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Z. W. Deng and C. Xu, “Frequency regulation of power systems with a wind farm by sliding-mode-based design,” IEEE/CAA J. Autom. Sinica, vol. 9, no. 11, pp. 1980–1989, Nov. 2022. doi: 10.1109/JAS.2022.105407
Citation: Z. W. Deng and C. Xu, “Frequency regulation of power systems with a wind farm by sliding-mode-based design,” IEEE/CAA J. Autom. Sinica, vol. 9, no. 11, pp. 1980–1989, Nov. 2022. doi: 10.1109/JAS.2022.105407

Frequency Regulation of Power Systems With a Wind Farm by Sliding-Mode-Based Design

doi: 10.1109/JAS.2022.105407
Funds:  This work was supported by Ministry of Science and Technology of Peoples Republic of China (2019YFE0104800) and the Joint Funds of the National Natural Science Foundation of China (U1865101)
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  • Load frequency regulation is an essential auxiliary service used in dealing with the challenge of frequency stability in power systems that utilize an increasing proportion of wind power. We investigate a load frequency control method for multi-area interconnected power systems integrated with wind farms, aimed to eliminate the frequency deviation in each area and the tie-line power deviation between different areas. The method explores the derivative and integral terminal sliding mode control technology to solve the problem of load frequency regulation. Such technology employs the concept of relative degrees. However, the subsystems of wind-integrated interconnected power systems have different relative degrees, complicating the control design. This study develops the derivative and integral terminal sliding-mode-based controllers for these subsystems, realizing the load frequency regulation. Meanwhile, closed-loop stability is guaranteed with the theory of Lyapunov stability. Moreover, both a thermal power system and a wind power system are applied to provide frequency support in this study. Considering both constant and variable external disturbances, several numerical simulations were carried out in a two-area thermal power system with a wind farm. The results demonstrate the validity and feasibility of the developed method.

     

  • WITH the increasing depletion of conventional fossil fuels, renewable energy technologies, that provide both sustainability and environmental friendliness, have drawn great attention and have been rapidly developed for several decades. Among them, wind power is one of the most promising technologies. Increasingly more electricity from wind farms has been generated in the last decade, making more of a contribution in the overall power system.

    The rising proportion of wind power affects the frequency stability and the operation of power systems to some extent due to some unique features of wind power technology [1]-[3]. Firstly, the randomness and fluctuation of wind energy increases the frequency variations of wind-integrated power systems [4]. Secondly, variable speed wind turbines (VSWTs) have been widely utilized in power systems. VSWTs could reduce the inertia of power systems and result in more severe frequency fluctuations once load variations rise up [5], [6]. Thirdly, the replacement of conventional power generators (e.g., thermal and hydroelectric generators) by wind generators reduces the frequency regulation capability of power systems because of an increase of the regulation constant [3]. However, the VSWTs respond faster in power regulation than conventional power generators [7], [8]. Thus the control methods of VSWTs via inertial emulation control, droop control, deloading control and over-production control have been investigated extensively for the purpose of frequency support in wind-integrated power systems [9]-[11].

    Load frequency control (LFC) is an essential auxiliary service to ensure the safety and stability of power systems. For a multi-area interconnected power system [12], the objective of LFC is to balance the load and power generation in all control areas, eliminating the frequency deviations and the tie-line power deviations between different areas [13]. Many methods concerning the LFC problem have been reported such as the integral-based distributed control method [14], the direct-indirect adaptive fuzzy control technique [15], the decentralized resilient H method [16], and so forth. Recently, the increasing impact of wind power on power systems has drawn great attention. A coordinated approach was designed through the zero dynamics technique for large-scale power systems in [17], which aimed to improve the transient stability of large-scale power systems including wind power systems. The model identification adaptive PID controller in [18] was designed for the LFC of wind-integrated power systems. The cascaded PID controller was designed in [19] for a power system with diverse power sources including wind turbines. However, improving the robustness of the controllers is required due to the uncertainty of wind energy.

