CN116920581A - Carbon dioxide recovery control system and method for natural gas power ship - Google Patents
Carbon dioxide recovery control system and method for natural gas power ship Download PDFInfo
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- CN116920581A CN116920581A CN202311115697.2A CN202311115697A CN116920581A CN 116920581 A CN116920581 A CN 116920581A CN 202311115697 A CN202311115697 A CN 202311115697A CN 116920581 A CN116920581 A CN 116920581A
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 183
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 104
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 89
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 89
- 239000003345 natural gas Substances 0.000 title claims abstract description 52
- 238000011084 recovery Methods 0.000 title claims abstract description 52
- 238000000034 method Methods 0.000 title claims abstract description 28
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims abstract description 218
- 239000003546 flue gas Substances 0.000 claims abstract description 218
- 238000005507 spraying Methods 0.000 claims abstract description 163
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- 238000001816 cooling Methods 0.000 claims abstract description 26
- 230000004044 response Effects 0.000 claims description 101
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- OFBQJSOFQDEBGM-UHFFFAOYSA-N Pentane Chemical compound CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 claims description 69
- 239000007788 liquid Substances 0.000 claims description 33
- 238000004458 analytical method Methods 0.000 claims description 19
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- 238000009833 condensation Methods 0.000 description 7
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Classifications
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/18—Absorbing units; Liquid distributors therefor
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D47/00—Separating dispersed particles from gases, air or vapours by liquid as separating agent
- B01D47/06—Spray cleaning
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/002—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by condensation
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1412—Controlling the absorption process
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1425—Regeneration of liquid absorbents
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1456—Removing acid components
- B01D53/1475—Removing carbon dioxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2258/00—Sources of waste gases
- B01D2258/01—Engine exhaust gases
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2258/00—Sources of waste gases
- B01D2258/02—Other waste gases
- B01D2258/0283—Flue gases
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Abstract
The application discloses a carbon dioxide recovery control system and a method for a natural gas power ship, wherein in the process of cooling cooled flue gas to about-90 ℃ through lower section spraying of a spray tower, the spraying quantity is adaptively adjusted based on the temperature change of the cooled flue gas.
Description
Technical Field
The application relates to the technical field of intelligent recovery control, in particular to a carbon dioxide recovery control system and method for a natural gas power ship.
Background
At present, liquefied Natural Gas (LNG) powered vessels are widely used in the shipping industry, using natural gas as a fuel, which has lower carbon emissions and air pollutant emissions than conventional petroleum fuels, with less environmental impact. However, although LNG fuels are relatively clean, a large amount of carbon dioxide (CO 2 ) And (5) discharging.
In order to cope with global climate change and reduce greenhouse gas emissions in the shipping industry, the International Maritime Organization (IMO) passed a preliminary strategy on reducing shipping greenhouse gas emissions, which aims to reduce greenhouse gas emissions of ships, including the requirements for LNG-powered ships.
In natural gas powered vessels, the main objective of the carbon dioxide recovery control system is to recover and separate carbon dioxide from the flue gas produced after combustion to reduce its emissions to the atmosphere. In order to improve the energy utilization efficiency of the LNG power ship and reduce the carbon dioxide emission, the gasification cold energy of the LNG power ship may be utilized to capture carbon dioxide in the flue gas.
However, the current spray control scheme for gasification cold energy is only to perform fixed control through experience of a professional technician, and during the running process of a ship, factors such as fuel components, loads, environmental conditions and the like can change, and the changes can lead to different flue gas temperatures, so that the required spray amount is different. In addition, in the actual carbon dioxide recovery process, the flue gas temperature can be changed continuously, if the flue gas temperature is controlled by only depending on the fixed spraying amount, the waste of energy sources or the deficiency of carbon dioxide recovery effect can be caused, and the actual application requirements are difficult to meet.
Accordingly, an optimized carbon dioxide recovery control system for a natural gas powered vessel is desired.
Disclosure of Invention
The embodiment of the application provides a carbon dioxide recovery control system and a method for a natural gas power ship, wherein in the process of cooling cooled flue gas to about-90 ℃ through lower-section spraying of a spray tower, the spray quantity is adaptively adjusted based on the temperature change of the cooled flue gas.
The embodiment of the application also provides a carbon dioxide recovery control system for the natural gas power ship, which comprises the following components:
pre-spray tower, flue gas cooler, H 2 O solid-liquid separator, n-pentane circulating pump, n-pentane multi-medium cooler and CO 2 A solid-liquid separator and an n-pentane LNG heat exchanger;
the method comprises the steps of feeding high-temperature flue gas generated after natural gas is combusted into a pre-spray tower for cooling treatment to obtain cooled flue gas, and feeding the cooled flue gas into the spray tower for spraying and cooling treatment based on low-temperature n-pentane liquid;
wherein, the flue gas after cooling is sent into the spray column carries out the spray cooling treatment based on low temperature n-pentane liquid, includes:
spraying the cooled flue gas through the lower section of the spray tower, cooling the cooled flue gas to about-90 ℃, and passing through the H 2 O solid-liquid separator for condensing and separating out cooled smokeH in the air 2 O and n-pentane recycle; and
cooling the cooled flue gas to about-115 ℃ through upper-section spraying of the spray tower, and condensing and separating CO in the flue gas 2 In the form of dry ice through the CO 2 The solid-liquid separator separates out the n-pentane circulating liquid.
