266 results about "Wet steam" patented technology

Reformer and method for producing hydrogen and steam where steam is used for steam-assisted extraction of heavy hydrocarbons. Steam is injected into a hydrocarbon-containing reservoir. Hydrocarbons are extracted from the reservoir along with produced water. Hydrogen is produced in a catalytic steam hydrocarbon reformer. Combustion product gas from the reformer is used to generate wet steam in a once-through steam generator from produced water recycled from the reservoir. The wet steam is used for the steam-assisted extraction of heavy hydrocarbons. The reformer has a heat exchanger section where a heat exchanger is suitable for processing the produced water by once-through steam generation and is suitable for mechanical cleaning.

A method and an apparatus are disclosed for the measurement of the aridity, temperature, flow rate, total pressure, still pressure, and kinetic pressure of steam at a downhole location within a well through which wet steam is flowing. The apparatus comprises a series of fiber optic sensors that are mounted on sections of a shell assembly. The apparatus is lowered into a well to different downhole locations, and measures the multiple parameters of steam at different locations and heights. The data can be stored on board for subsequent analysis at the surface when the apparatus is retrieved from the well. The apparatus is very reliable, accurate, and of long-life in harsh environments.

A steam generator includes a housing, a heating unit, an electrothermal unit and a one-way valve. The housing has a chamber and a water inlet. The heating unit includes a heating portion extending into the chamber. The heating portion has a first spiral channel thereon. One end of the heating portion is formed with a vaporization room and a steam outlet. The vaporization room has a second spiral channel therein to extend the time that the water and the wet steam pass through the heating unit so as to provide a complete heating and vaporizing function. Besides, by the one-way valve coupled to the water inlet, the steam generator of the present invention is simple in structure and cost-effective, providing an automatic water supply and re-heating function.

Systems and methods generate steam from produced water by passing the produced water through first and second steam generators coupled together. The first steam generator produces wet steam in which a liquid effluent with impurities of the produced water passes to the second steam generator. The second steam generator combusts fuel and oxidant in direct contact with the liquid effluent. The first and second steam generators limit fouling and waste while providing a combined steam output that may include combustion products from only the second steam generator.

Solar energy generates steam in a “once-through” configuration without recirculation, with closely managed steam quality, to produce wet steam from high-contaminant feed water without scaling or fouling. Feed water is pressurized, preheated, and evaporated in a series of pipes exposed to concentrated solar energy to produce a water-steam mixture for direct distribution to an industrial process such as enhanced oil recovery or desalination. Water flow rates are managed based on measurements of solar energy and steam production to manage variations in the solar energy. Steam generator piping system uses continuous receiver pipe that is illuminated by segmented parabolic mirrors enabled to track the sun. Provisions for steam generator piping recurring maintenance are provided. Thermal energy from hot condensate and/or from low quality steam is recaptured and warms inlet water.

The invention provides a method and a system of producing superheated steam. The method of producing the superheated steam comprises the following steps: A. qualified softened water is introduced to a steam-injection boiler to produce wet steam with the temperature of 350 DEG C and dryness of 75%; B. steam-water separation is carried out on the wet steam, and saturated water and dry steam with dryness of above 99% are separated out; and C. the dry steam is introduced into a secondary steam heater to be heated, and superheated dry steam with the superheat degree of 30-40 DEG C is obtained. The system of producing the superheated steam comprises the steam-injection boiler used for producing the wet steam, a steam-water separator connected with the steam-injection boiler, and a steam heating boiler connected with the steam-water separator, wherein the steam-water separator comprises a steam outlet and a saturated water outlet, and the steam heating boiler is independent from the steam-injection boiler. The method and the system of producing superheated steam produce the superheated steam with the superheat degree of 10 DEG C, fully utilize the heat of separated water, and reduce the processing amount of the separated water.

The invention discloses a residual heat utilization steam turbine steam complementing adjusting system and a control method, which comprises an adjustable steam complementing adjusting steam valve, a pressure steam turbine, a transducer, a steam-water separator and an adjustor, a steam complementing hole is arranged on the interpolar position of a steam turbine, a steam complementing pipeline is connected on the steam complementing hole, a steam-water separator is arranged on the steam complementing pipeline, the adjustable steam complementing adjusting steam valve is arranged on the steam complementing pipeline between the steam-water separator and the steam complementing hole, executing signals of the adjustable steam complementing adjusting steam valve are connected with the adjuster output control signals, a pressure transducer is arranged on the steam complementing pipeline, the steam complementing signals of the pressure transducer is connected with the adjuster pressure output signals. Steam complementing steam firstly passes through the steam-water separator, and wet steam is conversed to be dry steam to reduce waterworn. The residual heat utilization steam turbine steam complementing adjusting system which is got by the invention effectively solves the problem which exists in the existing technique, the system achieves automatic adjustment of steam complementing when a steam complementing system which is stably operated is guaranteed. Thereby residual heat utilization is led to be the highest.

