1. Introduction
As a clean and renewable resource, wind energy has been paid more and more attention, which developed rapidly all over the world [
1,
2,
3,
4,
5]. Due to the rising scale of grid-connected wind power, the intermittency, volatility, and uncertainty of wind energy bring great challenges to the planning and dispatching of a power system [
6,
7,
8,
9,
10,
11]. However, the short-term forecast of wind power can provide basic information for dispatchers. Therefore, during the process of power planning and dispatching, there is an urgent need to make accurate short-term forecasts of wind power in advance for a period of time in the future, in order to enhance the safety, stability, and economy of the power network.
Neural networks are widely used in the forecasting field of wind power, due to their adaptive and good non-linear mapping ability [
12,
13,
14,
15,
16]. In particular, recurrent neural networks (RNN), with the capability of maintaining states between different inputs, show an advantage in handling time sequences, but there are some disadvantages such as vanishing and exploding gradients. LSTM, as an extension of the RNN, may deal with the problem of vanishing gradients by introducing memory cells with controlling gates, and are used extensively to simulate the time-series correlation [
17]. Nevertheless, it is difficult to determine the number of neurons, the learning rate, and the iteration times of the LSTM, which may have a great influence on the generalized ability, the training time, and the predicting accuracy. For example, a forecasting model of wind power based on the RNN of the LSTM was proposed in [
18], which can implement a more accurate forecast of wind power according to the characteristic of the sequence dependence characteristic of the RNN by training with the smaller data sets. A hybrid model of the VMD–Kmeans–LSTM was proposed in [
19], which is applied to short-term prediction of wind power with multiple scales. The advantage of the proposed model is the ability to fit on multiple scales. A short-term forecasting model of wind power including the variational mode decomposition (VMD), the convolutional LSTM (ConvLSTM) predictor, and error series modelling was proposed in [
20], which can significantly increase the predicting accuracy. However, the initial parameters of the LSTM network of models mentioned above are determined by experiments, which result in a large computational cost in obtaining the optimal parameters, and may affect the predicting accuracy to a certain extent. Therefore, the introduction of an optimization algorithm can overcome the shortcoming of the artificially determined parameters of LSTM and automatically find the parameters, thus, improving the predicting accuracy. In addition, considering the high autocorrelation and the inherent volatility of the wind speed, there are large errors in directly predicting the wind power with the original time-series of wind speed, which may affect the predicting accuracy of wind power. A forecasting model of wind speed based on the WPD and artificial neural networks was established in [
21], which decomposed the original series of wind speed, and employed the back-propagation neural network optimized by the criss-cross optimization algorithm to predict the wind speed with components of different frequency bands after decomposition, and the results show that the proposed method has the minimum absolute error. The unstable time-series of wind and solar power are decomposed into smooth subsequences by VMD [
22,
23,
24], which reduces the undesirable effects caused by the volatility of the original series. With the help of the adaptive multiscale mathematical morphological algorithm, the original sequence of wind speed is decomposed into a series of subsequences, with different frequencies and fluctuant levels in the time domain [
25]. Wavelet velocity is used to decompose the wind speed in [
26], and neural networks with different structures are used to discover the regularity of the wind power in different frequency bands. In the literature mentioned above, the methods of comprehensive calculation of proposed models for the predicted component of wind power are relatively simple. However, the performance of each predicting model changes with the surrounding environment of the wind turbines, which may result in the different mapping relationship between predicting results and actual wind power. If a method of simple comprehensive calculation was employed to calculate the wind power at each moment only, the predicting accuracy would be significantly affected. Therefore, a method of classified fusion can fuse the components of wind power. In addition, to solve the problem that a single algorithm cannot adapt to the forecasting scenarios of different months in the whole year, an ultra-short-term wind power forecasting model was established in [
27], which combines four different models of machine learning to predict wind power with a single model, and the final forecasting results are obtained by the data fusion performed on the forecasting results in the same period. Compared with a single model of prediction, the ensemble method of prediction would be applied to different weather conditions, which can improve the predicting accuracy of wind power. Nevertheless, the forecasting effect of wind power is very poor when the correlation between meteorological factors and the wind power is predicted to be strong, and adding the Numerical Weather Prediction (NWP) to the combined forecasting method should be considered. The NWP data are the numerical meteorological information obtained from meteorological centers or local meteorological forecasts of wind farms.