The embodiment of the application also provides a carbon dioxide recovery control method for the natural gas power ship, which comprises the following steps:
acquiring flue gas temperature values and spraying speed values at a plurality of preset time points in a preset time period;
carrying out time sequence cooperative response analysis on the flue gas temperature values and the spraying speed values at a plurality of preset time points to obtain flue gas temperature-spraying speed response time sequence correlation characteristics;
based on the flue gas temperature-spray speed response time sequence correlation characteristics, it is determined that the spray speed value at the current time point should be increased, decreased or maintained.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, it being obvious that the drawings in the following description are only some embodiments of the application, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art. In the drawings:
fig. 1 is a schematic structural diagram of a carbon dioxide recovery control system for a natural gas powered vessel according to an embodiment of the present application.
Fig. 2 is a block diagram of the controller in a carbon dioxide recovery control system for a natural gas powered vessel according to an embodiment of the present application.
Fig. 3 is a flowchart of a carbon dioxide recovery control method for a natural gas powered vessel according to an embodiment of the present application.
Fig. 4 is a schematic diagram of a system architecture of a carbon dioxide recovery control method for a natural gas powered vessel according to an embodiment of the present application.
Fig. 5 is an application scenario diagram of a carbon dioxide recovery control system for a natural gas powered vessel according to an embodiment of the present application.
Wherein, 100, a carbon dioxide recovery control system for a natural gas powered vessel; 1. a pre-spray tower; 2. a spray tower; 3. a flue gas cooler; 4. h 2 An O solid-liquid separator; 5. a n-pentane circulation pump; 6. n-pentane multi-medium cooler; 7. CO 2 A solid-liquid separator; 8. n-pentane LNG heat exchanger.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present application more apparent, the embodiments of the present application will be described in further detail with reference to the accompanying drawings. The exemplary embodiments of the present application and their descriptions herein are for the purpose of explaining the present application, but are not to be construed as limiting the application.
Unless defined otherwise, all technical and scientific terms used in the embodiments of the application have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used in the present application is for the purpose of describing particular embodiments only and is not intended to limit the scope of the present application.
In describing embodiments of the present application, unless otherwise indicated and limited thereto, the term "connected" should be construed broadly, for example, it may be an electrical connection, or may be a communication between two elements, or may be a direct connection, or may be an indirect connection via an intermediate medium, and it will be understood by those skilled in the art that the specific meaning of the term may be interpreted according to circumstances.
It should be noted that, the term "first\second\third" related to the embodiment of the present application is merely to distinguish similar objects, and does not represent a specific order for the objects, it is to be understood that "first\second\third" may interchange a specific order or sequence where allowed. It is to be understood that the "first\second\third" distinguishing objects may be interchanged where appropriate such that embodiments of the application described herein may be practiced in sequences other than those illustrated or described herein.
It will be appreciated that a Liquefied Natural Gas (LNG) powered vessel is a vessel that uses LNG as fuel, and has many advantages over conventional fuel powered vessels. LNG is a clean fuel, and carbon dioxide (CO) is produced after combustion 2 ) The emission amount is low, and the emission of sulfur oxides (SOx) and Particulate Matters (PM) is hardly generated. Compared with fuel ships, the LNG power ship can remarkably reduce air pollution and greenhouse gas emission.
LNG fuels have a high heating value and a low combustion temperature, so that the combustion efficiency is higher. Compared with the traditional fuel ship, the LNG power ship has lower fuel consumption, thereby reducing the operation cost. LNG is a non-explosive and non-toxic fuel that is safer to burn and store than other fuel types. In addition, multiple safety systems are employed in LNG ship design, including fire and leak control systems, to ensure the safety of the ship operation.
The engine noise of the LNG powered ship is lower and the impact on marine life and nearby residents is smaller. This has a positive effect on protecting the marine ecosystem and improving the environment around sails. As the global demand for sustainable energy increases, LNG as a transitional fuel is considered an important option for reducing carbon emissions and achieving energy conversion. The use of LNG powered vessels helps to reduce reliance on conventional petroleum fuels, promoting sustainable development.
In recent years, LNG-powered vessels have been widely used in the shipping industry. In particular, LNG powered vessels are widely used in ocean going and port transportation to meet environmental regulations and carbon emission reduction requirements. With the continued development of LNG infrastructure and advances in technology, future applications of LNG-powered vessels are expected to expand further.
Capturing carbon dioxide in flue gas by utilizing gasification cold energy of LNG power ships is an effective method for improving energy utilization efficiency and reducing carbon dioxide emission. In LNG powered vessels, liquefied Natural Gas (LNG) is used as fuel for gasification to produce high temperature combustion gases that drive an engine. In this process, gasification cold energy (also referred to as cryogenic heat energy) is released into the environment in the form of waste heat. If this part of the waste heat can be used for carbon dioxide capture, the energy utilization efficiency can be improved, and this can be converted into useful energy.
