CN103984986A - Method for correcting wind power ultra-short-period prediction of self-learning ARMA model in real time - Google Patents
Method for correcting wind power ultra-short-period prediction of self-learning ARMA model in real time Download PDFInfo
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Abstract
The invention discloses a method for correcting wind power ultra-short-period prediction of a self- learning ARMA model in real time. The method includes the steps of inputting data to obtain auto regressive moving average model parameters, inputting wind resource monitoring system data and running monitoring system data, correcting startup capacity in real time according to the running monitoring data, establishing the auto regressive moving average model to obtain a wind power ultra-short-period prediction result, and introducing real-time anemometer tower data to correct the wind power ultra-short-period prediction result in real time. By predicting the wind power in the wind power generation process and introducing the real-time anemometer tower data to correct the wind power ultra-short-period prediction result in real time, the defect that in the existing ARMA technology, the wind power ultra-short-period prediction accuracy is low is overcome, and the aim of high-precision wind power ultra-short-period prediction is achieved.
Description
Technical Field
The invention relates to the technical field of wind power prediction in a new energy power generation process, in particular to a self-learning ARMA model wind power ultra-short-term prediction method for wind power, which is used for wind measurement network real-time correction.
Background
Most of large new energy bases generated after wind power enters a large-scale development stage in China are located in the three-north area (northwest, northeast and north China), the large new energy bases are generally far away from a load center, and the power of the large new energy bases needs to be transmitted to the load center for consumption through a long distance and high voltage. Due to the intermittency, randomness and fluctuation of wind and light resources, the wind power and photovoltaic power generation output of a large-scale new energy base can fluctuate in a large range along with the intermittency, randomness and fluctuation of the charging power of a power transmission network, and a series of problems are brought to the operation safety of a power grid.
By 4 months in 2014, the installed capacity of the grid-connected wind power of the Gansu power grid reaches 707 ten thousand watts, occupies about 22 percent of the total installed capacity of the Gansu power grid, and becomes the second main power source which is only inferior to thermal power. At present, the wind power and photovoltaic power generation installed capacity of the grids in Gansu province exceeds 1/3 of the total installed capacity of the grids in Gansu province. With the continuous improvement of the new energy grid-connected scale, the uncertainty and the uncontrollable property of wind power generation and photovoltaic power generation bring a plurality of problems to the safe, stable and economic operation of a power grid. Accurate estimation of available power generation wind resources is the basis for large-scale wind power optimization scheduling. The method can predict the wind power in the wind power generation process, and can provide key information for real-time scheduling of new energy power generation, a new energy power generation day-ahead plan, a new energy power generation month plan, new energy power generation capacity evaluation and wind curtailment power estimation.
The ARMA (autoregressive moving average model) is widely applied to wind power ultra-short-term prediction as a mature machine learning method. The ARMA model consists of an autoregressive model (AR) and a moving average Model (MA), and the wind power output in 0-4 hours in the future is predicted by carrying out autoregressive operation on historical power and carrying out moving average on a white noise sequence. The ARMA method has many advantages, so the ARMA method is widely used for ultra-short-term prediction of wind power, but the biggest defect of the ARMA method is the hysteresis of prediction, namely when the wind power output is changed, the change speed of the result of the ARMA prediction is generally slower than the change speed of the actual wind power output, and therefore the prediction precision of the ARMA is seriously influenced.
Disclosure of Invention
The invention aims to provide a real-time correction self-learning ARMA model wind power ultra-short term prediction method aiming at the problems so as to realize the advantage of high-precision wind power ultra-short term prediction.
In order to achieve the purpose, the invention adopts the technical scheme that:
a real-time correction ultra-short-term wind power prediction method for a self-learning ARMA model comprises the steps of inputting data to obtain autoregressive moving average model parameters;
inputting wind resource monitoring system data and operation monitoring system data, and correcting the starting capacity in real time according to the operation monitoring data;
establishing an autoregressive moving average model so as to obtain a wind power ultra-short term prediction result;
and introducing real-time anemometer tower data to correct the wind power ultra-short term prediction result in real time.
According to the preferred embodiment of the present invention, the obtaining of the autoregressive moving average model parameter from the input data comprises inputting model training basic data;
determining the order of the model;
and (3) estimating the fixed-order ARMA (p, q) model parameters by adopting a moment estimation method.
According to a preferred embodiment of the invention, the input model trains basic data, the input data comprising historical wind speed data and historical power data.
