Systems and methods for improved gas turbine engine performance are disclosed. The method can include receiving an error function for a wide range of fuels. The error function can provide lower heating value (LHV) corrections over the wide range of fuels. The method can include receiving gas turbine engine operation data for a first period of run time on the gas turbine from one or more sensors of the gas turbine engine. The engine operation data can include a performance data points. The method can include determining an optimum LHV based on the engine operation data for the first period of run time and the error function. The method can then include adjusting fuel consumption of the gas turbine engine based on the optimum LHV.

Disclosed is a control system for controlling the feed of a solid fuel in a combustion process. The system includes a control unit which is adapted to communicate by way of a communications link in the system, to receive from online measuring instruments online measurement data regarding a fuel coming from a fuel reception unit, and to control a feeding unit for delivering the measured fuel into a fuel silo on the basis of its content model and measurement data.

A method of delivering fuel to an engine during operation of the engine, that includes, sensing the speed of sound in the fuel, determining a density or property of the fuel, and based on that density or fuel property adjusting the flow rate of the fuel. Further, an established fuel profile or determined energy density value can also be used to adjust the flow rate of the fuel.

Conducted are coal-ash generating step for generating coal ash, sintered-ash generating step for heating the coal ash at temperatures within combustion temperature range of coal-fired boiler to generate sintered ash at each heating temperature, sticking-degree calculating step for rotatively separating each sintered ash by ratra tester to calculate sticking degree from weight ratio of each sintered ash after and before the rotary separation of the sintered ash, correlation determining step for burning each coal having corresponding sticking degree calculated to measure exhaust gas temperature and obtain correlation between sticking degrees and exhaust gas temperatures, exhaust-gas-temperature predicting step for predicting exhaust gas temperature from sticking degree of coal to be employed as fuel based on the correlation between the sticking degrees and the exhaust gas temperatures and adhesion predicting step for predicting ash adhesion in the coal-fired boiler based on the exhaust gas temperature predicted.

A system for controlling a flow may be provided. The system may comprise a first flow controller and a gas density meter. The gas density meter may be in fluid communication with the first flow controller. The gas density meter may be configured to calculate a gas density for a first gas flowing through the gas density meter. In addition, the gas density meter may be configured to output a first signal configured to cause the first flow controller to alter a first flow rate of the first gas flowing through the first flow controller. Furthermore, the gas density meter may be configured to output a density signal going to the second controller.

A carbon fiber production method includes a carbon fiber production step including an oxidation step and a carbonization step; and an exhaust gas processing step including a heat exchange step; an external air mixing step; and a mixed external air supplying step in which the mixed external air is supplied to at least one step that uses heated gas in the steps in the carbon fiber production step; and among the exhaust gases, a high heating value exhaust gas having a heating value of 250 kcal/Nm.sup.3 or higher is supplied to an inlet side of an exhaust gas combustion apparatus and a low heating value exhaust gas having a heating value lower than 150 kcal/Nm.sup.3 is supplied to an outlet side of the exhaust gas combustion apparatus, respectively.

To provide a method with which it is possible to ascertain a gas concentration in a furnace rapidly, and to charge an amount of fuel and/or oxygen corresponding to the state within the furnace, and with which it is possible to reduce the device maintenance load. In order to solve the abovementioned problem, this method for analyzing components contained in flue exhaust gas of a furnace includes: a sampling step of collecting a portion of the flue exhaust gas from a flue; a dust removal step of using a centrifugal dust collecting device to separate out dust in the flue exhaust gas collected in the sampling step, to yield an analysis gas; a measuring step of measuring components in the analysis gas to obtain the concentration of carbon monoxide in the analysis gas; and an analysis gas discharging step of causing the analysis gas to be sucked by an ejector.

In a method and system for the combustion of ammonia, wherein a first combustion chamber receives ammonia and hydrogen in controlled proportions, and an oxygen-containing gas such as air. Combustion of the ammonia and hydrogen produces nitrogen oxides among other combustion products. A second combustion chamber receives the nitrogen oxides along with further ammonia and hydrogen in further controlled proportions along with further oxygen-containing gas such as air. The nitrogen oxides are combusted into nitrogen and water.

A apparatus may extract temperature for each region of a feed water and steam system of a thermoelectric power plant with respect to a combustible combination including one or more combustibles, extract one or more vectors for each region from the temperatures extracted for each region, generate one or more combustible clusters, each cluster including one or more combustible combinations having similar properties from the extracted vectors, and extract a characteristic component of a combustible combination that increases or decreases a boiler performance index from among one or more combustible combinations included in the one or more combustible clusters.

A control device of a hydrogen gas burner device sets a target flow rate of a hydrogen gas such that a flow rate of the hydrogen gas decreases as a temperature of the hydrogen gas becomes higher, based on the temperature of the hydrogen gas and a needed quantity of heat of the hydrogen gas during the combustion, sets a target flow speed such that the flow speed of the hydrogen gas released from a combustion nozzle via a flow speed regulator becomes a flow speed based on the target flow rate and the flow speed of the hydrogen gas increases as a value of the target flow rate decreases, controls the flow rate regulator such that the flow rate of the hydrogen gas reaches the target flow rate, and controls the flow speed regulator such that the flow speed of the hydrogen gas reaches the target flow speed.