Abstract: A system comprising a parts-per-million (PPM) analyzer configured to analyze a multiphase fluid, the fluid comprising water. The analyzer includes a mesh comprising first adsorbent materials that adsorb specific substances from the multiphase fluid. The system includes a mass meter configured to measure a mass of multiphase fluid passing through the PPM analyzer; a molecular sieve dryer comprising second adsorbent material configured to adsorb the water from the multiphase fluid; and a plurality of valves configured to couple the mass meter and the molecular sieve dryer to the PPM analyzer. During routine operation, the valves direct the multiphase fluid through the PPM analyzer. During a validation operation, the valves divert the multiphase fluid through the molecular sieve dryer prior to entering the PPM analyzer.

Abstract: A load pulled oscillator circuit. The load pulled oscillator circuit comprises: i) an active circuit comprising a load pulled oscillator transistor, the active circuit having an optimal operational bias point; ii) an impedance matching circuit coupled to the active circuit; and iii) a temperature compensation circuit coupled to the active circuit and configured to compensate a bias voltage to the active circuit to thereby maintain the optimal operational bias point. The temperature compensation circuit comprises a thermistor that provides a variable resistance according to an ambient temperature in which the active circuit operates. The variable resistance of the thermistor compensates for changes in the ambient temperature to thereby maintain the optimal operational bias point.

Abstract: A wellhead test system comprising: i) a Coriolis mass flow meter configured to receive a flow of a liquid; ii) a water analyzer configured to receive the flow of the liquid; and iii) a controller coupled to the Coriolis mass flow meter and the water analyzer. The controller receives from the Coriolis mass flow meter at least one of: mass flow measurement data, mass density measurement data, and drive gain and also receives from the water analyzer at least one of water frequency measurement data, oil frequency measurement data, and insertion loss measurement data. The controller determines a gas volume fraction (GVF) value and modifies the operation of the Coriolis mass flow meter and the water analyzer based on the GVF value.

Abstract: An apparatus for analyzing the output of a plurality of oil wells. The apparatus comprises: i) a plurality of test headers coupled to the plurality of wells via a field testing infrastructure; and ii) a test separator configured to select a first well for testing and to receive a multiphase fluid flow from a first one of the plurality of test headers, the first test header associated with the first well. The test separator is further configured to: iii) separate the multiphase fluid flow into a gas phase stream and a liquid phase stream; iv) measure a plurality of parameters of the gas phase stream and the liquid phase stream over a current period; v) for each of the plurality of parameters, determine a mean value, a standard deviation, a maximum value, and a minimum value in the current period; and vi) determine if a standard deviation associated with a first parameter exceeds a first threshold of a mean value associated with the first parameter.

Abstract: An apparatus for analyzing a multiphase fluid in a pipeline. The apparatus comprises: i) an elongated shaft adapted to be inserted into the pipeline, the elongated shaft comprising a measurement electronics section and an extension section; ii) a housing coupled to the elongated shaft and adapted to be positioned outside the pipeline when the elongated shaft is inserted into the pipeline; and iii) a ground cage coupled to the elongated shaft, the ground cage comprising a sensor coupled to the measurement electronics section. The ground cage comprises a tube having perforations therein to permit multiphase fluid to flow within the ground cage. The sensor comprises a ceramic rod and an antenna within the ceramic rod.

Abstract: A load pulled oscillator circuit. The load pulled oscillator circuit comprises: i) an active circuit comprising a load pulled oscillator transistor, the active circuit having an optimal operational bias point; ii) an impedance matching circuit coupled to the active circuit; and iii) a temperature compensation circuit coupled to the active circuit and configured to compensate a bias voltage to the active circuit to thereby maintain the optimal operational bias point. The temperature compensation circuit comprises a thermistor that provides a variable resistance according to an ambient temperature in which the active circuit operates. The variable resistance of the thermistor compensates for changes in the ambient temperature to thereby maintain the optimal operational bias point.

