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Tight gas is the term commonly used to refer to low-permeability reservoirs that produce mainly dry natural gas. Tight gas reservoirs have one thing in common—a vertical well drilled and completed in a tight gas reservoir must be successfully stimulated to produce at commercial gas flow rates and produce commercial gas volumes. Normally, a large hydraulic fracturing treatment is required to produce gas economically. In some naturally fractured tight gas reservoirs, horizontal wells and/or multilateral wells can provide the stimulation required for commerciality.

To optimize the development of a tight gas reservoir, the geoscientists and engineers must optimize the number of wells drilled, as well as the drilling and completion procedures for each well. Often, more data and more engineering manpower are required to understand and develop tight gas reservoirs than are required for higher-permeability, conventional reservoirs. On an individual-well basis, a well in a tight gas reservoir will produce less gas over a longer period of time than one expects from a well completed in a higher-permeability, conventional reservoir. As such, many more wells must be drilled (or smaller well spacing must be attained) in a tight gas reservoir to recover a large percentage of the original gas-in-place (OGIP) when compared to a conventional reservoir.

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