The combustion process of LNG powered vessels produces carbon dioxide emissions, which is one of the major greenhouse gases. The carbon dioxide in the flue gas is captured, so that the amount of the carbon dioxide released into the atmosphere can be reduced, the carbon emission of the ship is reduced, the climate change can be dealt with, and the global requirement for reducing the emission of greenhouse gases is met.
By capturing the carbon dioxide in the flue gas, it can be treated and stored to prevent its release into the atmosphere. Carbon capture and storage technology (CCS) is a technology that already exists and is widely used to safely store carbon dioxide in underground reservoirs or other suitable locations. The gasification cold energy of the LNG power ship is utilized for carbon capture, and a promising application field is provided for the future implementation of CCS.
The utilization of the gasification cold energy of LNG powered vessels to capture carbon dioxide in flue gas is of great necessity. The method can not only improve the energy utilization efficiency, but also reduce the carbon emission of the ship, and makes positive contribution to sustainable development and coping with climate change. However, specific implementation details and technical challenges require further research and development.
In one embodiment of the present application, fig. 1 is a schematic structural diagram of a carbon dioxide recovery control system for a natural gas powered vessel according to an embodiment of the present application. As shown in fig. 1, a carbon dioxide recovery control system 100 for a natural gas powered vessel according to an embodiment of the present application includes: pre-spray tower 1, spray tower 2, flue gas cooler 3, H 2 O solid-liquid separator 4, n-pentane circulating pump 5, n-pentane multi-medium cooler 6, CO 2 A solid-liquid separator 7 and an n-pentane LNG heat exchanger 8; the method comprises the steps of feeding high-temperature flue gas generated after natural gas is combusted into a pre-spray tower 1 for cooling treatment to obtain cooled flue gas, and feeding the cooled flue gas into a spray tower 2 for spraying cooling treatment based on low-temperature n-pentane liquid; wherein, the temperature-reduced smokeThe gas is sent into the spray tower 2 for spray cooling treatment based on low-temperature n-pentane liquid, and the spray cooling treatment comprises the following steps: spraying the cooled flue gas through the lower section of the spray tower 2, cooling to about-90 ℃, and passing through the H 2 The O solid-liquid separator 4 condenses and separates H in the cooled flue gas 2 O and n-pentane recycle; and cooling the cooled flue gas to about-115 ℃ through upper-stage spraying of the spray tower 2, and condensing and separating CO in the flue gas 2 In the form of dry ice through the CO 2 The solid-liquid separator 7 separates out the n-pentane circulating liquid.
The workflow of capturing CO 2:
as can be seen from fig. 1, the high temperature flue gas generated by the combustion of natural gas by the main engine is fed into the pre-spray tower 1, and the pre-spray tower 1 has the function of reducing the temperature of the flue gas to as close to 0 ℃ as possible. In order to save cold energy consumption, the method is realized by a 2-stage spraying mode: the lower spray is cooled by seawater, so that the temperature of the flue gas can be reduced to about 40 ℃; the upper stage spraying is carried out by heating the low-temperature natural gas (about-90 ℃) and the low-temperature flue gas (about-115 ℃) of the final product, and the temperature of the flue gas is reduced to be close to 0 ℃. Condensed water in the flue gas is discharged from the bottom of the tower together with seawater.
The flue gas cooled by the pre-spray tower 1 enters a spray tower 2 and is further cooled to H by low-temperature n-pentane liquid spraying 2 O and CO 2 Is used for the condensation separation of the catalyst. The reason for adopting n-pentane as the spray liquid is mainly as follows: 1) N-pentane (C) 5 H 12 ) The melting point is-129.8 ℃, the boiling point is 36.1 ℃, and the liquid temperature range satisfies the condition of condensation to remove H 2 O and CO 2 Is not limited; 2) H 2 O and CO 2 Is insoluble in n-pentane and can therefore be separated from the n-pentane coolant after condensation.
The spray tower 2 adopts a 2-section spray cooling mode: the lower spray cools the flue gas to about-90 ℃ and then passes through H 2 The O solid-liquid separator 4 condenses and separates H in the flue gas 2 O and n-pentane recycle; the upper spray cools the flue gas to about-115 ℃ and condenses and separates CO in the flue gas 2 In the form of dry ice via CO 2 The solid-liquid separator 7 separates out the n-pentane circulating liquid. Upper section of spray tower 2The spray circulation liquid is cooled by LNG at the temperature of about-163 ℃, and the lower spray circulation liquid is used for recovering dry ice CO 2 Is cooled by the gasification latent heat of the natural gas at low temperature (about-115 ℃). The rest low-temperature flue gas enters a flue gas cooler 3 in the pre-spray tower 1 and is discharged after being heated by the flue gas.
