A method comprises obtaining or providing a treatment fluid comprising compounds comprising a structure of the formula (I) or (Ia) or compounds of the formula (Ib) and placing the treatment fluid in a subterranean formation.

Various embodiments disclosed relate to guanidine- or guanidinium-containing clay or shale stabilizers for treatment of subterranean formations, in various embodiments, the present invention provides a method of treating a subterranean formation that can include placing a composition including a clay or shale stabilizer including at least one of a substituted guanidine group and a substituted guanidinium group in a subterranean formation.

Various embodiments disclosed relate to methods of treating a subterranean formations that provide enhanced fracture conductivity over other methods. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a tackifier. The composition can have a viscosity less than about 20 cP. The method can include placing the composition in a subterranean formation downhole. The method can also include fracturing the subterranean formation with the composition.

Methods for treating subterranean formations are provided. The method includes contacting the formation with a fluid composition containing a porous metal-organic framework that contains at least one metal ion and an organic ligand. The organic ligand is at least bidentate and bonded to the metal ion. Pores in the framework are at least partially occupied by one or more additives.

The invention provides a process for making compounds according to Formula I: ##STR00001##
where R.sup.1, R.sup.1a, R.sup.2, R.sup.2a, R.sup.3 and R.sup.3a are defined as set forth in the specification. Formula I compounds are useful as chelants and stabilizers of cations in aqueous media and the invention therefore provides a method for using the compounds in the treatment of subterranean formations, such as in acidizing operations.

Various embodiments disclosed relate to clay stabilizers. In various embodiments, the present invention provides a method of treating a subterranean formation, including obtaining or providing a composition including a clay stabilizer having the structure YR.sup.1(OR.sup.2).sub.xY. The variable R.sup.1 can be a substituted or unsubstituted (C.sub.1-C.sub.20)hydrocarbylene. At each occurrence, R.sup.2 can independently be a substituted or unsubstituted (C.sub.1-C.sub.20)hydrocarbylene. At each occurrence, Y can be independently selected from a substituted or unsubstituted amino group, a substituted or unsubstituted ammonium group, a nitro group, a substituted or unsubstituted amine oxide group, and a substituted or unsubstituted (C.sub.1-C.sub.20)hydrocarbyloxy group, wherein at least one terminal group Y is a substituted amino group, a substituted or unsubstituted ammonium group, a substituted or unsubstituted amine oxide group, or a nitro group. The variable x can be an integer between 1 and 200,000. The method also includes placing the composition in a subterranean formation.

High density brine compositions may be formulated including water and at least one rare earth nitrate salt, where the at least one rare earth salt is present in an amount effective for the high density brine composition to have a density in the range of about 8.5 to about 21 pounds per gallon (about 1020 to about 2500 kg/m.sup.3). Suitable rare earth nitrate salts include, but are not necessarily limited to, lanthanum nitrate (La(NO.sub.3).sub.3), cerium nitrate (Ce(NO.sub.3).sub.3), scandium nitrate, and/or yttrium nitrate. Alkaline earth metal salts such as, but not limited to, calcium bromide (CaBr.sub.2), and alkali metal salts and metal salts may also be used with the rare earth nitrate salt(s). In one non-limiting embodiment the high density brines have an absence of zinc and cesium salts. These high density brine compositions may be suitably used for completion fluids in hydrocarbon recovery operations.

Disclosed herein are cementitious compositions comprising a non-aqueous fluid and an alkali-activated material. The non-aqueous fluid can include a natural oil, a synthetically derived oil, one or more surfactants, or a combination thereof. In some embodiments, the non-aqueous fluid can include an oil based mud, a synthetic based mud, or a mixture thereof. The alkali-activated material in the cementitious composition can be derived from an aluminosilicate material and an alkaline activator. In some embodiments, the aluminosilicate material includes fly ash. The alkaline activator can be selected from an alkali-hydroxide, an alkali-silicate, an alkali carbonate, an alkali bicarbonate, an alkali sulfate, and a mixture thereof. Wellbore servicing composition, such as compositions to reduce lost circulation of drilling fluids or cement a casing into the borehole, comprising the cementitious compositions are also disclosed. Methods for preparing and using the cementitious compositions are also disclosed.

A synthetic acid composition for use in oil industry activities, said composition comprising: urea and hydrogen chloride in a molar ratio of not less than 0.1:1; a metal iodide or iodate; an alcohol or derivative thereof. Optionally, formic acid or a derivative thereof; propylene glycol or a derivative thereof, ethylene glycol glycerol or a mixture thereof; cinnamaldehyde or a derivative thereof; and a phosphonic acid derivative can be added to the composition.

Water in oil emulsion drilling and well treatment fluids comprising an ester of trimer fatty acids and polyoxyethyiene glycol, the polyoxyethyiene glycol having average molecular weight from about (150) to about (600) and the trimer acids having at least about 20% of carboxyl acid groups esterified, as rheology modifier.