UNIT COMMITMENT METHOD CONSIDERING SECURITY REGION OF WIND TURBINE GENERATOR WITH FREQUENCY RESPONSE CONTROL

Abstract

The present invention discloses a unit commitment method considering security region of wind turbine generators with frequency response control, and the main steps are: 1) determining security region of wind turbine generators when provides frequency response; 2) based on the security region of the wind turbine generators when provides frequency response, establishing a unit commitment model considering security region of wind turbine generators; and 3) calculating the unit commitment model considering the security region of the wind turbine generators by using mixed-integer linear programming method, and obtaining the operation result of the unit commitment considering the security region of the wind turbine generators with frequency response control. The present invention can be widely used in the setting of frequency response parameters of wind turbine generators dispatched in the prior art and the start-stop and output plans of synchronous generator.

Claims

1. A unit commitment method considering security region of wind turbine generators with frequency response control, mainly comprises the following steps: 1) determining security region of wind turbine generators when provides frequency response; 2) based on the security region of the wind turbine generators when provides frequency response, establishing a unit commitment model considering the security region of the wind turbine generators; and 3) calculating the unit commitment model considering the security region of the wind turbine generators by using mixed-integer linear programming method, and obtaining the operation result of the unit commitment considering the security region of the wind turbine generators with frequency response control.

2. The unit commitment method considering security region of wind turbine generators with frequency response control of claim 1, wherein the main steps of determining security region of wind turbine generators when provides frequency response are as follows: 1) establishing an output model of wind turbine generators when provides frequency response, namely: $\begin{array}{cc}\Delta P_w^{\mathrm{PFR}}=K_w\Delta f\mathrm{and}& \left(1\right)\end{array}$ $\begin{array}{cc}\Delta P_w^{\mathrm{IR}}=J_w\frac{d\Delta f}{\mathrm{dt}}& \left(2\right)\end{array}$ in the above formulas, ΔP.sub.w.sup.PFR and ΔP.sub.w.sup.IR respectively represent primary frequency response and virtual inertia response provided by the wind turbine generators; frequency response coefficient K.sub.w=1/K.sub.droop-w; K.sub.droop-w is droop control parameter of the wind turbine generators in primary frequency response control; J.sub.w is virtual inertia control parameter of the wind turbine generators; Δf is system frequency deviation, and t refers to time; 2) establishing constraint condition of rotor rotational speed ω.sub.r, namely:
ω.sub.min≤ω.sub.r≤ω.sub.max  (3) in the above formulas, ω.sub.min and ω.sub.max respectively are the lowest speed and highest speed of the rotor rotational speed of the wind turbine generators; 3) establishing constraint conditions of wind power stability, and the main steps are as follows: 3.1) determining synchronization characteristics of the wind turbine generators, namely: $\begin{array}{cc}{P}_E=K_{DL}{\omega }_r^3-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\mathrm{and}& \left(4\right)\end{array}$ $\begin{array}{cc}{P}_E=P_M=0.5\rho \pi R^2{C}_P\left(\beta ,\lambda \right)v^3;& \left(5\right)\end{array}$ in the above formulas, P.sub.E is active output of the wind turbine generators; K.sub.DL is de-load factor of the wind turbine generators; when the wind turbine generators are working at maximum power tracking mode, coefficient K.sub.DL is the maximum power tracking coefficient, K.sub.DLω.sub.r.sup.3 is the output of the wind turbine generators when there is no virtual inertia response; p is air density; R is diameter of the rotor of the wind turbine generators; v is wind speed; C.sub.p is power coefficient of the wind turbine generators; P.sub.M is mechanical power of the wind turbine generators; and β is pitch angle of the wind turbine generators; wherein, the tip speed ratio λ is shown as follows: $\begin{array}{cc}\lambda =\frac{R{\omega }_r}{v}& \left(6\right)\end{array}$ 3.2) determining limit operating rotational speed co, of the wind turbine generators, and the limit operating rotational speed co, of the wind turbine generators meets the following formula: $\begin{array}{cc}\frac{\partial \left(K_{DL}{\omega }_r^3-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\right)}{\partial {\omega }_r}=\frac{\partial \left(0.5\mathrm{\rho \pi }{R}^2{C}_P\left(\beta ,\frac{R{\omega }_r}{v}\right)v^3\right)}{\partial {\omega }_r}& \left(7\right)\end{array}$ 3.3) substituting the limit operating rotational speed co, of the wind turbine generators into formula (5), and calculating to obtain limit operating point of the wind turbine generators $\left({\omega }_{rc},0.5\rho \pi R^2{C}_P\left(\beta ,\frac{R{\omega }_{rc}}{v}\right)v^3\right);$ 3.4) connecting extreme operating points at each wind speed to form stability boundary of the wind turbine generators, and substituting formula (6) into formula (7), and calculating limit tip speed ratio λ.sub.c; and the limit tip speed ratio λ.sub.c meets the following formula: $\begin{array}{cc}3{K_{DL}\left(\frac{\lambda v}{R}\right)}^2=0.5\rho \pi R^2\frac{\partial \left(C_P\left(\beta ,\lambda \right)\right)}{\partial \frac{\lambda v}{R}}{v}^3=0.5\rho \pi R^3\frac{\partial \left(C_P\left(\beta ,\lambda \right)\right)}{\partial \lambda }{v}^2& \left(8\right)\end{array}$ 3.5) establishing expression formula of the relationship between wind speed and rotor rotational speed on the stability boundary of the wind turbine generators, namely: $\begin{array}{cc}v=\frac{R{\omega }_r}{{\lambda }_c};& \left(9\right)\end{array}$ 3.6) substituting formula (9) into formula (5), and calculating to obtain expression formula of the stability boundary of the wind turbine generators, namely: $\begin{array}{cc}{P}_c=\frac{0.5\mathrm{\rho \pi }{R}^5{C}_P\left(\beta ,{\lambda }_c\right)}{{\lambda }_c^3}{\omega }_r^3=K_c{\omega }_r^3& \left(10\right)\end{array}$ 3.7) based on formula (10), updating the limit operating point of the wind turbine generators to (ω.sub.rc, K.sub.cω.sub.r.sup.3); 3.8) establishing stability constraints of the wind turbine generators when provides frequency response, and it is divided into the following three situations: I) when the wind turbine generators are operating at the lowest speed, the wind turbine generators do not provide frequency response, and the frequency response of the wind turbine generators is as follows: $\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}=0{\omega }_{r0}<{\omega }_{\min }& \left(11\right)\end{array}$ in the above formulas, ω.sub.r0 is the rotor rotational speed in initial operating state of the wind turbine generators; II) when the limit operating rotational speed ω.sub.rc is less than the lowest speed ω.sub.min, the stability constraints of the wind turbine generators when provides frequency response are as follows: $\begin{array}{cc}{K}_{DL}{\omega }_{\min }^3-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\le f_M\left({\omega }_{\min }\right){\omega }_{rc}<{\omega }_{\min }& \left(12\right)\end{array}$ in the above formulas, f.sub.M(ω.sub.min) is the mechanical power of the wind turbine generators at the lowest rotational speed ω.sub.min; III) when ω.sub.rc≥ω.sub.min, the stability constraints of the wind turbine generators when provides frequency response are as follows: $\begin{array}{cc}{K}_{DL}{\omega }_{rc}^3-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\le K_c{\omega }_{rc}^3& \left(13\right)\end{array}$ 4) establishing output constraints of the wind turbine generators when provides frequency response, and the main steps are as follows: 4.1) updating the active output P.sub.E* of the wind turbine generators, namely: $\begin{array}{cc}{P}_E^{*}=\left(1-d_w\right)P_w-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}};& \left(14\right)\end{array}$ in the above formulas, P.sub.w is available power of the wind turbine generators; d.sub.w is reserve coefficient of the wind turbine generators, and (1−d.sub.w)P.sub.w is actual output of the wind turbine generators when does not provide frequency response output; 4.2) establishing output constraints of the wind turbine generators when provides frequency response, namely: $\begin{array}{cc}\left(1-d_w\right)P_w-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\le P_w^{\max }& \left(15\right)\end{array}$ in the above formulas, P.sub.w.sup.max is the maximum output of wind turbine generators; 5) combining formula (10), formula (12), formula (13) and formula (15), the security region of the wind turbine generators meets formula (16) to formula (19), namely: $\begin{array}{cc}\begin{array}{cc}{K}_w=0;J_w=0& {\omega }_{r0}<{\omega }_{\min };\end{array}& \left(16\right)\end{array}$ $\begin{array}{cc}\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\le f_M\left({\omega }_{\min }\right)-K_{\mathrm{DL}}{\omega }_{\min }^3& {\omega }_{\mathrm{rc}}<{\omega }_{\min };\end{array}& \left(17\right)\end{array}$ $\begin{array}{cc}\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\le K_c{\omega }_{\mathrm{rc}}^3-K_{\mathrm{DL}}{\omega }_{\mathrm{rc}}^3& {\omega }_{\mathrm{rc}}\ge {\omega }_{\min };\mathrm{and}\end{array}& \left(18\right)\end{array}$ $\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\le P_w^{\max }-\left(1-d_w\right)P_w.& \left(19\right)\end{array}$

