**Smart Grid and Renewable Energy**

Vol.09 No.01(2018), Article ID:81768,15 pages

10.4236/sgre.2018.91001

Experimental Study of the Cloud Influence on PV Grid Connected System

Yassir Idris Abdalla Osman^{1,2,3}, Jinping Li^{1,2,3*}, Xiaofei Zhen^{1,2,3}, Airong Yang^{1,2,3}^{ }

^{1}Western China Energy & Environment Research Center, Lanzhou University of Technology, Lanzhou, China

^{2}Gansu Key Laboratory of Complementary Energy System of Biomass and Solar Energy, Lanzhou, China

^{3}China Northwestern Collaborative Innovation Center of Key Technology for Northwest Low Carbon Urbanization, Lanzhou, China

Copyright © 2018 by authors and Scientific Research Publishing Inc.

This work is licensed under the Creative Commons Attribution International License (CC BY 4.0).

http://creativecommons.org/licenses/by/4.0/

Received: November 27, 2017; Accepted: January 13, 2018; Published: January 16, 2018

ABSTRACT

In recent years, PV panels witnessed a vigorous gross, as their performance and the leverage of large-scale industrial production steadily decreased costs. Factors such as solar irradiance, insolation, mismatch of modules/arrays characteristic, aging, partial shading situation have a major effect on the harvested power. Evidence suggests that partial shading situation is the most critical factor and causes a significant reduction in PV system output. In this paper, a method based on two degrees of freedom, namely upper and lower was proposed in order to address the partial shading losses that due to cloud movement. Moreover, an extensive simulation of voltage, current indicators, bypassed modules, fault string, and DC output power was presented to analyze the PV system. The validation of experimental data analysis was carried out on two different days with different amounts of solar irradiance in Minqin County, Gansu Province, China. The results indicated that the power losses were 18.989 W and 127.629 W according to the minimum and the maximum irradiations (1.88 MW/m^{2}) and (2.104 MW/m^{2}) respectively. By considering the minimum irradiance, the upper and the lower degrees of freedom of the losses were 22.17 W/d, and 15.8 W/d respectively. On the other hand, by considering the maximum irradiance, the upper and the lower degrees of freedom were 130.49 W/d, 125.78 W/d respectively.

**Keywords:**

Photovoltaic Systems, Partial Shading, Current and Voltage Indicators, Degree of Freedom

1. Introduction

Recently, there was a large volume of published studies describing Photovoltaic (PV) array as an essential renewable energy source, obviously, due to the significant penetration of PV sources in electricity generation [1] [2] . It was generally considered that partial shading (PS) may seriously affect the characteristic curve of the PV arrays [3] [4] [5] . The presence of bypassing diodes provides an alternate path for the current, thus the amount of cell’s current of the module is greatly different under PS conditions. Therefore, the PV characteristic curve shows multiple maximum points.

In order to overcome PS effects, a number of techniques have been considered, such as the connection of bypass diodes in anti-parallel to PV cells/ modules. In case, reverse bias occurs to any solar cell/module, this module is bypassed and the full current passes through the bypass diode and thus avoids module damage. Clearly, the integration of bypass diodes into photovoltaic arrays is economically costly. Furthermore, extra losses are detected across these diodes under PS conditions. These losses have a major effect in case of low-vol- tage applications. Commonly, the non-linearity of PV characteristic and bypass diodes together are causing a significant issue under PS condition, mainly, the existence of multiple maxima. In order to overcome this issue, a considerable amount of literature has been published on finding GMPP out of all local MPP [6] [7] [8] . These publications concentrate on track speed, number and types of sensors required, accuracy, cost, hardware requirements, complexity, etc. On the other hand, techniques based on micro-converters are adopted to deal with PS losses [9] , other approaches utilize adaptive reconfiguration for connecting PV modules [10] - [15] , AC modules [16] [17] [18] , recovery of energy [19] . The major disadvantage of these approaches is the higher cost since, each module works at its MPP. A technique based on sudoku puzzle pattern, magic square pattern, and futoshiki puzzle pattern is adopted for reposition of modules which are reported in [20] [21] [22] [23] . Mainly, these techniques depend on the shadow pattern to locate the modules in the optimal position in order to minimize the losses. However, these approaches are commonly associated with square PV arrays; moreover, the line losses are increased as a result of increasing the length of interconnections. Generally, mismatch losses are a direct result of moving cloud shadows. Moreover, factors such as electrical configuration, PV array shape, and geographic orientation are also influenced mismatch losses [24] . The approach of determining the time window of shadows based on measured data was provided in [25] , where an average of around 13 m/s was found as a variant of the shadow’s speed.

