Table of Contents
ISRN Renewable Energy
VolumeΒ 2011, Article IDΒ 890582, 11 pages
Research Article

Time-Domain Modeling of Tower Shadow and Wind Shear in Wind Turbines

Department of Electrical and Computer Engineering, The University of Texas at Austin, Austin, TX 78712, USA

Received 11 July 2011; Accepted 31 July 2011

Academic Editors: W. E.Β Alnaser, M.Β Cheng, S. S.Β Kalligeros, and B.Β Mwinyiwiwa

Copyright Β© 2011 Swagata Das et al. This is an open access article distributed under the Creative Commons Attribution License, which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.


Tower shadow and wind shear contribute to periodic fluctuations in electrical power output of a wind turbine generator. The frequency of the periodic fluctuations is 𝑛 times the blade rotational frequency 𝑝, where 𝑛 is the number of blades. For three-bladed wind turbines, this inherent characteristic is known as the 3𝑝 effect. In a weak-power system, it results in voltage fluctuation or flicker at the point of common coupling of the wind turbine to the grid. The phenomenon is important to model so as to evaluate the flicker magnitude at the design level. Hence, the paper aims to develop a detailed time-domain upwind fixed speed wind turbine model which includes the turbine's aerodynamic, mechanical, electrical, as well as tower shadow and wind shear components. The model allows users to input factors such as terrain, tower height, and tower diameter to calculate the 3𝑝 oscillations. The model can be expanded to suit studies involving variable speed wind turbines. Six case studies demonstrate how the model can be used for studying wind turbine interconnection and voltage flicker analysis. Results indicate that the model performs as expected.

1. Introduction

In addition to the stochastic pulsations caused by wind, electrical power output from wind turbines connected to the power system grid experience short-term fluctuations at 𝑛 times the rotational frequency of the blades (𝑝) or 𝑛𝑝 frequency, where 𝑛 is the number of blades. Wind turbines generally have three blades and hence this is known as the 3𝑝 effect. The 3𝑝 fluctuations are due to two effects known as wind shear and tower shadow [1, 2]. Wind shear refers to the variation of wind with height while tower shadow is used to describe the redirection in wind due to the obstruction presented by the tower [1, 3]. These two effects are an inherent characteristic of any wind turbine and will result in periodic fluctuations in output power.

For wind turbines connected to a weak grid, the 3𝑝 frequency in the range of 0.5–2 Hz results in fluctuations in system rms voltage at the point of common coupling (PCC) and are known as voltage flicker or fluctuations [4, 5]. In a system with significant wind generation wherein wind farms supply majority of the power to the grid, synchronization of the blades in the wind farm contribute to larger power and voltage fluctuations [2]. From a consumer perspective, voltage flicker is a serious power quality issue [6] and hence wind turbine models have become indispensable for wind power interconnection study. Using such a model, the designer of the wind turbine must be capable of calculating at the design stage, the expected flicker magnitude and whether the flicker is below the threshold of objection [6]. The designer must also be able to assess the dependence of voltage flicker on wind speed, grid characteristics, as well as the loads connected at the PCC [4]. Many papers on wind power integration have been reported in the literature [4, 7, 8]. Due to their focus on voltage flicker and other power quality issues, these models often tend to oversimplify the torque considerations due to tower shadow and wind shear. They do not factor in wind turbine specifications such as hub height, tower diameter, and terrain on which the wind turbine is located which affect the magnitude of tower shadow and wind shear. These parameters should be an input to the wind turbine simulation model, offering insight into the wind turbine parameters which can be optimized to reduce 3𝑝 oscillations at the design level. Other papers oversimplify wind turbine operation and rotor performance characteristics [9].

Based on the aforementioned background, the objective of this paper is to develop a detailed time-domain wind turbine model upon which more sophisticated models can be developed. The paper focuses on modeling a fixed-speed wind turbine with an upwind rotor since they are most common due to reduced tower shading [1, 10]. The paper builds upon the most basic model of a fixed-speed wind turbine developed in [11] and includes the turbine's aerodynamic, mechanical, electrical, as well as tower shadow and wind shear components. The complete model can be easily implemented in popular simulation packages such as PSCAD/EMTDC and MATLAB. Since the model has been broken down into blocks/modules and each module is separately quantified, the model is flexible, allowing users to separately study the impact of wind shear and tower shadow on output power. The model can also be used to study the wind turbine integration to the grid, voltage flicker analysis, mitigation techniques of 3𝑝 effects, and expanded to suit studies involving variable speed wind turbines.

