The present invention refers to a method for removing fouling in carbonate reservoirs and/or depleted reservoirs by adding carbon dioxide to industrial or desulphated water to produce carbonic acid, in producing well stimulation operations, to be used as a weak acid for removing fouling in remote operation aiming at keeping the productivity of producing wells and lessening the need for remote operations with stimulation vessel, and therefore reducing operating costs.

The present invention refers to a method for removing fouling in carbonate reservoirs and/or depleted reservoirs by adding carbon dioxide to industrial or desulphated water to produce carbonic acid, in producing well stimulation operations, to be used as a weak acid for removing fouling in remote operation aiming at keeping the productivity of producing wells and lessening the need for remote operations with stimulation vessel, and therefore reducing operating costs.

Dual cation hydrate inhibitor compositions and methods of using such compositions to, for example, inhibit the formation of gas hydrate agglomerates are provided. In some embodiments, such methods include introducing a hydrate inhibitor composition into a fluid, wherein the hydrate inhibitor composition includes at least one compound having the structural formula: ##STR00001##
wherein each of R.sup.1, R.sup.2, and R.sup.3 is independently a C.sub.1 to C.sub.6 hydrocarbon chain, wherein R.sup.4 is selected from the group consisting of hydrogen and any C.sub.1 to C.sub.50 hydrocarbon chain, wherein each of R.sup.5 and R.sup.6 is independently selected from the group consisting of hydrogen and a C.sub.1 to C.sub.50 hydrocarbon chain, wherein X.sup.− and Y.sup.− are counter anions, and wherein each of a and b is independently an integer from 1 to 10.

A wellhead system includes a wellhead, a fluid line extending from the wellhead, a branch line fluidly connected to the fluid line at an inlet and at an outlet, an ejector device arranged on the branch line, a tank fluidly connected by a tank fluid line to the ejector device, and a pressure control valve arranged on the branch line upstream of the ejector device. The ejector device is configured to produce a mixture that includes the fluid from the wellhead flowing in the branch fluid line with a chemical flowing the tank fluid line. The ejector device is also configured to discharge the mixture downstream of the ejector device. The pressure control valve is configured to control the flow of a fluid entering the ejector device.

A wellhead system includes a wellhead, a fluid line extending from the wellhead, a branch line fluidly connected to the fluid line at an inlet and at an outlet, an ejector device arranged on the branch line, a tank fluidly connected by a tank fluid line to the ejector device, and a pressure control valve arranged on the branch line upstream of the ejector device. The ejector device is configured to produce a mixture that includes the fluid from the wellhead flowing in the branch fluid line with a chemical flowing the tank fluid line. The ejector device is also configured to discharge the mixture downstream of the ejector device. The pressure control valve is configured to control the flow of a fluid entering the ejector device.

A superior EUR additive that improves proppant placements and enhances flow capacity through a proppant pack to maximize EUR of hydrocarbons from unconventional shale wells

A superior EUR additive that improves proppant placements and enhances flow capacity through a proppant pack to maximize EUR of hydrocarbons from unconventional shale wells

Methods can include introducing a cleaning fluid into a near-wellbore zone of an injection well penetrating a subterranean formation, wherein the cleaning fluid includes: 0.5 wt % to about 5 wt % of a surfactant blend comprising an alkoxy carbonate surfactant and an internal olefin sulfonate surfactant; salt water having a total dissolved solids (TDS) of about 15,000 mg/L or greater; and 0 wt % to about 0.05 wt % of an organic acid; and dispersing a hydrocarbon from the near-wellbore zone in the cleaning fluid. Compositions for cleaning a near-wellbore zone of a subterranean formation can include 0.5 wt % to about 5 wt % of a surfactant blend comprising an alkoxy carbonate surfactant and an internal olefin sulfonate surfactant; salt water having a total dissolved solids (TDS) of about 15,000 mg/L or greater; and 0 wt % to about 0.05 wt % of an organic acid.

Methods can include introducing a cleaning fluid into a near-wellbore zone of an injection well penetrating a subterranean formation, wherein the cleaning fluid includes: 0.5 wt % to about 5 wt % of a surfactant blend comprising an alkoxy carbonate surfactant and an internal olefin sulfonate surfactant; salt water having a total dissolved solids (TDS) of about 15,000 mg/L or greater; and 0 wt % to about 0.05 wt % of an organic acid; and dispersing a hydrocarbon from the near-wellbore zone in the cleaning fluid. Compositions for cleaning a near-wellbore zone of a subterranean formation can include 0.5 wt % to about 5 wt % of a surfactant blend comprising an alkoxy carbonate surfactant and an internal olefin sulfonate surfactant; salt water having a total dissolved solids (TDS) of about 15,000 mg/L or greater; and 0 wt % to about 0.05 wt % of an organic acid.

A breaker composition comprising (i) a first acid precursor, (ii) a second acid precursor and (iii) an aqueous fluid wherein the first acid precursor has an effective operating temperature of from about 15° C. to about 120° C. and the second acid precursor has an effective operating temperature of from about 30° C. to about 180° C.