The beneficial effects of the application are as follows:
1. develops a method for removing CO in the flue gas by spraying and cooling low-temperature pentane liquid and condensing at the same time 2 Is a process of (2). After the flue gas is sprayed by the chilled water, most of water in the flue gas is condensed and separated from the flue gas; then spraying low-temperature pentane to about-90 ℃ and condensing and separating H 2 O; finally, the mixture is further cooled to-115 ℃ by low-temperature pentane, and 90 percent of CO is separated by condensation 2 。
2. Energy saving, utilizing sea water as cold source for high temperature flue gas precooling, and simultaneously utilizing LNG gasification cold gradually to freeze flue gas to trap CO 2 。
3. The flue gas of the process does not need to be dehumidified before being cooled, but is directly sprayed and cooled; condensing the separated H 2 O and CO 2 Is insoluble in pentane and can be separated from the washing liquid simply.
4. The consumption of intermediate medium is less, and closed circulation is adopted.
Aiming at the technical problems, the technical conception of the application is that in the process of cooling the cooled flue gas to about-90 ℃ through the lower section spraying of the spray tower, the spraying quantity is adaptively adjusted based on the temperature change of the cooled flue gas, and in such a way, the problems of low efficiency and low accuracy caused by the intervention of professional technicians can be avoided, so that the condensing effect can meet the actual change condition of the flue gas temperature, the waste of energy sources can be avoided, and the recovery effect of carbon dioxide is improved.
Fig. 2 is a block diagram of the controller in the carbon dioxide recovery control system for a natural gas powered vessel according to an embodiment of the present application, and as shown in fig. 2, the carbon dioxide recovery control system for a natural gas powered vessel further includes a controller 10 for controlling a spray speed value of the spray tower; wherein the controller 10 includes: the data acquisition module 110 is configured to acquire flue gas temperature values and spraying speed values at a plurality of predetermined time points within a predetermined time period; the data cooperative responsiveness analysis module 120 is configured to perform time-sequence cooperative responsiveness analysis on the flue gas temperature values and the spraying speed values at the multiple predetermined time points to obtain a flue gas temperature-spraying speed response time-sequence correlation characteristic; the spray control module 130 is configured to determine, based on the flue gas temperature-spray speed response time sequence correlation characteristic, that a spray speed value at a current time point should be increased, decreased or maintained.
In the data acquisition module 110, the accuracy and reliability of the data acquisition device are ensured to obtain accurate flue gas temperature and spraying speed data. In addition, the time interval and the duration of data acquisition are reasonably set according to specific conditions so as to meet the real-time monitoring requirement on the change of the flue gas temperature and the spraying speed. Through the data acquisition module, the data of the flue gas temperature and the spraying speed can be acquired in real time, and a foundation is provided for subsequent collaborative responsiveness analysis and spraying control.
In the data cooperative responsiveness analysis module 120, a time sequence relationship between the flue gas temperature and the spraying speed needs to be considered when performing cooperative responsiveness analysis, including factors such as hysteresis effect and response speed. In addition, the selection of the analysis method and algorithm also needs to be reasonably designed and optimized according to the specific situation. Through the data collaborative responsiveness analysis module, the correlation characteristic between the flue gas temperature and the spraying speed can be known, a basis is provided for the spraying control module, and more accurate and efficient spraying control is realized.
In the spray control module 130, the spray control module needs to set a proper control strategy and algorithm according to actual situations and system requirements. Meanwhile, the response speed and the adjustment precision of the spraying equipment also need to be considered so as to ensure the accuracy and the stability of the spraying control. The spraying control module can adjust the spraying speed in real time according to the change of the flue gas temperature so as to achieve the purpose of controlling the flue gas temperature. Through accurate spray control, the energy utilization efficiency can be improved, the carbon dioxide emission is reduced, and the stability and the performance of the system are improved.
The various modules of the controller play a critical role in LNG powered vessels. The data acquisition module acquires real-time flue gas temperature and spraying speed data, the data cooperative responsiveness analysis module analyzes time sequence correlation characteristics between the flue gas temperature and the spraying speed data, and the spraying control module adjusts the spraying speed according to analysis results so as to improve the energy utilization efficiency and reduce the carbon dioxide emission. The cooperation of the modules can optimize the spraying system of the ship and improve the performance and environmental protection benefits.
Specifically, the data acquisition module 110 is configured to acquire the flue gas temperature value and the spraying speed value at a plurality of predetermined time points within a predetermined period. In the technical scheme of the application, firstly, the flue gas temperature value and the spraying speed value of a plurality of preset time points in a preset time period are obtained.
By acquiring flue gas temperature and spray velocity data at multiple time points, data analysis and trend prediction can be performed. By analyzing the change trend of the flue gas temperature, the possible change direction of the flue gas temperature at the current time point can be predicted. In combination with the data of the spray speed, the spray speed adjustment strategy to be adopted at the current time point can be presumed.
There is a certain response between the flue gas temperature and the spray speed. By acquiring the flue gas temperature and spraying speed data at a plurality of time points and analyzing, the response characteristics of the flue gas temperature and the spraying speed can be determined. Based on the characteristics, the flue gas temperature change trend at the current time point can be judged, and the spraying speed is correspondingly adjusted so as to realize the control and adjustment of the flue gas temperature.
