The systems and methods provided herein relate generally to the improvement of data quality in optical liquid particle counters and control of optical particle counters to achieve longer expected lifetime, for example by avoiding damage caused by electromagnetic radiation and heat. The systems and methods incorporate sensors which characterize the fluid flowing through the flow cell, thereby enhancing accuracy and reducing the number of false positives.

Apparatuses, systems, and methods are provided for measuring the velocity and direction of a fluid flow. In some instances, a measuring system may include a housing capable of holding one or more pressure sensors in a desired location and orientation. The housing may include a cavity for each of the one or more pressure sensors and each cavity may have a connection to an opening at the outside surface of housing. Each opening may be able to face in any desired direction such that the pressure at any desired location on the outside surface of housing, which may be capable of facing in any desired direction, may extend to the cavity inside housing where it can be measured by a pressure sensor. The velocity and the direction of a fluid flow around the housing of the measurement system may be based on pressure readings generated by the pressure sensors.

This application describes methods and apparatus for monitoring flow of fluids within conduits using fiber optic Distributed Acoustic Sensing (DAS). The method can determine flow rate and/or flow regime within a conduit such as within a production well or a pipeline. Embodiments involve introducing an acoustic stimulus (802) into the fluid within the conduit (801); interrogating an optical fiber (104) deployed along the path of the conduit to provide a DAS sensor; and analyzing the acoustic signals detected by a plurality of channels of the DAS sensor to determine at least one flow characteristic. Analyzing the acoustic signal comprises identifying reflections (804) of said acoustic stimulus caused by the fluid within the conduit and analyzing said reflections to determine any Doppler shift (Δf).

This application describes methods and apparatus for monitoring flow of fluids within conduits using fiber optic Distributed Acoustic Sensing (DAS). The method can determine flow rate and/or flow regime within a conduit such as within a production well or a pipeline. Embodiments involve introducing an acoustic stimulus (802) into the fluid within the conduit (801); interrogating an optical fiber (104) deployed along the path of the conduit to provide a DAS sensor; and analyzing the acoustic signals detected by a plurality of channels of the DAS sensor to determine at least one flow characteristic. Analyzing the acoustic signal comprises identifying reflections (804) of said acoustic stimulus caused by the fluid within the conduit and analyzing said reflections to determine any Doppler shift (Δf).

A monitoring system includes an image sensor positioned about a rig, the image sensor directed at a drill string component positioned on the rig, and an onsite gateway communicably coupled to the image sensor and disposed proximate to the rig. The onsite gateway includes one or more processors, and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to receive an image stream of the drill string component from the image sensor, identify an operating parameter of the drill string component, generate an operating condition of the drill string component, determine that the generated operating condition meets a failure threshold of the drill string component, and send an instruction to drive a controllable device.

A monitoring system includes an image sensor positioned about a rig, the image sensor directed at a drill string component positioned on the rig, and an onsite gateway communicably coupled to the image sensor and disposed proximate to the rig. The onsite gateway includes one or more processors, and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to receive an image stream of the drill string component from the image sensor, identify an operating parameter of the drill string component, generate an operating condition of the drill string component, determine that the generated operating condition meets a failure threshold of the drill string component, and send an instruction to drive a controllable device.

The fuel flow rate to a gas turbine is measured using an inert gas. The inert gas is injected into the fuel flow and the concentration of the inert gas in the fuel/inert gas mixture is later measured. The concentration of the inert gas in the fuel/inert gas mixture is then used to calculate the mass flow rate of the fuel.

The fuel flow rate to a gas turbine is measured using an inert gas. The inert gas is injected into the fuel flow and the concentration of the inert gas in the fuel/inert gas mixture is later measured. The concentration of the inert gas in the fuel/inert gas mixture is then used to calculate the mass flow rate of the fuel.

A measuring rod (1) with a longitudinal axis (A) for insertion in the flow cross section of a tube and for the verification of a flowing medium in this tube having at least one first sender unit (2) for the transmission of a first acoustic or electromagnetic measuring signal (3) and at least one first receiver unit (4) for receiving the first measuring signal, wherein the first sender unit (2) and the first receiver unit (4) define a measuring section, wherein the first sender unit (2) is arranged in such a manner that the first measuring signal (3) crosses the measuring section and wherein the first receiver unit (4) is arranged in such a manner that it, at least during operation without flow, receives the first measuring signal (3) after crossing the measuring section.

The invention relates to a method for measuring a flow velocity (v) of a gas stream (14) featuring the steps: (a) time-resolved measurement of an IR radiation parameter (E) of IR radiation of the gas stream (14) at a first measurement point (P1) outside of the gas stream (14), thereby obtaining a first IR radiation parameter curve (E.sub.g1,1(t)), (b)time-resolved measurement of an IR radiation parameter (E) at a second measurement point (P2) outside of the gas stream (14), thereby obtaining a second IR radiation parameter curve (E.sub.g1,2(t)), (c) calculation of a transit time (τ1) from the first IR radiation parameter curve (E.sub.g1,1(t)) and the second IR radiation parameter curve (E.sub.g1,2(t)), in particular by means of cross-correlation, and (d) calculation of the flow velocity (vG) from the transit time (τ1), (e) wherein the IR radiation parameter (E.sub.g1) is measured photoelectrically at a wavelength (g1) of at least 780 nm, and (f) a measurement frequency (f) is at least 1 kilohertz.