    Considering wind-integrated power systems, both uncertainties from wind speed and disturbances from load highlight the LFC problem of such power systems substantially. One possible solution to this problem is the control design. The sliding mode control (SMC) methodology is a powerful tool, known for its invariance to system uncertainties and disturbances [20]-[22], which is a potential solution for the LFC problem. Some SMC-based methods have been applied in practice such as the adaptive SMC method [23], the full-order SMC method [24], the nonlinear SMC method [25], and the linear SMC method [26]. At the same time, the impact of renewable energy, especially wind power, has also gotten a lot of attention. In order to regulate the frequency and voltage of an isolated wind-diesel hybrid power system, an adaptive SMC method was developed in [27]. A neural-network-based integral sliding mode controller (NNB I-SMC) was employed in a multi-area interconnected power system integrated with wind farms in [28]. A nonlinear SMC method for the LFC problem of a wind-integrated power system was proposed in [29]. Considering the disturbance induced by integrated renewable energies, a robust H sliding mode LFC method for multi-area power systems with time delay was investigated in [30].

    Compared with other types of LFC methods, the SMC-based LFC methods exhibit stronger robustness. Furthermore, the terminal SMC technology has been utilized for frequency regulation, aiming to guarantee a system with finite-time convergence [2], [31]. Up to now, however, far too little attention has been paid to deal with the singularity problem existing in the LFC based on the terminal SMC technology. In [32], a unified dynamic terminal SMC technology known as the derivative and integral terminal SMC technology was proposed for a class of systems with different relative degrees. Such technology guarantees the system with finite-time convergence and avoids the singularity problem during the control design process. Moreover, it exhibits superior control properties and robustness performance in terms of system uncertainties and external disturbances. Consequently, this study proposes an LFC method for wind-integrated power systems based on the derivative and integral terminal SMC technology.

    Additionally, we apply both the thermal generators and wind generators in a wind-integrated power system to provide frequency support. To this end, a wind power system model based on the mechanical dynamics of VSWTs is utilized, which allows the wind power system to flexibly participate in the frequency regulation of the wind-integrated power system.

    The remaining part of this paper proceeds as below. In Section II, the models of a thermal power system, a VSWT system and a wind-integrated two-area thermal power system are established and briefly described. In Section III, the controllers are designed for the wind-integrated two-area thermal power system. In Section IV, the control performance of the proposed frequency control method is analyzed by numerical simulations. In Section V, some conclusions are presented eventually.

    This section first illustrates the system modeling of a single power system and a VSWT system, then, the compositions of a wind-integrated two-area thermal power system.

    A power system usually consists of multiple control areas interconnected by tie lines. Fig. 1 shows the linearized model of the nth control area of the power system with N areas. It mainly contains a governor, a turbine and the rotating mass and load, which are defined as below [28]:

    Figure  1.  Model of the nth control area
    Ggn(s)=1Tgn×s+1 (1)
    Gtn(s)=1Ttn×s+1 (2)
    Gpn(s)=KpnTpn×s+1 (3)

    where Tgn, Ttn, and Tpn are the governor time constant, turbine time constant, and electric system time constant, respectively. s is the Laplace variable.

    The equations describing the nth area of a multi-area power system are described as follows [29]:

    Δ˙fn(t)=1TpnΔfn(t)+KpnTpnΔPmn(t)KpnTpnΔPtien(t)KpnTpnΔPdn(t) (4)
    Δ˙Pmn(t)=1TtnΔPmn(t)+1TtnΔPvn(t) (5)
    Δ˙En(t)=KEnBnΔfn(t)+KEnΔPtien(t) (6)
    Δ˙Ptien(t)=2πNk=1(kn)Tnk(Δfn(t)Δfk(t)) (7)
    Δ˙Pvn(t)=1RnTgnΔfn(t)1TgnΔPvn(t)+1TgnΔEn(t)+gn(u) (8)

    where Δfn(t), ΔPmn(t), ΔEn(t), ΔPtien(t), and ΔPvn(t) are the system states representing the deviations of frequency (Hz), generator output (p.u.MW), integral control (p.u.MW), tie-line power flow (p.u.MW), and governor valve position (p.u.MW), respectively. ΔPdn(t) is the load disturbance (p.u.MW). Kpn, Rn, KEn, and Bn are the power system gain (Hz/p.u.MW), the speed regulation coefficient (Hz/p.u.MW), the integral control gain (Hz/p.u.MW), and the frequency bias factor (Hz/p.u.MW), respectively. Tnk is the interconnection tie-line gain (p.u.MW/rad/s) between the nth and kth area. u is the system input vector. gn(u) is a function of the system inputs.