The invention includes the following steps: heating the ammonia water working medium to a saturated liquid state and then being separated into strong ammonia steam and weak ammonia water; using the condensated strong ammonia steam as the refrigerating output and generate the strong ammonia wet steam; mixing the weak ammonia water after the power positive circulating work with the strong ammonia wet steam and then being condensated to be the fundamental concentration ammonia water working medium.

The invention relates to a liquid-phase water content detection device for wet steam. The liquid-phase water content detection device for the wet steam is arranged on a main wet steam pipeline and comprises a bypass pipeline, a first valve, a second valve, a test container and a heater, wherein the bypass pipeline is communicated with the main wet steam pipeline; the first valve and the second valve are arranged on the bypass pipeline; a set fixed quantity of air is filled in the test container; the heater is connected with the test container; the bypass pipeline between the first valve and the second valve forms a closed sampling space through a third valve; a pressure meter, a thermometer and a hygrometer are arranged on the test container; the test container is communicated with the closed sampling space through the third valve. The invention further provides a liquid-phase water content detection method for the wet steam. According to the liquid-phase water content detection device and the liquid-phase water content detection method, a state of tested gas can be measured on line, and only simple conventional accessory equipment is needed; the test process is simple and feasible; furthermore, calculation of heat is not needed; the heat dissipation loss cannot affect the measurement precision; the liquid-phase water content detection device and the liquid-phase water content detection method are suitable for the wet steam with various pressure levels.

The invention relates to a measuring method and a measuring device for liquid drop particles in a wet-steam region. An ultrasonic excitation signal acquires ultrasonic signals with three different frequencies by adopting a mode of superposing waves; the processing and analyzing process of the ultrasonic signals in a computer comprises the following steps: performing fast Fourier transform on the obtained signals to obtain ultrasonic signal amplitudes with three frequencies, and calculating to obtain sound attenuation coefficients; obtaining particle diameter values of the liquid drop particles according to the relationship between the measured particle diameter values of the liquid drop particles and the ratio of the sound attenuation coefficients with three frequencies; likewise, obtaining a volume concentration value according to the relationship between the volume concentration value and the sound attenuation coefficients, and obtaining a humidity value of wet steam according to the conversion relationship between the volume concentration and the humidity. The measuring device is simple in structure and low in cost; compared with the measuring method for the wet steam by adopting other principles, the measuring method disclosed by the invention has the advantages that ultrasonic waves have strong penetrating power; an ultrasonic transducer can normally work in a severe environment; online measurement of particles sizes, volume concentration and humidity of the liquid drop particles in the wet steam region with higher concentration at the final stage of a low-pressure cylinder can be realized without precision correction.

A steam dryness modulating system comprises a steam generator, a gas collecting tank and three branches connected between the steam generator and the gas collecting tank in parallel, wherein the steam generator in the branch I is directly connected with the gas collecting tank to be in a normally opened state, a humidifying device is arranged in the branch II, a dehumidification device is arranged in the branch III, and a gas outlet pipe of the gas collecting tank is connected with a gas using device and is provided with a dryness meter. The steam dryness modulating system is characterized in that the steam of the branches converge in the gas collecting tank, the branch II and the branch III are switched according to a steam dryness value actually measured by the dryness meter, the steam leading amount is adjusted through a valve, and dry and wet steam mixing of different proportions can be achieved. In addition, automatic detection and control of steam dryness can be achieved by adding a signal controller. The united online pipeline steam dryness meter is applied to the system, and online real-time detection of the steam quality of the key working section of a tobacco shred production line can be achieved. Good steam quality can not only guarantee the tobacco shred processing quality, but also improve the energy utilization rate, and the service life of the valve and the device can be effectively prolonged.