Although there are many reports in the literature on the PV performance and output power, most are restricted to overpassing cloud shadows and their effects, irradiance characteristics and mathematical modeling of irradiance as in [26] [27] [28] .

This paper presents a method based on the degree of freedom (DOF) to address the calculation of partial shading losses that due to cloud movement over the photovoltaic surface. The measured data of two different winter days with different amounts of irradiance were analyzed. Voltage and current indicators in addition to mathematical model presented in [29] are considered to detect the faults of PV. An extensive simulation of voltage and current indicators, bypassed modules, fault string, and DC output power was presented. Furthermore, two degrees of freedom are considered, namely upper and lower limit to address the shadow movement over the PV surface. Clearly, the most critical stage of using DOF method, emphasized that the amount of the losses has been revealed based on the measured irradiance of the two different winter days. The DC power losses (upper and lower limit), Average power generation, percentage of generation reduction, system consumption [30] , and percentage reduction of system consumption is calculated. However, the analyzation provided in this paper based directly on measured data associated with a specific location, the outcomes are not regionally bounded.

2. Methodology

Fault Detection Parameters

In order to detect faults in PV arrays and realize full automatic supervision indicators for current and voltage are considered and denoted as $N{R}_{c}$ and $N{R}_{v}$ respectively [29] .

$N{R}_{c}=\frac{{I}_{m}}{{I}_{sc}}$ (1)

$N{R}_{v}=\frac{{V}_{m}}{{V}_{oc}}$ (2)

${I}_{m}$ and ${V}_{m}$ are the current and voltage of MPP, these parameters can be calculated at the inverter input.

${V}_{oc}$ and ${I}_{sc}$ denote the open circuit voltage and short circuit current respectively, these values are related to the inverter and describe the status of irradiance and temperature in real time. In the light of this, it is necessary for the inverter to have the advantage of monitoring. Within the same context, under normal operation condition ${V}_{mo}$ and ${I}_{mo}$ are the voltage and current of the PV array at the maximum power point. Furthermore, in the absence of fault the expected values of $N{R}_{c}$ and $N{R}_{v}$ are:

$N{R}_{co}=\frac{{I}_{mo}}{{I}_{sc}}$ (3)

$N{R}_{vo}=\frac{{V}_{mo}}{{V}_{oc}}$ (4)

In order to detect the open circuit and short circuit the thresholds for current and voltage $TN{R}_{cfs}$ and $TN{R}_{vbm}$ .

Respectively must be defined as follows:

$TN{R}_{cfs}=1.02\alpha N{R}_{co}$ (5)

$TN{R}_{vbm}=1.02\beta {R}_{vo}$ (6)

where $\alpha $ and $\beta $ denote the relationship between the ratio of current in case of one fault string and fault-free operation, and the ratio between the voltage ration in the case of one PV module was bypassed and fault-free operation respectively provided by Equations (7) and (8). Further, in order to avoid detection of the false fault the constant in the Equations (5) and (6) must be included, this constant represent an offset of a 2% respect the expected value of the current indicator $N{R}_{co}$ .

$\alpha =\frac{N{R}_{cfs}}{N{R}_{co}}=1-\frac{1}{{N}_{p}}$ (7)

$\beta =\frac{N{R}_{vbm}}{N{R}_{vo}}=1-\frac{1}{{N}_{s}}$ (8)

When the PV array was totally damaged the corresponding voltage and current for open circuits or short circuit indicators mostly remain under its threshold.

Partial shading of PV arrays inevitably reduced the amount of the power output [20] [31] [32] . However, partial shading was characterized by dynamic evolution of the cloud, in addition to natural obstacle [24] [33] .

According to the number of shaded PV modules and the amount of shadow the total output current is reduced. On the other hand, the number of activated bypass diodes in the PV module affected directly the overall output voltage [34] . Monitoring process for current and voltage degradation can be achieved simultaneously or separately according to the shadow pattern and PV array alignment. Furthermore, the appearance of these effects is instantaneous due to the irradiance dynamic behavior except in case the PV module totally impaired. Accordingly, current and voltage are particularly useful in this context. Degradation in output voltage is given by:

$\Delta V=\left(\frac{{V}_{mo}-{V}_{m}}{{V}_{mo}}\right)\left(1-\frac{N{R}_{v}}{N{R}_{vo}}\right)$ (9)

Assuming ${N}_{s}$ is a number of PV modules in serious, PV modules bypassed numbers, BPmod, due to shadow influence are calculated by:

$BPmod=\Delta V{N}_{s}$ (10)

The variation of degradation in the current output $\Delta I$ is given by:

