Coordinated optimization method for vsc-hvdc frequency synchronization control and hydro power primary frequency regulation

Patent metadata

Field	Value
Publication number	US-2026088624-A1
Application number	US-202519026459-A
Country	US
Kind code	A1
Filing date	Jan 17, 2025
Priority date	Sep 24, 2024
Publication date	Mar 26, 2026
Grant date	—

Abstract

A coordinated optimization method for VSC-HVDC Frequency Synchronization Control and primary frequency regulation of hydropower includes: obtaining optimal PI parameters of the VSC-HVDC Frequency Synchronization controller from a first layer output of a dual-layer optimization model for coordinated parameters of VSC-HVDC Frequency Synchronization and primary frequency regulation; and obtaining a target PID control parameters from a second layer output of the dual-layer optimization model. The coordinated optimization method further includes adjusting the optimal PI parameters of the synchronization controller based on the target selection range and updating the PID control parameters of the primary frequency regulation system of hydropower based on the target PID control parameters. This approach aims to address the challenge of balancing the frequency response speed between the VSC-HVDC synchronization system and the primary frequency regulation system of hydropower.

First claim

What is claimed is:

1 - 10 . (canceled)

11 . A coordinated optimization method for VSC-HVDC frequency synchronization control and primary frequency regulation in hydropower, applied to a grid frequency regulation system, wherein the grid frequency regulation system comprises a dual-layer optimization model for coordinated parameters of Voltage Source Converter based High Voltage Direct Current Transmission (VSC-HVDC) Frequency Synchronization and primary frequency regulation, and the coordinated optimization method comprises:
obtaining a target selection range for K p and K i parameters of a VSC-HVDC frequency synchronization controller from a first layer output of the dual-layer optimization model for the coordinated parameters of the VSC-HVDC Frequency Synchronization and the primary frequency regulation, wherein a first layer comprises a large power step disturbance scenario, where a first objective function minimizes two integral indices: frequency deviations of sending and receiving grids and a power regulation magnitude of a VSC-HVDC system; obtaining target Proportional-Integral-Derivative (PID) control parameters from a second layer output of the dual-layer optimization model for the coordinated parameters of the VSC-HVDC Frequency Synchronization and the primary frequency regulation, wherein a second layer comprises a second objective function constrained by a shortest time required for primary frequency reserve activation in governor parameter-controlled generation units; and adjusting a selection range of the K p and K i parameters of the VSC-HVDC frequency synchronization controller based on the target selection range, and updating PID control parameters of a hydro power primary frequency regulation system based on the target PID control parameters.

12 . The coordinated optimization method according to claim 11 , wherein the first objective function is expressed as:

min
⁢

F
1

(

x
c

)

=

∫
0

t
sim

Δ
⁢

f
⁡
(
t
)

⁢
dt

+

10
α

⁢

∫
0

t
sim

Δ
⁢

P

Tp
.
double

(
t
)

⁢
dt

wherein minF 1 (x c ) represents the first objective function; t sim denotes a simulation duration;
x c refers to parameters of a VSC-HVDC Frequency Synchronization control loop; Δf inv is a sum of frequency deviations for the sending and receiving grids; ΔP TP.double represents a sum of power regulation values for the VSC-HVDC synchronization at both sending and receiving ends; and α is a scaling factor for adjusting magnitude.

13 . The coordinated optimization method according to claim 12 , wherein functional expressions of Δf(t) and ΔP TP.double are as follows:

{

Δ
⁢

P

TP
.
double

=

Δ
⁢

P

TP
.
rec

-

Δ
⁢

P

TP
.
inv

Δ
⁢
f

=

Δ
⁢

f
rec

+

Δ
⁢

f
inv

wherein ΔP TP.ree represents a power regulation amount for a sending-end system, ΔP TP.inv represents a power regulation amount for a receiving-end system, Δf ree denotes a frequency deviation of the sending-end grid, and Δf inv denotes a frequency deviation of the receiving-end grid;
functional expressions for ΔP TP (t) and Δf(t) are as follows:

{

Δ
⁢

P

TP
.
rec

(
t
)

Assignees

• Univ Kunming Science & Technology

Inventors

• Shu Hongchun
• Shao Zongxue
• Wang Guangxue
• He Tingyi
• Tang Yutao
• Mu Runzhi

Classifications

• Y02E60/60

  Arrangements for transfer of electric power between AC networks or generators via a high voltage DC link [HVCD] · CPC title

• H02J3/40

  Synchronisation of generators for connection to a network or to another generator · CPC title

• H02J2103/30

  Simulating, planning, modelling, reliability check or computer assisted design [CAD] of electric power networks · CPC title

• H02J2101/20

  Dispersed power generation using renewable energy sources · CPC title

• H02J2103/35

  Grid-level management of power transmission or distribution systems, e.g. load flow analysis or active network management · CPC title