3. The unit commitment method considering security region of wind turbine generators with frequency response control of claim 1, wherein the main steps of establishing a unit commitment model considering the security region of the wind turbine generators are as follows: 1) with the goal of minimizing the operating cost of the traditional synchronous generator, establishing the objective function, namely: $\begin{array}{cc}\begin{array}{cc}\min & \stackrel{T}{\underset{i=1}{.Math.}}\underset{g\in \zeta }{.Math.}\left[\left(c_g{P}_{g,i}+c_g^{\mathrm{nl}}{N}_{g,i}^{\mathrm{on}}\right)\Delta t+c_g^{\mathrm{su}}{N}_{g,i}^{\mathrm{su}}\right];\end{array}& \left(20\right)\end{array}$ in the above formulas, ζ is a set of traditional synchronous generators; c.sub.g is marginal cost; c.sub.g.sup.nl is no-load cost; c.sub.g.sup.su is start-up cost; P.sub.g,i is active power of the traditional synchronous generator; N.sub.g, i.sup.on is online synchronous generator; N.sub.g,i.sup.su is synchronous generator turned on at step i; T is total optimization time scale; Δt is unit time interval; variables with the subscript i represent variables of the i-th step; variables with subscript g represent variables related to traditional synchronous generator g; variables with subscripts g,i represent related variables of the traditional synchronous generator g at the i-th step; 2) establishing constraints of traditional unit commitment, which include power flow constraints, synchronous generator constraints, system frequency stability constraints, frequency change rate constraints, frequency lowest point constraints, and wind turbine generators security region constraints; 2.1) power flow constraints are as follows: $\begin{array}{cc}\begin{array}{cc}\underset{g\in \zeta }{.Math.}{P}_{g,i}+\underset{w\in W}{.Math.}\left(1-d_{w,i}\right)P_{w,i}=L_i& i\in T\end{array}& \left(21\right)\end{array}$ in the above formulas, W is a set of wind turbine generators; L.sub.i is total load of the system; the wind turbine generators parameters are all aggregate parameters; variables with subscript w represent variables related to wind turbine generators w; variables with subscripts w,i represent related variables of wind turbine generators w at step i; 2.2) synchronous generator constraints are shown in formula (22) to formula (28); $\begin{array}{cc}{N}_{g,i}^{\mathrm{on}}{P}_g^{\min }\le P_{g,i}\le N_{g,i}^{\mathrm{on}}{P}_g^{\max }& \left(22\right)\end{array}$ $\begin{array}{cc}{N}_{g,i}^{\mathrm{on}}=N_{g,i-1}^{\mathrm{on}}+N_{g,i}^{\mathrm{su}}-N_{g,i}^{\mathrm{sd}}& \left(23\right)\end{array}$ $\begin{array}{cc}{N}_{g,i}^{\mathrm{off}}=N_{g,i-1}^{\mathrm{off}}+N_{g,i}^{\mathrm{sd}}-N_{g,i}^{\mathrm{su}}& \left(24\right)\end{array}$ $\begin{array}{cc}{P}_{g,i}-P_{g,i-1}\le \Delta P_g^{\max }{N}_{g,i-1}^{\mathrm{on}}+\Delta P_g^{\mathrm{su}\max }\left(N_{g,i}^{\mathrm{on}}-N_{g,i-1}^{\mathrm{on}}\right)& \left(25\right)\end{array}$ $\begin{array}{cc}{P}_{g,i}-P_{g,i-1}\ge -\Delta P_g^{\max }{N}_{g,i}^{\mathrm{on}}+\Delta P_g^{\mathrm{sd}\max }\left(N_{g,i-1}^{\mathrm{on}}-N_{g,i}^{\mathrm{on}}\right)& \left(26\right)\end{array}$ $\begin{array}{cc}\underset{k=i+1-\Delta t_g^{\mathrm{up}}}{\stackrel{i}{.Math.}}{N}_{g,k}^{\mathrm{su}}\le N_{g,i}^{\mathrm{on}}& \left(27\right)\end{array}$ $\begin{array}{cc}\stackrel{i}{\underset{k=i+1-\Delta t_g^{\mathrm{dw}}}{.Math.}}{N}_{g,k}^{\mathrm{sd}}\le N_{g,i}^{\mathrm{off}}& \left(28\right)\end{array}$ in the above formulas, P.sub.g.sup.min and P.sub.g.sup.max are the minimum value and maximum value of the synchronous generator output, respectively; ΔP.sub.g.sup.max is the maximum value of output change of the synchronous generator; ΔP.sub.g.sup.su max and ΔP.sub.g.sup.sd max are the maximum upward and downward climbing power of the synchronous generator, respectively; N.sub.g, i.sup.sd is the number of synchronous generators shut down in step i; N.sub.g, i.sup.off is the number of synchronous generators offline at step i; Δt.sub.g.sup.up and Δt.sub.g.sup.dw are the minimum start and stop time of the unit; i ∈ T; g ∈ ζ; 2.3) the system frequency stability constraints are as follows: $\begin{array}{cc}2H_i\frac{d\Delta f}{\mathrm{dt}}+\left(D_i{L}_i+K_i\right)\Delta f=-\Delta L_i& \left(29\right)\end{array}$ wherein, D.sub.i is the load damping coefficient; H.sub.i is the system inertia time constant; K.sub.i is the frequency response coefficient; wherein, the system inertia time constant H.sub.i is shown as follows: $\begin{array}{cc}{H}_i=\frac{\underset{g\in \zeta }{.Math.