$\Delta I=\left(\frac{{I}_{mo}-{I}_{m}}{{I}_{mo}}\right)\left(1-\frac{N{R}_{c}}{N{R}_{co}}\right)$ (11)

In case the PV array are connected in parallel, the losses in output current are expressed in term of the number of equivalent faulty strings in open circuit $E{F}_{s}$ as:

$E{F}_{s}=\Delta I{N}_{p}$ (12)

Accordingly, by considering current and voltage indicators the partial shadow on the PV can be detected even if their values are below the thresholds of each. The number of bypassing modules and the equivalent number of faulty strings can be calculated using Equations (10) and (12) respectively in the presence of partial shadow. From Equations (9) and (11), the losses due the shadowing effect in the DC power are given by:

${P}_{\text{losses}}=\left(1-\frac{N{R}_{c}}{N{R}_{co}}\frac{N{R}_{v}}{N{R}_{vo}}\right)$ (13)

Estimation of the principal parameters associated with the equations play a major role in the accuracy of this method particularly ${I}_{sc}$ , ${V}_{ov}$ , ${I}_{mo}$ , ${V}_{mo}$ , ${I}_{m}$ , and ${V}_{m}$ .

The ability of the inverter to track the maximum power point affects the assessments of ${V}_{m}$ and ${I}_{m}$ . It should be mentioned that the values of $N{R}_{co}$ , $N{R}_{vo}$ , $TN{R}_{cfs}$ and $TN{R}_{vbm}$ are completely independent of MPP real values. In case the inverter stuck at local maxima, parameters such as $N{R}_{c}$ and $N{R}_{v}$ are lower than the real values of MPP. Clearly, the algorithm will be capable of detecting the amount of power losses, which is the difference between the actual MPP and MPP local value.

3. Degree of Freedom

The movement of the shadow over the PV surface is addressed in Figure 1, considering the degree of freedom technique (upper and lower limit) to define the shadow movement (red arrows). Figure 1(a) describes the upper limit case, where the shadow edges are located over the PV surface, on the other hand, Figure 1(b) shows the lower limit case, where a part of the shadow is situated over the PV surface. Based on the degree of freedom technique, the output of the system was analyzed and the results were presented.

4. Experiment Setup

Partial shading grid connecting PV system phenomenon was analyzed considering the evolution of current and voltage indicators. The PV system was a part of a project designed and tested in a single building in a MinQing China [30] . This experiment was conducted during the winter season, where two different days with different amount of irradiance were considered in order to study the

Figure 1. Movement of cloud shadow over PV surface.

behavior of PV system, in addition to the influence of cloud on the amount of the harvested power. A concept known as the degree of freedom considered describing the dynamic of shadow on the PV panel surface. The experiment outcomes indicate the effectiveness of the proposed method in all situations.

There are a number of instruments are utilized here for monitoring purpose includes two pyranometers (Kipp & Zonen CM 11) to measure irradiance of the panels (daily accuracy of this pyranometer is ±2% and it meets the requirements for this experiment), An Agilent Hp34970A for data acquisition. The configuration of the modules is 10 panels 5 parallel-connected strings of 2 series. The complete monitoring system details can be found in [30] . Table 1 presents the parameters of the PV considered in this experiment.

4.1. High Irradiance PV System

The irradiance pattern is shown Figure 2 where the highlight reveals the intervals of shadowing detect by the sensors. Physically the solar cells of the module under PS is bypassed thus the overall active cells is reduced.

The corresponding measured DC output of the PV panels as shown in Figure 3. The irradiance reduction can be seen clearly around 09:00 and 10:00, between 11:00 and 12:00 Also, a considerable reduction noticed around 16:00 moreover, around 13:00 a short disturbance in the grid occurs which leads to a complete inverter shutdown.

It should be mentioned here the influence of these shadows on the output power was well observed on clear days. The voltage indicators evolution is displayed in Figure 4, where the shadow influences the PV arrays around 09:00, between 11:00 and 12:00 and between 03:00 and 04:20 is more significant. What stands out in this figure is that, during the pre-mentioned interval indicators such as NRv seems under the voltage threshold TNRvbm.

However, reduction in DC output power of the PV arrays around 09:00 it is not because of bypassing PV modules as presented in Figure 4, in which a regular voltage evolution is shown by the indicators. The indicator is clearly explained the inverter disconnection.

The number of bypassing modules is depicted in Figure 5, and their activation

Table 1. Photovoltaic power system configuration.

Figure 2. Shaded solar radiation pattern March 18, 2015.

