Abstract: A system and method for predicting the failure and estimating the health of the industrial equipment or industrial measurement equipment and diagnosing the root cause of the incipient failures is provided. The system and method are applicable to different types of flow meters used in flow measurement applications and other industrial equipment or industrial measurement equipment. A means to detect anomalies in the industrial equipment or industrial measurement equipment diagnostic signals is provided and thereby allowing incipient failure prediction. The system and method provides the means to calculate the current state of health of the industrial equipment or industrial measurement equipment. Leading indicator/failed component in the industrial equipment or industrial measurement equipment can be tracked down in the event of a failure. The system and method provides the means to label the normal and abnormal periods in the historical data based on the available diagnostic alarms and signals.

Abstract: A method and system for operating an industrial process using an integrated quadratic controller (IQC) is provided for a single input multiple output system (SIMO). A target process value (PV) associated with an output of the industrial process is used to define an optimal output of the industrial process. Manipulated-variables (MVs) associated with a plurality of loads within the industrial process are utilized for controlling a rate of operation associated with the load impacting the PV of the industrial process. Quadratic programming (QP) is defined to optimize proportional action gains for the determined MVs given an update control variable PV. QP gain-modified proportional action are integrated into a control system of the industrial process and a modified control system to update MV output state map defining the multiple output to control respective loads in the industrial control process for achieving the target PV is generated.

Abstract: The present disclosure provides a burner management system (BMS) for an industrial gas appliance and method for controlling a warm-up operation of the industrial gas appliance. The BMS and control method only requires a subset of the burners to be provided with flame detectors. In accordance with one aspect, the method involves lighting a supervised burner by providing a fuel gas flow thereto; continuously detecting a flame at the supervised burner indicating that the supervised burner is lit; incrementally lighting non-supervised burners by providing the fuel gas flow thereto when a non-supervised burner status indicates a safe lighting condition, the non-supervised burner status being determined by: measuring a total fuel gas flowing to the plurality of burners; and determining the number of the non-supervised burners with the fuel gas flowing thereto from the measurement of the total fuel gas and a supervised burner status.

Abstract: Method and apparatus for enhancing the combustion of a process gas of variable composition which gas is used for steam generation in producing heavy oil. The mass flow of the process gas containing hydrocarbons, carbon dioxide and water is measured. It is assumed that the process gas is saturated with water vapor and the water content of the process gas is then obtained. The content of carbon dioxide in the process gas is nominally obtained with an oxygen analyser measuring the flue gas from a steam generator thereby giving a close approximation of hydrocarbon content and allowing an expedited calculation of the energy content and air required. The nominal carbon dioxide value is compared with the calculated carbon dioxide value based on the actual flow of process gas and purchase gas and the oxygen content so that the quantity of carbon dioxide is approximated.

Abstract: Method and apparatus for enhancing the combustion of a process gas of variable composition which gas is used for steam generation in producing heavy oil. The mass flow of the process gas containing hydrocarbons, carbon dioxide and water is measured. It is assumed that the process gas is saturated with water vapor and the water content of the process gas is then obtained. The content of carbon dioxide in the process gas is nominally obtained with an oxygen analyser measuring the flue gas from a steam generator thereby giving a close approximation of hydrocarbon content and allowing an expedited calculation of the energy content and air required. The nominal carbon dioxide value is compared with the calculated carbon dioxide value based on the actual flow of process gas and purchase gas and the oxygen content so that the quantity of carbon dioxide is approximated.

Abstract: Method and apparatus used to calculate the hydrogen sulfide and carbon dioxide loading of both rich and lean amine solutions used to remove acidic gas components from sour or production gases in order to produce a sweet or sales gas for transmission purposes. The amine solution is divided into three (3) liquid streams carrying different proportions of heat stable salts, hydrogen sulfide and carbon dioxide. Conductivity measurements are made on each of the streams and are converted to acid loading values for the amine. The acid loading values of the amine are used to obtain the hydrogen sulfide and carbon dioxide loading for the amine solution.

Abstract: Method and apparatus used to calculate the hydrogen sulfide and carbon dioxide loading of both rich and lean amine solutions used to remove acidic gas components from sour or production gases in order to produce a sweet or sales gas for transmission purposes. The amine solution is divided into three(3) liquid streams carrying different proportions of heat stable salts, hydrogen sulfide and carbon dioxide. Conductivity measurements are made on each of the streams and are converted to acid loading values for the amine. The acid loading values of the amine are used to obtain the hydrogen sulfide and carbon dioxide loading for the amine solution.

Abstract: Apparatus and method for determining the water content of an oil and water mixture such as is transported by pipelines and which oil and water may vary in density from time to time. A densitometer measures the density of the oil and water mixture in the pipeline and a value for the dielectric constant of the oil is obtained from the density measurement by correlating the density reading with a capacitance or dielectric constant reading from an empirically generated chart. A basal sediment and water instrument measures the dielectric constant of the same mixture. The difference between the two dielectric constants is then obtained. This result is converted directly into a water based percentage by volume of the oil-water mixture being carried by the pipeline.