The paper is organized as follows: Sections 2 and 3 study the modeling and identifies the factors affecting wind shear and tower shadow. Section 4 discusses the comprehensive modeling of the wind turbine. Section 5 presents six case studies to evaluate the validity of the model along with the dataset used in simulating the wind turbine so that it can be easily reproduced by the users. The results are consistent with those reported in the literature and hence the model performs as expected.

2. Wind Shear

Wind turbine blades experience maximum wind speed when facing directly upwards and minimum when the blades are facing downwards. This variation in wind with height is known as wind shear. For three-bladed wind turbines, each of the three blades will experience minimum wind speed in one complete rotation and hence wind shear contributes to the 3𝑝 frequency [1]. This section studies the wind shear model and identifies the factors which contribute to the wind shear effect.

2.1. Modeling Wind Shear

A simple wind shear model is given by the power law as [1, 3] 𝑉(𝑧)=π‘‰β„Žξ‚€π‘§π»ξ‚π›Ό,(1) where 𝑧, 𝐻, π‘‰β„Ž, and 𝛼 are the elevation above ground, hub height, wind speed at hub height, and empirical wind shear exponent, respectively. Writing (1) as a function of π‘Ÿ (radial distance from rotor axis) and πœƒ (blade azimuthal angle), the wind shear model becomes𝑉(π‘Ÿ,πœƒ)=π‘‰β„Žξ‚€π‘Ÿcosπœƒ+𝐻𝐻𝛼=π‘‰β„Žξ€Ί1+π‘Šπ‘ ξ€»(π‘Ÿ,πœƒ),(2) where π‘Šπ‘ (π‘Ÿ,πœƒ) is the disturbance in wind speed due to wind shear. It can be approximated by a third order truncated Taylor series as,π‘Šπ‘ ξ‚€π‘Ÿ(π‘Ÿ,πœƒ)β‰ˆπ›Όπ»ξ‚cosπœƒ+𝛼(π›Όβˆ’1)2ξ‚€π‘Ÿπ»ξ‚2cos2πœƒ+𝛼(π›Όβˆ’1)(π›Όβˆ’2)6ξ‚€π‘Ÿπ»ξ‚3cos3πœƒ.(3)

2.2. Factors Affecting Wind Shear

From (2) and (3), disturbance in wind due to wind shear is dependent on π‘‰β„Ž, 𝐻, 𝛼, and π‘Ÿ. Figure 1(a) shows the variation of wind shear with π‘‰β„Ž. For π‘‰β„Ž = 13.5 m/s, the maximum wind speed experienced by the blades of a wind turbine is 14.75 m/s while the minimum wind speed is 13.04 m/s. Hence, the variation in wind speed, that is, the difference between maximum and minimum wind speed for one complete blade rotation is 1.71 m/s. Similarly for π‘‰β„Ž = 14 m/s, the variation in wind speed is 1.77 m/s. Thus wind shear increases with the increase in π‘‰β„Ž. Also note that the minimum wind speed occurs at πœƒ=180∘, that is, when the blades are pointing downwards and maximum wind speed at πœƒ=0∘, that is, blades pointing upwards. Figure 1(b) shows the impact of 𝛼 on wind shear. The values of 𝛼 have been chosen depending on terrain, as shown in Table 1 [12]. As 𝛼 increases, wind shear increases. Figure 1(c) shows that wind shear decreases with increase in hub height. For example, at 𝐻 = 120 m, the variation in wind is 0.72 m/s while at 𝐻 = 80 m, the wind variation is 1.77 m/s. Figure 1(d) shows the wind shear experienced by different blade elements. Minimum wind shear is experienced by the blade element closest to the hub (π‘Ÿ = 5 m).

Table 1: Variation of 𝛼 with terrain.
Figure 1: Comparison of wind shear with different (a) π‘‰β„Ž, (b) 𝛼, (c) 𝐻, and (d) π‘Ÿ.

