1192results about "Combined combustion mitigation" patented technology

The invention belongs to the technical field of energy storage, and relates to a compressed air and water coupled multi-energy co-production energy storage system and method, comprising an air compressor, a first heat exchanger, a second heat exchanger, an air turbine and a cooling module; a circulating medium of the first circulating loop is fused salt; the circulating medium of the second circulating loop is water, and the second circulating loop comprises a low-temperature water tank, a first booster pump, a second heat exchanger, a high-temperature water tank, a flash tank, a third heat exchanger, a steam turbine high-pressure cylinder and a heating module which are sequentially communicated end to end. Compression heat generated by compressed air can be stored in fused salt and water, special geographical conditions needed for storing high-pressure air are avoided, meanwhile, in the energy release stage, the stored water is used for flash evaporation and fused salt heating and then enters a steam Rankine cycle to do work, combined heat and power generation can be achieved in winter, combined cooling and power generation can be achieved in summer, and the energy-saving effect is achieved. Therefore, combined supply of different kinds of energy in different seasons is achieved, and the energy supply efficiency is improved.

The utility model relates to the technical field of incinerator processing, in particular to a uniform anti-coking coating smearing device for a combustion chamber of a garbage incinerator, which comprises a bearing rack, a first lead screw is rotatably connected to one end in the bearing rack, and a push frame is slidably connected to one end of the top of the bearing rack; and the other end of the top of the bearing rack is fixedly connected with a fixed base, the bottom of the push frame is connected to the outer wall of the first lead screw in a sleeving and threaded mode, and an outer push rod is welded to the top of the push frame. According to the improved smearing device, the push frame achieves horizontal transmission through the lead screw, it is ensured that the spraying assembly moves along a set linear track, deviation is avoided, the coating uniformity is improved, the annularly-distributed high-pressure spray heads are combined with the rotatable workpiece, all parts of the workpiece receive paint spraying from different directions, and the spraying efficiency is improved. In addition, the extension rod can adjust the contact distance between the high-pressure nozzle and the inner wall of the workpiece, the uniform adhesiveness of the coating on the surface of the workpiece is guaranteed in all directions, and the situation that spraying parts are frequently replaced due to specification problems is avoided.

A thermal energy storage (TES) system converts variable renewable electricity (VRE) to continuous heat at over 900° C. Intermittent electrical energy heats a solid medium. Heat from the solid medium is delivered continuously on demand. Heat delivery via flowing gas establishes a thermocline which maintains high outlet temperature throughout discharge. The delivered heat which may be used for processes including power generation and cogeneration. Configurations of simple cycle systems and combined cycle power plants using thermal energy storage units can provide even greater efficiency and responsiveness.

An energy storage system converts variable renewable electricity (VRE) to continuous heat. Intermittent electrical energy heats a solid medium. Heat from the solid medium is delivered continuously on demand. An array of bricks incorporating internal radiation cavities is directly heated by thermal radiation. The cavities facilitate rapid, uniform heating via reradiation. Heat delivery via flowing gas establishes a thermocline which maintains high outlet temperature throughout discharge. Gas flows through structured pathways within the array, delivering heat which may be used for processes including calcination, hydrogen electrolysis, steam generation, and thermal power generation and cogeneration. Low temperature waste heat from energy production can be recovered and used to improve overall system efficiency.

A system includes a heat recovery steam generator (HRSG) configured to generate steam using heat from an exhaust gas, an exhaust stack disposed downstream of the HRSG, and a cooling transition duct disposed downstream of the exhaust stack. The cooling transition duct includes a converging duct that decreases in a cross-sectional area in a flow direction from an inlet to an outlet of the converging duct. The cooling transition duct also includes one or more coolers disposed in the converging duct. The one or more coolers are configured to cool the exhaust gas within the converging duct between the inlet and the outlet. The cooling transition duct is configured to direct cooled exhaust gas to a gas capture system, an exhaust gas recirculation (EGR) system, or both.

The invention belongs to the technical field of heat supply systems, and discloses a regional heat supply system optimization control method for multi-heat-source networking operation. The method comprises the steps that S1, physical entity data, hydraulic working condition data and temperature data in a regional heat supply pipe network are collected in real time, an adjacent matrix is constructed according to the actual connection relation of the physical entity data, and a digital network architecture is formed; s2, dividing the digital network architecture into a plurality of sub-architectures based on an improved GN algorithm, and establishing a state space model for each sub-architecture; and S3, constructing a rapid simulation model based on the state space model, and continuously fusing each physical entity data and a preset deviation range through a physical information neural network. According to the method, the thermal state change caused by hydraulic adjustment and the reaction of the thermal change on the hydraulic resistance characteristic can be captured in real time, meanwhile, all physical entity data and hydraulic working conditions are processed in a unified mode, and deviation caused by decoupling simplification in a traditional method is reduced.

