CN114611418A - Natural gas pipeline flow state prediction method - Google Patents
Natural gas pipeline flow state prediction method Download PDFInfo
- Publication number
- CN114611418A CN114611418A CN202111544230.0A CN202111544230A CN114611418A CN 114611418 A CN114611418 A CN 114611418A CN 202111544230 A CN202111544230 A CN 202111544230A CN 114611418 A CN114611418 A CN 114611418A
- Authority
- CN
- China
- Prior art keywords
- equation
- pipeline
- gas
- loss function
- momentum
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 70
- 238000000034 method Methods 0.000 title claims abstract description 49
- 239000003345 natural gas Substances 0.000 title claims abstract description 35
- 239000007789 gas Substances 0.000 claims description 57
- 230000006870 function Effects 0.000 claims description 51
- 238000013528 artificial neural network Methods 0.000 claims description 21
- 230000014509 gene expression Effects 0.000 claims description 10
- 210000002569 neuron Anatomy 0.000 claims description 9
- 238000005457 optimization Methods 0.000 claims description 9
- 238000012549 training Methods 0.000 claims description 7
- 230000004913 activation Effects 0.000 claims description 5
- 239000012530 fluid Substances 0.000 claims description 4
- ORILYTVJVMAKLC-UHFFFAOYSA-N Adamantane Natural products C1C(C2)CC3CC1CC2C3 ORILYTVJVMAKLC-UHFFFAOYSA-N 0.000 claims description 3
- 238000013135 deep learning Methods 0.000 claims description 3
- 230000004069 differentiation Effects 0.000 claims description 3
- 230000009466 transformation Effects 0.000 claims description 2
- 238000001514 detection method Methods 0.000 claims 1
- 239000000126 substance Substances 0.000 claims 1
- 238000004364 calculation method Methods 0.000 abstract description 4
- 238000005259 measurement Methods 0.000 description 3
- 238000004422 calculation algorithm Methods 0.000 description 2
- 238000007796 conventional method Methods 0.000 description 2
- 238000013136 deep learning model Methods 0.000 description 2
- 230000004075 alteration Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
Images
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
- G06F30/28—Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06N—COMPUTING ARRANGEMENTS BASED ON SPECIFIC COMPUTATIONAL MODELS
- G06N3/00—Computing arrangements based on biological models
- G06N3/02—Neural networks
- G06N3/04—Architecture, e.g. interconnection topology
- G06N3/045—Combinations of networks
Landscapes
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Theoretical Computer Science (AREA)
- General Physics & Mathematics (AREA)
- Mathematical Physics (AREA)
- Computing Systems (AREA)
- General Engineering & Computer Science (AREA)
- Evolutionary Computation (AREA)
- Geometry (AREA)
- Artificial Intelligence (AREA)
- Computer Hardware Design (AREA)
- Mathematical Optimization (AREA)
- Mathematical Analysis (AREA)
- Fluid Mechanics (AREA)
- Algebra (AREA)
- Health & Medical Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Pure & Applied Mathematics (AREA)
- Biomedical Technology (AREA)
- Biophysics (AREA)
- Computational Linguistics (AREA)
- Data Mining & Analysis (AREA)
- General Health & Medical Sciences (AREA)
- Molecular Biology (AREA)
- Software Systems (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
- Feedback Control In General (AREA)
Abstract
The invention discloses a natural gas pipeline flow state prediction method, which relates to the field of natural gas pipeline transportation. The method of the invention only needs one forward calculation. The flow state of the natural gas pipeline can be accurately predicted, and the calculated amount, the resource consumption and the prediction time are greatly reduced.
Description
Technical Field
The invention relates to the field of natural gas pipeline transportation, and provides a method for predicting the natural gas flow state in a pipeline by combining a prediction model with physical information.
Background
At present, the flow state in the pipeline is obtained by a numerical simulation method on the basis of natural gas pipeline flow management, and the method needs one-step and one-step iterative solution and cannot directly obtain the flow state, so that the calculation amount is overlarge, the efficiency is low, and the method is difficult to be applied to increasing pipeline length and user requirements. In addition, if a general intelligent model is used to predict the pipeline flow, a large amount of on-site measured data or simulated data is required, which results in a limitation in practical application due to data acquisition.