3. Tower Shadow

Tower shadow effect is the alteration in uniform flow of wind due to the presence of the tower. For an upwind turbine, when the blade is directly in front of the tower, it experiences minimum wind. For a three-bladed wind turbine, each of the blades experience minimum wind in one complete rotation and hence tower shadow contributes to the 3𝑝 effect [1, 2]. This section models tower shadow effect for an upwind turbine and identifies the factors affecting tower shadow.

3.1. Modeling the Disturbance in Wind due to Tower Shadow

Figure 2 shows an aerial view of the tower immersed in uniform wind flow. As seen from the figure, when the uniform wind is incident on the tower, it tries to bend around the tower. At the point marked as β€œsource,” the wind streamlines radiate outwards. At the point marked as β€œsink,” the wind streamlines converge. A source and sink at very close spacing (separated only by the tower diameter) form a doublet [13].

Figure 2: Wind flow around the tower obtained by superposing a doublet in uniform wind.

Hence, from potential flow theory, stream function of wind around the tower can be derived by superposing a doublet on uniform flow as [13]πœ“=πœ“uniform+πœ“doublet=π‘‰β„Žπ‘¦ξ‚΅π‘Ž1βˆ’2π‘₯2+𝑦2ξ‚Ά.(4) Differentiating stream function πœ“ with respect to 𝑦 yields the total wind flow velocity 𝑉(𝑦,π‘₯) in the π‘₯-direction as𝑉(𝑦,π‘₯)=πœ•πœ“πœ•π‘¦=π‘‰β„Žξƒ¬π‘Ž1+2𝑦2βˆ’π‘₯2ξ€Έξ€·π‘₯2+𝑦2ξ€Έ2ξƒ­=π‘‰β„Ž+𝑉tower(𝑦,π‘₯).(5) The second term in (5), that is, 𝑉tower(𝑦,π‘₯) represents the disturbance in wind due to the presence of the tower [1, 10]. Here π‘Ž is the tower radius, π‘₯ is the distance of blade origin from the tower midline and 𝑦 is the lateral distance of the blade from the tower midline, as shown in Figure 3. Writing 𝑉tower(𝑦,π‘₯) as a function of π‘Ÿ and πœƒ yields𝑉tower(π‘Ÿ,πœƒ,π‘₯)=π‘‰β„Žπ‘Ž2ξ€·π‘Ÿ2sin2πœƒβˆ’π‘₯2ξ€Έξ€·π‘Ÿ2sin2πœƒ+π‘₯2ξ€Έ2.(6) It should be noted that (6) is valid only when the blades are in the tower shadow zone, that is, 90βˆ˜β‰€πœƒβ‰€270∘, as shown in Figure 3. As justified in [1], the hub height wind speed in (5) is assumed to be equal to the spatial average wind speed.

Figure 3: Dimensions used in tower shadow formula.
3.2. Factors Affecting Tower Shadow

From (6), the disturbance in wind due to tower-shadow effect depends on three factors, π‘Ÿ, πœƒ, and π‘₯. Hence, in the first case, π‘Ÿ is varied from 5 m to 20 m in (6) while πœƒ is varied from 90∘ to 270∘, that is, the tower-shadow zone, as shown in Figure 4(a). It is observed that the blade elements closest to the hub (π‘Ÿ = 5 m) experience a longer duration of the tower shadow. However at πœƒ=180∘, that is, blade directly in front of the tower, the same wind deficit is seen by all the blade elements.

Figure 4: Comparison of tower shadow at different (a) radial distances π‘Ÿ and (b) lateral distances from tower midline π‘₯.

Next, the radial distance of blade element from the hub, that is, π‘Ÿ is kept constant at 20 m and the distance of blade origin from the tower midline, that is, π‘₯ is varied from 2 m to 5 m. As seen from Figure 4(b), the tower shadow effect is most pronounced when the blades are closer to the tower (π‘₯ = 2 m). Hence, mounting the blades away from the tower minimizes tower-shadow effect. Also note that there is an acceleration in wind when the blades are at either side of the tower, as seen in Figure 4. This is true since when the streamlines bend around the tower, they become concentrated on the sides of the tower, as shown in Figure 2, resulting in an acceleration of wind.

4. Time-Domain Modeling of Wind Turbines

From a modeling standpoint, the primary components of a wind turbine consist of turbine rotor (prime mover), shaft and gearbox unit (drive-train and speed changer), induction generator, and a control system [11]. Wind turbines extract the kinetic energy available in winds and convert it to electrical energy and hence require interaction between aerodynamic, mechanical, and electrical components, as illustrated in Figure 5. The modeling of these four building blocks are discussed in this section.