    Wind energy is converted into mechanical torque by the aerodynamic components of the wind power system. Then, the torque is transmitted to the generator by the drive train. The generator converts the torque into electricity and finally outputs it to the power system. Under the ideal condition of neglecting mechanical and electromagnetic losses, the mechanical power of the wind turbine is regarded as the power output to the power system when the wind power system is operating stably. Based on the ideal condition, a simplified VSWT model is applied here as a wind power system. As shown in Fig. 2, it mainly consists of an aerodynamic model and a drive train model. The aerodynamic model is based on the Cp (λ, β) curve of the wind turbine as below:

    Figure  2.  Wind power system
    {Cp=c0(c11λi+c2β+c3)ec41λi+c5λ1λi=1λ+b0β+b1β3+1 (9)

    where Cp is the power coefficient; β is the pitch angle; c0, c1, c2, c3, c4, c5, b0, and b1 are the constants given in the Appendix; λ is the tip-speed-ratio defined as below:

    λ=ωtRvw (10)

    where ωt is the rotating speed of the wind turbine rotor (rad/s); R is the rotor radius (m); vw is the incoming wind speed (m/s). The mechanical power Pm and mechanical torque Tm extracted by the rotor are calculated as follows:

    Pm=0.5ρCPπR2v3w (11)
    Tm=Pmωt (12)

    where ρ is the air density (kg/m3). A two-mass system describing the drive train system is as below [29]:

    {˙ωt=12Ht(TmDtωtDtg(ωtωr)Ttg)˙Ttg=Ktg(ωtωr)˙ωr=12Hg(Ttg+Dtg(ωtωr)DgωrTrefg) (13)

    where Ht and Dt are the inertia constant and mechanical damping coefficient of the wind turbine, respectively, while Hg and Dg are those of the wind generator; ωr is the generator rotating speed; Ttg and Ktg are the speed torque and shaft stiffness of the drive train, respectively; Dtg is the damping coefficient of the flexible coupling; Trefg is the braking electromotive torque of the generator. The transmission ratio of the gearbox is regarded as a unit.

    The proposed control method is implemented in a wind-integrated two-area thermal power system. Based on the models of the single area power system and the wind power system, the wind-integrated two-area thermal power system is finally established. As shown in Fig. 3, the wind power system is integrated into Area-1. The droop control method and pitch angle control method of VSWTs in [29] are applied to provide frequency support in this study. The pitch angle control system is given as below:

    Figure  3.  Wind-integrated two-area thermal power system
    β=Kβ1+Tβs(ωoptr2πΔf1ωr) (14)

    where Tβ is a time constant; Kβ is a proportionality constant; Δf1 is the frequency deviation of Area-1; ωoptr is the optimized rotating speed of the wind generator (rad/s).

    Additionally, uw and Pg are respectively the control input and power output of the wind power system; ωdr and Pdg are the target values of ωr and Pg, respectively, and the results after taking frequency regulation into account. Poptg is the optimized wind power output.

    The maximum power point tracking (MPPT) method is the most commonly used control method for VSWTs to maximize wind energy capture. According to the MPPT method, Poptgand ωoptr are obtained by the following process under different pitch angles:

    1) The range of β is set as [0°, 30°]. Taking (9) as the objective function and the range of λ as the constraint, the corresponding maximum power coefficient Cpmax and optimal tip-speed-ratio λopt under different values of β are obtained by solving the following performance objective function:

    max.Cp(λ,β0)s.t.2λ13

    where β0 is a concrete value between 0° and 30°. The constraint condition about λ is determined by the operation of the wind turbine. By this approach, the performance curves of Cpmax and λopt with respect to β are obtained (illustrated in Fig. 4).

    Figure  4.  Performance curves for MPPT (a) β-Cpmax curve; (b) β-λopt curve.

    2) During the controlling process, the corresponding values of λopt and Cpmax are obtained from the performance curves according to the real-time β value. Then ωropt and Pgopt are calculated by (10) and (11), respectively.

