are described herein. The nanoparticles can have a formula of:
A/[M.sub.x.sup.1M.sub.y.sup.2M.sub.z.sup.3]O.sub.nH.sub.m
where x is 0.03 to 3, y is 0.01 to 0.4, z is 0.01 to 0.4 and n and m are determined by the oxidation states of the other elements, and M.sup.1 can be aluminum (Al), gallium (Ga), indium (In), or thallium (Tl). M.sup.2 and M.sup.3 are not the same and can be a Column 2 metal, Column 14 metal, or a transition metal. A is can be a treatment additive.

A method of treating a fluid, which method includes the steps of: (a) contacting a fluid containing at least one sulfide with a sulfide-reducing amount of a composition comprising an lignocellulosic liquor comprising one or more lignin-derived compounds and one or more hemicellulose sugar monomers and/or oligomers and (b) allowing the lignocellulosic liquor to react with at least a portion of the sulfide in the fluid.