Effectiveness of Wind Turbine Fast Frequency Response Control on Electrically Distanced Active Power Disturbance Mitigation

Abstract

In a power system, increased wind energy penetration changes the dynamic system response to active power disturbances. Due to the lack of natural inertial response from converter connected wind sources, an advanced converter control is required for maintaining a transient frequency stability of modern power systems with high shares of renewable energy sources. This research examines the new wind turbine fast frequency response control capability on the addressing electrically near and distanced active power imbalances considering transient dynamics system parameters. The focus of this research is to analyze the effectiveness of wind turbine fast frequency response control in reduced inertia power system modeled as a four-inertial center system. The study is done on the case of Croatian power system with "real life" data for power generation, wind production, primary frequency regulation, and load shedding schemes. The simulation and scenario analysis are conducted under the MATLAB/Simulink environment using detailed power transmission system model.

Full text

Effectiveness of Wind Turbine Fast Frequency
Response Control on Electrically Distanced Active
Power Disturbance Mitigation
Josip Đaković, Perica Ilak, Tomislav Baškarad, Matej Krpan, Igor Kuzle
Department of Energy and Power Systems
University of Zagreb Faculty of Electrical Engineering and Computing
Zagreb, Croatia
josip.djakovic@fer.hr, perica.ilak@fer.hr, tomislav.baskarad@fer.hr, matej.krpan@fer.hr, igor.kuzle@fer.hr
Abstract —In a power system, increased wind energy
penetration changes the dynamic system response to active
power disturbances. Due to the lack of natural inertial
response from converter connected wind sources, an advanced
converter control is required for maintaining a transient
frequency stability of modern power systems with high shares
of renewable energy sources. This research examines the new
wind turbine fast frequency response control capability on the
addressing electrically near and distanced active power
imbalances considering transient dynamics system parameters.
The focus of this research is to analyze the effectiveness of wind
turbine fast frequency response control in reduced inertia
power system modeled as a four-inertial center system. The
study is done on the case of Croatian power system with “real
life” data for power generation, wind production, primary
frequency regulation, and load shedding schemes. The
simulation and scenario analysis are conducted under the
MATLAB/Simulink environment using detailed power
transmission system model.
Keywords— Converter control, Fast frequency response,
Frequency nadir, Inertial centers, Low-inertia power system,
Primary regulation, RoCoF, WindINERTIA.
ABBREVIATIONS
DFIG
Doubly-Fed Induction Generator
EM
Electromagnetic
FFR
Fast frequency response
GE
General Electric
HPP
Hydropower plants
IC
Inertial center
MPPT
Maximum power point tracking
OS
Osijek
PCC
Point of common coupling
PP
Power plants
RCCS
Rotor-Side Converter Control
RES
Renewable energy sources
RI
Rijeka
RoCoF
Rate of Change of Frequency
RKE
Rotational kinetic energy
ST
Split
TPP
Thermal power plants
UFLS
Under-Frequency Load Shedding
WF
Wind farm
WT(G)
Wind turbine (generator)
ZG
Zagreb
I. INTRODUCTION
Modern power systems around the globe are shifting
towards a high share of renewable energy sourced generation
which changes the overall system transient dynamics.
Conventional power sources contribute to the power system
”stiffness” with a large amount of kinetic energy
synchronously connected to the grid [1]. Renewable energy
sources (RES) such as wind and solar power plants mainly
interface with the power system through frequency
converters. However, these converters are often controlled in
a manner that decouples generating plants from system
frequency disturbances, resulting in reduced power system
inertia. i.e., the ability of a system to oppose frequency
changes with the rotational kinetic energy [2]. In the power
systems with a low share of RES, wind plants were allowed
to produce variable power output according to available wind
conditions. Such stochastic power sources have not been
considered important in maintaining power system stability
[3]. Nowadays, due to environmental and economic issues,
renewable sources rapidly displace conventional generators,
reaching significant production shares, which open many
concerns regarding power system operation and safety.
Hence, wind power involvement in frequency response is
undoubtedly a necessary measure to preserve reliability in
modern power systems. As converter connected power
sources do not provide inherent frequency (inertial) response
to active power disturbances, an advanced wind turbine
control is necessary to emulate frequency response [4].
In recent years, a significant amount of published papers
dealt with wind turbine “inertial response” capabilities [5-9].
However, it was shown that wind turbine could not emulate
inertial response in the same manner as synchronous
generators [10]. In [11] the WT control strategy to mitigate
the impacts of reduced system inertia was investigated on the
large power system considering electrical distances. The
share of wind power production was assumed to be less than
1% of total production which is not relevant for wind