    According to (13), the wind power system is represented in the state matrix form as follows:

    {˙xw(t)=Awxw(t)+Bwuw(t)+DwTm(t)yw(t)=Cwxw(t) (15)

    where uw = Tgref is the control input of the wind power system; AwR3×3, BwR3×1, CwR1×3, DwR3×1 are constants; xwR3×1 is the state vector; yw = ωr is the system output. The related parameters and the expressions of Aw, Bw, Cw, Dw, xw are illustrated in the Appendix.

    According to (1)–(8), the two-area thermal power system is also described in the state matrix form as below:

    {˙x(t)=Ax(t)+Bu(t)+Dd(t)y(t)=Cx(t) (16)

    where the output vector of the two-area power system is y = [Δf1, Δf2, ΔPtie1]T; the control input vector of it is u = [u1, u2, u3]T; xR9×1 is the state vector; d(t)R2×1 is the external disturbance vector; AR9×9, BR9×3, CR3×9, DR9×2 are the system matrices. The expressions of A, B, C, D, x, d and the relative parameters are also illustrated in the Appendix.

    This section describes the process of designing controllers for the wind-integrated two-area thermal power system based on the derivative and integral terminal SMC technology. The controllers of the two-area thermal power system and the wind power system are designed independently.

    According to the definition of the derivative and integral terminal SMC technology, the fractional integral terminal sliding mode control (fractional I-TSMC) method and the approximate derivative-integral terminal sliding mode control (approximate DI-TSMC) method are generated for systems with different relative degrees. The fractional I-TSMC method is designed for the output tracking of relative-degree-one systems. While for high relative degree systems (systems with at least one relative degree greater than 1), the fractional I-TSMC method is extended and simplified to the approximate DI-TSMC method for good convergence and easy implementation [32]. Therefore, the control design in each subsystem should be on the basis of its relative degrees.

    The two-area thermal power system of (16) is changed into the following form for convenience:

    {˙x(t)=f(x(t),d(t))+B(x(t))u(t)y(t)=h(x(t)) (17)

    where f(x(t), d(t)) = Ax(t)+Dd(t) is a dynamic function of the disturbances and states; the output vector is h(x(t)) = x(t).

    The relative degree vector of the two-area thermal power system is r = [r1, r2, r3] = [3, 3, 4]. Thus the approximate DI-TSMC method is applied to the control design of the two-area thermal power system. ri (i = 1, 2, 3) is the relative degree of the ith system output yi and is defined as the smallest number such that 3j=1LbjLri1fhi(x,d)uj0 is satisfied in (18).

    y(ri)i=Lrifhi(x,d)+3j=1LbjLri1fhi(x,d)uj (18)

    where yi(ri) is the rith derivative of yi. hi is the ith row of h(x(t)); Lf, Lbj are Lie derivatives; j = 1, 2, 3.

    The target values of Δf1, Δf2, and ΔPtie1 are as follows:

    Δfd1=0,Δfd2=0,ΔPdtie1=0. (19)

    Meanwhile, ΔE1d and ΔE2d are both 0. Combining (4)–(8) and (19), the target values of the other states can be obtained.

    According to (18), the input-output dynamics of the two-area thermal power system are expressed as

    [y(r1)1y(r2)2y(r3)3]=[Lr1fh1(x,d)Lr2fh2(x,d)Lr3fh3(x,d)]+[3j=1LbjLr11fh1(x,d)uj3j=1LbjLr21fh2(x,d)uj3j=1LbjLr31fh3(x,d)uj]=Z(x,d)+Gu (20)

    where GR3×3 consists of LbjLri1fhi(x,d) as defined in (20), and is independent of the system states and disturbances; Z(x, d)R3×1 is also directly defined in (20).

    Assumption 1: Z(x, d) is composed of the nominal part ˆZ(x) and the uncertain part ΔZ(d)

    Z(x,d)=ˆZ(x)+ΔZ(d) (21)

    where ˆZ,ΔZR3×1. ΔZ(d) is generated by system disturbances. There exists a known positive function θi(d) (i = 1, 2, 3) as the upper bound of ΔZi(d)

    ||ΔZi(d)||θi(d) (22)

    where ΔZi(d) is the ith component of ΔZ(d). ||·|| is the infinity norm.