Figure 5: Block diagram of a wind turbine.
4.1. Aerodynamic Block

The aerodynamic block consists of six modules.(i)Tip-speed ratio calculation πœ†0.(ii)Pitch-angle determination 𝛽.(iii)Rotor power coefficient 𝐢𝑝(πœ†0).(iv)Aerodynamic torque module. (v)Torque due to wind shear. (vi)Torque due to Tower Shadow.

The modeling of the first three modules have been discussed in details in [11]. This subsection discusses the modeling of the aerodynamic torque module and the two additional blocks on torque due to wind shear and tower shadow. Note that the input to the aerodynamic block is the hub height wind speed (π‘‰β„Ž) which can be set to any value during simulation run-time or can also be in the form of time-series data of an actual wind speed measurement [11].

4.1.1. Torque Computation

The wind turbine experiences a relatively constant hub height wind speed π‘‰β„Ž. However, due to tower shadow and wind shear, the blades of a wind turbine experience a varying wind speed as it rotates through a complete cycle, as seen in Sections 2 and 3. Hence the approach to formulating a pragmatic torque equation incorporating the 3𝑝 effect is to first derive the total spatially varying wind field, which includes the contribution from tower shadow and wind shear, and then compute the resultant aerodynamic torque [1]. The approach is briefly summarized below.