}{H}_g{P}_g^{\max }{N}_{g,i}^{\mathrm{on}}}{f_0}+\pi \underset{w\in W}{.Math.}{J}_{w,i}& \left(30\right)\end{array}$ in the above formulas, H.sub.g is the inertia time coefficient of synchronous generator; The optimized variables in formula (30) are the virtual inertia control parameters J.sub.w,i of the online synchronous generator N.sub.g, i.sup.on and the wind turbine generators at i-th step; f.sub.0 is the reference frequency of the power system; frequency response coefficient K.sub.i is shown as follows: $\begin{array}{cc}{K}_i=\frac{\underset{g\in \zeta }{.Math.}{K}_g{P}_g^{\max }{N}_{g,i}^{\mathrm{on}}}{f_0}+2\pi \underset{w\in W}{.Math.}{K}_{w,i}& \left(31\right)\end{array}$ in the above formulas, K.sub.g=1K.sub.droop-g; K.sub.droop-g is the droop control parameter of the synchronous generator; the optimized variables in formula (31) are the frequency response parameter K.sub.w,i of the online synchronous generator N.sub.g, i.sup.on and the wind turbine generators at the i-th step; system frequency deviation Δf is shown as follows: $\begin{array}{cc}\Delta f\left(t\right)=\frac{\left(e^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}-1\right)\Delta L_i}{\left(D_i{L}_i+K_i\right)}& \left(32\right)\end{array}$ frequency change rate dΔf/dt is shown as follows: $\begin{array}{cc}\frac{d\Delta f\left(t\right)}{\mathrm{dt}}=-\frac{\Delta L_i}{2H_i}{e}^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}& \left(33\right)\end{array}$ 2.4) frequency change rate constraints are shown as follows: $\begin{array}{cc}.Math.\left(\frac{d\Delta f\left(t\right)}{\mathrm{dt}}\right).Math.\le \frac{\Delta L_i}{2H_i}\le {\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }& \left(34\right)\end{array}$ 2.5) frequency lowest point constraints are shown as follows: $\begin{array}{cc}.Math.\Delta f\left(t\right).Math.\le .Math.\Delta f_{\mathrm{nadir},i}.Math.=\frac{\Delta L_i}{\left(D_i{L}_i+K_i\right)}\le \Delta f_{\max }& \left(35\right)\end{array}$ 2.6) Based on formula (1), formula (2), formula (32) to formula (35), establishing the equation of frequency response provided by the wind turbine generators, namely: $\begin{array}{cc}-K_{w,i}\Delta f\left(t\right)-J_{w,i}\frac{d\Delta f\left(t\right)}{\mathrm{dt}}& \left(36\right)\end{array}$ $=-K_{w,i}\frac{\left(e^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}-1\right)\Delta L_i}{\left(D_i{L}_i+K_i\right)}+J_{w,i}\frac{\Delta L_i}{2H_i}{e}^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}$ $=\left(-\frac{K_{w,i}\Delta L_i}{\left(D_i{L}_i+K_i\right)}+\frac{J_{w,i}\Delta L_i}{2H_i}\right)e^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}+\frac{K_{w,i}\Delta L_i}{\left(D_i{L}_i+K_i\right)}$ $\le \max \left\{\frac{K_{w,i}\Delta L_i}{(D_i{L}_i+K_{i)}},\frac{J_{w,i}\Delta L_i}{2H_i}\right\}$ $\le \max \left\{K_{w,i}\Delta f_{\max },{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\right\};$ 2.7) substituting formula (36) into formula (17) to formula (19) to establish the security region constraints of the wind turbine generators, which are shown as formula (37) to formula (43) respectively: $\begin{array}{cc}{K}_w=0;J_w=\begin{array}{cc}0& {\omega }_{r0}<{\omega }_{\min }\end{array}& \left(37\right)\end{array}$ $\begin{array}{cc}{K}_{w,i}\Delta f_{\max }\le f_M\left({\omega }_{\min }\right)-K_{\mathrm{DL}}\begin{array}{cc}{\omega }_{\min }^3& {\omega }_{\mathrm{rc}}<{\omega }_{\min }\end{array}& \left(38\right)\end{array}$ $\begin{array}{cc}{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\le f_M\left({\omega }_{\min }\right)-K_{\mathrm{DL}}\begin{array}{cc}{\omega }_{\min }^3& {\omega }_{\mathrm{rc}}<{\omega }_{\min }\end{array}& \left(39\right)\end{array}$ $\begin{array}{cc}{K}_{w,i}\Delta f_{\max }\le K_c{\omega }_{\mathrm{rc}}^3-K_{\mathrm{DL}}\begin{array}{cc}{\omega }_{rc}^3& {\omega }_{\mathrm{rc}}\ge {\omega }_{\min }\end{array}& \left(40\right)\end{array}$ $\begin{array}{cc}{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\le K_c{\omega }_{rc}^3-K_{\mathrm{DL}}\begin{array}{cc}{\omega }_{rc}^3& {\omega }_{\mathrm{rc}}\ge {\omega }_{\min }\end{array}& \left(41\right)\end{array}$ $\begin{array}{cc}{K}_{w,i}\Delta f_{\max }\le P_w^{\max }-\left(1-d_{w,i}\right)P_{w,i}& \left(42\right)\end{array}$ $\begin{array}{cc}{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\le P_w^{\max }-\left(1-d_{w,i}\right)P_{w,i}.& \left(43\right)\end{array}$

