دیکشنری تخصصی مهندسی نفت - نسخه آنلاین

n: the value obtained when the absolute dynamic viscosity is divided by the density (expressed in grams per cubic centimetre) of the liquid at the temperature concerned.

n: the maximum flow rate that a well could theoretically deliver with zero pressure at the face of the reservoir.

the maximum rate that a well can produce at the lowest possible bottom hole pressure.

the theoretical maximum flow that a well could deliver with a zero backpressure at the middle of the perforations.

n: the theory that minerals such as oil and gas are fully owned in place before they are extracted and reduced to possession. Despite this theory, title to oil and gas may be lost by legitimate drainage and by the rule of capture. Also called ownership in place. See rule of capture.

n: a measure of the ability of a single fluid (such as water, gas, or oil) to flow through a rock formation when the formation is totally filled (saturated) with that fluid. The permeability measure of a rock filled with a single fluid is different from the permeability measure of the same rock filled with two or more fluids. Compare effective permeability, relative permeability.

permeability to a single phase fluid in a cleaned core.

n: the percentage of the total bulk volume of a rock sample that is composed of pore spaces or voids. See porosity.

the percentage of the total bulk volume that is pore spaces, voids or fractures.

n: total pressure measured from an absolute vacuum. It equals the sum of the gauge pressure and the atmospheric pressure. Expressed in pounds per square inch.

the reading of gauge pressure plus the atmospheric pressure.

temperature measurement starting at absolute zero (total absence of heat).