Disclosure of Invention
The invention aims to provide a natural gas pipeline flow state prediction method, which is characterized in that a prediction model of a deep neural network is constructed, flow is simulated in a data driving mode, a flow differential equation is used as a loss function of model parameter optimization, the prediction model is optimized through learning, and the finally obtained intelligent prediction model is used for predicting the natural gas pipeline flow state.
In order to achieve the purpose, the technical scheme adopted by the invention is as follows:
a natural gas pipeline flow state prediction method comprises the following steps:
acquiring natural gas pipeline parameters: pipeline length, pipeline internal diameter and friction coefficient, and detect the natural gas fluid parameter in the pipeline: establishing a one-dimensional flow control equation of the natural gas pipe network according to the gas density, the gas velocity, the gas pressure and the gas temperature, wherein the one-dimensional flow control equation comprises a continuity equation, a momentum equation and a state equation;
selecting a pipeline length value, a gas velocity value, a gas pressure value and a gas density value of a boundary condition as characteristic quantities, introducing dimensionless quantities by using the characteristic quantities to express the pipeline length, the gas velocity, the gas pressure and the gas density, and carrying out dimensionless transformation on a continuous equation, a momentum equation and a state equation of the one-dimensional flow control equation;
constructing a prediction model of a full-connection deep neural network, wherein the full-connection deep neural network comprises an input layer, five hidden layers and an output layer, the input layer is a neuron representing the length of a pipeline, and the output layer is three neurons representing the gas speed, the gas pressure and the gas density; the activation function of the full-connection deep neural network adopts a hyperbolic tangent function;
constructing derivatives of output quantities to input quantities of a continuous equation, a momentum equation and a state equation which are non-dimensionalized to obtain three differential equations of the continuous equation, the momentum equation and the state equation, and constructing a model loss function for the three differential equations and the boundary conditions, wherein the model loss function is composed of weighting of a boundary condition loss function, a continuous equation loss function, a momentum equation loss function and a state equation loss function;
for the fully-connected deep neural network prediction model, an Adam optimization solver is adopted to pre-learn the boundary condition loss function, and the input quantity is any length value in the total pipeline length of the natural gas pipeline; and continuously learning by adopting an LBFGS optimization solver on the basis of the pre-learning to finally obtain an intelligent prediction model, and predicting the flow state of the natural gas pipeline by using the intelligent prediction model.
Preferably, the expression of the one-dimensional flow control equation is as follows:
the continuous equation:
the momentum equation:
the state equation is as follows:
p=ρRgT;
wherein x is the length of the pipeline, ρ is the gas density, u is the gas velocity, p is the gas pressure, λ friction coefficient, D is the internal diameter of the pipeline, R is the gas velocitygGas constant, T is the gas temperature.
Preferably, the value of the length x of the pipe is chosen+Gas velocity value urGas pressure value prAnd gas density value ρrAs the characteristic quantity, a dimensionless quantity is setThe pipe length, gas velocity, gas pressure and gas density are then introduced into dimensionless quantities denoted x ═ x+X,u=Uur,p=Ppr,
Preferably, the expressions of the continuity equation, the momentum equation and the momentum equation of the non-dimensionalized one-dimensional flow control equation are:
preferably, the equation of state is derivedThe expression of the dimensionless momentum equation is reduced to
Preferably, the number of neurons of 5 hidden layers is [100,200,300,200,100 ].
Preferably, the activation function employs a tanh function:
preferably, the expression of the output quantity of the deep neural network is as follows:
tanh(W5 tanh(W4 tanh(W3 tanh(W2 tanh(W1x+b1)+b2)+b3)+b4)+b5);
where, tanh () is hyperbolic tangent function, and W, b are parameters.
Preferably, the derivatives of the output quantities to the input quantities are constructed for the non-dimensionalized continuous equations, momentum equations and state equations using automatic differentiation techniques provided by the open source deep learning framework; the three differential equation expressions of the continuous equation, the momentum equation and the state equation are obtained as follows:
preferably, the mean variance method is adopted to construct a model loss function, and the expression of the model loss function is MSE-wbMSEb+wcMSEc+wuMSEu+wpMSEp(ii) a Wherein w is a weight coefficient, MSEb、MSEc、MSEu、MSEpRespectively representing a boundary condition loss function, a continuous equation loss function, a momentum equation loss function and a state equation loss function;
the loss function for the mean variance of an arbitrary variable is expressed asWherein t ═ b, c, u, p, x ═ fc,fu,fpAnd boundary conditions of the deep neural network output; x is the number of0Is a target value for fc,fu,fp,x0Are all zero; for the boundary condition, x0Is a given value; and N is the training data volume.