Description

BRIEF DESCRIPTION OF THE DRAWINGS

[0058] FIG. 1 is a schematic diagram of the security region of the wind turbine generators when provides frequency response.

[0059] FIG. 2 is a schematic diagram of wind speed.

[0060] FIG. 3 is a schematic diagram of system frequency indicators.

[0061] FIG. 4 is a schematic diagram of the influence of the security region of the wind turbine generators on the frequency response output of the wind turbine generators.

[0062] FIG. 5 is a schematic diagram of the influence of the reserve capacity of the wind turbine generators on the frequency response output of the wind turbine generators.

DETAILED DESCRIPTION OF THE INVENTION

[0063] The present invention will be further described below in conjunction with embodiments, but it should not be understood that the scope of the above subject matter of the present invention is limited to the following embodiments. Without departing from the above-mentioned technical idea of the present invention, various substitutions and changes based on common technical knowledge and conventional means in the field shall be included in the protection scope of the present invention.

Embodiment 1

[0064] Refer to FIG. 1 to FIG. 5, the unit commitment method considering security region of wind turbine generators with frequency response control, mainly comprises the following steps.

[0065] 1) Determining the security region of the wind turbine generators when provides frequency response, and the main steps are as follows.

[0066] 1.1) Establishing an output model of wind turbine generators when provides frequency response, namely:

[00027]$\begin{array}{cc}\Delta P_w^{PFR}=K_w\Delta f\mathrm{and}& \left(1\right)\end{array}$$\begin{array}{cc}\Delta P_w^{\mathrm{IR}}=J_w\frac{d\Delta f}{\mathrm{dt}}.& \left(2\right)\end{array}$

[0067] In the above formulas, ΔP.sub.w.sup.PFR and ΔP.sub.w.sup.IR respectively represent the primary frequency response and virtual inertia response provided by the wind turbine generators. Frequency response coefficient K.sub.w=1/K.sub.droop-w. K.sub.droop-w is the droop control parameter of the wind turbine generators in primary frequency response control. J.sub.w is the virtual inertia control parameter of the wind turbine generators. Δf is the system frequency deviation, and t refers to time.

[0068] 1.2) Establishing constraint condition of the rotor rotational speed ω.sub.r, namely:

ω.sub.min≤ω.sub.r≤ω.sub.max  (3)

[0069] In the above formulas, ω.sub.min and ω.sub.max respectively are the lowest speed and highest speed of the rotor rotational speed of the wind turbine generators.

[0070] 1.3) Establishing constraint conditions of wind power stability, the main steps are as follows.

[0071] 1.3.1) Determining the synchronization characteristics of the wind turbine generators, namely:

[00028]$\begin{array}{cc}{P}_E=K_{DL}{\omega }_r^3-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\mathrm{and}& \left(4\right)\end{array}$$\begin{array}{cc}{P}_E=P_M=0.5\rho \pi R^2{C}_P\left(\beta ,\lambda \right)v^3.& \left(5\right)\end{array}$

[0072] In the above formulas, P.sub.E is the active output of the wind turbine generators. K.sub.DL is the de-load factor of the wind turbine generators. When the wind turbine generators are working at maximum power tracking mode, the coefficient K.sub.DL is the maximum power tracking coefficient, and K.sub.DLω.sub.r.sup.3 is the output of the wind turbine generators when there is no virtual inertia response. p is the air density. R is the diameter of the rotor of the wind turbine generators. v is the wind speed. C.sub.p is the power coefficient of the wind turbine generators. P.sub.M is the mechanical power of the wind turbine generators. β is the pitch angle of the wind turbine generators.

[0073] Wherein, the tip speed ratio λ is shown as follows.

[00029]$\begin{array}{cc}\lambda =\frac{R{\omega }_r}{v}& \left(6\right)\end{array}$

[0074] 1.3.2) At a certain wind speed, the stability condition of the wind turbine generator is that the curve of formula (4) and the curve of formula (5) have at least one intersection, otherwise the wind turbine generators may lose its balance point and cause instability. Therefore, the stability limit of the wind turbine generators is that the curve of formula (4) and the curve of formula (5) have one and only one intersection point, which is the tangent point of the curve of formula (4) and the curve of formula (5). Therefore, the limit operating speed ω.sub.rc of the wind turbine generators is calculated by deriving formula (4) and formula (5).