The total wind experienced by the wind turbine blades due to tower shadow and wind shear is𝑣(𝑑,π‘Ÿ,πœƒ)β‰ˆπ‘‰β„Žξ‚Έ1+π‘Šπ‘ π‘‰(π‘Ÿ,πœƒ)+tower(π‘Ÿ,πœƒ,π‘₯)π‘‰β„Žξ‚Ή,(7) where π‘Šπ‘ (π‘Ÿ,πœƒ) and 𝑉tower(π‘Ÿ,πœƒ,π‘₯) are given by (3) and (6). Next, the total aerodynamic torque produced by a three-bladed wind turbine when immersed in a wind field of 𝑣(𝑑,π‘Ÿ,πœƒ) is,𝑇aero1(𝑑,πœƒ)=2πœŒπ΄π‘‰3β„ŽπΆπ‘ξ€·πœ†0ξ€Έπœ”rotor+3𝑏=1ξ€œπ‘…π‘Ÿ02πœŒπ΄π‘‰β„ŽπΆπ‘ξ€·πœ†0ξ€Έ3π‘ π‘…πœ†0π‘Ÿξ€Ίπ‘£(𝑑,π‘Ÿ,πœƒ)βˆ’π‘‰β„Žξ€»π‘‘π‘Ÿ,(8) where 𝑇aero(𝑑,πœƒ) is the aerodynamic torque, π‘Ÿ0 the radius at which the blade profile begins, 𝑅 the radius of the rotor disk, 𝐴 is the cross-sectional area of rotor, 𝜌 is the air density, πœ”rotor is the rotor angular velocity, and 𝑠 is defined to be equal to 1βˆ’(π‘Ÿ0/𝑅)2. This equation has been obtained by linearizing the classical torque equation about the hub height wind speed [1, 10]. To remove the radial dependence in 𝑣(𝑑,π‘Ÿ,πœƒ), [10] defines an equivalent wind speed 𝑣eq(𝑑,πœƒ), which would give rise to the same aerodynamic torque 𝑇aero(𝑑,πœƒ), such that,𝑇aero1(𝑑,πœƒ)=2πœŒπ΄π‘‰3β„ŽπΆπ‘ξ€·πœ†0ξ€Έπœ”rotor+3𝑏=1ξ€œπ‘…π‘Ÿ02πœŒπ΄π‘‰β„ŽπΆπ‘ξ€·πœ†0ξ€Έ3π‘ π‘…πœ†0π‘Ÿξ€Ίπ‘£eq(𝑑,πœƒ)βˆ’π‘‰β„Žξ€»π‘‘π‘Ÿ.(9) Equating (8) and (9) and simplifying, the expression for equivalent wind speed is obtained as 𝑣eq=(𝑑,πœƒ)2π‘‰β„Ž3𝑠𝑅23𝑏=1ξ€œπ‘…π‘Ÿ0ξƒ¬π‘Ÿ+π‘Ÿ2𝛼𝐻cosπœƒπ‘+π‘Ÿ3𝛼(π›Όβˆ’1)2𝐻2cos2πœƒπ‘+π‘Ÿ4𝛼(π›Όβˆ’1)(π›Όβˆ’2)6𝐻3cos3πœƒπ‘+π‘Ž2ξ€·π‘Ÿ3sin2πœƒπ‘βˆ’π‘Ÿπ‘₯2ξ€Έξ€·π‘Ÿ2sin2πœƒπ‘+π‘₯2ξ€Έ2ξƒ­π‘‘π‘Ÿ=𝑣eq0+𝑣eqws+𝑣eqts.(10) Equation (10) has been split into three components: 𝑣eq0 due to the hub height wind speed, 𝑣eqws due to wind shear, and 𝑣eqts due to the tower shadow, where𝑣eq0=2π‘‰β„Ž3𝑠𝑅23𝑏=1ξ€œπ‘…π‘Ÿ0π‘Ÿπ‘‘π‘Ÿ=π‘‰β„Žπ‘£,(11)eqws=2π‘‰β„Ž3𝑠𝑅23𝑏=1ξ€œπ‘…π‘Ÿ0ξ‚Έπ‘Ÿ2𝛼𝐻cosπœƒπ‘+π‘Ÿ3𝛼(π›Όβˆ’1)2𝐻2cos2πœƒπ‘+π‘Ÿ4𝛼(π›Όβˆ’1)(π›Όβˆ’2)6𝐻3cos3πœƒπ‘ξ‚Ήπ‘‘π‘Ÿ=π‘‰β„Žξ‚Έπ›Ό(π›Όβˆ’1)8𝑅𝐻2+𝛼(π›Όβˆ’1)(π›Όβˆ’2)𝑅60𝐻3cos3πœƒπ‘ξ‚Ή,𝑣(12)eqts=2π‘‰β„Ž3𝑠𝑅23𝑏=1ξ€œπ‘…π‘Ÿ0ξƒ¬π‘Ž2ξ€·π‘Ÿ3sin2πœƒπ‘βˆ’π‘Ÿπ‘₯2ξ€Έξ€·π‘Ÿ2sin2πœƒπ‘+π‘₯2ξ€Έ2ξƒ­=π‘‰π‘‘π‘Ÿβ„Ž3𝑅23𝑏=1ξƒ¬π‘Ž2sin2πœƒπ‘ξƒ©π‘…ln2sin2πœƒπ‘π‘₯2ξƒͺβˆ’+12π‘Ž2𝑅2𝑅2sin2πœƒπ‘+π‘₯2ξƒ­.(13) Note that (12) and (13) have been simplified by assuming π‘Ÿ0=0. The resultant aerodynamic torque due to 𝑣eq(𝑑,πœƒ) can be then obtained by substituting 𝑣eq(𝑑,πœƒ) in (9) and simplifying𝑇aero1(𝑑,πœƒ)=2πœŒπ΄π‘‰3β„ŽπΆπ‘ξ€·πœ†0ξ€Έπœ”rotor+πœŒπ΄π‘‰β„ŽπΆπ‘ξ€·πœ†0ξ€Έπ‘…πœ†0𝑣eqws+𝑣eqtsξ‚„.(14) Equation (14) is the complete torque equation representing aerodynamic torque due to kinetic energy in wind as well as torque due to tower shadow and wind shear and has been implemented for modeling. The aerodynamic torque module, shown in Figure 5 implements the classical torque equation, that is, first term in (14) as𝑇classicalaero=12πœŒπ΄π‘‰3β„ŽπΆπ‘ξ€·πœ†0ξ€Έπœ”rotor.(15) The wind shear module implements the disturbance in torque due to wind shear, that is, the second term in (14) as𝑇windshearaero=πœŒπ΄π‘‰β„ŽπΆπ‘ξ€·πœ†0ξ€Έπ‘…πœ†0𝑣eqws.(16) The tower shadow module implements the disturbance in torque due to tower shadow, that is, the third term in (14) as𝑇towershadowaero=πœŒπ΄π‘‰β„ŽπΆπ‘ξ€·πœ†0ξ€Έπ‘…πœ†0𝑣eqts.(17) Modeling (14) into three separate modules gives the wind turbine model greater flexibility allowing tower shadow and wind shear to be studied separately, as will be demonstrated in Section 5. Also note that the tower shadow and wind shear modules input the wind turbine specifications (𝐻,π‘₯,π‘Ž,𝛼) for calculating the torque oscillations due to 3𝑝 effect, as shown in Figure 5. Few important points when modeling the above three modules are (i)𝐢𝑝(πœ†0) and πœ†0 should be computed at the hub height wind speed π‘‰β„Ž; (ii)computation of 𝑣eqws and 𝑣eqts in (16) and (17) require instantaneous values of the three blade angles. The azimuthal angle of the first blade (πœƒπ‘1) can be obtained by integrating rotor angular velocity. Integrator has to be reset once the first blade angle reaches 360∘. The other two blade angles can be obtained by adding 120∘ and 240∘ to πœƒπ‘1, respectively;. (iii)𝑣eqts should be computed only when the individual blade is in the tower-shadow zone, as discussed in Section 3. For example, the first blade (reference blade) will be in the tower-shadow zone only when πœƒπ‘1 is between 90∘ and 270∘. A logical operator should be used so that when the first blade is outside the tower-shadow zone, contribution to 𝑣eqts from the first blade should be zero.