By acquiring data at multiple time points, real-time spray rate control and optimization can be achieved. According to the change condition of the flue gas temperature, the spraying speed can be timely adjusted at the current time point by combining the response characteristics analyzed in advance, so that the optimal control effect is achieved. Through real-time control and optimization, the energy utilization efficiency can be improved, the carbon dioxide emission is reduced, and the stability and the performance of the system are ensured.
The acquisition of the flue gas temperature values and the spray velocity values at a plurality of predetermined time points over a predetermined period of time is important for determining that the spray velocity value at the current time point should be increased, should be decreased or should remain. Through data analysis, trend prediction and response adjustment, the flue gas temperature can be accurately controlled and adjusted, so that the energy utilization efficiency is improved, the carbon dioxide emission is reduced, and the performance of the system is optimized.
Specifically, the data cooperative responsiveness analysis module 120 is configured to perform time-sequence cooperative responsiveness analysis on the flue gas temperature values and the spraying speed values at the multiple predetermined time points to obtain a flue gas temperature-spraying speed response time-sequence correlation characteristic. The data collaborative responsiveness analysis module 120 includes: the data time sequence arrangement unit is used for respectively arranging the flue gas temperature values and the spraying speed values of the plurality of preset time points into a flue gas temperature time sequence input vector and a spraying speed time sequence input vector according to the time dimension; the position-by-position response association coding unit is used for carrying out position-by-position response association coding on the flue gas temperature time sequence input vector and the spraying speed time sequence input vector so as to obtain a flue gas temperature-spraying speed position-by-position response time sequence input vector; the vector segmentation unit is used for segmenting the position-by-position response time sequence input vector of the flue gas temperature-spraying speed to obtain a plurality of position-by-position response local time sequence input vectors of the flue gas temperature-spraying speed; the local time sequence response characteristic extraction unit is used for respectively extracting time sequence characteristics of the plurality of flue gas temperature-spraying speed position-by-position response local time sequence input vectors so as to obtain a plurality of flue gas temperature-spraying speed position-by-position response local time sequence characteristic vectors; the global time sequence correlation feature extraction unit is used for carrying out global correlation analysis on the local time sequence feature vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds so as to obtain a global context flue gas temperature-spraying speed position-by-position response time sequence feature vector which is used as the flue gas temperature-spraying speed response time sequence correlation feature.
Next, considering that the flue gas temperature value and the spraying speed value have a time sequence dynamic change rule in a time dimension, in order to effectively capture the time sequence cooperative association change characteristics of the flue gas temperature value and the spraying speed value, the flue gas temperature value and the spraying speed value at the plurality of preset time points are respectively arranged into a flue gas temperature time sequence input vector and a spraying speed time sequence input vector according to the time dimension, so that the time sequence distribution information of the flue gas temperature value and the spraying speed value is respectively integrated.
In one embodiment of the present application, the position-by-position response association coding unit is configured to: and dividing the position-by-position point between the flue gas temperature time sequence input vector and the spraying speed time sequence input vector to obtain a position-by-position response time sequence input vector of the flue gas temperature-spraying speed.
Then, in consideration of a cooperative association relationship due to suitability between the flue gas temperature value and the spray speed value, that is, in the actual control of the spray amount, the spray amount should be adaptively controlled based on a change in the flue gas temperature. Therefore, in the technical scheme of the application, in order to obtain the correlation and interaction between the flue gas temperature value and the spraying speed value, the correlation between the flue gas temperature value and the spraying speed value needs to be established. Based on the above, in the technical scheme of the application, the position-by-position response time sequence input vector of the flue gas temperature-spraying speed is obtained by dividing the position-by-position point between the time sequence input vector of the flue gas temperature and the time sequence input vector of the spraying speed, wherein the value corresponding to each position point in the time sequence input vector of the flue gas temperature-spraying speed represents the response association relation between the flue gas temperature and the spraying speed, and the association relation reflects the influence degree of the flue gas temperature on the spraying speed.
In practical applications, the operating conditions of the ship may change during operation, such as load changes, fuel composition changes, etc., which may affect the carbon dioxide recovery process. Therefore, in the technical scheme of the application, the position-by-position response time sequence input vector of the flue gas temperature-spraying speed is further segmented to obtain a plurality of position-by-position response local time sequence input vectors of the flue gas temperature-spraying speed, and thus, the whole position-by-position response time sequence input vector of the flue gas temperature-spraying speed is segmented into a plurality of local time sequence input vectors so as to better capture control characteristics in different time periods or different working conditions, namely, time sequence response correlation characteristics between the flue gas temperature and the spraying speed, and further, control requirements in different time periods or different working conditions are better analyzed and processed.
In one embodiment of the present application, the local timing response feature extraction unit is configured to: and respectively passing the local time sequence input vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds through a time sequence feature extractor based on a one-dimensional convolution layer to obtain local time sequence feature vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds.
Further, the local time sequence input vectors of the plurality of flue gas temperature-spraying speeds are subjected to feature mining in a time sequence feature extractor based on a one-dimensional convolution layer, so that local time sequence cooperative response associated feature information between the flue gas temperature and the spraying speeds in a time dimension is extracted, and the adaptive associated relation between the flue gas temperature and the spraying speeds in different time periods is more fully captured, so that the local time sequence feature vectors of the plurality of flue gas temperature-spraying speeds in the position-by-position response are obtained.