Figure 3. Reduction in DC output power due to shade on PV, and inverter disconnection.

is due to shadow phenomenon. The total number of connected modules is Ns = 10. Figure 5 also significantly reveals the shadowy influence at 11:30 that cause activation of bypassing diode in 2 modules while at noon 4 PV modules are bypassed. Figure 6 shows the zero value of the inverter current input due to the islanding prevention followed by a normal voltage build up. What stands out in Figure 6 is that the influence of shadowing phenomenon in the reduction of PV arrays output current. Particularly at morning, before midday, and at noon is obvious. Figure 6 also clearly determines the interval where the inverter disconnection occurs, during this interval, the inverter output current is zero and the number of faulty strings is EFs = 2 at the time of fault presence as shown in Figure 7. The disconnection of the inverter can be translated as a safety measure in

Figure 4. Evolution of voltage at PV output, threshold, and the expected value of the inverter, in normal operation of the PV system.

Figure 5. Number of bypassing PV modules, due to the shadowing of the PV array.

order to avoid islanding. Before the midday the degradation of the current occurs because of shadow and hence the equivalent fault EFs is up to 0.47. As a result, the current of the strings is reduced by 25% of expectation.

Further, a reduction of current is detected at 09:00, also between 11:00 to 12:00, and at 03:00. Nevertheless, the amount of power reduction is higher in the morning than in the afternoon.

4.2. Low Irradiance PV System

The irradiance associated to one day of December is presented in Figure 8,

Figure 6. Evolution of current, threshold and inverter output.

Figure 7. Number of equivalent faulty strings.

where a reduction of irradiance is detected around 09:00 Accordingly a reduction in the output power of the PV arrays is observed at the same time interval, this is depicted in Figure 9.

Looking at Figure 10, it is apparent that the shadow of the PV arrays has a very low effect on the evolution of the voltage indicators. Shadowing effects are detected at 09:00, which directly reduces the output power. However, this effect was not significant, due to presence of bypassing modules in the strings. Figure 11 emphasize the fact that the number of bypassing modules has never exceeded one.

By contrast, as seen in Figure 12 a reduction in the current is detected, because of partial shading at 09:00. The output power is reduced according to the current low levels at the same time intervals. Finally, what is appealing about Figure 13 is that the reduction of the output current at 18:20 was not significant.

Figure 8. Shaded solar radiation pattern December 31, 2015.

Figure 9. DC output power.

5. Results and Discussions

Table 2 and Table 3 show the system losses based on two degrees of freedom. In these calculations the average values per day for each parameter is considered. In order to define the upper limit of DOF +3W is added to the average parameter, on the other hand, −3W is subtracted from the average parameter to define the lower limit of DOF.

The most interesting aspects of these two tables are the average generated power is 2.468 kW/d and 2.47 kW/d according to the upper and lower limit of DOF case of low irradiance respectively. On the other hand, when considering

Figure 10. Evolution of voltage indicators.

Figure 11. Number of bypassing modules.

high irradiance case, the average generated power is 2.359 kW/d and 2.364 kW/d associated with the upper and lower limit of DOF respectively. The key aspects of the two days under consideration are firstly, March 18, 2015 has significant irradiance over December 31, 2015. Secondly, December 31, 2015 experience lower losses than March 18, 2015. Thirdly, March 18 2015 is heavily clouded in contrast to December 31, 2015. As a result of a PS event (low irradiance) the average generated power is reduced by 0.88% and 0.64% case of upper and lower limit of DOF respectively. Within the same context, in case of high irradiance the average generated power is reduced by 5.53% and 5.32% with respect to upper

Figure 12. Evolution of current indicators, threshold and inverter output.

Figure 13. Number of faulty strings.

and lower limit of DOF respectively. The data presented in Table 2 and Table 3 indicates that the system consumption of power is reduced by 0.713% and 0.53% in low irradiance case of upper and lower limit of DOF respectively. On the other hand, in case of high irradiance 4.55% and 4.38% is reported as a reduction of system consumption.

6. Conclusion

In this paper, the PV array system under partial shading caused by moving cloud was investigated. A method based in two degrees of freedom is considered. Moreover, the system was characterized in terms of losses and performances. Simulation and outdoor measurements are conducted in order to validate the

Table 2. Power loss calculation case of low irradiance.

Table 3. Power loss calculation case of high irradiance.

proposed method. The major advantages of this method are computational efficiency, accuracy, simplicity, and the generic formulation. Based on these advantages, this method is suitable for fast loss calculation in shaded PV arrays.

Cite this paper

Osman, Y.I.A., Li, J.P., Zhen, X.F. and Yang, A.R. (2018) Experimental Study of the Cloud Influence on PV Grid Connected System. Smart Grid and Renewable Energy, 9, 1-15. https://doi.org/10.4236/sgre.2018.91001

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