Therefore, for enhancing the predicting accuracy of wind power, the objective of this paper is to propose a forecasting model of wind power based on IPSO–LSTM and classified fusion. The contributions of this paper are (1) for the sake of overcoming the shortcoming of the artificially determined parameters of LSTM, the LSTM optimized by IPSO was employed to predict the components of wind power. (2) Consider the variability of the environment surrounding wind turbines, which may cause the change in the performance of each predicting model accordingly. As the mapping relationship between different predicting results and actual wind power will be different, a method of classified fusion was adopted to fuse these components in this paper. (3) A mutual iteration optimization framework of the classification model of the fusion pattern and fusion model is employed to obtain the optimal classification model of the fusion pattern and the corresponding fusion model.
5. Case Studies
The proposed wind power prediction model is implemented in Python in PyCharm editor and MATLAB. Data preprocessing, such as wavelet packet decomposition, is performed in MATLAB, algorithms such as IPSO and SVM and parameter search for LSTM are implemented in Python, and the TensorFlow framework in Python is used to build LSTM models with different parameters to achieve accurate prediction of wind power.
This paper proposes a short-term predicting model of wind power based on IPSO–LSTM and classified fusion, the data set used in this case study is the measurement data of a wind farm in 2018, with a time resolution of 15 min. Some data sets of this experiment are listed in
Table 1.
For the classification model of the fusion pattern and data fusion model, this paper selects 700 continuous time periods to test the model at different times. The first 600 data are used for model training, and the last 100 data are used to test the trained model.
Ι. For the sake of verifying that the decomposition of series for wind speed can reduce the influence for volatility and instability of wind speed on the prediction of wind power, in this paper the predicting value of wind power of the IPSO–LSTM without decomposing the wind speed is compared with the predicting value of the IPSO–LSTM with decomposing the wind speed. The results are displayed in
Figure 9.
It is easily seen from
Figure 9 that the trends of the predicting value of wind power based on the IPSO–LSTM are similar to the actual values of wind power when the wind speed is decomposed, which verifies the effectiveness of the proposed model. Moreover, the predicted value of the decomposed wind speed is more accurate than the non-decomposed one. As the wind speed has high autocorrelation and inherent volatility, this affects the predicting accuracy of wind power. Decomposing the wind speed into steadily multiple components, and predicting the components, separately, can greatly reduce the impact and improve the predicting accuracy.
In order to show the difference in performance and predicting accuracy of each model more clearly, there are three error indexes of root-mean-square error (RMSE), mean absolute error (MAE), and coefficient of determination (R
2) that can be employed to evaluate the accuracy in this paper. The evaluation indexes of each model are listed in
Table 2. For a more intuitive display, each evaluation index is displayed with a bar chart, as illustrated in
Figure 10.
Furthermore, it is clearly observed from
Table 2 and
Figure 10 that the RMSE and the MAE of the model with decomposing wind speed decrease by 4.6021 and 2.4477, respectively, and the R
2 increases by 0.1311 compared with the model without decomposing wind speed. It is further verified that decomposing the wind speed into steadily multiple components, and predicting the components individually, can reduce the influence of the characteristics of the wind speed on the predicting accuracy of wind power.
II. An LSTM optimized by IPSO is employed to predict the wind power in this paper, which not only overcomes the shortcoming of the difficulty of determining the parameters of LSTM when predicting wind power, but also solves the risk that PSO is prone to fall into a locally optimal solution. In order to verify the effectiveness of the predicting model based on the IPSO–LSTM proposed in this paper, the prediction values of the IPSO–LSTM are compared with those of the model based on the LSTM optimized by the PSO (PSO–LSTM) and the model based on the LSTM. The comparison results are shown in
Figure 11. In addition, the models used in this case study are on the basis of a single fusion pattern.