The invention provides a combined heat and power system and a control method thereof, and relates to the technical field of combined heat and power. The system comprises a fuel gas heat and power cogeneration subsystem, a heat supply subsystem and a fused salt heat storage subsystem, the fuel gas heat and power cogeneration subsystem is used for fuel gas power supply, the fused salt heat storage subsystem can convert solar energy and / or flue gas generated by power supply into heat energy of high-temperature fused salt to be stored, and the heat supply subsystem conducts primary heating on heat supply return water through geothermal energy; and flue gas and / or high-temperature fused salt generated by power supply are / is used for conducting secondary heating on heat supply return water. Geothermal energy, solar energy and fused salt heat storage are coupled, and renewable energy sources are fully utilized for heat and power cogeneration, so that the power supply requirement and the heat supply requirement of a user are met. In the ground source heat pump unit, primary heating is conducted through geothermal energy, heat supply return water is heated into warm water, then the warm water is secondarily heated into hot water through smoke in the gas heat and power cogeneration system, the compression ratio of a compressor in a ground source heat pump can be reduced, and power consumption of the compressor is reduced.

The embodiment of the invention discloses a peak regulation method, device and equipment for a cogeneration unit and a storage medium, and relates to the technical field of electric power, and the method comprises the steps: determining the heat user demand heat of a preset region in a current unit time length based on the heat supply scene information of heat users in the preset region and a predicted outdoor temperature sequence of the preset region in the current unit time length, based on heat supply network heat supply steam information extracted from the combined heat and power generation unit by a heat supply network heat supply system in the preset area in the current unit time, heat source heat supply heat of the preset area in the current unit time is determined; the supply and demand deviation is determined according to the heat user demand heat and the heat source heat supply heat, and when the supply and demand deviation is larger than a set deviation threshold value, a heat storage adjusting valve is opened to start a heat storage mode of the heat supply network heat supply system, and when the heat user demand heat is larger than the heat source heat supply heat, heat stored by the heat supply network heat supply system in the heat storage mode is used for heat supply. And the peak regulation flexibility of the cogeneration unit is improved in a peak load shifting manner.

The embodiment of the invention provides a multi-steam-source cooperative frequency modulation combined heat and power generation system and a control method. The system comprises a boiler, a high-pressure cylinder, an intermediate-pressure cylinder, a low-pressure cylinder, a power generator, a multi-stage regenerative heater, a heating system and a heating steam supply pipeline. A main steam outlet of the boiler is connected to the high-pressure cylinder through a main steam pipeline, a steam exhaust port of the high-pressure cylinder is connected to the intermediate-pressure cylinder through a pipeline, a steam exhaust port of the intermediate-pressure cylinder is connected to the low-pressure cylinder through a pipeline, and a steam exhaust port of the low-pressure cylinder is connected to the generator through a pipeline. A condensate water outlet of the medium-pressure cylinder is communicated to a condensate water inlet of the boiler through a first condensate water pipeline; the heating system is communicated with a steam exhaust port of the medium-pressure cylinder through a heating steam supply pipeline; the multi-stage regenerative heater is arranged on the first condensate water pipeline and connected with the high-pressure cylinder and / or the intermediate-pressure cylinder through steam extraction pipelines, and steam extraction adjusting valves are correspondingly arranged on the steam extraction pipeline between the high-pressure cylinder and the multi-stage regenerative heater and / or the steam extraction pipeline between the intermediate-pressure cylinder and the multi-stage regenerative heater.

The invention discloses a fuel gas and steam combined cycle power generation system coupling fused salt heat storage and biomass energy storage, which comprises a fuel gas and steam combined cycle power generation subsystem, a fused salt heat storage and release subsystem and a biomass energy storage system, an outlet of the gas-steam combined cycle power generation subsystem is connected with the fused salt heat storage and release subsystem and the biomass energy storage system, and a smoke outlet of the biomass energy storage system is connected with the gas-steam combined cycle power generation subsystem. And the utilization efficiency of energy and the economical efficiency of the system are improved.

A system includes a gas treatment system having first and second gas capture systems and a steam supply circuit. The first gas capture system is configured to capture a first portion of an undesirable gas from a combined cycle power plant. The second gas capture system is configured to capture a second portion of the undesirable gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series relative to a fluid flow path through the combined cycle power plant. The steam supply circuit includes a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply circuit is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant.

A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.

