332results about "Specific gravity by measuring pressure differences" patented technology

Embodiments of the present invention generally provide methods, apparatus, and systems for determining void fractions of individual phase components of a multiphase mixture. The void fractions may be determined based on measured parameters of the mixture as a whole, such as differential pressure, bulk velocity of the mixture and speed of sound in the mixture. According to some embodiments, the mixture parameters may be measured using non-intrusive fiber optic based sensors. Various other parameters may also be derived from the void fractions, such as individual phase flow rates, liquid holdup and watercut parameters (for oil and gas mixtures).

A flow meter obtains the individual flow rates of gas, liquid hydrocarbons, and water in a predominantly gas-containing flowing fluid mixture. The flow meter comprises a water content meter (7) provides a signal representing a measure of the water content of said fluid. It also comprises a double differential pressure generating (3) and measuring (4) structure, denoted a DDP-unit (2), that provides two measurement signals (6A and 6B) representing two independent values of differential pressure (DP) in said fluid (1). In addition to the above, the meter also comprises a signal processing unit (8) having inputs (9A-C) for receiving the measurement signals and the water content signal, and a calculation module (10) which calculates values representing the volumetric flow rates of said gas, liquid hydrocarbons and water in said fluid.

Methods and apparatuses for determining entrained and / or dissolved gas content of gas-liquid mixtures. Data generated is used to control the True (air-free) or Apparent (air-containing) Density or Entrained Air content of liquids within optimum ranges, e.g. in paper coating processes and in the manufacture of food products, personal care products, pharmaceutical products, paints, petroleum blends, etc. For example, an indirect method of continuously determining the amount of gas entrained in a liquid, by: continuously measuring the temperature, flow rate, and apparent density of the mixture at two different pressure states, and calculating the volume percentage of the gas in the liquid by using equation (28) x⁢%=VsVs+V(28)wherein V is the volume of the gas-free liquid calculated by equation (23) V=1ρ1-[P2P2-P1⁢(1ρ1-1ρ2)-RTP2-P1⁢g⁡(Δ⁢ ⁢PQa)](23)in which P1 and P2 are two different ambient pressures and ΔP=P2−P1, ρ1 and ρ2 are apparent densities of the liquid sample measured at P1 and P2, respectively, R is the constant of the Ideal Gas Law, T is the liquid temperature, Q is the flow rate, g(ΔP / Qa) is a function for determining the amount of gas being dissolved between P2 and P1, and Vs is determined by equation (27) Vs=TsT⁢P1⁢P2Ps⁡(P2-P1)⁢(1ρ1-1ρ2)-RTsPs⁢(P1P2-P1⁢g⁡(Δ⁢ ⁢PQa)-g⁡(P1-PsQa)).(27)

An apparatus for determining a fluid cut measurement of a multi-liquid mixture includes a first device configured to sense at least one parameter of the mixture to determine a fluid cut of a liquid in the mixture. A second device is configured to determine a concentration of gas in the mixture in response to a speed of sound in the mixture; and a signal processor is configured to adjust the fluid cut of the liquid using the concentration of the gas to determine a compensated fluid cut of the liquid. The parameter of the mixture sensed by the first device may include a density of the mixture (e.g., by way of a Coriolis meter), a permittivity of the mixture (e.g., by way of a resonant microwave oscillator), or an amount of microwave energy absorbed by the mixture (e.g., by way of a microwave absorption watercut meter). The signal processor may employ different correction factors depending on the type of fluid cut device used. The second device may include a gas volume fraction meter.

This invention relates to one food storage volume measurement method, which comprises the following steps: using laser sensor to measure its volume and starting cameral head for shot stored into PC database; correcting according to the volume by laser sensor; measuring food storage intensity by use of pressure sensor to weight sensor above column weight and measuring sensor food column height through laser sensor; computing food column intensity according to the weight, height and pressure area; computing food storage total weight according to the intensity and volume.

