A method of detecting an amine-based additive in wellbore servicing fluid (WSF) comprising contacting an aliquot of WSF with an amine detector reagent and aqueous medium to form a detection solution; wherein the amine detector reagent comprises an amine detector compound, and a polar organic solvent (POS) with flash point >105° C.; wherein the WSF comprises the amine-based additive; and wherein the detection solution is characterized by at least one absorption peak wavelength in 380-760 nm; detecting an absorption intensity for detection solution at a wavelength within ±20% of the at least one absorption peak wavelength; comparing the absorption intensity of detection solution at the wavelength within ±20% of the at least one absorption peak wavelength with a target absorption intensity of amine-based additive to determine the amount of amine-based additive in WSF; and comparing the amount of amine-based additive in WSF with a target amount of amine-based additive.

Methods of treating a subterranean formation are described. The methods include introducing a treatment fluid that includes a friction reducing polymer (e.g., a cationic friction reducing polymer) into the subterranean formation. The cationic friction reducing polymer is allowed to degrade and release choline chloride or polyDADMAC, which can each act as a clay stabilizer.

Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that includes an aqueous base fluid, one or more drilling fluid additives, and an anti-bit balling additive where the anti-bit balling additive comprises a C.sub.15-C.sub.18 alkene or a mixture of two or more C.sub.15-C.sub.18 alkenes. Methods for using the drilling fluid compositions may further include mixing the mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes a C.sub.15-C.sub.18 alkene or a mixture of two or more C.sub.15-C.sub.18 alkenes, and introducing the drilling fluid to a subterranean formation.

The provided method allows optimizing the fracturing design (frac design) while taking into account the two-dimensional modelling of the transport processes in the fracture. The generation of the fracturing design in a well comprises the steps of: obtaining data on hydraulic fracturing including the proppant pumping schedule and the fibre pumping schedule for various types of fibres; generating a degradation matrix for the various types of fibres; generating possible options of the hydraulic fracturing operation according to the fibre type and pumping schedule. Moreover, the method of hydraulic fracturing, which comprises generating a schedule of fracturing in a well, preparing a fracturing fluid containing carrier fluid, proppant, additives, and fibres, and pumping the fracturing fluid into the formation through the well following the selected (optimal) option of the fracturing operation, is provided.

A preparation method of an ionic liquid shale inhibitor for drilling fluid comprises the following step: subjecting the imidazole-based ionic liquid to a polymerization reaction in water environment under an inert atmosphere, and the produced polymer is used as an ionic liquid shale inhibitor for drilling fluid. The ionic liquid shale inhibitor for drilling fluid has the advantages of desirable inhibition effect, good compatibility, strong high-temperature resistance, simple preparation method and low cost.

Compositions and methods comprising certain microemulsions and certain clay control additives for enhancing clay swelling protection and persistency in treating swelling clay of a subterranean formation of oil and/or gas wells are generally provided. The combination of certain microemulsions and certain clay control additives exhibit synergistic effects by enhancing clay swelling protection and persistency in treating swelling clay. The well treatment composition may use up to four times less concentration of clay control additive compared to using the same clay control additive alone, while still providing the same, similar, or higher degree of clay swelling protection and enhanced persistency. The microemulsion and the clay control additive may be added to a carrier fluid to form the well treatment composition, which is injected into the subterranean formation to provide enhanced clay swelling protection and persistency of continuing to provide clay swelling protection for a longer period of time during flowback.

Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

A quaternary amine composition selected from the group consisting of Formula I, Formula II, Formula III, and combinations of the same. A method of synthesizing a quaternary amine composition comprising the steps of reacting an alkoxylated dimer diamine with a methyl halogen, where the methyl halogen is selected from the group consisting of methyl chloride, methyl iodine, and combinations of the same; and allowing the reaction to proceed to produce the quaternary amine composition, the quaternary amine composition selected from the group consisting of Formula I, Formula II, Formula III, and combinations of the same. A method of treating a well comprising the steps of introducing an additive-containing well fluid to a well, where the additive-containing well fluid comprises a quaternary amine composition and a well fluid, allowing the additive-containing well fluid to interact with the well, and treating the well with the additive-containing fluid.

In one embodiment, a retarded acid system comprises an aqueous acid and a retarding surfactant. The aqueous acid may comprise from 5 wt. % to 25 wt. % of a strong acid, that is, an acid having a K.sub.a greater than or equal to 0.01. The aqueous acid may further comprise from 75 wt. % to 95 wt. % water. The retarding surfactant may have the general chemical formula R—(OC.sub.2H.sub.4).sub.X—OH where R is a hydrocarbon having from 11 to 15 carbon atoms and x is an integer from 6 to 10. The retarding surfactant may have a hydrophilic-lipophilic balance from 8 to 16.

Solid shale inhibitor additives and methods of using such additives to, for example, inhibit shale are provided. In some embodiments, such methods include providing an aqueous treatment fluid that includes an aqueous base fluid and a solid shale inhibitor additive, the solid shale inhibitor additive including carrier particles and a treatment composition that includes a shale inhibitor; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.