generation and low-inertia analyses considering expected
future RES penetrations of 20% and higher.
Synchronous generators have an instantaneous response
on the frequency deviation, absorbing disturbances with its
rotating masses, while modern converter-based WTGs
cannot provide the same response due to converter
limitations. Therefore, here, the inertial response of a
synchronous generator will be emulated with the Fast
Frequency Response (FFR) capability of the WT, also
referred to as ‘synthetic inertia’. Although, previous research
has shown that the wind frequency response can contribute
to the transient frequency stability, but due to considerably
simplified models, the actual effectiveness in geographically
distributed power production and consumption is
insufficiently investigated. Therefore, the focus of this paper
is to quantify the impact of a wind turbine’s FFR on low-
inertia system transient dynamics when active power
disturbances occur in spatially distanced areas. Also, varying
FFR capabilities of different WT types are accounted for in
this research.
This paper is organized into four sections. In section II
the research methodology with a representative model of the
Croatian power system and the implemented WT FFR
control is presented. The section III presents and describes
analyzed scenarios and discuses obtained results. The
conclusion regarding the method effectiveness and
applicability are given in section IV.
II. METHODOLOGY
A. Power system model
For this research, a detailed model of the Croatian
electric power system was developed in the
MATLAB/Simulink. The model of Croatian 110 kV power
system shown in Fig. 1 is constructed as a four-area system
where each area represents one inertial center (IC) (Fig. 2).
The inertial center concept was first introduced in [12]
where the contribution of DFIG in short-term frequency
control was investigated. According to the geographical
locations of the Croatian Power Plants (PP), inertial centers
are formed in a manner that realistically represents Croatian
110 kV power system.
Fig. 1 Geographical position of different types of power plants in Croatia
Each IC abbreviation is named after the largest city in
the region. The southernmost IC is Split (ST) which consists
of all wind farms (WF) and hydropower plants (HPP) in the
area. All WFs are modeled as one equivalent Simscape
Doubly-Fed Induction Generator (DFIG) phasor model with
implemented fast frequency control, described later in the
text. Most of the Croatian WFs are comprised of variable
speed Type 3 (DFIG) and Type 4 (Full-converter) WTGs
that inherently have similar transient dynamics [4]. This
justifies the usage of only DFIG type to simplify analysis
and decrease calculation time. HPPs are aggregated in one
three-phase synchronous machine block with a hydraulic
turbine, governor and excitation system block.
Fig. 2 The four inertial centers model of Croatian power system
Power plants are separated by the type, aggregated and
represented with the equivalent power plant with the inertial
constant estimated for entire IC according to [13]. The
generators and transmission system are connected via the
step-up transformer model. Every IC has its own switchable
three-phase RLC load capable of performing an Under-
Frequency Load Shedding (UFLS). WF and HPP are
attached to the IC node via separated three-phase π-section
lines with IC nodes are directly linked to interface buses
toward other IC buses. Other three ICs: Rijeka (RI); Zagreb
(ZG); and Osijek (OS) only have thermal (TPP) and HPP.
The IC parameters are shown in Table I [14]. The turbine
controllers of synchronous generators use droop
characteristic and dead-zone settings acquired from Croatian
TSO.
Currently, installed WTG capacity in Croatia is around
540 MW of which only one 6 MW-plant is Type 2, not
capable of implementing converter-based frequency control
so that plant is omitted from simulations.
TABLE I. PARAMETERS OF CROATIAN INERTIAL CENTERS
Inertial
centers (IC)
ST
RI
ZG
OS
HPP
TPP
HPP
TPP
HPP
TPP
Capacity
(MW)
1384
701
474
13601
246
89
H (s)
3.59
4.16
2.88
4.21
1.68
4.93
1
Half of NPP Krško nominal power was included due to dual ownership
with Slovenia
ST
RI
ZG OS
SRB
HUN
SLO
BIH
TPP-RI
ST
RI ZG
OS
Load-ST
Load-RI
HPP-RI
TPP-ZG
Load-ZG
HPP-ZG
Load-OS TPP-OS
HPP-ST
WTG-ST
Bus-RI
Bus-ST
Bus-ZG
Bus-OS