Figure 11 demonstrates that the trend of the predicting result of the model based on the IPSO–LSTM is most similar to the real value among the three models, which verifies the effectiveness of the proposed model. However, there are some differences in the comparative results. Compared with the model based on the LSTM, the IPSO–LSTM uses the IPSO to optimize the number of neurons, the learning rate, and the number of iterations for LSTM, and also search for appropriate parameters automatically. This not only overcomes the shortcoming of the artificially determined parameters of the LSTM, but also effectively improves the predicting accuracy. In addition, it can be seen from
Figure 11 that the proposed model has more accurate predicting results than the PSO–LSTM, which indicates that the IPSO may obtain better parameters to optimize the LSTM in the process of iteration comparing with the PSO.
It is found that the predicting accuracy of the model based on the IPSO–LSTM is the highest among the three models by comparing the evaluation indexes in
Table 3 and
Figure 12 in case study II. Compared with the models based on the LSTM and the PSO–LSTM, the RMSE of the model on basis of the IPSO–LSTM decreases by 1.0148 and 0.8776, separately, the MAE decreases by 0.6669 and 0.3969, respectively, and the R
2 increases by 0.0195 and 0.0148, respectively. The effectiveness of the IPSO–LSTM proposed in this paper can be further verified.
III. In this paper, a method of classified fusion is proposed to fuse the components of wind power, which solves the problem that the fused accuracy may be reduced by the surrounding environment of the wind turbines when adopting a model of single fusion. For the sake of verifying that the method of classified fusion can significantly improve the predicting accuracy of wind power, the predicted value of the IPSO–LSTM in case study II is compared with the predicted value of the IPSO–LSTM using classified fusion. The comparative results are displayed in
Figure 13, and the evaluation indexes of each model are shown in
Table 4 and
Figure 14.
From the results given in
Figure 13 and
Figure 14, and
Table 4, the model of the IPSO–LSTM when using classified fusion is better suited for the actual curve of wind power, which verifies the effectiveness of the proposed model in this paper, especially because the predicting effect is obviously better when the power value changes dramatically. As the wind speed, the ambient temperature and humidity, the atmospheric pressure surrounding wind turbines, and even the temperature of the unit change, this may cause a change in the performance of each predicting model accordingly. Meanwhile, the mapping relationship between different predicting results and actual wind power is different, so the predicting accuracy of power is affected when a model of single fusion is applied. Furthermore, compared with the model on basis of the IPSO–LSTM under single fusion, it is found that the RMSE and the MAE of the model on basis of the IPSO–LSTM decrease by 1.0460 and 0.5920, respectively, and the R
2 increases by 0.0114 under classified fusion. It verifies the effectiveness of classified fusion in dealing with the problem of the variable environment surrounding wind turbines.
IV. Recently, a number of global and regional NWP forecast models were developed. In our research, we use the weather research and forecasting (WRF) NWP model.
Figure 15 and
Table 5 present the comparison between the model mentioned in this paper and the results of wind power prediction made without the use of NWP data.
As shown in
Figure 15, as compared to a prediction model that just uses historical wind power data, the actual wind power curve may be more accurately predicted when NWP is included in the input data. The evaluation indices show that, in comparison to the model utilizing only historical wind power data, the RMSE and MAE of the model with the inclusion of NWP rise by 8.5885 and 13.9382, respectively, while R
2 lowers by 0.0689. This is because the NWP is introduced into the input data to further explore the correlation between NWP characteristics and wind power, and the NWP is used to numerically describe the trend of weather processes to further improve the predicting accuracy of wind power.
V. To verify the validity of the model proposed in this paper, the proposed model is compared and analyzed with the models reconstructed in [
18,
22]. The results are shown in
Figure 16 and
Table 6.
It can be seen from
Figure 16 that the model proposed in this paper better fits the actual wind power curve than the other two models, and has better prediction accuracy. By comparing the evaluation indexes of the model in this paper with those in the literature [
18,
22], as shown in
Table 6, it is be seen that the predicting accuracy of the model proposed in this paper is the highest, and its RMSE increases by 13.0525 and 14.9365, and MAE increases by 12.4613 and 12.6712, respectively, compared with the two models in the literature, and its R
2 decreases by 0.0654 and 0.0520, respectively. It shows that the method proposed in this paper solves the deficiencies of the models in the above literature, and greatly improves the predicting accuracy of wind power, while also further confirming the conclusion of this paper.