    Assumption 2: ˆZ(x) is locally Lipschitz for a proper discussion control region xΩ. The following inequality is held [32]:

    sT(ˆZ(x)ˆZ(xd))ςκ=0ρg×||e_||2κ×||s||2 (23)

    where s = [s1, s2, s3]T is the terminal sliding function vector of the two-area thermal power system; ς and ρg are constants satisfying ς > 0 and ρg > 0; κ = 0, 1,, ς; e = xxd is the tracking error vector of the system states, eR9×1; xdR9×1 is the target value of the state vector x. ||·|| in this paper represents any norm of the same type. Without loss of generality, the 2-norm is applied in this study for the simulation analysis.

    According to the approximate DI-TSMC method, the recursive structure of si is as below:

    {si=eD(ri1)i,eD0i=ei=yiydieDli=˙eD(l1)i+βlieD(l1)i+αlieIli˙eIli=tanh(eD(l1)i/μli) (24)

    with eIli(0)=(˙eD(l1)i(0)+βlieD(l1)i(0))/αli, where si (i = 1, 2, 3) is the ith term of s; l = 1, …, ri −1; αli, μli and βli are parameters respectively satisfying αli > 0, μli > 0 and βli > 0; yid is the ith component of the objective output vector y d, which takes values according to (19), y dR3×1; ei is the tracking error of yi. tanh(·) is a hyperbolic tangent function that is continuous and smooth.

    The definition of the initial value eIli(0) ensures that the sliding function si starts from the plane of si(0) = 0, which eliminates the reaching time of the sliding mode. ei converges to 0 when the system keeps operating on the plane of si(t) = 0. As mentioned above, the approximate DI-TSMC method achieves a near-finite-time convergence. Some researchers have studied the estimation of the convergence time [21], [22], which is out of the scope of this study.

    The derivative of si with respect to time is as follows:

    ˙si=˙eD(ri1)i=¨eD(ri2)i+β(ri1)i˙eD(ri2)i+α(ri1)i˙eI(ri1)i (25)

    Substituting the derivative of eDli into (25), another form of it is obtained as below:

    ˙si=e(ri)i+ri1l=1(βlie(ril)D(l1)i+αlie(ril)Ili)=Zi(x,d)+Giu(ydi)(ri)+γi(e(ril)D(l1)i,e(ril)Ili) (26)

    with, γi(e(ril)D(l1)i,e(ril)Ili)=ri1l=1(βkie(ril)D(l1)i+αlie(ril)Ili), where Zi and Gi are the ith terms of Z and G, respectively. To drive the vector s to zero, the control law of the two-area thermal power system is designed as

    u=ˉG[y(r)dˆZ(xd)γKs||s||ςκ=0ρg×||e_||2κ×s] (27)

    where yd(r) = [y1d(r1), y2d(r2), y3d(r3)]T, γ = [γ1, γ2, γ3]T; KR3×3 is a positive-defined diagonal matrix; ρg is a positive constant; ˉGR3×3 is the pseudo-inverse matrix of G.

    Theorem 1: The tracking error vector e(t) = [e1, e2, e3]T is guaranteed with asymptotical stability and near-finite-time convergence when K satisfies

    K=diag{θ1,θ2,θ3} (28)

    where θ1, θ2, θ3 are the upper bounds of ΔZ1, ΔZ2, ΔZ3, respectively.

    Proof: The Lyapunov function is selected as V=sTGˉGs/2. GˉG is a 3×3 positive definite symmetric matrix. According to the property of the pseudo-inverse matrix, G and ˉG satisfy ˉG=ˉGGˉG. Therefore, the following formula is obtained by taking the derivative of V and then substituting (26)–(28) into it:

    ˙V=sTGˉG˙s=sTGˉG(Z(x,d)+GˉG[y(r)dˆZ(xd)γKs||s||ςκ=0ρg×||e_||2κ×s]y(r)d+γ)=sTGˉG[(ˆZ(x)ˆZ(xd))ςκ=0ρg×||e_||2κ×s]+sTGˉG[ΔZ(d)Ks||s||]sT×||GˉG||×(ˆZ(x)ˆZ(xd))||GˉG||×ςκ=0ρg×||e_||2κ×||s||2+sT×||GˉG||×ΔZ(d)||GˉG||×K×||s||.