A steam compressor arrangement comprises the following components: a positive displacement compressor for compressing the steam which is sucked into a reaction space and is used as a gas phase object fluid and discharging to a discharging tube with a preset discharging pressure; a liquid guiding mechanism for guiding the liquid phase objective fluid into the reaction space or a suction space of the compressor; and a dehydrator which is configured on the discharging tube and separates liquid phase part from the objective fluid discharged from the compressor, wherein, the liquid guiding mechanism guides the liquid phase object fluid with enough amount for the following states: namely, the heat is consumed as latent head of vaporization, which is used for vaporizing the liquid phase object fluid; the heat is the residual heat which is in the energy given from the compressor to the object fluid and is after energy consumption for increasing the pressure of the gas phase object fluid sucked by the compressor to the discharging pressure; and furthermore the object fluid is discharged from the compressor with a state that one part of the object fluid is liquid phase wet steam. Therefore the excessive temperature increase of the compressor is prevented, and the output of the compressor is furthest used as the steam energy.

The invention relates to a soft measurement method based on variable-boundary segmentation energy balance, a multifunctional wet steam measuring needle and a wet steam heat absorption measurement and control device. The multifunctional wet steam measuring needle is characterized by consisting of an electric heating rod, an electric heating rod sleeve with uniform and screw pitch-equal convex spiral ribs, a multifunctional wet steam measuring needle outer wall tube, a front sensor seat and a rear sensor seat. The wet steam heat absorption measurement and control device consists of an isothermal sleeve, temperature measuring points distributed on the inner wall and the outer wall of the isothermal sleeve at equal distances and computer online measurement and control equipment. The multifunctional wet steam measuring needle is put in the wet steam heat absorption measurement and control device and is wholly pressed and fixed by an outer sleeve, an outer sleeve flange cover and an outer sleeve flange disc; based on the flowing and heating process mechanism analysis of wet steam in the structure, a soft measurement model and an online calibration model of measurement results are established; and the whole equipment is simple in structure and is suitable for various measurement fields in relation to wet steam two-phase flow, in particular to the measurement of exhaust steam humidity of a condensing turbine.

A method of detecting the dryness of wet steam of a once-through steam injection boiler, comprises:

• • first, by detecting and/or calculating, obtaining volume flow of wet steam, corresponding volume flow of saturated liquid, and corresponding volume flow of saturated vapour; and
  • then obtaining the dryness of wet steam of the once-through steam injection boiler, X, according to the following relationship equation:

A detecting apparatus for detecting dryness of wet steam of a once-through steam injection boiler, specifically comprises: a data detecting module 1, a data processing module 2, and a data displaying module 3, wherein the data processing module 2 connects the data detecting module 1 and the data displaying module 3.

The invention provides a recycled two-phase flow flowmeter calibrating platform of wet steam, which is characterized in that a heat storage box of a stable water supply unit is communicated with a concurrent boiler through a boiler feed pipe; a gear pump, a water feed flowmeter and a water feed conductivity meter are arranged on the boiler feed pipe in sequence; a concurrent boiler of a steam-generating unit is communicated with a cooling heat exchanger by a steam supply pipe; a detected meter, a meter detector and a water sampler are arranged on the steam supply pipe in sequence; a cooling heat exchanger of a waste heat recovery unit is connected with the heat storage box by a water inlet tube of the heat storage box; the water sampler is communicated with a sampling water pipe; and the sampling water pipe is connected with a water sample conductivity meter and a sampling water regulating valve. The calibrating platform can provide the wet steam for calibration and the wet steam for the calibration can regulate mass flow rate and steam dryness. A high-accuracy wet steam standard flowmeter and a standard dryness meter are arranged on the calibrating platform, thus being capable of executing high-accuracy calibration on the detected meter. The wet steam for the calibration can be used for recycling fluids and waste heat, thus reducing the operating cost.

The invention discloses a flow measurement device of gas-liquid multiphase flow, used for measuring the flow of wet steam in heterogeneous distribution. The flow measurement device is characterized inthat a homogeneous rectifier A, a flow meter sensor A, a homogeneous rectifier B and a flow meter sensor B are arranged in a straight-way pipe sequentially, and a numeral display meter in which a flow processing program of the gas-liquid multiphase flow is arranged is fixed outside the straight-way pipe. The invention also discloses a method for measuring the flow of wet steam in heterogeneous distribution by the flow measurement device of gas-liquid multiphase flow, and the method comprises the following steps: acquiring flow characteristic signals of the A flow meter sensor and the B flow meter sensor; and simultaneously working out the flow of the wet steam in heterogeneous distribution by mass conservation equation of the A flow meter sensor and the B flow meter sensor. The inventionnot only can measure the flow quality of gas-liquid multiphase flow but also has the advantages of high measurement accuracy, good stability and reliability, simple structure and low manufacturing cost.

