Power systems wide-area voltage stability assessment considering dissimilar load variations and credible contingencies
- 418 Downloads
This paper reveals that the existing techniques have some deficiencies in the proper estimation of voltage stability margin (VSM) when applied to a power system with different load change scenarios. The problem gets worse when credible contingencies occur. This paper proposes a real-time wide-area approach to estimate VSM of power systems with different possible load change scenarios under normal and contingency operating conditions. The new method is based on an artificial neural network (ANN) whose inputs are bus voltage phasors captured by phasor measurement units (PMUs) and rates of change of active power loads. A new input feature is also accommodated to overcome the inability of trained ANN in prediction of VSM under N−1 and N−2 contingencies. With a new algorithm, the number of contingencies is reduced for the effective training of ANN. Robustness of the proposed technique is assured through adding a random noise to input variables. To deal with systems with a limited number of PMUs, a search algorithm is accomplished to identify the optimal placement of PMUs. The proposed method is examined on the IEEE 6-bus and the New England 39-bus test system. Results show that the VSM could be predicted with less than 1% error.
KeywordsArtificial neural network (ANN) Phasor measurement unit (PMU) Voltage stability margin (VSM)
Voltage stability is defined as the ability of the power system to maintain steady voltages when it is subjected to perturbations . In general, a power system is designed to operate under various conditions; however, it is inevitable that complex power systems will experience difficulties in the operation process some of which lead to the voltage collapse. In the sequel of many major blackouts [2, 3], tackling system voltage instability has attracted researchers’ attention [4, 5, 6, 7].
Among several methods developed so far to calculate voltage stability limit [8, 9, 10, 11], continuation power flow (CPF) is one of the most efficient methods. In CPF method, new forms of power flow equations are introduced to overcome the convergence problem of conventional power flow algorithms near the stability limit point . CPF method, although offers accurate outcomes, is time-consuming and undesirable for real-time applications. In , a modified coupled single-port model was proposed to monitor voltage stability of the system. Results show improvement in monitoring voltage stability in comparison with the conventional CPF method. In  and , two methods were developed to analyze voltage stability based on the Thevenin equivalent concept. What is missing in these methods is considering systems different conditions like contingencies.
As the CPF method is an offline method, it is not appropriate to be used it for online applications. In this manner, several data mining tools such as support vector machine, artificial neural networks (ANNs), fuzzy systems, and expert systems together with conventional techniques have been proposed to develop online monitoring of voltage stability [15, 16, 17, 18]. Among these methods, ANN is a fast response technique promising to be used in real-time applications . The capability of ANN in capturing nonlinear characteristics of the power system makes it suitable for real-world practices [19, 20]. ANN, as a “black-box” tool, includes input and output neurons. The performance of ANN is dominantly affected by the input feature selection. In the context of voltage stability assessment,  has selected active and reactive line flows as ANN inputs. In , active and reactive powers of load buses were used in the ANN input vector. Reference  used voltage magnitude of load buses and active and reactive powers of load and generation buses. In , performances of different inputs of the ANN were compared and it was deduced that the best performance of ANN is attained using bus voltage phasors as the input vector.
Dealing with a broad range of contingencies, such as line outages, is a challenge in voltage stability analysis. In N−1 contingency states, the trained ANN may fail to accurately estimate voltage stability margin (VSM) because of the change in the system configuration and characteristics. This may become worse in N−2 contingencies. Research attempts in [20, 21, 22, 23] have used an ANN to evaluate voltage stability in the normal condition and a separate ANN for contingency states. This may be inappropriate for a large power system with a huge number and different types of contingencies.
In the previous works, voltage stability of power systems has been evaluated by using state variables of the current operating point. The long-term voltage stability phenomenon is highly dependent on the load change scenarios . Since in large-scale power systems the loads vary in different scenarios, incorporating the rates of change in loads in the ANN design process can be a viable alternative . To the best knowledge of the authors, this subject has not been covered in previous research efforts.
Proximity of voltage collapse could be estimated by using voltage magnitude.
Power flow could be predicted by means of phase angles .