Abstract: An apparatus for analyzing the output of a plurality of oil wells. The apparatus comprises: i) a plurality of test headers coupled to the plurality of wells via a field testing infrastructure; and ii) a test separator configured to select a first well for testing and to receive a multiphase fluid flow from a first one of the plurality of test headers, the first test header associated with the first well. The test separator is further configured to: iii) separate the multiphase fluid flow into a gas phase stream and a liquid phase stream; iv) measure a plurality of parameters of the gas phase stream and the liquid phase stream over a current period; v) for each of the plurality of parameters, determine a mean value, a standard deviation, a maximum value, and a minimum value in the current period; and vi) determine if a standard deviation associated with a first parameter exceeds a first threshold of a mean value associated with the first parameter.

Abstract: An apparatus for validating the operation of a pipeline infrastructure. The apparatus comprises: i) a plurality of test headers coupled to a plurality of wells via a field testing infrastructure; and ii) a test separator configured to select a first well for testing and to receive a multiphase fluid flow from a first one of the plurality of test headers, the first test header associated with the first well. The test separator compares at least one parameter from a current test data of the multiphase fluid flow received from the first test header with at least one parameter from a previous test data of a previous multiphase fluid flow received from the first test header and, in response to the comparison, determines whether the field testing infrastructure is operating properly.

Abstract: A wellhead test system comprising: i) a Coriolis mass flow meter configured to receive a flow of a liquid; ii) a water analyzer configured to receive the flow of the liquid; and iii) a controller coupled to the Coriolis mass flow meter and the water analyzer. The controller receives from the Coriolis mass flow meter at least one of: mass flow measurement data, mass density measurement data, and drive gain and also receives from the water analyzer at least one of water frequency measurement data, oil frequency measurement data, and insertion loss measurement data. The controller determines a gas volume fraction (GVF) value and modifies the operation of the Coriolis mass flow meter and the water analyzer based on the GVF value.

Abstract: A salinity determining system for determining a salinity of water in a hydrocarbon emulsion of oil and water. The salinity determining system includes an antenna element in contact with the hydrocarbon emulsion and a switch coupled to the antenna element. The salinity determining system includes a first analyzer device configured to be coupled to the antenna element via the switch. The first analyzer device is associated with a first coincidence function based on first measured electrical parameters of transmitted radio-frequency (RF) energy. The salinity determining system also includes a second analyzer device configured to be coupled to the antenna element via the switch.

Abstract: An apparatus for measuring a water content in a multiphase fluid flow stream is provided. The apparatus includes a measurement section configured to obtain a series of electrical measurements of the multiphase fluid flow stream over a first predetermined time interval, and determine a minimum electrical measurement Fmin_baseline from the series of electrical measurements. The measurement section also is configured to calculate a running average of the frequency (Fmin_gas_pattern) from the series of electrical measurements indicative of a change in a gas flow pattern of the multiphase fluid flow stream over a second predetermined time interval. The measurement section further is configured to calculate a corrected electrical measurement F_calc_WC for determining the water content in the multiphase fluid flow stream by subtracting the running average of the frequency. Fmin_gas_pattern from the minimum electrical measurement Fmin_baseline.

Abstract: A self-checking analyzer system is provided according to an embodiment of this disclosure. The analyzer system includes a pipeline for receiving a multi-phase fluid flow and a first measuring device configured to provide a first frequency response corresponding to the multi-phase fluid flow. The analyzer system also includes a second measuring device differing in frequency response from the first measuring device and configured to provide a second frequency response corresponding to the multi-phase fluid flow. The analyzer system is configured to validate the first frequency response using the second frequency response.

Abstract: A self-checking analyzer system is provided according to an embodiment of this disclosure. The analyzer system includes a pipeline for receiving a multi-phase fluid flow. The analyzer system also includes a first measuring device configured to provide a first reflected power/insertion loss measurement corresponding to the multi-phase fluid flow, and a second measuring device differing in frequency response from the first measuring device and configured to provide a second reflected power/insertion loss measurement corresponding to the multi-phase fluid flow. The analyzer system is configured to validate the first reflected power/insertion loss measurement using the second reflected power/insertion loss measurement.