The invention has the following beneficial effects:
compared with the traditional prediction method, the intelligent prediction model capable of predicting the flow state of the natural gas pipeline is obtained by solving the pipeline flow differential equation by using the deep learning model, and due to the introduced physical equation and the deep neural network, the dependence on actual measurement data is greatly reduced, the investment of measurement equipment is greatly reduced, and the management cost of natural gas management flow is reduced.
Drawings
Fig. 1 is a flow chart of a method for predicting a flow state of a natural gas pipeline according to an embodiment of the present invention.
Fig. 2 is a comparative graph of natural gas pipeline pressure distribution prediction using a conventional method and the method of the present invention.
FIG. 3 is a comparison graph of natural gas pipeline velocity profiles predicted using a conventional method and the method of the present invention.
Detailed Description
In order to make the aforementioned and other features and advantages of the invention more comprehensible, embodiments accompanied with figures are described in detail below.
The embodiment of the invention provides a method for predicting a flow state of a natural gas pipeline, which specifically comprises the following steps as shown in fig. 1:
1) acquiring natural gas pipeline parameters: pipeline length, pipeline internal diameter, friction coefficient etc to and detect and acquire the interior natural gas fluid parameter of pipeline: gas density, gas velocity, gas pressure, gas temperature, etc.; because the length of the pipeline is far greater than the diameter of the pipeline, a one-dimensional flow control equation is established according to the parameters, and comprises a continuous equation, a momentum equation and an ideal gas state equation:
the continuous equation:
the momentum equation:
the state equation is as follows:
p=ρRgT (3)
wherein x is the length of the pipeline, ρ is the gas density, u is the gas velocity, p is the gas pressure, λ friction coefficient (constant), D is the inner diameter of the pipeline, R is the gas velocitygThe gas constant (287J/(kg. K)) and T are the gas temperature (288.15K).
2) SelectingCharacteristic amount: the characteristic length, the characteristic speed, the characteristic pressure and the characteristic density are used for calculating dimensionless quantity of the one-dimensional flow control equation. In this embodiment, the characteristic length x is selected+D (pipe inside diameter), characteristic speed urAt maximum or boundary flow rate, characteristic pressure prAs boundary pressure, characteristic density ρrFor boundary density and dimensionless quantity The corresponding physical variable can be expressed as x ═ x using dimensionless quantities+X,u=Uur,p= Ppr,Note that: the selected characteristic quantity can be selected at will according to the actual situation, and the principle is to ensure the value of the dimensionless quantity to be between 0 and 1 as far as possible, but the value is not necessarily kept in the interval. The boundary values are directly given according to actual conditions, measurement is not needed, and in special cases, a characteristic quantity can be directly and artificially set for calculating the dimensionless quantity.
Substituting the physical variables represented by the dimensionless quantities into the one-dimensional flow control equation in step 1) to obtain a dimensionless one-dimensional flow control equation, which is:
in addition, the method can be obtained according to the state equationSubstituting equation (6) yields:
3) it can be seen from the above equation that the fluid flow state is represented by three variables, namely pressure, density, flow rate, which are all functions of the length of the pipe, so that the function can be learned through a neural network, thereby achieving the purpose of prediction. Therefore, a fully-connected deep neural network is constructed, and the input layer of the network is a neuron for expressing the length of the pipeline; the output layer is three neurons for expressing pressure, density and flow rate, 5 hidden layers are included between the input layer and the output layer, and the number of the neurons of the 5 hidden layers is [100,200,300,200 and 100 ]. The activation function adopts a hyperbolic tangent function:
the neural network output constructed according to the above parameters can be expressed by the following expression:
tanh(W5 tanh(W4 tanh(W3 tanh(W2 tanh(W1x+b1)+b2)+b3)+b4)+b5) (9)
the parameters W, b are needed to be adjusted by an optimization method, which is described below.