The total aerodynamic torque can be then obtained by summing up 𝑇classicalaero, 𝑇windshearaero, and 𝑇towershadowaero, scaled by the gear ratio and used as an input to the drive-train model, as shown in Figure 5.

4.2. Mechanical Block

The mechanical block consisting of the wind turbine shaft, generator shaft, and gearbox has been modeled using a two-mass inertia representation, since the two-mass model is simpler to model and shows the dynamic response of the wind turbine generator. State-space equations governing the two-mass model have been detailed in [11].

4.3. Electrical Block

The main component of the electrical block is an induction generator. A fixed speed wind turbine requires squirrel-cage induction machine while variable speed wind turbines need a wound rotor induction machine [11].

4.4. Control Block

This block can be developed for adjusting the pitch angle in variable speed wind turbines or controlling reactive compensation devices to meet wind turbine reactive power demand. For a fixed-speed wind turbine, no control is required [11].

5. Case Studies: Performance Evaluation of Wind Turbine Model

The aforementioned wind turbine components are integrated to form a 1.5 MW fixed speed wind turbine model. The numerical data set used for simulation of wind turbine model is listed in Table 2. The wind turbine is then connected to a weak grid via a 2-MVA 0.6/20 kV delta-wye-grounded transformer with a leakage inductance of 5% and a 6 mile medium voltage cable [14]. The grid has been intentionally chosen to be weak so as to study the impact of tower shadow and wind shear on power quality. The grid short-circuit capacity (SCC) was selected to be 25 MVA, since the grid is considered electrically weak when [15]SCC𝑃𝑛<20,(18) where 𝑃𝑛 is the rated power of the wind turbine, that is, 1.5 MW in this case. 𝑋/𝑅 ratio of the grid is assumed to be 6. At the point of common coupling (PCC), a 1-MVA, 0.98 power factor load is connected. Figure 6 shows the complete system arrangement. Case studies presented in this section aim at evaluating the wind turbine model performance and demonstrate the analyses that can be done using this model. The simulation package used is PSCAD/EMTDC.

Table 2: Specifications of wind turbine model.
Figure 6: Fixed-speed wind turbine connected to the grid.
5.1. Performance of the Wind Turbine without 3𝑝 Effect

The performance of the wind turbine without 3𝑝 effect (tower shadow and wind shear modules disconnected) is studied to determine the rotor angular velocity at the rated wind speed. The rated wind speed can be obtained from the power curve shown in Figure 7. The wind turbine model is subjected to hub height wind speed (π‘‰β„Ž) ranging from 0 to 20 m/s. Since this is a fixed speed wind turbine, pitch angle remains constant at βˆ’6.15∘. The rated wind speed is 15 m/s and rated power is 1.5 MW. The rotor angular velocity πœ”rotor is 1.8 rad/s or 0.286 Hz.