In one embodiment of the present application, the global timing related feature extraction unit is configured to: and the local time sequence characteristic vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds pass through a time sequence context encoder based on a converter module to obtain the time sequence characteristic vector of the global context flue gas temperature-spraying speed.
Then, considering that the correlation characteristics of the flue gas temperature and the spraying speed in each time period are different, that is, the correlation variation of the time sequence cooperative response between the flue gas temperature and the spraying speed is different, if the correlation characteristic information about the cooperative response between the flue gas temperature and the spraying speed in the whole time sequence is sufficiently captured, the spraying quantity is adaptively adjusted based on the temperature variation of the flue gas after the actual cooling.
Specifically, the spray control module 130 includes: the feature distribution optimizing unit is used for carrying out feature distribution optimization on the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector so as to obtain an optimized global context flue gas temperature-spraying speed position-by-position response time sequence feature vector; and the spraying speed classification unit is used for enabling the optimized global context flue gas temperature-spraying speed position-by-position response time sequence feature vector to pass through a classifier to obtain a classification result, wherein the classification result is used for indicating that the spraying speed value at the current time point should be increased, decreased or kept.
Particularly, in the technical scheme of the application, when the plurality of flue gas temperature-spraying speed position-by-position response local time sequence feature vectors pass through the time sequence context encoder based on the converter module, the local time sequence correlation features of the flue gas temperature-spraying speed response expressed by the flue gas temperature-spraying speed position-by-position response local time sequence feature vectors can be subjected to the context correlation encoding crossing local time domains. That is, in the case of performing association coding based on the local time domain whole, when the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector is classified by the classifier, a class probability mapping based on a scale heuristic of a local time domain scale is performed, and meanwhile, the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector is considered to include a local time domain time sequence association feature and a local time domain inter-time context association feature representation in a global time domain, that is, a mixed time sequence space feature representation is included, which can cause the training efficiency of the classifier to be reduced. Based on the above, the application performs semantic information homogenization activation of feature rank expression on the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector when the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector is classified by a classifier.
In an embodiment of the application, the feature distribution optimizing unit is configured to: carrying out semantic information homogenization activation of feature rank expression on the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector by using the following optimization formula to obtain the optimized global context flue gas temperature-spraying speed position-by-position response time sequence feature vector;
wherein, the optimization formula is:
wherein v is i Is the ith characteristic value of the global context flue gas temperature-spraying speed position-by-position response time sequence characteristic vector y, V 2 Representing the two norms of the global context flue gas temperature-spraying speed position-by-position response time sequence characteristic vector, log is logarithm based on 2, alpha is a weight super-parameter, v i ' is the i-th eigenvalue of the optimized global context flue gas temperature-spray velocity position-by-position response time sequence eigenvector.
Here, considering the feature distribution mapping of the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector V in the high-dimensional feature space to the classification regression space, different mapping modes are presented on different feature distribution levels based on the mixed time sequence spatial features, so that the mapping efficiency of a mapping strategy based on a scale heuristic is required to be improved, therefore, similar feature rank expressions can be activated in a similar manner by combining with the scale heuristic for feature matching based on rank expression semantic information homogenization of feature vector norms, and the correlation between feature rank expressions with larger difference can be reduced, thereby solving the problem that the probability expression mapping efficiency of the feature distribution of the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector V under different spatial rank expressions is low, and improving the training efficiency when the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector is classified by a classifier. Like this, can carry out the self-adaptation adjustment of spraying volume in real time based on the change condition of flue gas temperature after the cooling to make the condensation effect can satisfy the actual change condition of flue gas temperature, can avoid the waste of energy simultaneously, improve carbon dioxide's recovery effect.
Further, the global context flue gas temperature-spray velocity position-by-position response time sequence feature vector is passed through a classifier to obtain a classification result, which is used to indicate that the spray velocity value at the current point in time should be increased, decreased or maintained. That is, the classification is performed by the full-time response correlation characteristic between the temperature value of the cooled flue gas and the spraying speed value, so that the spraying speed is adaptively adjusted based on the temperature change condition of the flue gas after actual cooling, the condensation effect can meet the actual change condition of the flue gas temperature, and meanwhile, the waste of energy sources can be avoided.
In summary, the carbon dioxide recovery control system 100 for a natural gas powered vessel according to the embodiment of the present application is illustrated, which avoids the problems of low efficiency and low accuracy caused by the intervention of professional technicians, so that the condensation effect can meet the actual change condition of the flue gas temperature, and meanwhile, the waste of energy sources can be avoided, and the recovery effect of carbon dioxide is improved.
As described above, the carbon dioxide recovery control system 100 for a natural gas powered vessel according to an embodiment of the present application may be implemented in various terminal devices, such as a server or the like for carbon dioxide recovery control of a natural gas powered vessel. In one example, the carbon dioxide recovery control system 100 for a natural gas powered vessel according to an embodiment of the application may be integrated into the terminal device as one software module and/or hardware module. For example, the carbon dioxide recovery control system 100 for a natural gas powered vessel may be a software module in the operating system of the terminal device, or may be an application developed for the terminal device; of course, the carbon dioxide recovery control system 100 for a natural gas powered vessel may equally be one of the numerous hardware modules of the terminal equipment.