According to the preferred embodiment of the present invention, the model order specifically is:
performing model order determination by using a residual variance graph method, specifically setting xtFor the term to be estimated, xt-1,xt-2,...,xt-nFor an ARMA (p, q) model, determining the values of parameters p and q in the model by the model in order for the known historical power sequence;
fitting the original sequence with a model with a series of increasing orders, calculating the sum of squares of the residuals each timeThen draw the sum of the ordersWhen the order number is increased from small to small,will be obviously reduced and reach the real orderWill gradually tend to be flat and even reversedBut is increased in the size of the container body,
the square sum of the fitting errors/(number of actual observed values-number of model parameters),
the number of actual observed values refers to the number of observed value terms actually used in fitting the model, for a sequence with N observed values, fitting an AR (p) model, the actually used observed values are at most N-p, the model parameter number refers to the number of parameters actually contained in the established model, for the model with a mean value, the number of model parameters is the number of model orders plus 1, and for the sequence with N observed values, the residual estimation formula of the ARMA model is as follows:
wherein Q is a sum of squares function of the fitting error,and thetaj(1. ltoreq. j. ltoreq. q) is the model coefficient, N is the observation sequence length,is a constant term in the model parameters.
According to the preferred embodiment of the present invention, the estimating the fixed-order ARMA (p, q) model parameters by using the moment estimation method specifically comprises the following steps:
utilizing historical power data of wind power plant by data sequence x1,x2,...,xtRepresentation with sample autocovariance defined as
Wherein k is 0,1,2tAnd xt-kAre all data sequences x1,x2,...,xtThe numerical values of (1);
then <math>
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The historical power data sample autocorrelation function is then:
wherein k is 0,1,2, 1, n-1;
the moment of the AR part is estimated as,
order to
The covariance function is then
By usingInstead of gammak，
Available parameters
For MA (q) model coefficientUsing the moment estimate to have
Wherein k is 1, 2.. times, m,
and solving the nonlinear equations of the above m +1 equations by an iterative method to obtain the parameters of the autoregressive moving average model.
According to a preferred embodiment of the present invention,
the wind resource monitoring system data comprises real-time wind measurement data monitored by a wind measurement tower related to the wind power plant to be predicted and the average wind speed of the wind power plant predicted by numerical weather forecast data, and the operation monitoring system data is real-time monitoring information of a fan of the wind power plant to be predicted and comprises real-time startup and shutdown conditions of the fan and unit pitch angle state information.
According to a preferred embodiment of the present invention, further comprising,
outputting the prediction result;
and post-evaluating the prediction result and modifying the model.
According to a preferred embodiment of the present invention, the autoregressive moving average model is:
wherein,and thetaj(1. ltoreq. j. ltoreq. q) is a coefficient, alphatIs a white noise sequence.
According to the preferred embodiment of the present invention, the introducing of the real-time anemometer tower data to perform the real-time correction on the wind power ultra-short term prediction result specifically comprises:
let t1At any moment, the average wind speed of the wind power plant obtained by monitoring the anemometer tower is v1And the average wind speed of the wind power plant predicted by numerical weather forecast data is u1The actual output of the wind farm is p1(ii) a The next time t2At the moment, the average wind speed of the wind power plant predicted by numerical weather forecast data is u2Then the average wind speed v of the wind farm2In order to realize the purpose,
v2＝v1+(u2-u1)
the correction quantity of the parameter of the wind power plant power prediction is
According to the preferred embodiment of the present invention, the final prediction result is output as:
wherein, XtIs the prediction of the output of the wind power plant at the moment t,and thetaj(1. ltoreq. j. ltoreq. q) is a coefficient, alphatIs a white noise sequence, λ is a weighting coefficient, vtIs the average wind speed of the wind farm at time t.
The technical scheme of the invention has the following beneficial effects:
according to the technical scheme, the wind power in the wind power generation process is predicted, the wind power ultra-short term prediction result is corrected in real time by introducing real-time wind measuring tower data, the defect of low wind power ultra-short term prediction precision in the existing ARMA technology is overcome, and the purpose of high-precision wind power ultra-short term prediction is achieved.
The technical solution of the present invention is further described in detail by the accompanying drawings and embodiments.
Drawings
FIG. 1 is a schematic block diagram of a real-time corrected wind power ultra-short term prediction method for a self-learning ARMA model according to an embodiment of the present invention.