A system for producing CO and CO2 to achieve an efficient oil recovery operation that minimizes undesirable gaseous emissions is provided. The system includes a portable CO-producing device, a portable CO2-producing device located proximate to the reservoir, and a gas collecting device configured to receive CO and CO2 and selectively distribute a desired ratio of CO and CO2 dynamically based on current reservoir conditions. Producing CO2 proximate to the reservoir comprises reforming carbon-based fuel within oxygen. Electrical energy generated is used to selectively distribute the desired ratio of CO / CO2 to the reservoir with de minimis greenhouse gases produced transmitted into the atmosphere. The system is an energy-efficient arrangement that recycles and reuses by-products and unused products from the process. Greenhouse gas emissions are significantly reduced compared to conventional processes by-products are fully utilized. Hydrogen produced can be used to generate electricity, as can heat generated from other sources within the process.

MEANS FOR SOLVING THE PROBLEM: To provide an inlet duct system for a heat recovery steam generator.SOLUTION: A system (10) includes an exhaust diffuser system (22) for a heat recovery steam generator (HRSG) (16). The system (10) includes an inlet portion (23), a diffuser portion (24) axially extending from the inlet portion (23), and an outlet portion (26) fluidly coupled to an axial distal end of the diffuser portion (24), where an outlet extent (252) of the outlet portion (26) is greater than an inlet extent (254) of the inlet portion (23). The diffuser portion (24) includes multiple wall portions (272), and the multiple wall portions (272) are incrementally angled relative to an axial extent (258) extending from the inlet portion (23) to the outlet portion (26). The system (10) may further include a gas turbine engine (12) coupled to the inlet portion (23), and the HRSG (16) coupled to the outlet portion (26).SELECTED DRAWING: Figure 2

The present invention provides an energy optimal management system using turquoise hydrogen, the system comprising: a turquoise hydrogen production system (300) in which a portion of methane flows and is pyrolyzed so that turquoise hydrogen and heat are produced; a fuel cell (500) to which the turquoise hydrogen produced in the turquoise hydrogen production system (300) flows so that electricity and heat are produced by means of an electrical reaction; a hydrogen engine system (700) in which the turquoise hydrogen produced in the turquoise hydrogen production system (300) flows and is combusted so that electricity and heat are produced; and a cogeneration system (600) to which the other portion of methane flows and heat flows from the fuel cell (500) so that electricity and heat are produced.

A thermal energy storage (TES) system converts variable renewable electricity (VRE) to continuous heat at over 900° C. Intermittent electrical energy heats a solid medium. Heat from the solid medium is delivered continuously on demand. Heat delivery via flowing gas establishes a thermocline which maintains high outlet temperature throughout discharge. The delivered heat which may be used for processes including power generation and cogeneration. Configurations of simple cycle systems and combined cycle power plants using thermal energy storage units can provide even greater efficiency and responsiveness.

The invention belongs to the technical field of gas turbine cooling, and particularly relates to a gas turbine cooling air multi-energy combined supply system. Comprising a multi-energy combined supply system, a gas turbine system and a transcritical Rankine cycle system, the gas turbine system and the transcritical Rankine cycle system are coupled through a TCA, cooling air in the multi-energy combined supply system is cooled through the TCA and then enters a gas turbine, and a medium in the transcritical Rankine cycle system absorbs heat in the TCA and then enters a turbine to expand and do work. Cooling water outside the system absorbs heat through a condenser in the transcritical Rankine cycle system to form high-temperature water, the high-temperature water supplies heat to a bromine cooling unit in the multi-energy combined supply system, and low-temperature water generated by the bromine cooling unit is atomized and then mixed with inlet air of an air compressor so as to reduce the inlet air temperature. According to the system, the combined cycle power generation efficiency can be improved, multi-energy combined supply and stable energy recovery of gas turbine cooling air can be achieved, and safe operation of a gas turbine cooling system is fundamentally guaranteed.

A gas turbine combustion system includes a combustor that has at least two injection stages each configured to inject fuel into a combustion chamber of the combustor. A fuel supply circuit is in fluid communication with the at least two injection stages for providing the fuel from a fuel supply to the injection stages. The fuel supply circuit includes at least two branches, each branch being fluidly coupled to a respective injection stage. The gas turbine combustion system further includes at least two heat exchangers fluidly coupled to a thermal fluid supply. Each heat exchanger is disposed in thermal communication on a respective branch of the at least two branches for modifying a temperature of fuel within the respective branch.