    It is easy to present the following conclusions from Assumption 1 and Assumption 2:

    {sT×||GˉG||×(ˆZ(x)ˆZ(xd))||GˉG||×ςκ=0ρg×||e_||2κ×||s||20sT×||GˉG||×ΔZ(d)||GˉG||×K×||s||0.

    Thus, ˙V0 is held true, and the equation holds only when s = 0. This illustrates that the approximate DI-TSMC method with the control law in (27) ensures the two-area thermal power system with asymptotic stability. Besides, the tracking error e(t) converges to zero in an approximate super twisting way [32].

    Similar to (17), the wind power system of (15) is also changed into the following form:

    {˙xw(t)=fw(xw(t),dw(t))+Bwuw(t)yw(t)=hw(xw(t)) (29)

    where the disturbance term is dw = Tm; The relative degree of yw is rw = 1. Thus, the fractional I-TSMC method is applied to the wind power system. The input-output dynamics of the wind power system is also expressed in the following form similar to (18):

    y(1)w=Lrwfwhw(xw)+LBwLrw1fwhw(xw,dw)uw=Zw(xw)+Gwuw (30)

    where Zw and Gw are constants directly defined in (30). Zw does not contain the disturbance term.

    Assumption 3: Zw(xw) is locally Lipschitz for a proper discussion control region xwΩw. The following inequalities can be held [32]:

    sTw(Zw(xw)Z(xdw))ςκ=0ρw×||ew_||2κ×||sw||2 (31)

    where sw is the sliding function of the wind power system; ρw is a constant satisfying ρw>0; ew_ = xwxwd, xwd is the target value of xw. ew_R3×1, xwdR3×1.

    The control objective of the system of (29) is to force ωr to track its target value ωrd. From Fig. 3, ωrd and the tracking error ew are calculated as below:

    ωdr(t)=ωoptr(t)2πΔf1(t) (32)
    ew(t)=yw(t)ydw(t)=ωr(t)ωdr(t). (33)

    According to the fractional I-TSMC method, the sliding function of the wind power system is designed as follows:

    sw(t)=ew(t)+αewI(t) (34)
    ˙ewI(t)=eq/pw(t),withewI(0)=ew(0)/α (35)

    where α is a positive parameter; p and q are positive odd numbers satisfying p > q, which avoids the singularity problem; the nonlinear term ewq/p = sign(ew)|ew|q/p, |·| is the absolute value function. ewI(0) is defined to eliminate the reaching time of the sliding mode. From (34), the following equation is obtained when on the surface of sw(t) = 0:

    ew(t)=αewI(t). (36)

    From (35) and (36), the following equation is derived:

    Tw=|ewI(0)|1q/pαq/p(1q/p) (37)

    where Tw is the convergence time of ewI(t). Moreover, the time for ew(t) to converge to 0 is also Tw, according to (34).

    Taking the derivative of the sliding function (34) with respect to time, and then substituting (33) and (35) in it, the following equation is obtained:

    ˙sw(t)=˙ew(t)+α˙ewI(t)=Zw+Gwuw(t)˙ydw(t)+α˙ewI(t). (38)

    The control law of the wind power system is set as

    uw(t)=G1w[˙ydwZw(xdw)(Kw+δw×||α˙ewI||)sw||sw||+ςκ=0ρw×||ew_||2κ×sw] (39)

    where Kw and δw are constants.

    Theorem 2: If the parameters Kw and δw in the control law satisfy the following conditions:

    Kw>0andδw>1

    then the control errors ewI(t) and ew(t) are guaranteed with finite-time convergence stability.

    Proof: The Lyapunov function is selected as Vw=sTwsw/2. Taking the derivative of Vw and then substituting (38) and (39) in it:

    ˙Vw=sTw×˙sw=sTw(Zw(xw)Zw(xdw))(Kw+δw×||α˙ewI||)×||sw||ςκ=0ρw×||ew_||2κ×sw+α˙ewIsTwsTw(Zw(xw)Zw(xdw))ςκ=0ρw×||ew_||2κ×||sw||+||α˙ewI||×||sw||δw×||α˙ewI||×||sw||Kw×||sw||.

    According to Assumption 3 and Theorem 2, the following inequalities are held true:

    {sTw(ZwZdw)ςκ=0ρw×||ew_||2κ×||sw||20||α˙ewI||×||sw||δw×||α˙ewI||×||sw||0Kw×||sw||0.