4) Before introducing the optimization method, an evaluation standard in deep neural network training learning needs to be constructed, so that a loss function of the neural network needs to be constructed. The derivative of the output quantity to the input quantity is constructed using an automatic differentiation technique provided by an open source deep learning framework (e.g., Tensorflow), and the following differential equations are established by combination:
the final result of the three differential equations is required to be 0, so that the model loss function can be constructed for the three differential equations and the boundary conditions by using the mean variance method as follows:
MSE=wbMSEb+wcMSEc+wuMSEu+wpMSEp (13)
wherein w is weight coefficient (10-10000), MSEb、MSEc、MSEu、MSEpLoss functions representing boundary conditions, a continuity equation, a momentum equation, and a state equation, respectively, the loss function for the mean variance of an arbitrary variable is expressed as:
wherein t ═ b, c, u, p, x ═ fc,fu,fpAnd boundary conditions of the neural network output; x is the number of0Is a target value for fc,fu,fp, x0Are all zero; for the boundary condition, then x0Is a value given according to the actual situation; and N is the training data volume.
5) Firstly, utilizing Adam to optimize solver to carry out MSE on boundary condition loss functionbPre-learning is carried out, the input quantity is any length value in the total length of the pipeline, and the output quantity obtains a loss function MSE through the average variance of the boundary condition constructed in the step 4)bThe number of learning is usually about 10000; secondly, on the basis of pre-learning, the LBFGS optimization solver is used for continuing learning, and learning times are repeatedThe number is usually about 50000 times, and finally the W and b after training and adjustment are obtained, so that parameter values in the neural network constructed in the step 3) are determined, and a prediction model capable of predicting the flow state of the natural gas pipeline is obtained. In the step, corresponding functions in the Matlab or python of the computing software can be directly called to finish training.
The invention lists a specific application example as follows:
in this example, the natural gas pipeline has a length of 10m, an inner diameter D of 0.6m, a friction coefficient lambda of 300, and an inlet constant flow boundary of min1kg/s, constant pressure boundary at outlet pout=105Pa. The discrete point N0 is 1000, and the number of training times is 10000,20000. The flow state of the natural gas pipeline is predicted by using the traditional method and the method provided by the invention, the predicted structures are compared, and the comparison result is shown in fig. 2 and fig. 3. The result comparison shows that the result obtained by the prediction method is basically coincident with the result obtained by the prediction of the traditional method, which shows that the flow state of the natural gas pipeline can be correctly solved by the method. Moreover, the traditional method needs to iterate for tens of thousands of times or even millions of times to obtain a correct result, but the method can obtain the same result by forward calculation only once through the trained intelligent prediction model, so that the calculation amount, the resource consumption and the prediction time are greatly reduced. In addition, the numerical solution algorithm of the traditional method can only obtain results by stepping from the inlet or the outlet of the pipeline, but the intelligent prediction model of the method can directly obtain the corresponding flow state by outputting the length of the pipeline, so that the method is more flexible and convenient to use. Therefore, compared with the traditional method, the method provided by the invention has the advantages that the efficiency and the flexibility are obviously improved.
According to the embodiment, the natural gas pipeline flow state prediction method provided by the invention simulates flow by a data-driven mode by constructing the deep learning model and fully utilizing the 'black box' characteristic of the prediction model. And then, the derivative of the output variable and the input variable of the prediction model is obtained by utilizing an automatic differential technology (a function derivative operation method realized by a computer), a flow differential equation is combined to be used as a loss function for optimizing model parameters, and the prediction model is learned by an LBFGS optimization algorithm to obtain a flow prediction model solution.
Although the present invention has been described with reference to the above embodiments, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (10)
1. A natural gas pipeline flow state prediction method is characterized by comprising the following steps:
acquiring natural gas pipeline parameters: pipeline length, pipeline internal diameter and friction coefficient to and the natural gas fluid parameter in the detection pipeline: the method comprises the following steps of (1) establishing a one-dimensional flow control equation of a natural gas pipe network according to the parameters, wherein the one-dimensional flow control equation comprises a continuous equation, a momentum equation and a state equation;
selecting a pipeline length value, a gas velocity value, a gas pressure value and a gas density value of a boundary condition as characteristic quantities, introducing dimensionless quantities by using the characteristic quantities to express the pipeline length, the gas velocity, the gas pressure and the gas density, and carrying out dimensionless transformation on a continuous equation, a momentum equation and a state equation of the one-dimensional flow control equation;
constructing a prediction model of a full-connection deep neural network, wherein the full-connection deep neural network comprises an input layer, five hidden layers and an output layer, the input layer is a neuron representing the length of a pipeline, and the output layer is three neurons representing gas speed, gas pressure and gas density; the activation function of the full-connection deep neural network adopts a hyperbolic tangent function;
constructing derivatives of output quantities to input quantities of a continuous equation, a momentum equation and a state equation which are non-dimensionalized to obtain three differential equations of the continuous equation, the momentum equation and the state equation, and constructing a model loss function for the three differential equations and the boundary conditions, wherein the model loss function is composed of weighting of a boundary condition loss function, a continuous equation loss function, a momentum equation loss function and a state equation loss function;
for the fully-connected deep neural network prediction model, an Adam optimization solver is adopted to pre-learn the boundary condition loss function, and the input quantity is any length value in the total pipeline length of the natural gas pipeline; and continuously learning by adopting an LBFGS optimization solver on the basis of the pre-learning to finally obtain an intelligent prediction model, and predicting the flow state of the natural gas pipeline by using the intelligent prediction model.