Detailed Description
The preferred embodiments of the present invention will be described in conjunction with the accompanying drawings, and it will be understood that they are described herein for the purpose of illustration and explanation and not limitation.
A real-time correction ultra-short-term wind power prediction method for a self-learning ARMA model comprises the steps of inputting data to obtain autoregressive moving average model parameters;
inputting wind resource monitoring system data and operation monitoring system data, and correcting the starting capacity in real time according to the operation monitoring data;
establishing an autoregressive moving average model so as to obtain a wind power ultra-short term prediction result;
and introducing real-time anemometer tower data to correct the wind power ultra-short term prediction result in real time.
As shown in fig. 1, the ultra-short term prediction of wind power proposed by the technical solution of the present invention can be divided into two stages: a model training phase and a power prediction phase.
Stage 1: model training
Step 1.1: model training basic data input
Input data required by model training of the wind power prediction system mainly comprise historical wind speed data, historical power data and the like. And inputting the basic data into a prediction model for model training.
Step 1.2: order determination of model
Since it is not possible to determine in advance how many terms of the known time series need to be used to build the estimation function, a decision to rank the model is required.
Let xtFor the term to be estimated, xt-1,xt-2,...,xt-nFor the ARMA (p, q) model, the model order is to determine the values of the parameters p and q in the model for the known historical power sequence.
And carrying out model order determination by adopting a residual variance graph method. Assuming that the model is a finite order autoregressive model, if the set order is smaller than the true order, the model is an insufficient fitting, so that the fitted residual sum of squares is necessarily large, and at this time, the residual sum of squares can be remarkably reduced by increasing the order. Conversely, if the order has reached the true value, then increasing the order again is an overfitting, and increasing the order does not significantly reduce the sum of squared residuals, or even slightly increases the sum.
Thus, a series of models with progressively increasing order were fitted to the original sequence, each time the sum of the squares of the residuals were calculatedThen draw the sum of the ordersThe pattern of (2). When the order number is increased from small to small,will be obviously reduced and reach the real orderThe value of (a) tends to be gradually gentle and sometimes even to increase. The residual variance is estimated as:
the square sum of fitting errors/(number of actual observed values-number of model parameters)
The "number of actual observations" refers to the number of observation terms actually used in fitting the model, and for a sequence having N observations, fitting the ar (p) model results in the actually used observations being at most N-p.
The number of model parameters is the number of parameters actually included in the established model, and for the model with the mean value, the number of model parameters is the number of model orders plus 1. For a sequence of N observations, the residual estimate for the corresponding ARMA model is:
in equation 1, Q is a function of the sum of the squares of the fitting errors,and thetaj(1. ltoreq. j. ltoreq. q) is the model coefficient, N is the observation sequence length,is a constant term in the model parameters.
Step 1.3: model parameter estimation
Model parameters of ARMA (p, q) are estimated by a moment estimation method. Firstly, utilizing historical power data of the wind power plant by a data sequence x1,x2,...,xtRepresentation with sample autocovariance defined as
Wherein k is 0,1,2tAnd xt-kAre all data sequences x1,x2,...,xtThe numerical values in (1).
In particular, it is possible to use, for example,
The historical power data sample autocorrelation function is then:
Wherein k is 0,1, 2.
The moments of the AR portion are estimated as
(formula 5)
Order to
(formula 6)
The covariance function is then
(formula 7)
By usingInstead of gammakIs provided with
(formula 8)
Available parameters
For the MA (q) model coefficient theta1,θ2,...,θqUsing the moment estimate to have
………
………
Wherein k is 1, 2.
The above equations contain m +1 equations, and for the parameters, the equations are nonlinear and are solved by an iterative method.
The specific steps are as follows, transforming the equation into:
Given theta1,θ2,...,θqAnda set of initial values, e.g. of
Substituting the right side of the above two formulas, the value obtained at the left side is the first step iteration value, and recording asThen the value is substituted into the right side of the two formulas in sequence to obtain a second step iteration value,and analogizing in turn until the results of two adjacent iterations are smaller than a given threshold value, and taking the obtained results as approximate solutions of the parameters.
Finding out that the order of the time series model is required to be solved through the solving process, and obtaining the predicted value of the time series; to obtain a predicted value of the time sequence, a specific prediction function must be established first; to build a specific prediction function, the order of the model must be known.