Alternatively, in another example, the carbon dioxide recovery control system 100 for a natural gas powered vessel and the terminal device may be separate devices, and the carbon dioxide recovery control system 100 for a natural gas powered vessel may be connected to the terminal device through a wired and/or wireless network and transmit interactive information in a agreed data format.
Fig. 3 is a flowchart of a carbon dioxide recovery control method for a natural gas powered vessel according to an embodiment of the present application. Fig. 4 is a schematic diagram of a system architecture of a carbon dioxide recovery control method for a natural gas powered vessel according to an embodiment of the present application. As shown in fig. 3 and 4, a carbon dioxide recovery control method for a natural gas powered vessel includes: 210, acquiring flue gas temperature values and spraying speed values at a plurality of preset time points in a preset time period; 220, carrying out time sequence collaborative responsiveness analysis on the flue gas temperature values and the spraying speed values at the plurality of preset time points to obtain flue gas temperature-spraying speed response time sequence correlation characteristics; 230, determining that the spray velocity value at the current point in time should be increased, decreased or maintained based on the flue gas temperature-spray velocity response time sequence correlation characteristics.
It will be appreciated by those skilled in the art that the specific operation of the respective steps in the above-described carbon dioxide recovery control method for a natural gas powered vessel has been described in detail in the above description of the carbon dioxide recovery control system for a natural gas powered vessel with reference to fig. 1 to 2, and thus, repetitive descriptions thereof will be omitted.
Fig. 5 is an application scenario diagram of a carbon dioxide recovery control system for a natural gas powered vessel according to an embodiment of the present application. As shown in fig. 5, in the application scenario, first, flue gas temperature values (e.g., C1 as illustrated in fig. 5) and spray velocity values (e.g., C2 as illustrated in fig. 5) at a plurality of predetermined time points within a predetermined period of time are acquired; the obtained flue gas temperature value and spray velocity value are then input into a server (e.g. S as illustrated in fig. 5) deployed with a carbon dioxide recovery control algorithm for the natural gas powered vessel, wherein the server is capable of processing the flue gas temperature value and the spray velocity value based on the carbon dioxide recovery control algorithm for the natural gas powered vessel to determine that the spray velocity value at the current point in time should be increased, decreased or should be maintained.
The foregoing description of the embodiments has been provided for the purpose of illustrating the general principles of the application, and is not meant to limit the scope of the application, but to limit the application to the particular embodiments, and any modifications, equivalents, improvements, etc. that fall within the spirit and principles of the application are intended to be included within the scope of the application.
Claims (10)
1. A carbon dioxide recovery control system for a natural gas powered vessel, comprising: pre-spray tower, flue gas cooler, H 2 O solid-liquid separator, n-pentane circulating pump, n-pentane multi-medium cooler and CO 2 A solid-liquid separator and an n-pentane LNG heat exchanger;
the method comprises the steps of feeding high-temperature flue gas generated after natural gas is combusted into a pre-spray tower for cooling treatment to obtain cooled flue gas, and feeding the cooled flue gas into the spray tower for spraying and cooling treatment based on low-temperature n-pentane liquid;
wherein, the flue gas after cooling is sent into the spray column carries out the spray cooling treatment based on low temperature n-pentane liquid, includes:
spraying the cooled flue gas through the lower section of the spray tower, cooling the cooled flue gas to about-90 ℃, and passing through the H 2 Condensing and separating H in the cooled flue gas by using an O solid-liquid separator 2 O and n-pentane recycle; and
cooling the cooled flue gas to about-115 ℃ through upper-section spraying of the spray tower, and condensing and separating CO in the flue gas 2 In the form of dry ice through the CO 2 The solid-liquid separator separates out the n-pentane circulating liquid.
2. The carbon dioxide recovery control system for a natural gas powered vessel of claim 1, further comprising a controller for controlling a spray velocity value of the spray tower;
wherein, the controller includes:
the data acquisition module is used for acquiring flue gas temperature values and spraying speed values at a plurality of preset time points in a preset time period;
the data cooperative responsiveness analysis module is used for carrying out time sequence cooperative responsiveness analysis on the flue gas temperature values and the spraying speed values at a plurality of preset time points so as to obtain flue gas temperature-spraying speed response time sequence correlation characteristics;
and the spraying control module is used for determining that the spraying speed value at the current time point should be increased, decreased or maintained based on the flue gas temperature-spraying speed response time sequence correlation characteristic.