A process for process for generating power in an ammonia-fueled gas turbine power plant includes flowing an ammonia feed stream to an ammonia cracker reactor in geographical proximity to an ammonia-fueled gas turbine power plant to crack ammonia feed stream under cracking conditions, thereby producing a product effluent comprising ammonia and hydrogen, flowing the product effluent comprising ammonia and hydrogen to an ammonia-fueled gas turbine of an ammonia-fueled gas turbine power plant, and combusting the product effluent comprising ammonia and hydrogen to drive the ammonia-fueled gas turbine. An exhaust gas stream generated from the ammonia-fueled gas turbine is recycled back to supply heat to the ammonia cracker reactor.

A method and an apparatus for treating comminuted waste material the method comprising: •a) providing a heating chamber (28) and one or more combustion heating means (40a-f) for heating the contents of the heating chamber (28), the heating chamber (28) having an inlet (21) and an outlet (22), •b) feeding comminuted waste material through the inlet (21) and into the heating chamber (28); •c) heating the comminuted waste material in the heating chamber (28), using the combustion heating means (40a-f), to generate a combustible gas; and •d) supplying at least a portion of the generated combustible gas to the one or more combustion heating means (40a-f) for heating the heating chamber (28).

A system includes a heat exchanger having a plurality of tubes arranged in a tube bundle having opposite first and second sides, opposite third and fourth sides extending from the first side to the second side, and opposite fifth and sixth sides extending from the first side to the second side, wherein the fifth and sixth sides extend between the third and fourth sides. The heat exchanger further includes a plurality of external flow lanes extending across the tube bundle and between the fifth and sixth sides outside of the plurality of tubes. Each tube of the plurality of tubes comprises a plurality of tubing portions extending in opposite first and second directions between the first and second sides in a sequence, and each successive tubing portion in the sequence switches lanes between the plurality of external flow lanes relative to a preceding tubing portion.

The invention discloses steam turbine high-low pressure bypass heat supply equipment, which relates to the technical field of heat energy engineering and power machinery, and comprises a signal acquisition module, an offset early warning module, a correction control module and a stable operation module, and constructing a time anchor point set, and generating a phase residual frequency spectrum for identifying a steam flow fluctuation source. According to the method, signals are collected through a unified time base line, a steam fluctuation source is identified in combination with a phase residual frequency spectrum, an impact track is reconstructed through phase conjugate inversion, and an overtemperature risk window is identified. Feedforward correction control is generated through track playback and predictive mapping, real-time rearrangement of valve behaviors is achieved, and the operation stability and the overtemperature resistance of the steam turbine under the deep peak regulation and disturbance conditions are improved.

The utility model provides a heat transfer strengthening structure, a heat transfer strengthening pipe and a preheating device. The heat transfer strengthening structure comprises a coal water slurry pipe and at least one protrusion distributed on the inner wall of the coal water slurry pipe. The ratio of the height of the protrusions to the inner diameter of the coal water slurry pipe is (1-8): 50. The heat transfer strengthening pipe comprises the heat transfer strengthening pipe structure. The preheating device comprises a shell and the heat transfer strengthening pipe located in the shell. According to the heat transfer strengthening structure, the protrusions are arranged on the inner wall of the coal water slurry pipe and serve as inner wall face modification, blocking during flowing of coal water slurry is prevented, and heat transfer strengthening is facilitated.

A small coal-fired cogeneration peak shaving system coupled with fused salt heat storage comprises a cogeneration coal-fired generator set and a fused salt heat storage system. The combined heat and power generation coal-fired generator set is composed of a back pressure unit and a straight condensing unit. The fused salt heat storage system is composed of a low-temperature fused salt tank, a high-temperature fused salt tank, a fused salt electric heater, a steam reheater and a steam superheater. During electricity consumption valley, the molten salt is heated through valley electricity, and electric energy is converted into heat energy to be stored; when the electricity utilization peak value occurs, heat stored in the high-temperature molten salt tank is released, and feed water is heated into high-pressure steam for direct heat supply; the residual feed water is conveyed to a hearth to generate high-temperature steam, then the high-temperature steam enters a back pressure unit and a straight condensing unit for power generation, meanwhile, part of exhaust steam of the back pressure unit is extracted to meet the low-pressure steam heat supply requirement, and the capacity of the unit for participating in power grid peak regulation is improved; the small coal-fired combined heat and power generation system can participate in peak regulation of the power grid while meeting the heat supply requirement, and the operation flexibility and reliability are improved.

A method including: operating a pumped-heat energy storage (“PHES”) system in a generation mode to generate electricity; and responsive, at least in part, to a determination that a power generation plant will reduce supply of electricity to an electrical grid by a reduction amount of electricity, changing modes of the PHES system from the generation mode to operate in a charge mode. Operating in the charge mode can include receiving a charge amount of electricity, at least equal to the reduction amount of electricity, into the PHES system from the power generation plant and converting at least a portion of the charge amount of electricity to stored thermal energy.