[00030]$\begin{array}{cc}\frac{\partial \left(K_{DL}{\omega }_r^2-K_w\Delta f-J_w\frac{d\Delta f}{\mathrm{dt}}\right)}{\partial {\omega }_r}=\frac{\partial \left(0.5\mathrm{\rho \pi }{R}^2{C}_p\left(\beta ,\frac{R{\omega }_r}{v}\right)v^3\right)}{\partial {\omega }_r}& \left(7\right)\end{array}$

[0075] 1.3.3) Substituting the limit operating rotational speed ω.sub.rc of the wind turbine generators into formula (5), calculating to obtain the limit operating point of the wind turbine generators

[00031]$\left({\omega }_{rc},0.5\mathrm{\rho \pi }{R}^2{C}_P\left(\beta ,\frac{R{\omega }_{rc}}{v}\right)v^3\right).$

[0076] Connecting the extreme operating points at each wind speed to form the stability boundary of the wind turbine generators, and substituting formula (6) into formula (7) to calculate the limit tip speed ratio λ.sub.c. The limit tip speed ratio λ.sub.c meets the following formula.

[00032]$\begin{array}{cc}3{K_{DL}\left(\frac{\lambda v}{R}\right)}^2=0.5\rho \pi R^2\frac{\partial \left(C_P\left(\beta ,\lambda \right)\right)}{\partial \frac{\lambda v}{R}}{v}^3=0.5\rho \pi R^3\frac{\partial \left(C_P\left(\beta ,\lambda \right)\right)}{\partial \lambda }{v}^2& \left(8\right)\end{array}$

[0077] 1.3.5) Establishing the expression formula of the relationship between wind speed and rotor rotational speed on the stability boundary of the wind turbine generators, namely:

[00033]$\begin{array}{cc}v=\frac{R{\omega }_r}{{\lambda }_c}.& \left(9\right)\end{array}$

[0078] 1.3.6) Substituting formula (9) into formula (5), and calculating to obtain the expression formula of the stability boundary of the wind turbine generators, namely:

[00034]$\begin{array}{cc}{P}_c=\frac{0.5\mathrm{\rho \pi }{R}^5{C}_P\left(\beta ,{\lambda }_c\right)}{{\lambda }_c^3}{\omega }_r^3=K_c{\omega }_r^3.& \left(10\right)\end{array}$

[0079] 1.3.7) Based on formula (10), updating the limit operating point of the wind turbine generators to (ω.sub.rc, K.sub.cω.sub.r.sup.3).

[0080] 1.3.8) Establishing the stability constraints of the wind turbine generators when provides frequency response, and it is divided into the following three situations.

[0081] I) When the wind turbine generator is operating at the lowest speed, the wind turbine generator does not provide frequency response. The frequency response of the wind turbine generator is as follows.

[00035]$\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{dt}=0{\omega }_{r0}<{\omega }_{\min }& \left(11\right)\end{array}$

[0082] In the above formulas, ω.sub.r0 is the rotor rotational speed in the initial operating state of the wind turbine generators.

[0083] II) When the limit operating rotational speed ω.sub.rc is less than the lowest speed ω.sub.min, the stability constraints of the wind turbine generators when provides frequency response are as follows.

[00036]$\begin{array}{cc}{K}_{DL}{\omega }_{\min }^3-K_w\Delta f-J_w\frac{d\Delta f}{dt}\le f_M\left({\omega }_{\min }\right){\omega }_{rc}<{\omega }_{\min }& \left(12\right)\end{array}$

[0084] In the above formulas, F.sub.M(ω.sub.min) is the mechanical power of the wind turbine generators at the lowest rotational speed ω.sub.min.

[0085] III) When ω.sub.rc≥ω.sub.min, the stability constraints of the wind turbine generators when provides frequency response are as follows.

[00037]$\begin{array}{cc}{K}_{DL}c{o}_{rc}^3-K_w\Delta f-J_w\frac{d\Delta f}{dt}\le K_c{\omega }_{rc}^3& \left(13\right)\end{array}$

[0086] 1.4) Establishing the output constraints of the wind turbine generators when provides frequency response, and the main steps are as follows.

[0087] 1.4.1) Updating the active output P.sub.E* of the wind turbine generators, namely:

[00038]$\begin{array}{cc}{P}_E=\left(1-d_w\right)P_w-K_w\Delta f-J_w\frac{d\Delta f}{dt}.& \left(14\right)\end{array}$

[0088] In the above formulas, P.sub.w is the available power of the wind turbine generators. d.sub.w is the reserve coefficient of the wind turbine generators, and (1−d.sub.w)P.sub.w is the actual output of the wind turbine generators when does not provide frequency response output.

[0089] 1.4.2) Establishing the output constraints of the wind turbine generators when provides frequency response, namely:

[00039]$\begin{array}{cc}\left(1-d_w\right)P_w-K_w\Delta f-J_w\frac{d\Delta f}{dt}\le P_w^{\max }.& \left(15\right)\end{array}$

[0090] In the above formulas, P.sub.w.sup.max is the maximum output of wind turbine generators.

[0091] 1.5) Combining formula (10), formula (12), formula (13) and formula (15), the security region of the wind turbine generators meets formula (16) to formula (19), namely:

[00040]$\begin{array}{cc}{K}_w=0;J_w=0{\omega }_{r0}<{\omega }_{\min };& \left(16\right)\end{array}$$\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{dt}\le f_M\left({\omega }_{\min }\right)-K_{DL}{\omega }_{\min }^3{\omega }_{rc}<{\omega }_{\min };& \left(17\right)\end{array}$$\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{dt}\le K_c{\omega }_{rc}^3-K_{DL}{\omega }_{rc}^3{\omega }_{rc}\ge {\omega }_{\min };\mathrm{and}& \left(18\right)\end{array}$$\begin{array}{cc}-K_w\Delta f-J_w\frac{d\Delta f}{dt}\le P_w^{\max }-\left(1-d_w\right)P_w.& \left(19\right)\end{array}$

[0092] 2) Based on the security region of the wind turbine generators when provides frequency response, establishing a unit commitment model considering the security region of the wind turbine generators. The main steps are as follows.