Figure 7: Power curve of a 1.5 MW fixed speed wind turbine.
5.2. Performance of the Wind Turbine with 3𝑝 Effect
5.2.1. Initialization of the Wind Turbine Model

The wind turbine can be started at any wind speed above the cut-in speed. Initially, a switch SW disconnects the tower shadow and wind shear modules till steady-state is reached. Then SW is switched β€œON.” This initialization is necessary since 𝑇windshearaero and 𝑇towershadowaero require the values of 𝐢𝑝(πœ†0) and πœ†0 at the hub height wind speed π‘‰β„Ž. Sample/hold circuits are used in conjunction with switch SW such that when SW is switched β€œON,” the S/H circuits hold the values of 𝐢𝑝(πœ†0) and πœ†0, as illustrated in Figure 8. Depending on the simulation time step, the initialization step requires a few seconds, that is, 10 seconds in PSCAD/EMTDC.

Figure 8: Sample/Hold circuit to hold 𝐢𝑝(πœ†0) and πœ†0 at wind speed π‘‰β„Ž.
5.2.2. Output Power from Wind Turbine

The wind turbine is subjected to rated π‘‰β„Ž. After initialization, the wind shear and tower shadow modules are activated by toggling the switch (SW = 1). The output power from the wind turbine starts to oscillate as soon as the tower shadow and wind shear modules are activated, as shown in Figure 9. An FFT block with fundamental frequency equal to rotational frequency of the blades (πœ”rotor = 0.286 Hz) is used to determine the frequency components present in the output power. As shown in Figure 10, FFT indicates the presence of a significant third harmonic, that is, 0.86 Hz (which is three times πœ”rotor), whose magnitude is 0.0516 MW.

Figure 9: Output power with tower shadow and wind shear switched on.
Figure 10: FFT indicating 3𝑝 frequency.
5.3. Increase in Output Power due to 3𝑝 Effect

The output power swings beyond the rated power (1.5 MW) when tower shadow and wind shear modules are switched β€œON,” as shown in Figure 9. This is counterintuitive since output power should decrease as the 3𝑝 effect leads to a net decrease in the wind speed. Figure 11 shows the equivalent wind speed and aerodynamic torque scaled down to bring them on the same scale as the output power. As seen from the figure, a decrease in equivalent wind due to 3𝑝 effect results in a corresponding decrease in torque. The output power, however, seems to peak at that time instant.

Figure 11: Equivalent wind, torque, and output power.

The reason for the output power swinging beyond the rated power was determined to be the transient response of the generator. The oscillations in torque continually disturb the system, that is, the generator is not allowed to reach steady state, which is why the output power is swinging above the rated power. To prove the above theory, the inertia of the turbine 𝐽rot was increased from 1000 kgmm to 2000 kgmm, since inertia plays a significant role in controlling the transient response. Now, the 3𝑝 oscillations in the output power does not swing beyond the rated power, as shown in Figure 11.

5.4. Impact of Wind Shear and Tower Shadow Individually on Output Power

This section demonstrates how the model can be used to study the impact of tower shadow and wind shear individually on the magnitude of output power oscillations. The wind turbine model is initialized by subjecting it to rated π‘‰β„Ž and then switch SW is used to activate the tower shadow module only. The output power oscillates between 1.528 MW and 1.429 MW, as shown in Figure 12. When switch SW activates the wind shear module only, the output power oscillates between 1.469 MW and 1.461 MW. The magnitude of the oscillations are very small, indicating that tower shadow effect has a more dominant impact on output power that wind shear. This is consistent with the analysis reported in [1].

Figure 12: Magnitude of 3𝑝 oscillations due to tower shadow and wind shear individually.
5.5. Voltage at the PCC

Rms voltage was measured at PCC as shown in Figure 13. The voltage remains constant at 11.28 kV during the initialization of the model. Once the tower shadow and wind shear modules are switched β€œON,” the rms voltage shows the presence of the 3𝑝 oscillations. These fluctuations in system rms voltage may cause consumer annoyance and complaint and are known as voltage flicker. The usual method of expressing flicker is similar to that of voltage modulation, that is, change in voltage with respect to the average voltage over a certain time period as [6]𝑉%VoltageModulation=maxβˆ’π‘‰min𝑉0.(19) Here 𝑉max and 𝑉min are the maximum and minimum values of modulated signal while 𝑉0 is the average value of normal operating voltage. Using (19), the voltage flicker (expressed in percentage of voltage modulation) was calculated to be 0.186%. This is below the threshold of objection. However, in a wind farm, if many wind turbine blades synchronize, the magnitude of voltage flicker would be severe [2].

