Drilling fluid compositions include invert emulsion fluids having an oleaginous phase, an aqueous phase, and an emulsifier composition that includes an ethoxylated alcohol compound and a polyaminated fatty acid compound. The ethoxylated alcohol compound has the formula R.sup.1—(OCH.sub.2CH.sub.2).sub.n—OH, where R.sup.1 is a hydrocarbyl group having from 8 to 22 carbon atoms and n is from 1 to 8. The ethoxylated alcohol compound has a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6. The polyaminated fatty acid compound has the formula R.sup.2—CO—NH—CH.sub.2—CH.sub.2—N(COR.sup.2)—CH.sub.2—CH.sub.2—NH—CO—R.sup.3, where R.sup.2 is a hydrocarbyl group having from 1 to 20 carbon atoms and R.sup.3 is a hydrocarbyl group having from 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R.sup.4—COOH, where R.sup.4 is a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms. Methods of drilling wells include operating a drill in a wellbore in the presence of drilling fluid compositions.

Embodiments of the invention relate to an oil recovery medium for injection into a ground hole in a ground comprising oil, a method of recovering oil from a reservoir utilizing the oil recovery medium, an arrangement for recovering oil from a reservoir, and a method of using an oil recovery medium or an arrangement for recovering oil from a reservoir. The oil recovery medium for injection into a ground hole in a ground comprising oil comprises a base liquid and potassium carbonate.

A subterranean product extraction composition may include a borehole fluid that may include a thiamine based shale inhibitor active to inhibit reactivity of a formation shale to a base fluid of a borehole fluid. A method of extracting a subterranean product via a borehole may include providing a borehole fluid containing a thiamine-based shale inhibitor and inhibiting reactivity of a formation shale contacted with the borehole fluid. A system for extracting a subterranean product via a borehole may include a tubular having an end in proximity to a formation shale and in fluid communication with a container dispensing a borehole fluid containing a thiamine-based shale inhibitor. The thiamine-based shale inhibitor is inert to the borehole fluid and has superior activity as compared to potassium chloride to inhibit shale reactivity. The borehole fluid may be a drilling fluid. The base fluid may be water.

The present invention relates to a method to form or obtain a high performance aqueous phase polymer fluid, which is a seawater-based drilling fluid for well drilling in low gradient formations. It is formulated based on liquid state polymer chemical products, easy to aggregate, and quickly mixed; a preparation and homogenization process that reduces preparation times, designed to drill hydrocarbon-producing deposits, focusing on minimizing damages to the producing formations, with a high rate of circulation loss in naturally fractured deposits. The system is environmentally-friendly, it complies with the main functions required of drilling fluids, while also providing a high inhibition control by swelling and dispersion of clay zones, due to the polymeric nature of the materials with which it is formulated. It is a fluid that does not contain solids in its formulation and provides an excellent transport and cleaning of drilling shears in the well.

Some embodiments described herein relate to methods comprising providing a proposed invert emulsion formulation, wherein the proposed invert emulsion formulation comprises an oil phase, an aqueous phase, and a particulates fraction comprising a first sub-fraction and a second sub-fraction, wherein the first sub-fraction comprises high-gravity particulates and the second sub-fraction comprises low-gravity particulates; calculating an initial associative stability value of the proposed invert emulsion based on the degree of association between the aqueous phase and the particulates fraction comprising both the first sub-fraction and the second sub-fraction; manipulating the proposed invert emulsion based on the initial associative stability value so as to produce an associatively stable invert emulsion having a final associative stability value in the range of between about 50% and about 100%; and introducing the associatively stable invert emulsion into a subterranean formation.

A method for improving the performance of hydraulic fracturing processes in oil production fields wherein modifiable coated proppants used in the fracturing fluid are produced on a well-site. Various types of coated proppants may be produced based on real-time, down-hole information obtained and utilized at the well-site.

Clay stabilization compositions include one or a plurality of triamino compounds and/or derivatives thereof, fluids containing an effective amount of the clay stabilization compositions and methods for making and using same.

The present invention refers to a composition for water-based foamed fluid with high thermal stability for drilling depressed areas in oil and gas wells, comprising: i) a base fluid or drilling water consisting of fresh water; ii) a stabilizing agent; ii) a viscosifying agent; iv) a filtering reducing agent; v) a clay inhibiting agent; vi) an alkalizing agent and acid gas sequestering agent; vii) a thermal stabilizing agent; and viii) a foaming agent. Also, the present invention refers to a system that uses said composition for fluid and water-based foamed fluid with high thermal stability, the method of preparing the composition for fluid, the method of preparing the fluid and application of the composition and fluid in a water-based foamed fluid system with high thermal stability for drilling depressed or low-pressure areas in oil and gas wells.

Disclosed herein are compositions and methods for increasing recovery, or flowback, of hydrocarbon compounds from hydrocarbon-containing subterranean fractured rock formations (tight shale reservoirs). The flowback compositions include an anionic dimer surfactant, an anionic monomer surfactant, and a demulsifier. The flowback compositions convert oil-wet rocks to water-wet, yet exhibit a low tendency of composition components to sorb to the rock. The flowback compositions do not cause formation of emulsions with hydrocarbon compounds within the subterranean fractured rock formations. The flowback composition are useful for increasing the yield of hydrocarbons recovered from tight shale reservoirs.

A method of detecting an amine-based additive in a wellbore servicing fluid (WSF) comprising contacting an aliquot of WSF with an amine detector compound and an aqueous salt solution to form a detection solution; wherein the aqueous salt solution comprises an inorganic salt and organic carboxylate salt; wherein the WSF comprises the amine-based additive; and wherein the detection solution is characterized by at least one absorption peak wavelength in the range of 380-760 nm; detecting an absorption intensity for detection solution at a wavelength within about ±20% of the at least one absorption peak wavelength; comparing the absorption intensity of detection solution at the wavelength within about ±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.