[0093] 2.1) With the goal of minimizing the operating cost of the traditional synchronous generator, establishing the objective function, namely:

[00041]$\begin{array}{cc}\min \underset{i=1}{\overset{T}{.Math.}}\underset{g\in \zeta }{.Math.}\left[\left(c_g{P}_{g,i}+c_g^{nl}{N}_{g,i}^{on}\right)\Delta t+c_g^{su}{N}_{g,i}^{su}\right].& \left(20\right)\end{array}$

[0094] In the above formulas, ζ is a set of traditional synchronous generators. c.sub.g is the marginal cost. c.sub.g.sup.nl is the no-load cost. c.sub.g.sup.su is the start-up cost. P.sub.g,i is the active power of the traditional synchronous generator. N.sub.g,i.sup.on is an online synchronous generator. N.sub.g,i.sup.su is the synchronous generator turned on at step i. T is the total optimization time scale. Δt is the unit time interval. Variables with the subscript i represent the variables of the i-th step. Variables with subscript g represent variables related to traditional synchronous generator g. Variables with subscripts g,i represent the related variables of the traditional synchronous generator g at the i-th step.

[0095] 2) Establishing constraints of traditional unit commitment, which include power flow constraints, synchronous generator constraints, system frequency stability constraints, frequency change rate constraints, frequency lowest point constraints, and wind turbine generators security region constraints.

[0096] 2.2.1) Power flow constraints are as follows.

[00042]$\begin{array}{cc}\underset{g\in \zeta }{.Math.}{P}_{g,i}+\underset{w\in W}{.Math.}\left(1-d_{w,i}\right)P_{w,i}=L_{i}i\in T& \left(21\right)\end{array}$

[0097] In the above formulas, W is a set of wind turbine generators. L.sub.i is the total load of the system. The wind turbine generators parameters are all aggregate parameters. Variables with subscript w represent variables related to wind turbine generators w. Variables with subscripts w,i represent related variables of wind turbine generators w at step i.

[0098] 2.2.2) Synchronous generator constraints are shown in formula (22) to formula (28).

[00043]$\begin{array}{cc}{N}_{g,i}^{on}{P}_g^{\min }\le P_{g,i}\le N_{g,i}^{on}{P}_g^{\max }& \left(22\right)\end{array}$$\begin{array}{cc}{N}_{g,i}^{on}=N_{g,i-1}^{on}+N_{g,i}^{su}{\mathrm{\_N}}_{9^j}^{sd}& \left(23\right)\end{array}$$\begin{array}{cc}{N}_{g,i}^{on}=N_{g,i-1}^{on}+N_{g,i}^{su}{\mathrm{\_N}}_{9^j}^{sd}& \left(24\right)\end{array}$$\begin{array}{cc}{P}_{g,i}-P_{g,i-1}\le \Delta P_g^{\max }{N}_{g,i-1}^{on}+\Delta P_g^{\mathrm{su}\max }\left(N_{g,i}^{on}-N_{g,i-1}^{on}\right)& \left(25\right)\end{array}$$\begin{array}{cc}{P}_{g,i}-P_{g,i-1}\ge -\Delta P_g^{\max }{N}_{g,i}^{on}+\Delta P_g^{\mathrm{sdmax}}\left(N_{g,i}^{on}-N_{g,i-1}^{on}\right)& \left(26\right)\end{array}$$\begin{array}{cc}\underset{k=i+1-\Delta t_g^{\mathrm{up}}}{\overset{i}{.Math.}}{N}_{g,k}^{su}\le N_{g,i}^{on}& \left(27\right)\end{array}$$\begin{array}{cc}\underset{k=i+1-\Delta t_g^{\mathrm{dw}}}{\overset{i}{.Math.}}{N}_{g,k}^{\mathrm{sd}}\le N_{g,i}^{\mathrm{off}}& \left(28\right)\end{array}$

[0099] In the above formulas, P.sub.g.sup.min and P.sub.g.sup.max are the minimum value and maximum value of the synchronous generator output, respectively. ΔP.sub.g.sup.max is the maximum value of the output change of the synchronous generator. ΔP.sub.g.sup.su max and ΔP.sub.g.sup.sd max are the maximum upward and downward climbing power of the synchronous generator, respectively. N.sub.g, i.sup.sd is the number of synchronous generators shut down in step i. N.sub.g,i.sup.off is the number of synchronous generators offline at step i. Δt.sub.g.sup.up and Δt.sub.g.sup.dw are the minimum start and stop time of the unit. i∈T. g∈ζ.

[0100] 2.2.3) The system frequency stability constraints are as follows.

[00044]$\begin{array}{cc}2H_i\frac{d\Delta f}{dt}+\left(D_i{L}_i+K_i\right)\Delta f=-\Delta L_i& \left(29\right)\end{array}$

[0101] Wherein, D.sub.i is the load damping coefficient. H.sub.i is the system inertia time constant. K.sub.i is the frequency response coefficient.

[0102] Wherein, the system inertia time constant H.sub.i is shown as follows.

[00045]$\begin{array}{cc}{H}_i=\frac{\underset{g\in \zeta }{.Math.}{H}_g{P}_g^{\max }{N}_{g,i}^{on}}{f_0}+\pi \underset{w\in W}{.Math.}{J}_{w,i}& \left(30\right)\end{array}$

[0103] In the above formulas, H.sub.g is the inertia time coefficient of synchronous generator. The optimized variables in formula (30) are the virtual inertia control parameters J.sub.w,i of the online synchronous generator N.sub.g, i.sup.on and the wind turbine generators at i-th step. f.sub.0 is the reference frequency of the power system.

[0104] The frequency response coefficient K.sub.i controlled by the P-f of the synchronous generator and wind turbine generators is shown as follows.

[00046]$\begin{array}{cc}{K}_i=\frac{\underset{g\in \zeta }{.Math.}{K}_g{P}_g^{\max }{N}_{g,i}^{on}}{f_0}+2\pi \underset{w\in W}{.Math.}{K}_{w,i}& \left(31\right)\end{array}$

[0105] In the above formulas, K.sub.g=1/K.sub.droop-g. K.sub.droop-g is the droop control parameter of the synchronous generator. The optimized variables in formula (31) are the frequency response parameter K.sub.w,i of the online synchronous generator N.sub.g, i.sup.on and the wind turbine generators at the i-th step.

