448 results about "Fluid density" patented technology

A blending apparatus for blending a first fluid stream having a first density and a second fluid stream having a second fluid density, the first density being greater than said second density, is discussed. The apparatus includes a first fluid director including a plurality of baffles affixed therein to create turbulence and shear in the first fluid, a cylindrical second fluid director, a primary mixing chamber receiving the first sheared fluid from the first fluid director and receiving the second fluid from the second fluid director, wherein the first fluid and second fluid are mixed in the primary mixing chamber to form a mixed primary fluid stream, and a secondary blending chamber comprising at least one static mixer and coaxially aligned with and receiving the mixed primary fluid stream from the primary mixing chamber.

Subsurface wellbore conditions are measured directly in the wellbore while the fluid circulation system is not pumping. The measured values are recorded at the subsurface location and subsequently transmitted to the well surface when circulation is resumed using fluid pulse telemetry (FPT). Real-time measurements made when the fluids are circulating are transmitted real time using FPT. Axially spaced measurements are used to obtain differential values. The apparatus of the invention comprises an assembly carried by a drill string that is used to selectively isolate the area within the well that is to be evaluated. The apparatus includes an assembly having axially spaced inflatable well packers that are used to isolate an uncased section of the wellbore. The apparatus is equipped with self-contained measuring and recording equipment, a fluid receiving reservoir, circulation valving, measurement while drilling equipment, and automated controls. Measurements are made while the circulation is terminated or while the well packers are being used to isolate an area of the wellbore from the circulating fluid. The method is used to directly measure and evaluate conditions caused by pumping and drill string movement, such as swab and surge pressures. Other conditions such as the formation strength, formation pressure, the fluid density, and other subsurface conditions related to the well are also measured.

A method of hydraulically fracturing a hydrocarbon-bearing subterranean formation ensures that the conductivity of water inflow below the productive zone of the subterranean formation is reduced. The method consists of two principal steps. In the first step, a fracture in and below the productive zone of the formation is initiated by introducing into the subterranean formation a fluid, free of a proppant, such as salt water, fresh water, brine, liquid hydrocarbon, and / or nitrogen or other gases. The proppant-free fluid may further be weighted. In the second step, a proppant laden slurry is introduced into the subterranean formation which contains a relatively lightweight density proppant. Either the fluid density of the proppant-free fluid is greater than the fluid density of the proppant laden slurry or the viscosity of the proppant-free fluid is greater than the viscosity of the proppant laden slurry. The method limits undesirable fracture height growth in the hydrocarbon-bearing subterranean formation during the fracturing.

Methods and apparatus for measuring density of a fluid. The apparatus includes a shaft adapted to be positioned within a fluid and a biased float disposed on the shaft and capable of movement along the shaft. The apparatus further includes a displacement sensor for detecting a position of the float along the shaft. A method of sensing the density includes positioning the biased float in the fluid and sensing the position of the float to obtain data representative of the density of the fluid.