Figure 13: Phase an RMS voltage.
5.6. Factors Affecting Voltage Flicker

Voltage flicker due to tower shadow and wind shear depends on [4, 5] (i)hub height wind speed π‘‰β„Ž;(ii)grid short-circuit capacity; (iii)grid impedance angle or 𝑋/𝑅 ratio.

To investigate how these parameters influence voltage flicker, they are varied one at a time. The parameters used in Figure 6 will be used as the base case, that is, π‘‰β„Ž, SCC, and 𝑋/𝑅 ratio of grid are 15 m/s, 25 MVA, and 6, respectively. Turbulence intensity and loads connected at the PCC also affect voltage flicker, however, they are not studied in this section.

5.6.1. Impact of π‘‰β„Ž on Voltage Flicker

The wind turbine was subjected to wind speeds ranging from cut-in to cut-out speed and the voltage flicker at each wind speed was calculated using (19). As seen from Figure 14, voltage flicker increases almost linearly with wind speed till the rated wind speed is reached. For π‘‰β„Ž greater than the rated speed, voltage flicker starts decreasing due to the stall regulation of the rotor which significantly reduces the turbulence-induced fluctuations. Hence, voltage flicker is maximum at the rated wind speed or, in other words, voltage flicker is maximum when wind power output is maximum.

Figure 14: Voltage flicker variation with π‘‰β„Ž.
5.6.2. Impact of Grid Short-Circuit Capacity (𝑆𝐢𝐢) on Voltage Flicker

The SCC or strength of the grid is varied at each simulation. Figure 15 illustrates the approximately inversely proportionally relationship with short-circuit capacity (SCC) of grid. Higher the SCC, stronger the grid is, and hence voltage flicker is minimum.

Figure 15: Variation of voltage flicker with SCC. 𝑋/𝑅 ratio of grid is 6.
5.6.3. Impact of Network Impedance Angle (X/R Ratio) on Voltage Flicker

In this subsection, 𝑋/𝑅 ratio of the grid is varied from 1 to 7 while the grid SCC is kept constant at 25 MVA. As shown in Figure 16, minimum voltage flicker is obtained for an 𝑋/𝑅 ratio of 2.

Figure 16: Variation of voltage flicker with 𝑋/𝑅 ratio. Grid SCC is 25 MVA.

The V-shaped curve can be explained by considering voltage change (Ξ”π‘ˆ) across the grid impedance (𝑅 and 𝑋) as [5]ξ€·Ξ”π‘ˆ=𝑃𝑅cosπœƒβˆ’πœƒpfξ€Έπ‘ˆπ‘”cosπœƒpfcosπœƒ.(20) Here 𝑃 is the real power produced by the wind turbine, πœƒ is the network impedance angle, πœƒpf is the power factor at which the wind turbine is operating while π‘ˆπ‘” represent the voltage at the PCC. From (20), the determining factor for minimizing the voltage drop is cos(πœƒβˆ’πœƒpf). When (πœƒβˆ’πœƒpf) approaches 90∘, voltage flicker is minimum, as shown in Figure 17. Since πœƒpf is approximately 26∘ in the simulation case, minimum voltage flicker occurs for πœƒ=64∘ or 𝑋/𝑅=2.

Figure 17: Variation of voltage flicker with πœƒβˆ’πœƒpf.

6. Conclusion

This paper presents a detailed model of a fixed speed wind turbine with an upwind rotor. The modeling includes a detailed representation of tower shadow and wind shear modules which are often approximated or neglected in existing models. The model will allow the user to input wind turbine specifications and observe how those parameters will directly affect the magnitude of 3𝑝 oscillations. Another advantage is that the model is flexible, allowing the user to study tower shadow and wind shear individually. Case studies have been carried out to use this model for studying the integration of wind turbine to the grid and analyzing voltage flicker at the PCC. The results are consistent with those reported in the literature and hence the model performs as expected. In addition, the model can also be used to study the mitigation of 3𝑝 effect and expanded to include power and pitch controllers to suit other studies involving variable speed wind turbines.


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