Rates of load change give a direct implication to the devised ANN that which loads or regions has more effect on the system voltage stability limit. Note that the load change rate can be obtained by having two sequent power quantities captured by measurement and monitoring system.
The proposed method is able to estimate VSM in normal and contingency conditions by using a single ANN. The ability to determine voltage stability status in normal and contingency at the same time is the main advantage of the proposed method in comparison with the other online methods. To keep the ANN accuracy in contingency conditions, a specific input standing for contingency number is accounted for. As in the large-scale systems the number of contingencies is intractable, the performance of the proposed method would be affected. Accordingly, a new algorithm is introduced to reduce the number of contingency states supposed to be added in training phase of the ANN. The effectiveness of the proposed algorithm is examined on IEEE 6-bus test system and New England 39-bus test system.
The rest of the paper is organized as follows: some fundamental considerations of voltage stability are discussed in Section 2. An introduction to the ANN and the proposed methodology are presented in Section 3. Section 4 outlines simulation results. Section 5 summarizes the conclusions.
2 Fundamentals of voltage stability analysis
3 Proposed methodology
The first step towards developing an appropriate ANN for the voltage stability monitoring is clarification of the goal of ANN and the problem in question. The problem defined in previous attempts is: “For a specific system condition, what would be the stability margin?” Specifying system condition includes obtaining system parameters and variables, such as voltage magnitude, active and reactive powers of the loads, etc. However, the problem in question in this paper is: “For a specific system condition and rates of load changes, what would be the stability margin?” The aspect of various load change scenarios is emphasized here since, based on the authors’ experiences, real power systems do not have a unique and identical load increase pattern in all load points. This feature leads to significant deficiencies of the existing ANN models in proper estimation of VSMs. Neither increasing ANN training samples nor applying different configuration of ANN could handle this complexity. To overcome this difficulty, the rates of various load changes should be predicted and inserted as inputs into the ANN.
To compute VSM, MATLAB-based open source software tool PSAT is employed by applying CPF method on sample cases. After generating appropriate sample cases for training, validating, and testing the designed ANN, MATLAB neural network toolbox is employed to estimate VSM [21, 24].
3.1 ANN structure
3.2 Input variables selection
There are many available variables of which those improving performance of the model should be selected.
Selected variables should have less correlation to avoid redundancy.
Selected variables should have a potential in estimation of VSM; worthless features may even lead to malfunction.
As indicated before, the combination of voltage angles and magnitudes of system buses as the input of ANN is the most effective feature combination in comparison to others, such as voltage magnitudes and reactive powers, etc. . This deduction does not hold in the problem at hand since different rates of load changes are accommodated. Under these circumstances, a third input feature is needed. To do so, the rates of load changes are selected as the third input feature. In this way, ANN could directly learn how to respond along with different load change scenarios.
3.3 Data set generation
3.4 Evaluation of model performances
R is equal to one when the trained ANN is able to exactly predict all VSMs. Inaccurate estimation of VSM leads to lower values of R measure.
3.5 Incorporation of system configuration changes
Power system components (e.g. lines, generators, and etc.) need periodical maintenances. In addition, there are always unexpected outages in the system due to component failures or protection system incorrect actions. Power systems likely face with the condition that one, two, or more components are out of service. Dealing with power system assessments in contingency conditions is hence crucial for the system operators [5, 27]. Note as well that since the higher order of contingencies are of trivial probabilities, usually single and double outage contingencies are merely accounted for in system studies. However, power system resilience analysis calls for low probability but very sever disturbances.
Explicit method in which the ANN samples include contingency samples; moreover, an extra input(s), which specifies contingency identification, is added to the input features. In this manner, each sample corresponds to a specified contingency. Results show that this method can improve the ANN performance.
3.6 Flowchart for VSM estimation using ANN
Step 1: Train ANN with normal state samples.
Step 2: Choose some samples among N−1 contingencies. If the trained ANN is able to predict VSM, there is no need to add these contingencies to sample cases of ANN. Otherwise, the contingencies are added to sample cases and ANN is retrained. This step may be applied for all N−1 contingencies. In this stage, some of contingencies, with low effects on the voltage stability or with impacts similar to those of contingencies already included in the training, are omitted.