According to practice, the time series model order generally does not exceed 5. Therefore, when the algorithm is specifically implemented, the model can be assumed to be 1 order, the parameter of the first-order model is obtained by using the parameter estimation method in the step 1.3, and then an estimation function is established so that the time series model of the first-order model can be estimated to obtain the predicted value of each item, and the residual variance of the first-order model can be obtained; then, assuming that the model is of the second order, the residual error of the second-order model is obtained by the method; by analogy, the residual errors of the models of 1 to 5 orders can be obtained, and the order of the model with the minimum residual error is selected as the order of the final model. After the order of the model is determined, the parameter theta can be calculated1,θ2,...,θqThe value of (c).
And (2) stage: power prediction
Step 2.1: wind resource monitoring system data input
The wind resource monitoring system data mainly comprises real-time wind measurement data monitored by a wind measuring tower related to the wind power plant to be predicted and the average wind speed of the wind power plant predicted by NWP (numerical weather forecast data).
Step 2.2: operation monitoring system data input
The operation monitoring system data refers to real-time monitoring information of a wind turbine of the wind power plant to be predicted and mainly comprises state information of real-time startup and shutdown conditions of the wind turbine, a unit pitch angle and the like.
Step 2.3: real-time correction of boot capacity for operation monitoring data
In the operation process of the wind power plant, the shutdown condition caused by various reasons always exists, for example, a typical 20-ten-thousand-kilowatt installed wind power plant comprises 134 fans, about 10 fans are in a shutdown state on average, so the actual startup capacity of wind power can be known through real-time fan operation monitoring data, and the installed capacity of the wind power plant is not used for wind power ultra-short-term prediction.
Step 2.4: ARMA model-based wind power ultra-short term prediction
After the model parameters are estimated, a time series equation for the ultra-short term prediction of the wind power can be obtained by combining the estimated model orders. The p and q values obtained from the above steps 2 and 3, anθ1,θ2,...,θqEstablishing an autoregressive moving average model;
the autoregressive moving average model is as follows:
(formula 14)
Wherein,and thetaj(1. ltoreq. j. ltoreq. q) is a coefficient, and α t is a white noise sequence.
Step 2.5: resource monitoring data real-time correction wind power ultra-short term prediction result
According to the ARMA prediction model, the model always has hysteresis for real-time change of the wind power, and the wind power ultra-short term prediction result is corrected in real time by introducing real-time anemometer tower data.
Let t1At any moment, the average wind speed of the wind power plant obtained by monitoring the anemometer tower is v1And the average wind speed of the NWP predicted wind power plant is u1The actual output of the wind farm is p1(ii) a The next time t2At the moment, the average wind speed of the NWP predicted wind power plant is u2Then the average wind speed v of the wind farm2In order to realize the purpose,
v2＝v1+(u2-u1) (formula 15)
The correction quantity of the parameter of the wind power plant power prediction is
Step 2.6: outputting and displaying final prediction result
The ultra-short term prediction result of the ARMA model wind power corrected by the wind measuring network in real time is
(formula 17)
Wherein, XtIs the prediction of the output of the wind power plant at the moment t,and thetaj(1. ltoreq. j. ltoreq. q) is a coefficient, alphatIs a white noise sequence, λ is a weighting coefficient, vtIs the average wind speed of the wind farm at time t.
By introducing the predicted wind speed corrected by the real-time monitoring data of the anemometer tower, the weighted adjustment can be made on the next prediction of the ARMA model, so that the problem of the hysteresis of the prediction of the ARMA model is solved.
And outputting the prediction result to a database, and displaying the prediction result through a chart and a curve, and displaying the comparison between the prediction result and the actual measurement result.
Step 2.7: post-prediction evaluation and model correction
The step is to firstly carry out post evaluation on the prediction result and analyze the error between the predicted value and the measured value. And if the prediction error is larger than the maximum error allowed, jumping to the model training process, and re-performing the model training.
Finally, it should be noted that: although the present invention has been described in detail with reference to the foregoing embodiments, it will be apparent to those skilled in the art that changes may be made in the embodiments and/or equivalents thereof without departing from the spirit and scope of the invention. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (10)
1. A real-time correction ultra-short-term wind power prediction method for a self-learning ARMA model is characterized by comprising the steps of inputting data to obtain parameters of an autoregressive moving average model;
inputting wind resource monitoring system data and operation monitoring system data, and correcting the starting capacity in real time according to the operation monitoring data;
establishing an autoregressive moving average model so as to obtain a wind power ultra-short term prediction result;
and introducing real-time anemometer tower data to correct the wind power ultra-short term prediction result in real time.