An assembly adapted to be affixed to a container which contains a sample fluid, and a method of affixing the assembly to the container, are provided. In particular, a contact pressure can be applied to a surface of the container, such that a particular arrangement, which has a portion situated within an opening of the container, is affixed to the container without piercing the surface of the container. For example, the container can be a tank, the particular arrangement can be a sensor arrangement, and a further arrangement can be used to affix the particular arrangement to the container. Moreover, the contact pressure preferably can be applied to an exterior surface of the container so that the further arrangement may be more accessible to a user of the assembly.

The present invention provides an objective bubble point pressure determination method enables new applications of downhole PV (Pressure Volume) test results such as in situ measurement of the bubble point pressure for use as a quality control parameter for sampling. The present invention provides a method and apparatus to fit data points to a curve and to smooth these points over an interval of N points. The derivative of the curve is determined to obtain peak acceleration. The peak acceleration represents the bubble point pressure. This bubble point pressure is verified by comparison to changes in fluid compressibility and visual observation of a pressure volume plot history.

Systems, program product, and methods to estimate and manage flowing fluid characteristics of a fluid stream flowing through a pipeline in real-time, are provided. A system can include a vertically oriented extent of a pipeline for transporting crude oil, a pair of spaced vertically apart sensors or sensor assemblies connected to a bypass line interfaced with or positioned across the vertically oriented extent of the pipeline to obtain pressure and temperature readings of the crude oil flowing through the pipeline, a controller in communication with the pair of sensors or sensor assemblies, and crude oil analysis and management program product stored in the memory of the controller and adapted to determine or estimate density, specific gravity, and API gravity of the crude oil to thereby manage flowing fluid characteristics of the crude oil.

A solids circulation system receives a gas stream containing char or other reacting solids from a first reactor. The solids circulation system includes a cyclone configured to receive the gas stream from the first reactor, a dipleg from the cyclone to a second reactor, and a riser from the second reactor which merges with the gas stream received by the cyclone. The second reactor has a dense fluid bed and converts the received materials to gaseous products. A conveying fluid transports a portion of the bed media from the second reactor through the riser to mix with the gas stream prior to cyclone entry. The bed media helps manipulate the solids that is received by the cyclone to facilitate flow of solids down the dipleg into the second reactor. The second reactor provides additional residence time, mixing and gas-solid contact for efficient conversion of char or reacting solids.

The present invention provides an objective bubble point pressure determination method enables new applications of downhole PV (Pressure Volume) test results such as in situ measurement of the bubble point pressure for use as a quality control parameter for sampling. The present invention provides a method and apparatus to fit data points to a curve and to smooth these points over an interval of N points. The derivative of the curve is determined to obtain peak acceleration. The peak acceleration represents the bubble point pressure. This bubble point pressure is verified by comparison to changes in fluid compressibility and visual observation of a pressure volume plot history.

Mechanical, electronic, algorithmic, and computer network facets are combined to create a highly integrated advanced sensor that monitors the gas density, state-of-repair, and events associated with switchgear. Measurements of gas pressure, atmospheric pressure, gas temperature, are used with models of the non-ideal behavior of a particular gas to realistically estimate gas density. A hierarchical system of signal processing optimizes measurements working within high-frequency, real-time, short-term, medium-term, diurnal, long-term, and historical timeframes and overcomes measurement errors present in real-world applications. The time at which a condition such as gas density will reach a particular level is calculated. Events such as threshold attainments and switchgear operation are detected. A large memory stores all raw data values allowing flexible re-processing and verification at any future time. Instantaneous as well as logged information is communicated in convenient formats over a selected digital network. An embedded web server provides a familiar graphical user interface.

Systems, program product, and methods to estimate and manage flowing fluid characteristics of a fluid stream flowing through a pipeline in real-time, are provided. A system can include a vertically oriented extent of a pipeline for transporting crude oil, a pair of spaced vertically apart sensors or sensor assemblies connected to the vertically oriented extent to obtain pressure and temperature readings of the crude oil, a controller in communication with the pair of sensors or sensor assemblies, and crude oil analysis and management program product stored in the memory of the controller and adapted to determine or estimate density, specific gravity, and API gravity of the crude oil to thereby manage flowing fluid characteristics of the crude oil.