Step 3: The same process of Step 2 is applied to N−2 contingencies. In comparison to N−1 contingencies, an N−2 contingency brings about more severe impacts only when the two outaged elements are electrically (and likely geographically) close to each other. Otherwise, N−2 contingency has no further mutual impact compared to two respective N−1 contingencies. In such a case, usually one of contingencies has more effect on voltage stability and it would determine the limitation of voltage stability. That is why analysis of N−2 contingencies will start after investigating all N−1 contingencies. Thus, majority of N−2 contingencies would be eliminated in this stage and just a few are added to the training data set. However if in a large-scale system, the number of N−2 contingencies is intractable, contingency screening and selection procedures can be taken in use to handle the computational difficulty.
In summary, the ANN is trained to respond normal, N−1, and N−2 contingencies. If the system experience a contingency in real-time, then the input standing for the contingency number implicitly assist ANN to lead to a more accurate result. In this manner, the designed method is well capable to deal with contingencies.
4 Simulation results
According to the nature of long-term voltage stability, test cases are designed as such they can specify the effect of load change during a long-term voltage stability assessment. The IEEE 6-bus standard and the New England 10-machine 39-bus test systems are examined for the numerical analysis purposes .
4.1 Illustrative example
The first step is generating sample cases. To do so, random variables are added to the system base cases. The tolerances of active and reactive powers are set at ±30%. This means that Δ equals to 0.3 in (4). The tolerance of generators voltage magnitude is set at ±3%. The tolerance of the rate of change of active power is set at ±30%. The number of generated cases is 3000. These cases are randomly divided into three groups: training, validation, and testing cases. 70% of the whole cases are used for training phase, while each of the validation and testing phase include 15% of cases. Training and validation phases are done concurrently. The validation phase is used to stop training before over fitting occurs. Only normal condition is considered in this stage and contingency analysis will be discussed later. Using CPF method for each of the sample case, VSM is obtained and used as the target of the designed ANN.
The next step is to adopt ANN inputs. In this regard, voltage magnitudes and angles of all buses except the slack bus plus the rate of active power changes of all load buses are selected as the inputs. Slack bus voltage magnitude and angle are fixed during simulations, so it is omitted from the input list. Thus, we have thirteen inputs and a single output target for the ANN.
4.2 New England 39-bus test system
The number of samples used for training, validation, and testing phase of the ANN is 3000 (70% for training, 15% for validation, and 15% for testing).
Method 1: Inputs are voltage phasors and rates of change of active powers. Also, different load change scenarios are used in the training phase.
Method 2: Inputs are voltage phasors. Different load change scenarios are used in the training phase.
Method 3: Inputs are voltage phasors. However, only a single load change scenario is used in the training phase. Actually, this is the conventional method assuming a unique load variation pattern for the whole system.
Referring to Fig. 11, it is concluded that the conventional Method 3 fails in the proper estimation of VSM (R = 0.6144). Thus, adding various load change scenarios to the train sample set is an inevitable requirement in real-world practices. Comparison of two other techniques reveals that the direct consideration of various load change scenarios in the ANN (Method 1) outperforms Method 2 in which load change scenarios are only seen among in the training set.
Next, N−2 contingencies are similarly covered. From the viewpoint of voltage stability assessment, the most severe N−2 contingencies are outage of transmission lines terminating to a given load bus. These double contingencies with a count of 45 are initially considered and next filtered out. Finally, 10 double contingency is recognized valuable to be added to the training samples. Figure 12b shows the regression results of the designed ANN in response to the normal, N−1 contingency, and N−2 contingency states.
4.3 ANN training time
Among the aspects of real-time application of VSM assessment approaches is the computational time. Talking about ANN, one computational time is important: How long does the devised ANN take to estimate VSM?