2. The method of claim 1, wherein the one-dimensional flow control equation is expressed as follows:
the continuous equation:
the momentum equation:
the state equation is as follows:
p=ρRgT;
wherein x is the length of the pipeline, ρ is the gas density, u is the gas velocity, p is the gas pressure, λ friction coefficient, D is the internal diameter of the pipeline, R is the gas velocitygGas constant, T is the gas temperature.
3. The method of claim 2, wherein the pipe length value x is selected+Gas velocity value urGas pressure value prAnd gas density value ρrAs the characteristic quantity, a dimensionless quantity is setThe length of the pipeline is longDegree, gas velocity, gas pressure and gas density are introduced into dimensionless quantities expressed as x ═ x+X,u=Uur,
6. The method of claim 1, wherein the number of neurons in the 5 hidden layers is [100,200,300,200,100], respectively.
8. the method of claim 8, wherein the output of the deep neural network is expressed as:
tanh(W5 tanh(W4 tanh(W3 tanh(W2 tanh(W1x+b1)+b2)+b3)+b4)+b5);
where tanh () is a hyperbolic tangent function and W, b are parameters.
9. The method of claim 5, wherein derivatives of the output quantities to the input quantities are constructed for the non-dimensionalized continuous equations, momentum equations, and state equations using an automatic differentiation technique provided by an open source deep learning framework; the three differential equation expressions of the continuous equation, the momentum equation and the state equation are obtained as follows:
10. the method of claim 9, wherein the model loss function is constructed using an average variance method, and the expression of the model loss function is MSE wbMSEb+wcMSEc+wuMSEu+wpMSEp(ii) a Wherein the content of the first and second substances,w is a weight coefficient, MSEb、MSEc、MSEu、MSEpRespectively representing a boundary condition loss function, a continuous equation loss function, a momentum equation loss function and a state equation loss function;
the loss function for the mean variance of an arbitrary variable is expressed asWherein t ═ b, c, u, p, x ═ fc,fu,fpAnd boundary conditions of the deep neural network output; x is the number of0Is a target value for fc,fu,fp,x0Are all zero; for the boundary condition, x0Is a given value; and N is the training data volume.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CN202111544230.0A CN114611418B (en) | 2021-12-16 | 2021-12-16 | Natural gas pipeline flow state prediction method |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CN202111544230.0A CN114611418B (en) | 2021-12-16 | 2021-12-16 | Natural gas pipeline flow state prediction method |
Publications (2)
Publication Number | Publication Date |
---|---|
CN114611418A true CN114611418A (en) | 2022-06-10 |
CN114611418B CN114611418B (en) | 2024-06-04 |
Family
ID=81857275
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
CN202111544230.0A Active CN114611418B (en) | 2021-12-16 | 2021-12-16 | Natural gas pipeline flow state prediction method |
Country Status (1)
Country | Link |
---|---|
CN (1) | CN114611418B (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN116205013A (en) * | 2022-12-22 | 2023-06-02 | 北京市燃气集团有限责任公司 | Natural gas diffusion amount and diffusion time calculation method and device |
Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20170351948A1 (en) * | 2016-06-01 | 2017-12-07 | Seoul National University R&Db Foundation | Apparatus and method for generating prediction model based on artificial neural network |
CN108197070A (en) * | 2018-01-05 | 2018-06-22 | 重庆科技学院 | Natural gas not exclusively blocks pipeline method for numerical simulation |
CN112163722A (en) * | 2020-10-30 | 2021-01-01 | 中国石油大学(北京) | Method and device for predicting gas supply state of natural gas pipe network |
CN112818591A (en) * | 2021-01-20 | 2021-05-18 | 北京科技大学 | Physical constraint-based method for predicting tight oil fracturing range by using DL model |
-
2021
- 2021-12-16 CN CN202111544230.0A patent/CN114611418B/en active Active
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20170351948A1 (en) * | 2016-06-01 | 2017-12-07 | Seoul National University R&Db Foundation | Apparatus and method for generating prediction model based on artificial neural network |