An apparatus is provided for monitoring the fluidic contents of a tank. The tank includes a quick disconnect valve and an assembly includes a monitor device, such as, for example, a gas density monitor, a pressure monitor, a temperature monitor, etc., and a quick disconnect fitting. The monitor device is coupled to the quick disconnect fitting. The quick disconnect fitting is adapted to couple to the quick disconnect valve such that the interior of the quick disconnect fitting is in fluidic communication with the interior of the monitor device for reducing the chance of leakage upon connection / disconnection.

Methods and apparatus for measuring individual phase fractions and phase flow rates in a multiphase flow based on velocity of the flow, speed of sound through the fluid mixture, and the density of the fluid mixture. Techniques presented herein are based on measuring frictional pressure drop across a flowmeter conduit, determining a surface roughness term for the conduit during initial flow tests or through other mechanical means, implementing a correction method to balance the momentum equation, and calculating the fluid mixture density using the measured pressure drop. The techniques may be applicable to measuring flow parameters in horizontally oriented conduits and, more generally, conduits of any orientation.

A method for detecting a change in a wellbore fluid includes estimating at least two pressure differences in the wellbore fluid and estimating a change in a density of the fluid using the at least two pressure differences. The density change may be estimated by the equation, Δρ=(ΔPbefore<sub2>—< / sub2>influx−ΔPafter<sub2>—< / sub2>influx) / (g×ΔTVD), wherein ΔP is a fluid pressure difference between two points along the wellbore, ρ is a mean value of density of the fluid between the two points, g is gravity and ΔTVD is a vertical distance between the two points. The method may include estimating a density change using an estimated inclination of the wellbore. An apparatus for estimating density changes includes at least two axially spaced apart pressure sensors. The sensor positions may be switched to estimate a correction term to reduce a relative offset between the two pressure sensors.

The invention is a composite sensing device and its quantitative degas device. The density sensor and the temperature sensor connect with the detecting container, the slurry pump transmits the waiting detected well liquid by the conveying tube, and the conveying device connects the quantitative degas device. The quantitative box of the degas device is set at the bottom of the degasser, and the bottom of its side wall has the inlet snout and connects the conveying tube, the bracket is on the quantitative box and has the tray of degasser, and the tray has the limiting slurry inlet, the conductive sensing device is equipped on the bracket and can contact the raw liquid position of the quantitative box. The invention can online correctly detects the density of the well liquid, the conductive ratio and the temperature.

Systems and methods are disclosed for measuring densities and flow rates of gas-liquid fluid mixtures. In the systems and methods, the fluid mixture is caused to exhibit swirling flow as it flows through a conduit that includes a constriction, a first pressure difference is measured between two vertically-spaced measurement positions in the conduit, a second pressure difference is measured between two horizontally-spaced measurement positions in the conduit, the first horizontally-spaced measurement position being at the constriction region and the second horizontally-spaced measurement position being upstream or downstream of the constriction region, and one or more of the pressure differences is used to determine a density or a flow rate of the gas-liquid fluid mixture.

The invention relates to a method for measuring density of slurry in a desulfurization absorption tower, which comprises the following steps: firstly selecting a low-pressure side pressure sampling point and a high-pressure side pressure sampling point in the vertical direction of an absorption tower body, then leading out sampling pipe sections from the high-pressure side pressure sampling point and the low-pressure side pressure sampling point respectively, next connecting a high-pressure side capillary tube and a low-pressure side capillary tube of a double-flange diaphragm differential pressure transmitter to a sampling pipe section respectively, and finally calculating a density value by a measured value delta P of the double-flange diaphragm differential pressure transmitter according to a formula rho1=(delta P + rho2 gh) / (gh), wherein in the formula, rho1 is the density of the slurry in the absorption tower, rho2 is the density of the filling liquid in the capillary tube, g is gravitational acceleration, and h is the altitude difference between the high-pressure side pressure sampling point and the low-pressure side pressure sampling point. The method can measure more conveniently and accurately, needs no complex operation or measures, can simply maintain corresponding used measuring equipment and devices with low cost, and ensure stable and reliable running of the measuring equipment and the devices.