The invention provides an SAGD (steam assisted gravity drainage) wet steam injection station system, and a boiler water recycling method thereof. The system comprises a steam generator and a separator, wherein the separator is used for separating high-dryness steam and high-temperature saline water output by a boiler; the system also comprises a flash evaporator, a water maker, a drum boiler and a heat exchanger; the flash evaporator is connected with the separator for carrying out flash evaporation treatment on the high-temperature saline water separated by the separator so as to generate wet steam and high-concentration saline water; the water maker is connected with the flash evaporator for carrying out evaporative desalination treatment on the high-concentration saline water generated by the flash evaporator so as to generate product water by the wet steam generated by the flash evaporator; the drum boiler is connected with the water maker for heating the product water generated by the water maker to form overheat steam, and the heat exchanger is respectively connected with the water maker and the steam generator for recovering smoke afterheat generated by the steam generator as a supplied heat source of the water maker for carrying out evaporative desalination treatment. According to the wet steam injection station system, energy and water can be saved and the utilization of heat can be improved.

The invention discloses a large-diameter high-speed liquid jet impact test device which comprises a test bed rack, a jet power device, a power bracket device, a liquid jet device, a sample clamping device and an observation device, wherein the jet power device is positioned on the rear side of the test bed rack and is clamped by the power bracket device; the liquid jet device is positioned in front of the jet power device and is fixed on the test bed rack by virtue of a bolt, a liquid nozzle rack is arranged at the front end of the liquid jet device, and a sleeve rack through which only a nylon rod is allowed to penetrate is arranged at the rear end of the liquid jet device; the sample clamping device is positioned in front of the liquid jet device, and a rectangular groove is formed in the middle of the device and is used for clamping the sample; and the observation device is used for observing the speed and diameter of liquid jet. The device can be used for researching notch damage generated by different materials under the impact of high-speed drops of different diameters, the analysis experiment result can guide material selection of wet-steam region steam turbine vanes and other mechanical parts which operate in a water erosion environment, and the test device has significant academic value for further researching the liquid-solid high-speed impact mechanism.

The invention relates to a method for calculating the efficiency of a low-pressure cylinder of a thermal power plant steam turbine. The conventional method for calculating the efficiency of the low-pressure cylinder at present is low in precision. The method comprises the following steps: (1) calculating steam extraction pressure from high to low, supposing that a first steam extraction point in a wet steam state is i, calculating enthalpy values and entropy values of the steam extraction points i-1 and i-2 according to pressure and temperature which are acquired by a performance test, and calculating section efficiency [mu](i-2 to i-1) of i-2 to i-1; (2) supposing that the efficiency reduction coefficient is a, i.e. the section efficiency [mu](i-2 to i-1) of i-2 to i-1 is [mu]i-1 to i= a*[mu](i-2 to i-1); (3) calculating an actual enthalpy value of the point i; (4) calculating the steam discharging enthalpy h(steam discharging) of the low-pressure cylinder; (5) calculating the steam discharging leaving velocity loss V(leaving velocity loss) of the final stage; (6) calculating an enthalpy value UEEP of the unit mass of steam discharged by the low-pressure cylinder; and (7) calculating the efficiency of the low-pressure cylinder. The method is easy to operate and high in calculation precision.

A method for calculating moisture loss in a steam turbine operating under wet steam conditions. The method may include the steps of: 1) assuming equilibrium expansion, calculating a flow field initialization to determine initial pressure values, initial expansion rate, initial velocity values at an inlet and an exit of each of a plurality of bladerows in the steam turbine, and initial enthalpy values through each of the plurality of bladerows in the steam turbine; 2) using the initial pressure values, the initial velocity values, and the initial enthalpy values, calculating an initial subcooling ΔT value through each of the plurality of bladerows of the steam turbine; 3) calculating an Wilson Point critical subcooling ΔT value through each of the plurality of bladerows of the steam turbine required for spontaneous nucleation to occur based on the initial pressure value and the initial expansion rate; and 4) comparing the initial subcooling ΔT values to the Wilson Point critical subcooling ΔT values to determine where spontaneous nucleation occurs through the plurality of bladerows of the steam turbine.