CN108197070A (en) * | 2018-01-05 | 2018-06-22 | 重庆科技学院 | Natural gas not exclusively blocks pipeline method for numerical simulation |
CN112163722A (en) * | 2020-10-30 | 2021-01-01 | 中国石油大学(北京) | Method and device for predicting gas supply state of natural gas pipe network |
CN112818591A (en) * | 2021-01-20 | 2021-05-18 | 北京科技大学 | Physical constraint-based method for predicting tight oil fracturing range by using DL model |
Non-Patent Citations (2)
Title |
---|
李玉星, 冯叔初: "湿天然气管输瞬态模拟及调峰技术研究", 天然气工业, no. 04, 28 July 2000 (2000-07-28) * |
陈新果;冷绪林;安云朋;张健;王会豪;宫敬;: "基于深度学习结构网络的输气管道水力预测模型", 油气田地面工程, no. 08, 20 August 2018 (2018-08-20) * |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN116205013A (en) * | 2022-12-22 | 2023-06-02 | 北京市燃气集团有限责任公司 | Natural gas diffusion amount and diffusion time calculation method and device |
Also Published As
Publication number | Publication date |
---|---|
CN114611418B (en) | 2024-06-04 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CN111474965B (en) | Fuzzy neural network-based method for predicting and controlling water level of series water delivery channel | |
Lu et al. | Generalized radial basis function neural network based on an improved dynamic particle swarm optimization and AdaBoost algorithm | |
CN111324990A (en) | Porosity prediction method based on multilayer long-short term memory neural network model | |
CN106444379A (en) | Intelligent drying remote control method and system based on internet of things recommendation | |
Zhang et al. | A novel variable selection algorithm for multi-layer perceptron with elastic net | |
CN112052617B (en) | Method and system for predicting branch vascular flow field for non-disease diagnosis | |
CN108595803A (en) | Shale gas well liquid loading pressure prediction method based on recurrent neural network | |
CN115438584A (en) | Wing profile aerodynamic force prediction method based on deep learning | |
CN114611418A (en) | Natural gas pipeline flow state prediction method | |
CN108763718A (en) | The method for quick predicting of Field Characteristics amount when streaming object and operating mode change | |
CN114777192A (en) | Secondary network heat supply autonomous optimization regulation and control method based on data association and deep learning | |
CN110162910A (en) | A kind of hill start optimization method based on technology of Internet of things | |
CN115421216A (en) | STL-ARIMA-NAR mixed model-based medium-and-long-term monthly rainfall forecasting method | |
Ma et al. | A modified online sequential extreme learning machine for building circulation fluidized bed boiler's NOx emission model | |
CN115049041A (en) | Moisture pipe liquid holding rate prediction method based on WOA-BP neural network | |
CN114912364A (en) | Natural gas well flow prediction method, device, equipment and computer readable medium | |
CN117786286A (en) | Fluid mechanics equation solving method based on physical information neural network | |
CN109408896B (en) | Multi-element intelligent real-time monitoring method for anaerobic sewage treatment gas production | |
CN114239397A (en) | Soft measurement modeling method based on dynamic feature extraction and local weighted deep learning | |
Sahu et al. | Prediction of entrance length for low Reynolds number flow in pipe using neuro-fuzzy inference system | |
CN111708388B (en) | Boiler pressure regulation prediction control method based on GRU-PID | |
CN113515882A (en) | Turbulent model coefficient correction method based on PINN | |
CN117034808A (en) | Natural gas pipe network pressure estimation method based on graph attention network | |
CN110619382A (en) | Convolution depth network construction method suitable for seismic exploration | |
CN116595845A (en) | Structure optimization method of spiral fin tube type heat exchanger |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PB01 | Publication | ||
PB01 | Publication | ||
SE01 | Entry into force of request for substantive examination | ||
SE01 | Entry into force of request for substantive examination | ||
GR01 | Patent grant | ||
GR01 | Patent grant |