    Thus, ˙Vw0 is held true, and the equation holds only when sw = 0. This illustrates that the fractional I-TSMC method with the control law in (39) ensures the wind power system with asymptotic stability. In addition, as sw(0) = 0 is achieved by (35), the tracking errors ewI(t) and ew(t) are ensured to converge to 0 within the time of Tw.

    To evaluate the effectiveness of the proposed control method, corresponding numerical simulations are carried out on the wind-integrated two-area thermal power system. The parameters of the wind power system controller are set as q = 13, p = 15, α = 2, δw = 2, Kw = 0.15, ρw = 300, Lw = 10, ς = 1. The parameters of the two-area thermal power system controller are set as β11 = β12 = β13 = β21 = β22 = β23 = β33 = 15, α11 = α12 = α13 = α21 = α22 = α23 = α33 = 8, μ11 = μ12 = μ13 = μ21= μ22 = μ23 = μ33 = 0.1, K = diag(50, 50,300), ρg = 0.2, L = 10.

    For the first simulation experiment, comparisons among the LFC method proposed in this study and the LFC methods based on the nonlinear SMC method [29] and the NNB I-SMC method [28] are carried out.

    For comparison, the wind speed and load disturbances are set to be the same constants under different LFC methods. The wind speed of the wind power system is set to vw = 10 m/s, and the load disturbances of the two-area thermal power system are set to ΔPd1 = 0.01 and ΔPd2 = 0.01, respectively.

    The simulation results of the three methods are displayed in Fig. 5. Fig. 5(a) shows the responses of the power output Pg of the wind power system under the three methods. Though Pg converges stably under different methods, it converges significantly faster by applying the proposed method. Figs. 5(b), 5(c), and 5(d) exhibit the responses of Δf1, Δf2, and ΔPtie1 of the two-area thermal power system, respectively. The nadir of the dot-dash line in Fig. 5(b) is −1.84×10−3 Hz at 0.38 s and that of the dot-dash line in Fig. 5(c) is −1.91×10−3 Hz at 0.49 s. To compare the responses of Δf1 and Δf2 more clearly, Figs. 5(b) and 5(c) only show the signals in the ordinate range from −2×10−4 Hz to 2×10−4 Hz. Δf1, Δf2, and ΔPtie1 converge to 0 in the shortest time under the LFC method proposed in this study. Moreover, the oscillations under the proposed method are significantly smaller than those under the other two methods. Thus, the LFC method proposed in this study have better effectiveness in solving the LFC problem of the wind-integrated power system.

    Figure  5.  Response comparison between the proposed LFC method, the nonlinear SMC-based method and the NNB I-SMC-based method (a) Power output of the wind power system Pg; (b) Frequency deviation Δf1; (c) Frequency deviation Δf2; (d) Deviation of tie-line power flow ΔPtie1.

    For the second simulation experiment, the dynamic robustness of the wind-integrated power system when applying the proposed method is validated under variable external disturbances. Fig. 6 shows the signal settings of the external disturbances, including the wind speed fluctuations and load disturbances.

    Figure  6.  Wind speed fluctuations and load disturbances (a) Wind speed vw; (b) Load disturbance ΔPd1; (c) Load disturbance ΔPd2.

    The responses of the wind power system are shown in Fig. 7. With changes in the external disturbances, uw, Pg, and ωr respond quickly (see Figs. 7(a)7(c)). Both Pg and ωr steadily track their corresponding target values. The responses of uw, Pg, and ωr are consistent with the variation of external disturbances. β remains almost at 0 after the initial over-shoot (see Fig. 7(d)).

    Figure  7.  Responses of the wind power system (a) Control input uw; (b) Power output of the wind power system Pg; (c) Generator rotating speed ωr; (d) Pitch angle β.

    Meanwhile, Fig. 8 shows the responses of the two-area thermal power system. The control inputs u1, u2, and u3, respond rapidly to the changes in external disturbances (see Figs. 8(a), 8(c), and 8(e)). In this process, Δf1, Δf2, and ΔPtie1 almost remain at their respective target values (see Figs. 8(b), 8(d), and 8(f)). Moreover, every time the wind speed and load disturbances change, system fluctuations are created. Those fluctuations can be observed by the response signals in Fig. 8. There are enlarged views in Fig. 8 showing the system fluctuation at the time around 45 s. From the enlarged views, it can be seen that fluctuation is produced and smoothed down in a short time. Indeed, the system converges to a new stable state after the fluctuation. Under the stable state, the frequency and tie-line power flow deviations are almost eliminated.