3. The carbon dioxide recovery control system for a natural gas powered vessel of claim 2, wherein the data collaborative responsiveness analysis module comprises:
the data time sequence arrangement unit is used for respectively arranging the flue gas temperature values and the spraying speed values of the plurality of preset time points into a flue gas temperature time sequence input vector and a spraying speed time sequence input vector according to the time dimension;
the position-by-position response association coding unit is used for carrying out position-by-position response association coding on the flue gas temperature time sequence input vector and the spraying speed time sequence input vector so as to obtain a flue gas temperature-spraying speed position-by-position response time sequence input vector;
the vector segmentation unit is used for segmenting the position-by-position response time sequence input vector of the flue gas temperature-spraying speed to obtain a plurality of position-by-position response local time sequence input vectors of the flue gas temperature-spraying speed;
the local time sequence response characteristic extraction unit is used for respectively extracting time sequence characteristics of the plurality of flue gas temperature-spraying speed position-by-position response local time sequence input vectors so as to obtain a plurality of flue gas temperature-spraying speed position-by-position response local time sequence characteristic vectors;
the global time sequence correlation feature extraction unit is used for carrying out global correlation analysis on the local time sequence feature vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds so as to obtain a global context flue gas temperature-spraying speed position-by-position response time sequence feature vector which is used as the flue gas temperature-spraying speed response time sequence correlation feature.
4. A carbon dioxide recovery control system for a natural gas powered vessel as defined in claim 3, wherein the position-wise response association encoding unit is configured to: and dividing the position-by-position point between the flue gas temperature time sequence input vector and the spraying speed time sequence input vector to obtain a position-by-position response time sequence input vector of the flue gas temperature-spraying speed.
5. The carbon dioxide recovery control system for a natural gas powered vessel as defined in claim 4, wherein the local time series response feature extraction unit is configured to: and respectively passing the local time sequence input vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds through a time sequence feature extractor based on a one-dimensional convolution layer to obtain local time sequence feature vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds.
6. The carbon dioxide recovery control system for a natural gas powered vessel of claim 5, wherein the global timing-related feature extraction unit is configured to: and the local time sequence characteristic vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds pass through a time sequence context encoder based on a converter module to obtain the time sequence characteristic vector of the global context flue gas temperature-spraying speed.
7. The carbon dioxide recovery control system for a natural gas powered vessel of claim 6, wherein the spray control module comprises:
the feature distribution optimizing unit is used for carrying out feature distribution optimization on the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector so as to obtain an optimized global context flue gas temperature-spraying speed position-by-position response time sequence feature vector;
and the spraying speed classification unit is used for enabling the optimized global context flue gas temperature-spraying speed position-by-position response time sequence feature vector to pass through a classifier to obtain a classification result, wherein the classification result is used for indicating that the spraying speed value at the current time point should be increased, decreased or kept.
8. The carbon dioxide recovery control system for a natural gas powered vessel as defined in claim 7, wherein the feature distribution optimizing unit is configured to: carrying out semantic information homogenization activation of feature rank expression on the global context flue gas temperature-spraying speed position-by-position response time sequence feature vector by using the following optimization formula to obtain the optimized global context flue gas temperature-spraying speed position-by-position response time sequence feature vector;
wherein, the optimization formula is:
wherein v is i Is the ith characteristic value of the global context flue gas temperature-spraying speed position-by-position response time sequence characteristic vector V, V 2 Representing the two norms of the global context flue gas temperature-spraying speed position-by-position response time sequence characteristic vector, log is logarithm based on 2, alpha is a weight super-parameter, v i ' is the i-th eigenvalue of the optimized global context flue gas temperature-spray velocity position-by-position response time sequence eigenvector.
9. A carbon dioxide recovery control method for a natural gas powered vessel, comprising:
acquiring flue gas temperature values and spraying speed values at a plurality of preset time points in a preset time period;
carrying out time sequence cooperative response analysis on the flue gas temperature values and the spraying speed values at a plurality of preset time points to obtain flue gas temperature-spraying speed response time sequence correlation characteristics;
based on the flue gas temperature-spray speed response time sequence correlation characteristics, it is determined that the spray speed value at the current time point should be increased, decreased or maintained.
10. The carbon dioxide recovery control method for a natural gas powered vessel according to claim 9, wherein performing a time-series cooperative responsiveness analysis of the flue gas temperature values and the spray velocity values at the plurality of predetermined time points to obtain a flue gas temperature-spray velocity response time-series correlation feature comprises:
arranging the flue gas temperature values and the spraying speed values of the plurality of preset time points into flue gas temperature time sequence input vectors and spraying speed time sequence input vectors according to time dimensions respectively;
carrying out position-by-position response association coding on the flue gas temperature time sequence input vector and the spraying speed time sequence input vector to obtain a flue gas temperature-spraying speed position-by-position response time sequence input vector;
dividing the position-by-position response time sequence input vector of the flue gas temperature-spraying speed to obtain a plurality of position-by-position response local time sequence input vectors of the flue gas temperature-spraying speed;
respectively extracting time sequence characteristics of the local time sequence input vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds to obtain local time sequence characteristic vectors of the position-by-position response of the plurality of flue gas temperature-spraying speeds;
and carrying out global association analysis on the local time sequence feature vectors of the position-by-position response of the flue gas temperature-spraying speed to obtain a global context flue gas temperature-spraying speed position-by-position response time sequence feature vector serving as the flue gas temperature-spraying speed response time sequence association feature.
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