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Modified blinder-based out-of-step relays with renewable integration

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Abstract

This research investigates the impact of renewable energy integration on blinder-based Out-Of-Step (OOS) relays, which protect synchronous generators from unstable power swings. Challenges arise in distinguishing stable and unstable power swings due to fault ride-through (FRT), control operation, and weak inertia of renewable sources. Modified blinder-based OOS relays are analyzed in MATLAB using a modified Kundur two-area system. Findings show that high renewable energy penetration increases the likelihood of blinder-based relay failures during transient and small-signal stability incidents. The study also explores the effects of power swings on neighboring and remote OOS relays. Additionally, it examines the interaction between synchronous generators and renewable sources, and their impact on system stability during FRT. Modifications to single and double blinder-based OOS relays and their synchronization are proposed. The study concludes that the modified relay protection functions as inoperable for stable swings and operable for unstable swings, enhancing overall relay performance.

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Authors and Affiliations

  1. U. V. Patel College of Engineering, Ganpat University, Mehsana, India

    Jigneshkumar P. Desai

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  1. Jigneshkumar P. Desai
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JPD contributed to conceptualization, implementation, methodology, data curation, writing—original and final draft preparation, visualization, investigation, research and development, training, testing, reviewing, simulation, and result validation.

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Correspondence to Jigneshkumar P. Desai.

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Appendix and nomenclature

Appendix and nomenclature

1.1 Appendix A1: Kundur two area system details

The system is made up of two analogous segments linked by a highly sensitive tie line. Each region has two generating units with 900 MVA and 20 kV ratings. The following are the generator limits in p.u. based on their rated MVA and KV base:

Generator Parameters:

Bsat = 9.6; Yt1 = 0.9; H = 6.5(G1 & G2) H = 6.175 (G3 & G4); KD = 0;

Xd = 1.8; Xq = 1.7;Xl = 0.2;Xd' = 0.3. Xq' = 0.55; Xd'' = 0.25;Xq'' = 0.25; Ra = 0.0025. Td0' = 8.0 s; Tq0' = 0.4 s'; Td0'' = 0.03 s; Tq0'' = 0.05 s. Asat = 0.015

For each step-up transformer:

ZT = 0 + j0.15 pu on 900 MVA & 20/230 kV base. Off nominal ratio = 1.0

For Transmission line:

r = 0.0001pu/km; xL = 0.001pu/km; bC = 0.00175 pu/km and length = 220 km

The system is operational, with region 1 exporting 400 MW to area 2, and generators parameters:

G1:P1 = 700 MW;Q = 185MVAr; ET = 1.03(20.2◦) G2:P2 = 700 MW;Q = 235MVAr; Et = 1.01(10.5◦) G3:P3 = 719 MW;Q = 176MVAr; Et = 1.03(6.8◦) G4:P4 = 700 MW;Q = 202MVAr; Et = 1.01(17.0◦)

The following are the loads and reactive power provided by shunt capacitors on buses 7 and 9:

Bus 7: PL = 967 MW;QL = 100MVAr; QC = 200MVAr. Bus 9: PL = 1767 MW; QL = 100MVAr; QC = 350MVAr

1.2 Appendix A2: Turbine, governor, and excitation system model’s details

Steam turbine and governor modeling parameters:

Regulator gain

1

Permanent droop

0.05

dead zone

0 s

Speed relay

0.001 s

servo-motor time constants

0.15 s

Gate opening limits

Vgmin = −0.1; Vgmax = 0.1; Gmin = 0; Gmax = 4.496

Speed

3600 rpm

Steam turbine time constants

T2 = 0 s; T3 = 10 s T4 = 3.3 s;T5 = 0.5 s

Turbine torque fractions

F2 = 0;F3 = 0.36 F4 = 0.36; F5 = 0.28

Initial power

0.7778 pu

Excitation modeling data are as follows:

The low-pass filter time constant

0.002 s

Regulator gain and time constant

200 and 0.001 s

Exciter

Ke = 1 Te = 0 s

Transient gain reduction

Tb = 0 s; Tc = 0 s

Damping filter gain & time constant

Kf = 0; Tf = 0 s

Regulator output limits & gain

Efmax =  + 12.3, Efmin = −12.3, kp = 0

1.3 Appendix A3: Wind power source modeling as renewable source with usual notation

Fault ride through strategy

Mode:1 as Reactive power support, Mode:2 as zero power mode

UVRT trigger constant, OVRT trigger constant, FRT band constant, FRT max time

0.8, 1.2, 0.01, 5 s

Proportional gains: kUVRT, kOVRT

2, 2

Voltage protection parameters in p.u: Vmax, Vmaxdelay, Vmin, Vmindelay

1.25, 0.1, 0.8,5

Frequency protection parameters in p.u.: fmax, fmaxdelay, fmin, fmin delay

1.05, 1, 0.95, 1

Maximum Power of 1 unit, Total unit in W1

2 MW, 50

1.4 List of symbols

G1, G2; G3; G4

Generator 1, generator 2, generator 3 and generator 4 respectively

\(\theta 1,\theta 2;\theta 3;\theta 4\)

Rotor angle 1, rotor angle 2, rotor angle 3, rotor angle 4 respectively

\(I_{{{\text{fl}}}}\)

Full load current

\(Z_{{{\text{base}}}}\)

Base value of Impedance

\(KV_{{{\text{base}}}}\)

Base value of KV of system

\(B_{{{\text{g}}_{1} }}\)

Generator bus 1

\(B_{{{\text{g}}_{2} }}\)

Generator bus 2

\(B_{{{\text{g}}_{3} }}\)

Generator bus 3

\(B_{{{\text{g}}_{4} }}\)

Generator bus 4

\({\text{MVA}}_{{{\text{base}}}}\)

MVA base value of the system

R

Resistance in ohm

X

Reactance in ohm

W1, W2, W3, W4

Wind generator 1, wind generator 2, wind generator 3, wind generator 4 respectively

tcr

Critical Clearing time

Td1

Delay time 1 between Zmho and inner blinder

Td2

Delay time 2 for between right to left blinder ad vice versa

Td3

Delay time between two right or left blinder in DB

\(\delta\)

Power angle between generator and load

I

Current from the stator of the generator during out of step conditions

Imax

Maximum current through generator stator

t

Simulation run time

VPOC

Voltage at the point of common coupling

PPOC

Active power at the point of common coupling

QPOC

Reactive power at the point of common coupling

1.5 List of abbreviations

CCT

Critical clearing time

CT

Current transformer

DB

Double blinder

EAC

Equal area criteria

EMTDC

Electromagnetic transients including DC

LVRT

Low voltage ride through

GU

Generator transformer unit

HV

High voltage

OOS

Out of step

PT

Potential transformer

POC

Point of common coupling

PSCAD

Power system computer-aided design

SB

Single blinder

MATALB

Math works laboratory

SIMULINK

MATLAB-based graphical programming environment for modeling

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Desai, J.P. Modified blinder-based out-of-step relays with renewable integration. Electr Eng 106, 493–507 (2024). https://doi.org/10.1007/s00202-023-01993-2

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