[0106] System frequency deviation Δf is shown as follows.

[00047]$\begin{array}{cc}\Delta f\left(t\right)=\frac{\left(e^{-\frac{\left(D_{i}L+K_i\right)}{2H_i}t}-1\right)\Delta L_l}{\left(D_i{L}_i+K_i\right)}& \left(32\right)\end{array}$

[0107] Frequency change rate dΔf/dt is shown as follows.

[00048]$\begin{array}{cc}\frac{d\Delta f\left(t\right)}{dt}=-\frac{\Delta L_i}{2H_i}{e}^{\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}& \left(33\right)\end{array}$

[0108] 2.2.4) Frequency change rate constraints are shown as follows.

[00049]$\begin{array}{cc}.Math.\left(\frac{d\Delta f\left(t\right)}{\mathrm{dt}}\right).Math.\le \frac{\Delta L_i}{2H_i}\le {\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }& \left(34\right)\end{array}$

[0109] 2.2.5) Frequency lowest point constraints are shown as follows.

[00050]$\begin{array}{cc}.Math.\Delta f\left(t\right).Math.\le .Math.\Delta f_{\mathrm{nadir},i}.Math.=\frac{\Delta L_i}{\left(D_i{L}_i+K_i\right)}\le \Delta f_{\max }& \left(35\right)\end{array}$

[0110] 2.2.6) Based on formula (1), formula (2), formula (32) to formula (35), establishing the equation of frequency response provided by the wind turbine generators, namely:

[00051]$\begin{array}{cc}-K_{w,i}\Delta f\left(t\right)-J_{w,i}\frac{d\Delta f\left(t\right)}{\mathrm{dt}}=-K_{w,i}\frac{\left(e^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}}-1\right)\Delta L_i}{\left(D_i{L}_i+K_i\right)}+J_{w,i}\frac{\Delta L_i}{2H_i}{e}^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}=\left(-\frac{K_{w,i}\Delta L_i}{\left(D_i{L}_i+K_i\right)}+\frac{J_{w,i}\Delta L_i}{2H_i}\right)e^{-\frac{\left(D_i{L}_i+K_i\right)}{2H_i}t}+\frac{K_{w,i}\Delta L_i}{\left(D_i{L}_i+K_i\right)}\le \max \left\{\frac{K_{w,i}\Delta L_i}{\left(D_i{L}_i+K_i\right)},\frac{J_{w,i}\Delta L_i}{2H_i}\right\}\le \max \left\{K_{w,i}\Delta f_{\max },{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\right\}.& \left(36\right)\end{array}$

[0111] 2.2.7) Substituting formula (36) into formula (17) to formula (19) to establish the security region constraints of the wind turbine generators, which are shown as formula (37) to formula (43) respectively.

[00052]$\begin{array}{cc}{K}_w=0;J_w=0{\omega }_{r0}<{\omega }_{\min }& \left(37\right)\end{array}$$\begin{array}{cc}{K}_{w,i}\Delta f_{\max }\le f_M\left({\omega }_{\min }\right)-K_{DL}{\omega }_{\min }^3{\omega }_{rc}<{\omega }_{\min }& \left(38\right)\end{array}$$\begin{array}{cc}{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\le f_M\left({\omega }_{\min }\right)-K_{DL}{\omega }_{\min }^3{\omega }_{rc}<{\omega }_{\min }& \left(39\right)\end{array}$$\begin{array}{cc}{K}_{w,i}\Delta f_{\max }\le K_c{\omega }_{rc}^3-K_{DL}{\omega }_{rc}^3{\omega }_{rc}\ge {\omega }_{\min }& \left(40\right)\end{array}$$\begin{array}{cc}{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\le K_c{\omega }_{rc}^3-K_{DL}{\omega }_{rc}^3{\omega }_{rc}\ge {\omega }_{\min }& \left(41\right)\end{array}$$\begin{array}{cc}{K}_{w,i}\Delta f_{\max }\le P_w^{\max }-\left(1-d_{w,i}\right)P_{w,i}& \left(42\right)\end{array}$$\begin{array}{cc}{J_{w,i}\left(\frac{d\Delta f}{\mathrm{dt}}\right)}_{\max }\le P_w^{\max }-\left(1-d_{w,i}\right)P_{w,i}& \left(43\right)\end{array}$

[0112] 3) Calculating the unit commitment model considering the wind turbine generators security region by using mixed-integer linear programming method, to obtain the operation result of the unit commitment considering the wind turbine generators security region with frequency response control.

Embodiment 1

[0113] An experiment to verify the unit commitment method considering the wind turbine generators security region with frequency response control, mainly comprises the following steps.

[0114] 1) Taking the UK 2030 power system (GB 2030 power system) as test system. Information of the synchronous generator is shown in Table 1.

TABLE-US-00001 TABLE 1 Related parameters of the synchronous generator nuclear power closed loop open loop plant set gas turbine gas turbine number of units 4 100 30 rated capacity (MW) 1800 500 100 minimum output (MW) 1400 250 50 no-load cost c.sub.g.sup.nl (£/h) 0 4500 3000 marginal cost c.sub.g.sup.m (£/MWh) 10 47 200 start-up cost c.sub.g.sup.st (£) — 10000 0 duration time (h) — 4 4 inertial time coefficient 5 4 4 H.sub.g (s) droop control parameters 0.2 0.2 0.2 K.sub.droop-g maximum one-time — 10% 10% FM output ramping rate (MW/h) 360 100 20

[0115] The maximum and minimum load requirements of the system are 30 GW and 60 GW. The capacity of a single wind turbine generators is 1.5 MW, and the total wind power capacity of the system changes according to demand. In each case, the total wind power output accounts for about 35% of the load. The load damping parameter is set to D=0.5%/Hz. Considering the typical N−1 failure scenario, the maximum power fluctuation of the system is the push operation of the synchronous unit with the largest capacity ΔL.sub.max=1800 MW. The limit value of the frequency drop rate is (dΔf/dt).sub.max=0.5 Hz/s, and the lowest point of the frequency is Δf.sub.nadir=0.5 Hz/s. The unit commitment is solved by gurobi.