Training and execution time of ANN
Training time (s)
Estimation time (s)
4.4 Effect of measurement errors on proposed method
R value of designed ANN considering noisy inputs
4.5 Optimal phasor measurement unit (PMU) placement
Most of the power systems around the world have only limited number of PMUs and there is far distance with the complete phasor observability of electric power networks. The reason was the high price of PMU devices in the past and is the limited available wide-band communication media todays. Accordingly, the optimal placement with the objective of VSM analysis could be a practically fruitful alternative . Usually, it is not computationally feasible to test every possible combinations of PMU placement (2N, where N is the number of buses). A search algorithm could thus be employed to obtain a proper combination. To do so, the New England 39-bus test system is studied.
Among many methods proposed to find the optimal placement of PMUs for complete observability of the system [31, 32], integer linear programming (ILP) method is the most commonly used . In , optimal PMU placement of the New England 39-bus system ensuring complete observability is reported. Each PMU by means of current phasors and line parameters makes its hosting bus and all adjacent buses observable (zero injection bus effect is overlooked because of its low reliability and high propagated error). Doing so here, buses 2, 6, 9, 10, 11, 14, 17, 19, 22, 23, 25, 29, 34 are selected as candidates for PMU placement ensuring entire observability. Among candidate buses, the search algorithm is to find the best placement of a given number of PMUs achieving the best performance of the proposed method.
Initially, the place of first PMU among 13 buses is specified. Afterward, the second PMU is placed in a bus out of 12 remaining buses. This process will continue until the last available PMU. Note as well that this procedure looks for appropriate schemes within the context of the final full observability PMU placement plan.
This paper revealed that an ANN with bus voltage phasors as inputs is unable to estimate VSM when various load change scenarios are expected. To deal with this problem, the rates of change of active powers were adopted to be added to the input vector of ANN. The designed ANN was trained off-line and used for real-time VSM estimation. For the sake of practicality, two explicit and implicit methods have been discussed for incorporation of contingencies. The results indicated that the explicit method has more reliable performances. In large-scale power systems, the immense number of contingencies could be cumbersome. An algorithm was accordingly developed to reduce the number of contingencies in large-scale power systems. Results show that the performance of the proposed method is more than 99% in all case studies and is not affected by the size of the system. In addition, the effect of noise on the ANN inputs has been tested and the results clarified that the VSM could be obtained in noisy environments by using the proposed method.
- Kundur P, Paserba J, Ajjarapu V et al (2004) Definition and classification of power system stability. IEEE Trans Power Syst 19(3):1387–1401Google Scholar
- U.S.-Canada Power System Outage Task Force (2004) Blackout 2003: final report on the August 14, 2003 blackout in the United States and Canada: causes and recommendations. Office of Electricity Delivery & Energy Reliability, Washington, USAGoogle Scholar
- Anderson G, Donalek P, Farmer R et al (2005) Causes of the 2003 major grid blackouts in North America and Europa, and recommended means to improve system dynamic performance. IEEE Trans Power Syst 20(3):1922–1928Google Scholar
- Glavic M, Cutsem TV (2009) Wide-area detection of voltage instability from synchronized phasor measurements. Part I: principle. IEEE Trans Power Syst 24(3):1408–1416Google Scholar
- Shekari T, Gholami A, Aminifar F et al (2018) An adaptive wide-area load shedding scheme incorporating power system real-time limitations. IEEE Syst J 12(1):759–767Google Scholar
- Wang Y, Pordanjani IR, Li W et al (2011) Voltage stability monitoring based on the concept of coupled single-port circuit. IEEE Trans Power Syst 26(4):2154–2163Google Scholar
- Milosevic B, Begovic M (2003) Voltage-stability protection and control using a wide-area network of phasor measurements. IEEE Trans Power Syst 18(1):121–127Google Scholar