    Figure  8.  Responses of the tow-area thermal power system (a) Control input u1; (b) Frequency deviation Δf1; (c) Control input u2; (d) Frequency deviation Δf2; (e) Control input u3; (f) Deviation of tie-line power flow ΔPtie1.

    According to the responses in Figs. 7 and 8, the whole system responds well to the changes both in the load disturbances and wind speed, where the wind speed fluctuations have the most apparent impact on the system. The proposed LFC method enables the wind-integrated two-area thermal power system with stability and robustness to external disturbances.

    In this study, the LFC problem of a two-area thermal power system integrated with a wind power system is solved by applying derivative and integral terminal SMC technology. According to the relative degrees of different subsystems, the fractional I-TSMC method and the approximate DI-TSMC method are applied to the wind power system and the two-area thermal power system, respectively. In this way, the suitable sliding mode controllers with corresponding sliding surface functions are designed for the two-area thermal power system and the wind power system to stabilize the whole system. System stability is proven in the sense of Lyapunov. With the help of droop control and pitch angle control, the wind power system also participates in frequency regulation. Numerical simulations are carried out to test both the effectiveness and the dynamic performances of the proposed control method. The simulation results indicate that the presented control method is feasible.

    1) System matrices and parameters of the wind power system

    Aw=[(Dt+Dtg)2Ht12HtDtg2HtKtg0KtgDtg2Hg12Hg(Dg+Dtg)2Hg],Bw=[0012Hg]Dw=[12Ht00],Cw=[001]T,xw=[ωtTtgωr]

    where Kβ = 1, Tβ = 0.5, Ht = 2.49 s, Hg = 0.9 s, Dtg = 1.5, Dt = Dg = 0, Ktg = 296.7 p.u.

    Parameters of the wind power system: rotor radius, 50 m; rated capacity, 3.5 MW; rated generator revolution speed, 2 rad/s.

    Parameters of the Cp (λ, β) curve: c0 = 0.5176, c1 = 116, c2 = −0.4, c3 = −5, c4 = −21, c5 = 0.0068, b0 = 0.08, b1 = −0.035.

    2) System matrices and corresponding parameters of the two-area thermal power system

    x=[Δf1Δf2ΔPm1ΔPm2ΔE1ΔE2ΔPtie1ΔPv1ΔPv2]Td=[ΔPd1PgΔPd2]T
    A=[1TP10Kp1Tp1001TP20Kp2Tp2001Tt100001Tt2KE1B10000KE2B2002πT122πT12001R1Tg100001R2Tg20000Kp1Tp10000Kp2Tp2000001Tt1000001Tt200KE10000KE200000001Tg1001Tg1001Tg2001Tg2]
    C=[100000000010000000000000100]
    B=[zeros(7,3)1Tg11Tg101Tg201Tg2],D=[Kp1Tp100Kp2Tp2zeros(7,2)]

    where Tch1 = 0.3, Tch2 = 0.17, Kp1 = 1, Kp2 = 0.67, Tp1 = 10, Tp2 = 8, Tg1 = 0.1, Tg2 = 0.4, R1 = R2 = 0.05, B1 = 41, B2 = 81.5, KE1 = 0.5, KE2 = 0.5, T12 = 3.77 (taken from [29]).

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    Highlights

    • A load frequency control (LFC) method based on the derivative and integral terminal sliding mode technology is investigated for multi-area interconnected power systems integrated with wind power. This method guarantees the system with finite-time convergence and avoids the singularity problem during the control design process
    • Considering the flexibility of wind power regulation, wind generators are also applied to provide frequency support by adopting a wind power system model based on the mechanical dynamics of variable speed wind turbines (VSWTs)
    • Numerical simulations are carried out, which indicated that the proposed LFC method has the advantages of fast convergence and small oscillation. Moreover, effective frequency regulation and strong robustness are achieved under external disturbances

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