[0116] 2) Determining the influence of wind turbine generators security region on unit commitment.

[0117] It can be seen from FIG. 1 that the security region of wind turbine generators changes with the changes of wind speed, and the security region has different effective constraints under different wind speeds. In this embodiment, the distribution of effective constraints at different wind speeds is shown in Table 2. In the FIG. 1, line A represents the rotor rotational speed constraints, line B represents the stability boundary constraints, and line C represents the output constraints. The wind speed is shown in FIG. 2, wherein line D represents the rated wind speed.

TABLE-US-00002 TABLE 2 Distribution of effective constraints at different wind speeds wind speed(m/s) 7.2< 7.2-9 >9 effective rotor stability output constraints rotational constraints constraint speed constraints

[0118] Therefore, the period of effective constraint distribution is as follows.

TABLE-US-00003 TABLE 3 Period distribution of effective constraints dispatch point 6-15 4-6, 16-18 0-3, 19-23 effective rotor stability output constraints rotational constraints constraints speed constraints

[0119] It can be seen from Table 2 and Table 3 that in the high wind speed section, the security region constraints are mainly determined by the output constraints. In the medium wind speed section, the security region constraints are mainly determined by the stability constraints. In the low wind speed section, the security region constraints are mainly determined by the rotor rotational speed constraints. The security region of the wind turbine generators when provides inertia response changes with the changes of wind speed. Therefore, the inertia response parameter of the wind turbine generators should not be set to a fixed value, but should be optimized in real time with changes of wind speed and system status.

[0120] The system frequency indexes are shown in FIG. 3. RoCoF and FN are the system frequency conditions when the security region is not considered, and RoCoF-SR and FN-SR are the system frequency conditions when the security region is considered. It can be seen from FIG. 3 that the method provided by the present invention can meet the needs of system frequency stability. The frequency response output of wind turbine generators is shown in FIG. 4. Wherein, SR is the security region of the wind turbine generators when provides frequency response, PFR and IR respectively are the frequency response output of the wind turbine generators when the security region is not considered, and PFR-SR and IR-SR respectively are the frequency response output of the wind turbine generators when the security region is considered.

[0121] It can be seen from FIG. 3 that when the security region of wind turbine generators is not considered, the frequency response output of wind turbine generators at dispatching points 1-3 and 21-23 will exceed the security region of the wind turbine generators, which may cause the wind turbine generators cannot be safely and stably operated, or will overestimate the frequency response capability of the wind turbine generators and causes the frequency response output of the wind turbine generators cannot meet the system frequency requirements, and resulting system frequency becoming unstable. The method provided by the present invention can simultaneously meet the system frequency stability and the wind turbine generators security region requirements, and ensure the safe and stable operation of the system.

[0122] 3) The influence of wind turbine generators reserve capacity on frequency response output.

[0123] When considering the reserve capacity of wind turbine generators, its frequency response output is shown in FIG. 5. Wherein, SR-D is the security region constraints when considering the reserve capacity, and PFR-D and IR-D respectively are the frequency response output of the wind turbine generators when considering the reserve.

[0124] According to the analysis in the previous section, the main effective constraints of this embodiment are the output constraints of the wind turbine generators. Therefore, when the wind power has a certain amount of reserve capacity, it can effectively expand the security region of the wind turbine generators, thereby improving the ability of the wind turbine generators to provide frequency response.

[0125] To ensure the stability of the system frequency, when the wind turbine generators inertia response is insufficient, more synchronous generators need to be launched. Since the synchronous generators are restricted by minimum output and climbing constraints, the launch of a large number of synchronous generators will compress the penetration rate of wind turbine generators and cause a large amount of wind curtailment.

[0126] In this embodiment, the wind power utilization rate is shown in Table 4, and the wind power utilization rate unlisted dispatching points is 100%. At the dispatch points of 0-2 and 23, due to the influence of thermal power climbing constraints, it is impossible to fully balance the fluctuations of the wind turbine generators output, which results in partial wind power curtailment. During this time period, the curtailed wind can be fully utilized as a reserve. Other dispatching points need to sacrifice part of the wind power output as reserve capacity. It can be seen from Table 4 that after considering the reserve of wind turbine generators, although part of the wind power output is reduced, the security region of wind power is expanded, and the inertia response capability of wind turbine generators is enhanced, which reduces the pressure of synchronous generators to provide frequency response, thereby reducing the number of online synchronous power generator, and increasing the utilization rate of wind power output.

[0127] The method provided by the present invention can effectively optimize the wind power reserve capacity and fully guarantee the wind power utilization rate.

TABLE-US-00004 TABLE 4 Wind power utilization rate dispatching points 0 1 2 3 4 19 21 22 23 security region constraints are not considered 95% 88% 88% 100% 100% 100% 100%  100%  98% security region constraints are considered, 52% 22% 64%  77%  91%  97% 81% 42% 41% and reserve is not considered both security region constraints and reserve 95% 88% 88% 100% 100% 100% 98% 95% 95% are considered

[0128] From the experimental results, it can be seen that the unit commitment method considering the security region of wind turbine generators with frequency response control proposed by the present invention can ensure the safe operation of the wind turbine generators while meeting the needs of system frequency stability, and can make full use of the reserve capacity of the wind turbine generators to improve the ability of providing frequency response by the wind turbine generators, improve wind power utilization and reduce the wind curtailment.

[0129] In summary, the present invention proposes a unit commitment method considering both frequency stability and safe operation of wind turbine generators. Comprehensively considering the stability constraints, rotational speed constraints and output constraints of wind turbine generators, and the security region of wind turbine generators when provides frequency response is deduced. With the goal of minimizing the operating cost of synchronous generator, the system frequency stability constraints and wind turbine generators security region constraints are added to the traditional unit commitment model to achieve economic, stable and safe operation of the entire system. The study of the embodiment shows that the method provided by the present invention can effectively guarantee the stability of the system frequency and the safe operation of wind turbine generators. It can make full use of wind power resources by optimizing the reserve capacity of wind turbine generators, and can provide guidance to the set of frequency response parameters of wind turbine generators and the unit commitment considering high-penetration wind turbine generators.