2. The real-time corrected self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 1, wherein the obtaining of autoregressive moving average model parameters from the input data comprises inputting model training base data;
determining the order of the model;
and (3) estimating the fixed-order ARMA (p, q) model parameters by adopting a moment estimation method.
3. The real-time corrected self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 2, wherein the input model trains basic data, and the input data comprises historical wind speed data and historical power data.
4. The real-time correction self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 3, wherein the model order determination specifically comprises:
performing model order determination by using a residual variance graph method, specifically setting xtFor the term to be estimated, xt-1,xt-2,...,xt-nFor an ARMA (p, q) model, determining the values of parameters p and q in the model by the model in order for the known historical power sequence;
fitting the original sequence with a model with a series of increasing orders, calculating the sum of squares of the residuals each timeThen draw the sum of the ordersWhen the order number is increased from small to small,will be obviously reduced and reach the real orderThe value of (a) will gradually become flat, or even increase,
the square sum of the fitting errors/(number of actual observed values-number of model parameters),
the number of actual observed values refers to the number of observed value terms actually used in fitting the model, for a sequence with N observed values, fitting an AR (p) model, the actually used observed values are at most N-p, the model parameter number refers to the number of parameters actually contained in the established model, for the model with a mean value, the number of model parameters is the number of model orders plus 1, and for the sequence with N observed values, the residual estimation formula of the ARMA model is as follows:
wherein Q is a sum of squares function of the fitting error,and thetaj(1. ltoreq. j. ltoreq. q) is the model coefficient, N is the observation sequence length,is a constant term in the model parameters.
5. The real-time correction self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 4, wherein the specific steps of estimating fixed-order ARMA (p, q) model parameters by using a moment estimation method are as follows:
utilizing historical power data of wind power plant by data sequence x1,x2,...,xtRepresentation with sample autocovariance defined as
Wherein k is 0,1,2tAnd xt-kAre all data sequences x1,x2,...,xtThe numerical values of (1);
then
The historical power data sample autocorrelation function is then:
wherein k is 0,1,2, 1, n-1;
the moment of the AR part is estimated as,
order to
The covariance function is then
By usingInstead of gammak，
Available parameters
For the MA (q) model coefficient theta1,θ2,...,θqUsing the moment estimate to have
Up to
Wherein k is 1, 2.. times, m,
and solving the nonlinear equations of the above m +1 equations by an iterative method to obtain the parameters of the autoregressive moving average model.
6. The real-time corrected self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 5,
the wind resource monitoring system data comprises real-time wind measurement data monitored by a wind measurement tower related to the wind power plant to be predicted and the average wind speed of the wind power plant predicted by numerical weather forecast data, and the operation monitoring system data is real-time monitoring information of a fan of the wind power plant to be predicted and comprises real-time startup and shutdown conditions of the fan and unit pitch angle state information.
7. The real-time corrected self-learning ARMA model wind power ultra-short term prediction method as recited in claim 6, further comprising,
outputting the prediction result;
and post-evaluating the prediction result and modifying the model.
8. The real-time corrected self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 7, wherein the autoregressive moving average model is:
wherein,and thetaj(1. ltoreq. j. ltoreq. q) is a coefficient, alphatIs a white noise sequence.
9. The real-time correction self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 8, wherein the real-time correction of the wind power ultra-short term prediction result by introducing real-time anemometer tower data specifically comprises:
let t1At any moment, the average wind speed of the wind power plant obtained by monitoring the anemometer tower is v1And the average wind speed of the wind power plant predicted by numerical weather forecast data is u1The actual output of the wind farm is p1(ii) a The next time t2At the moment, the average wind speed of the wind power plant predicted by numerical weather forecast data is u2Then the average wind speed v of the wind farm2In order to realize the purpose,
v2＝v1+(u2-u1)
the correction quantity of the parameter of the wind power plant power prediction is
(vtNot equal to 0).
10. The real-time correction self-learning ARMA model wind power ultra-short term prediction method as claimed in claim 9, wherein the final output prediction result is:
wherein, XtIs the prediction of the output of the wind power plant at the moment t,and thetaj(1. ltoreq. j. ltoreq. q) is a coefficient, alphatIs a white noise sequence, λ is a weighting coefficient, vtIs the average wind speed of the wind farm at time t.
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