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Methods according to the present disclosure are typically useful, for example, for increasing the productivity of oil and/or gas wells that have brine and liquid hydrocarbons present in a near well bore region of a hydrocarbon-bearing formation. 57The term "productivity" as applied to a well refers to the capacity of a well to produce hydrocarbons (i.e., the ratio of the hydrocarbon flow rate to the pressure drop, where the pressure drop is the difference between the average reservoir pressure and the flowing bottom hole well pressure (i.e., flow per unit of driving force)). 58The brine present in the formation may be from a variety of sources including at least one of connate water, flowing water, mobile water, immobile water, residual water from a fracturing operation or from other downhole fluids, or crossflow water (e.g., water from adjacent perforated formations or adjacent layers in the formation). 59In some embodiments, the brine is connate water. 60In some embodiments, the brine causes water blocking (i.e., declining productivity resulting from increasing water saturation in a well). 61The liquid hydrocarbons in the hydrocarbon-bearing formation may be, for example, at least one of retrograde gas condensate or oil and may comprise, for example, at least one of methane, ethane, propane, butane, pentane, hexane, heptane, octane, nonane, decane, or higher hydrocarbons.