Data characterizing a fuel storage facility can be received from one or more of a plurality of sensors disposed in the fuel storage facility. A fuel leak prediction for the fuel storage facility can be determined by a server, based on the received data, and further based on at least one predictive model that predicts whether a fuel leak exists in the fuel storage facility. The fuel leak prediction can be provided by the server. Related apparatus, systems, methods, techniques, and articles are also described.

In one aspect, data characterizing a fuel storage facility can be received from a sensor in operable communication with the fuel storage facility. An estimate of meter drift of a flow meter of a fuel dispenser in fluid communication with the fuel storage facility can be determined based on the received data. The estimate of meter drift can be determined based on at least one predictive model that predicts whether a calibration parameter characterizing a calibration of the flow meter has deviated from a predetermined flow meter calibration parameter. The estimate of meter drift can be provided.

A method for testing a device under test, the device under test being a measuring instrument to measure a physical parameter of a fluid, includes: performing a plurality of valid test runs, wherein a valid test run includes: exposing the device under test and a reference measuring instrument to the fluid under a set of influences, the set of influences being defined by influence parameters; monitoring the influence parameters; obtaining a reference value for the physical parameter from the reference measuring instrument; and obtaining a test value for the physical parameter from the device under test, wherein a test run is invalidated if influence parameters do not meet specified test requirements for the influence parameters; and then evaluating a plurality of test values originating from the plurality of valid test runs with respect to at least one of accuracy, repeatability and reproducibility.

Embodiments of a portable verification system (5) can move from one in-field gas flow meter location to another and temporarily connect downstream of a main pipeline's meter run or station. A control valve (19) of the portable verification system (5) allows volume measurement at different flow velocities to be verified. In some embodiments, the portable verification system (5) is connected to the meter run (13) and the main pipeline by a corresponding slip or linearly adjustable pipeline section (30/70). This section (30/70) can extend horizontally and vertically, as well as swivel to provide versatility when connecting in the field. Adaptor fittings may be used to connect the system (5) to the meter run (13) and main pipeline or a quick connect/disconnect (105) may be used. Downtime is limited to the time required to complete a circuit between the meter run, portable verification system (5), and main pipeline.

A method produces a void fraction (VF) error curve which correlates an apparent VF with the actual VF of a multi-phase flow, the method comprising (a) using a device to measure a property of the multi-phase flow from which an apparent VF may be calculated; (b) calculating the apparent VF using the measured property from the device; (c) determining the actual VF of the multiphase flow using a radiometric densitometer; (d) using the values from steps (b) and (c) to calculate the VF error; (e) repeating steps (b) through (d) for all expected flow conditions to generate a VF error curve.

The present invention relates to a device wherein fluid or air-induced instability is converted into a flow sensing mechanism by building a CPW (Coplanar Wave Guide) resonator. Depending on the flow rate, periodic transitions between two bistable states emerge. Owing to the dependence of the transition period and the flow rate, the use of this effect for on-chip flow rate sensing is achieved with this invention. Moreover, the present invention ensures a flow rate sensor to be used in the ventilation machines for the treatment of the COVID-19 pandemic.

A method for proving or calibrating a first flow meter integrated into a common platform with a second flow meter is provided. The first flow meter comprises a first driver, a first flow tube, and a first meter electronics, and the second flow meter comprises a second driver, a second flow tube, and a second meter electronics. The method includes configuring the first flow meter to vibrate the first flow tube with a first driver voltage at a first default driver voltage amplitude using the first meter electronics, and configuring the second flow meter to vibrate the second flow tube with a second driver voltage at a second standby driver voltage amplitude using the second meter electronics.

A method for testing a device under test, the device under test being a measuring instrument to measure a physical parameter of a fluid, includes: performing a plurality of valid test runs, wherein a valid test run includes: exposing the device under test and a reference measuring instrument to the fluid under a set of influences, the set of influences being defined by influence parameters; monitoring the influence parameters; obtaining a reference value for the physical parameter from the reference measuring instrument; and obtaining a test value for the physical parameter from the device under test, wherein a test run is invalidated if influence parameters do not meet specified test requirements for the influence parameters; and then evaluating a plurality of test values originating from the plurality of valid test runs with respect to at least one of accuracy, repeatability and reproducibility.

A multiphase vortex flowmeter system determines the gas-to-liquid ratio (GLR) and flow rates from a well producing multiphase gas, oil and water by detecting the frequency and amplitude of vortices shed in a vortex flowmeter. In particular, the phase of the flow can be identified by detecting the change in the frequency of the vortices with respect to time, and the amplitude of the vortices. Based on the phase, the flow rates of liquid and gas can be calculated. As a feedback technique, these calculated values can be “tuned” by comparison with actual GLR and flow rates recorded for the well by a test separator.

Methods, apparatuses and systems for providing offset calibration and fault monitoring are disclosed herein. An example controller component may comprise: a resistance-based bridge circuit; a signal conditioning circuit configured to condition an output of the resistance-based bridge circuit; a first diagnostic circuit coupled to the signal conditioning circuit configured to monitor an output of a first branch of the resistance-based bridge circuit; and a second diagnostic circuit coupled to the signal conditioning circuit configured to monitor an output of a second branch of the resistance-based bridge circuit.