An integrated gasification and power generation system includes a gasifier configured to receive biomass and generate syngas, wherein the gasifier is configured to operate at a pressure of approximately 100 bar to approximately 400 bar. The system further includes a recuperated Brayton thermodynamic power generation loop configured to receive the generated syngas and convert the generated syngas into a CO2 working fluid, wherein at least a portion of the CO2 working fluid from the power generation loop is reintroduced from the power generation loop to the gasifier.

The invention provides a method, device and equipment for controlling the steam drum water level of a gas-steam combined cycle unit. The method comprises the steps that the opening degree of an inlet guide vane of a gas compressor, the turbine exhaust temperature, the feed water flow, the steam flow, a steam drum water level set value and the steam drum water level are obtained in real time; according to the opening degree of an inlet guide vane of a gas compressor and the exhaust temperature of a turbine, the gas turbine side feed-forward control quantity is determined; according to the steam drum water level set value and the steam drum water level, a first PID controller is adopted to determine an original feed water flow set value; according to the feed water flow, the steam flow, the original feed water flow set value and the gas turbine side feed-forward control quantity, a second PID controller is adopted to determine a first feed water adjusting valve opening instruction; and adjusting the opening degree of the feed water adjusting valve according to the first feed water adjusting valve opening degree instruction, and controlling the steam drum water level of the gas-steam combined cycle unit. According to the invention, reliable guarantee is provided for safe and efficient operation of the unit through a cooperative regulation mechanism of the gas turbine side feed-forward control quantity and three-impulse control.

The present invention relates to a heat exchange substation (50) of an energy distribution system comprising: a heat exchanger (51) with thermal inertia comprising a primary side (37a) connected to a primary supply line (36) and to a primary return line (37) and a secondary side (37b), opposite the first primary side (37a), the secondary side (37b) being connected to a secondary supply line (56) and to a secondary return line (57) of a secondary heating circuit (68), the secondary supply and return lines (56, 57) being in communication with one or more heating units (18), wherein the heat exchanger (51) comprises a tank (67) within which a first shell- and-tube circuit (81) is arranged connected at the inlet to the primary supply line (36) and at the outlet to the primary return line (37) and a second shell-and-tube circuit (82) connected at the inlet to the secondary return line (57) and at the outlet to the secondary supply line (56), and the tank (67) contains a phase change material (71), the first shell-and-tube circuit (81) and the second shell-and- tube circuit (82) being in contact with the phase change material (71).

The present invention discloses a slag remover capable of automatically replenishing water, comprising a slag receiving portion, a water trough, a slag pushing assembly, and a water replenishing device. The slag pushing assembly comprises a slag pushing arm and a driving mechanism. The driving mechanism drives the slag pushing arm to push the garbage and waste slag from the rear trough section to the front trough section of the water trough. The slag pushing arm is in a first position in the front trough section of the water trough and in a second position in the rear trough section of the water trough. The water replenishing device comprises a water tank, a water replenishing pipe, and a solenoid valve. The solenoid valve is electrically coupled to the driving mechanism to receive a swing position signal of the slag pushing arm. When the slag pushing arm swings from the first position to the second position, the solenoid valve opens the water replenishing pipe to replenish water to the water trough. When the slag pushing arm swings from the second position to the first position, the solenoid valve closes the water replenishing pipe. In this way, the water replenishing device can replenish water to the water trough at a predetermined time, avoiding the problem of uncontrollable water level in the water trough. At the same time, the amount of water in the water trough does not increase during the slag pushing process, avoiding the problem of rising water level in the water trough, causing overflow or excessive water in the garbage and waste slag.

The present application relates to the technical field of cooling water system control, especially to a self-shutdown control method for a closed cycle cooling water system of a gas turbine combined cycle unit. The closed cycle cooling water system comprises multiple closed water pumps and multiple closed coolers. The present application realizes full automatic control of three closed water pumps, optimizes the standby logic of the closed water pumps, sets up a primary standby function and a secondary standby function, and integrates all the three closed water pumps into the shutdown control process. Through the closed cooler shutdown process and the closed water pump shutdown process, the most suitable closed cooler and closed water pump are automatically selected for shutdown, and the shutdown of the closed cycle water system is realized in an orderly and efficient manner according to the established rules. Without the need for human judgment and operation by the operation personnel, the full automatic shutdown of the closed cycle cooling water system is realized without disturbing the stable operation state of the unit, and the labor intensity of the operation personnel is reduced, and the safety and the automation level of the unit are improved.