- Zambroni DSAC, Stacchini DSJC, Leite DSAM (2000) On-line voltage stability monitoring. IEEE Trans Power Syst 15(4):1300–1305Google Scholar
- Gao B, Morison GK, Kundur P (1992) Voltage stability evaluation using modal analysis. IEEE Trans Power Syst 7(4):1529–1549Google Scholar
- Ajjarapu V (2006) Computational techniques for voltage stability assessment and control. Springer, New YorkGoogle Scholar
- Ajjarapu V, Christy C (1992) The continuation power flow: a tool for steady state voltage stability analysis. IEEE Trans Power Syst 7(1):416–422Google Scholar
- Liu JH, Chu CC (2014) Wide-area measurement-based voltage stability indicators by modified coupled single-port models. IEEE Trans Power Syst 29(2):756–764Google Scholar
- Xu J, Huang L, Sun Y et al (2016) Voltage instability detection based on the concept of short circuit capacity. IEEE Trans Electr Energ Syst 26(2):444–460Google Scholar
- Lee DHA (2016) Voltage stability assessment using equivalent nodal analysis. IEEE Trans Power Syst 31(1):454–463Google Scholar
- Zhou DQ, Annakkage UD, Rajapakse AD (2010) Online monitoring of voltage stability margin using an artificial neural network. IEEE Trans Power Syst 25(3):1566–1574Google Scholar
- Zheng C, Malbasa V, Kezunovic M (2013) Regression tree for stability margin prediction using synchrophasor measurements. IEEE Trans Power Syst 28(2):1978–1987Google Scholar
- Gomez FR, Rajapakse AD, Annakkage UD et al (2011) Support vector machine-based algorithm for post-fault transient stability status prediction using synchronized measurements. IEEE Trans Power Syst 26(3):1474–1483Google Scholar
- Kamalasadan S, Swann GD, Yousefian R (2014) A novel system-centric intelligent adaptive control architecture for power system stabilizer based on adaptive neural networks. IEEE Syst J 8(4):1074–1085Google Scholar
- Hassan LH, Moghavvemi M, Almurib HAF et al (2013) Current state of neural networks applications in power system monitoring and control. Int J Electr Power Energy Syst 51:134–144Google Scholar
- Chakrabarti S, Jeyasurya B (2004) On-line voltage stability monitoring using artificial neural network. In: Proceedings of large engineering systems conference on power engineering, Halifax, Canada, 28–30 July 2004, 5 ppGoogle Scholar
- Chakrabarti S (2008) Voltage stability monitoring by artificial neural network using a regression-based feature selection method. Expert Syst Appl 35(4):1802–1808Google Scholar
- Devaraj D, Roselyn JP (2011) On-line voltage stability assessment using radial basis function network model with reduced input features. Int J Electr Power Energy Syst 33(9):1550–1555Google Scholar
- Demuth H, Beale M, Hagan M (2008) Neural network toolbox user’s guide. Math Works, NatickGoogle Scholar
- May RJ, Dany GC, Maier HR (2011) Review of input variable selection methods for artificial neural networks. In: Suzuki K (ed) Artificial neural networks-methodological advances and biomedical applications. InTech, Croatia, pp 19–44Google Scholar
- Beiraghi M, Ranjbar AM (2018) Additive model decision tree-based adaptive wide-area damping controller design. IEEE Syst J 12(1):328–339Google Scholar
- Pai MA (1989) Energy function analysis for power system stability. Springer, New YorkGoogle Scholar
- IEEE Std. C37.118-2005 (2005) IEEE standard for synchrophasors for power systemsGoogle Scholar
- Aminifar F, Fotuhi-Firuzabadi M, Safdarian A (2013) Optimal PMU placement based on probabilistic cost/benefit analysis. IEEE Trans Power Syst 28(1):566–567Google Scholar
- Aminifar F, Lucas C, Khodaei A et al (2009) Optimal placement of phasor measurement units using immunity genetic algotithm. IEEE Trans Power Del 24(3):1014–1020Google Scholar
- Li Q, Cui T, Weng Y et al (2013) An information-theoretic approach for PMU placement in electric power systems. IEEE Trans Smart Grid 4(1):446–456Google Scholar
- Dua D, Dambhare S, Gajbhiye RK et al (2008) Optimal multistage scheduling of PMU placement: an ILP approach. IEEE Trans Power Syst 23(4):1812–1820Google Scholar
- Chakrabarti S, Kyriakides E (2008) Optimal placement of phasor measurement units for power system observability. IEEE Trans Power Syst 23(3):1433–1440Google Scholar
Open AccessThis article is distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution, and reproduction in any medium, provided you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons license, and indicate if changes were made.