Abstract: A salinity determining system for determining a salinity of water in a hydrocarbon emulsion of oil and water. The salinity determining system comprises an antenna element in contact with the hydrocarbon emulsion and a switch coupled to the antenna element. The salinity determining system comprises a first analyzer device configured to be coupled to the antenna element via the switch. The first analyzer device is associated with a first coincidence function based on first measured electrical parameters of transmitted radio-frequency (RF) energy. The salinity determining system also comprises a second analyzer device configured to be coupled to the antenna element via the switch.

Abstract: Systems and methods for measuring the moisture and sediment content of a sample. In one embodiment, a sample to be tested is collected in a field bottle. The sample from the field bottle is then transferred from the field bottle, and into and through an analysis bottle containing a desiccant material. As the sample is being pulled through the analysis bottle, a microwave measurement system (or other scattering parameter measuring system) is used to measure the effects of the sample on the scattering parameters of the desiccant material. By measuring the effects of the sample on the scattering parameters of the desiccant material, the sample's moisture content can be determined. The sample's moisture can also be determined by measuring the expanded volume of the desiccant. A filter section having a sight glass with graduations is used to determine the sediment content of the sample.

Abstract: Methods and systems for determining the water, oil, and gas fractions in hydrocarbons from high water cut hydrocarbon wells. A hydrocarbon flow stream discharging from a well is subjected to hydro-separation to produce an oil-enriched fractional stream upon which water content measurements can be more accurately and reproducibly made. Calculations based on the water content of the oil-enriched fractional stream and the flow rate of at least one of the streams through the separator are conducted to determine the water content of the original stream. This provides a simple approach to measuring the water content in high water cut hydrocarbons that is real-time, accurate, and reproducible.

Abstract: Systems and methods for measuring the moisture and sediment content of a sample. In one embodiment, a sample to be tested is collected in a field bottle. The sample from the field bottle is then transferred from the field bottle, and into and through an analysis bottle containing a desiccant material. As the sample is being pulled through the analysis bottle, a microwave measurement system (or other scattering parameter measuring system) is used to measure the effects of the sample on the scattering parameters of the desiccant material. By measuring the effects of the sample on the scattering parameters of the desiccant material, the sample's moisture content can be determined. The sample's moisture can also be determined by measuring the expanded volume of the desiccant. A filter section having a sight glass with graduations is used to determine the sediment content of the sample.

Abstract: A self-checking analyzer system is provided according to an embodiment of this disclosure. The analyzer system includes a pipeline for receiving a multi-phase fluid flow and a first measuring device configured to provide a first frequency response corresponding to the multi-phase fluid flow. The analyzer system also includes a second measuring device differing in frequency response from the first measuring device and configured to provide a second frequency response corresponding to the multi-phase fluid flow. The analyzer system is configured to validate the first frequency response using the second frequency response.

Abstract: A self-checking analyzer system is provided according to an embodiment of this disclosure. The analyzer system includes a pipeline for receiving a multi-phase fluid flow. The analyzer system also includes a first measuring device configured to provide a first reflected power/insertion loss measurement corresponding to the multi-phase fluid flow, and a second measuring device differing in frequency response from the first measuring device and configured to provide a second reflected power/insertion loss measurement corresponding to the multi-phase fluid flow.

Abstract: Methods and systems for testing a hydrocarbon well. Real time monitoring of the flow stream discharging from a well is used to collect physical and electromagnetic characterization data on the flow stream. A data filter is used to exclude data points uncharacteristic of the true performance of the well at that time in the operational cycle of the well. A statistical evaluation during or after at least some data has been collected is used to determine when the data set meets an acceptable level of data quality. The filtering parameters are adjusted to improve future detection, correction, and filtering of uncharacteristic data. Corrective transforms can be derived and applied to selected uncharacteristic data to recondition and retain the data. The filtered and completed data set is used to generate a hindsight determination of crude petroleum oil production output, including petroleum oil, water, and gas fractions and production rates.