Methods for operating multi-probed formation testers to determine a fluid density gradient in the formation. The probes of the multi-probed formation tester are connected to a pressure gauge through a flowline that establishes a differential height between the probes. In some embodiments, a gradient of the fluid density in the flowline is determined as a function of the gradient of fluid density in the wellbore. The flowline fluid density gradient is then used to determine a formation fluid density gradient as a function of the flowline fluid density gradient.

A method and apparatus for determining the specific gravity of a monophasic or polyphasic fluid flowing in a conduit. The apparatus employs an square wave shaped tube known for its effectiveness in differential pressure measurements. The apparatus is configured such that the differential pressure is measured in crosswise manner Pressure taps comprising high and low pressure taps for a respective pressure sensing device are associated with a different leg. The apparatus has also been found to be effective for determining flow rate of the fluid in the conduit using differential pressure measurements.

An apparatus for estimating a viscosity or density of a fluid downhole includes a carrier configured to be conveyed through a borehole penetrating the earth. A pump is disposed at the carrier and configured to pump the fluid. A flow restriction element is configured to receive a flow of the fluid pumped by the pump and to reduce pressure of the fluid flowing through the flow restriction element. A sensor is configured to measure a differential pressure across the flow restriction element and to provide an output that is used to estimate the viscosity or density.

Dynamic monitoring of the amount of fuel remaining in an aircraft fuel tank is effected by delivering a constant volume flow of an inert gas into the fuel through the respective open distal ends of a sensor conduit tube and a reference conduit tube, each of which extends from a proximal end exterior of the tank to its respective distal open end located within the fuel tank. The sensor conduit tube distal end is fixed closely proximate the bottom of the tank, and the reference conduit tube distal end is fixed proximate but at a vertical spacing h from the sensor conduit tube distal end. The pressure at which the gas is delivered into the fuel at the constant volumetric rate through each of the sensor and reference conduit tubes is monitored. The pressure difference between the monitored pressure in the sensor conduit tube and the pressure in the free space in the fuel tank above the surface of the remaining fuel is directly proportional to the weight of the fuel lying above the sensor conduit tube distal end. The density of the fuel is proportional to the monitored pressure difference between the sensor and reference conduit tubes, divided by the vertical spacing h. The calculated weight of the fuel, divided by the calculated density of the fuel, is proportional to the volume of the fuel remaining in the tank.

The invention relates to a measuring system for measuring a density of a medium flowing in a process line, said medium being variable regarding its thermodynamic state, especially at least being proportionally compressible, along an imaginary axis of flow of the measuring system. The measuring system comprises at least one temperature sensor that is located in a temperature measuring point and that primarily reacts to a local temperature, theta, of a medium flowing past, said temperature sensor supplying at least one temperature measurement signal that is influenced by the local temperature of the medium to be measured, at least one pressure sensor that is located in a pressure measuring point and that primarily reacts to a local, especially static, pressure, p, of a medium flowing past, said pressure sensor supplying at least one pressure measurement signal that is influenced by the local pressure, p, in the medium to be measured, and at least one electronic measuring unit that at least temporarily communicates with at least the temperature sensor and the pressure sensor. The electronic measuring unit generates a provisional density value, using the temperature measurement signal and at least the pressure measurement signal, said density value representing a density which the flowing medium only apparently has in a virtual density measuring point that is especially interspaced from the pressure measuring point and / or the temperature measuring point along the axis of flow at a defined distance. The electronic measuring unit further generates at least temporarily at least one especially digital density value, which is different from the provisional density value, using the provisional density value and at least one correctional density value that depends on a flow speed of the medium and on the local temperature prevailing in the temperature measuring point, said correctional value being determined during operation time.