Droop R (%)
4
5
4
5
4
8
Dead zone
(mHz)
10
20
20
10
20
5
Power ramp
(p.u./s)
0.1
0.00028
0.1
0.0001
0.2
0.005
IC Distances
ST – 150km – RI – 100km – ZG – 200km – OS
Table II shows the nominal WTG power data used in the
model. The parameters were selected to match loading
conditions on the analyzed day, explained later in the text.
TABLE II. WTG DATA
WTG
farm
Rated active
power (MW)
Rated
apparent
power (MVA)
Rated wind
speed (m/s)
Rated
power
factor
DFIG
491
545
14
0.9
Maximum rotor speed is restricted to 1.2 p.u. of
synchronous speed at nominal wind speed of 14 m/s,
producing rated WTG active power. With the described
model components, the UFLS program is implemented
according to the Croatian Grid Code for the island operation
mode [17]. The first stage of UFLS is prescribed at the
49.20 Hz and the second is at 49.00 Hz.
B. WT Fast Frequency Response Control
Most of the modern WTs are controlled to follow an
optimal power-speed characteristic to extract maximum
power at a wide range of wind speeds conditions (MPPT).
The generic control loop, extended with the GE
WindINERTIA control block [17] for WTG power control
is illustrated in Fig. 3. The frequency control module is
added to the Rotor-Side Converter Control System (RCCS)
implemented in DFIG control algorithm [16]. The
measurement block passes relative grid angular frequency
deviation,  , to the frequency control block which
processes the signal and outputs FFR power reference, ,
to the RCCS summation element on the negative input (as
the frequency control reacts only on frequency decrease).
The MPPT block output,  , is the MPPT power
reference defined by actual rotor angular speed  and
implemented tracking characteristics. Overall active power
reference,  , (composed of MPPT, losses and FFR) is
subtracted from measured active power output  and passed
as a power error  to the PI-regulator in Power regulator
block, which output is the reference rotor EM torque-
producing current component  . The actual rotor
current component errors Δ and Δ are processed in
current PI-regulator. The output of Current regulator is
rotor converter reference voltage signals 
 regulating
active power and 
 controlling AC rotor voltage. The FFR
control block parameters are set according to the GE wind
turbine model parameters [17]. The purpose of FFR is the
high-frequency disturbances limitation, while small constant
frequency disturbances are neglected. Therefore, the Dead
Zone block threshold setting is 0.0025 p.u. Low-pass filter
(  s) signal is multiplied with the gain    and
passed to Washout filter (   s) to form a smooth
error signal while Saturation and Rate Limiter blocks
restrict signal down-rate to -0.1 p.u./s (due to negative
frequency error) and amplitude to -0.1 p.u.
Fig. 3 RCCS extended with FFR
MPPT
Losses
PMPPT
PL
Pref
FFR PFFR
Δωgrid
Measurements
Iqr_ref
Iqr
ΔIqr
ΔIdr
Vqr, Vdr
ωr
ωr, V, I
V, I
Vref
Idr
Idr_ref
Power
regulator
P
+-ΔP
RCCS
+-Current
regulator
-
+
AC
Voltage
regulator
Rotor-Side
Converter
+-
-
FFR

III. SCENARIO ANALYSIS
The Croatian power system is a part of ENTSO-E
interconnection with tie-lines toward Slovenia, Hungary,
Serbia and Bosnia and Herzegovina (Fig. 2). In this paper,
the island operation was assumed to emulate low inertia
power system with high wind production share. To simulate
realistic loading situation, power production data of
November 29th of 2016 were used. On that day, ~20%
domestic power production was covered by WTs, ~50% was
covered by HPP production and remaining load is covered
by TPP. Average load on that day was 2300 MW. The
cross-border imports of ~500 MW have been dispatched to
domestic power plants proportional to their relative share in
overall production. Table III shows the initial generation
and load conditions in each of the ICs. The plants are
simulated with sufficient spinning reserve for primary
frequency regulation provision according to the Croatian
Grid Code.
TABLE III. INITIAL CONDITIONS IN THE ICS
Initial conditions
(MW)
ST
RI
ZG
OS
∑
WTG
491
-
-
-
491
HPP
529
360
118
-
1008
TPP
-
455
360
45
860
Load
510
975
733
82
2300
Gen-Load
510
-160
-255
-37
58
A. Case 1: High load trip-in IC-ST
The first analyzed case is a high load tripping-in in ST
IC node. Instantaneous load increase disturbance is set at
120 MW which is equivalent to HPP ‘Dubrovnik’
generation tripping-out at the November 29th of 2016. Two
scenarios were analyzed; the first with enabled wind turbine
FFR and the second without FFR. Wind power output
conditions were selected to cover ~21% of load at nominal
parameters, i.e., the wind speed at 14 m/s during all
simulation periods, and initial production at the nominal
output power of 491 MW. From the standpoint of severity
and security of supply, nominal wind speed is considered as
the worst-case scenario due to the highest share of inertia-
less WTs production and the lowest share of synchronous
rotational kinetic energy presented in the power system. The
first UFLS stage trip is set at 40 MW at IC-ZG, and the
second was 70 MW at IC-OS.
B. Case 2: High load trip-in IC-ZG
The second scenario was simulated at the same date and
under the same loading and UFLS conditions as the Case 1.
This time load disturbance is in 250 km distant IC-ZG
(Table I). The intention of this case was to emulate active
power disturbance equal to partial generation trip of TPP
‘Zagreb’ (120 MW). As in the previous case, disabled and
enabled FFR control scenarios are analyzed.
C. Results
The simulations were conducted for 150 seconds period.
Load tripping occurs at the 50th second when the system
achieves stable operation. Fig. 4 shows frequency deviation
results for all four scenarios. The yellow and blue curve
(Fig. 4) show the frequency behavior measured in IC-ST
with the enabled FFR control.
Fig. 4 Frequency deviations in IC-ST
Although the FFR is used, the first stage of Load
Shedding occurred in all scenarios, but the second stage was
successfully prevented with FFR in both trip locations.
Scenarios with disabled FFR led to the second LS stage
which caused fast frequency restoration close to the nominal
value because the amount of shredded load is approximately
equal to the initial load disturbance. After the system inertial
response, the primary regulation of synchronous generators
and WTs FFR restored the frequency to steady-state
condition at lower than nominal values. The difference
between frequency nadir values can be explained by the
amount of rotational kinetic energy (RKE) present in
different ICs, i.e., a trip in IC with a higher amount of RKE
cause a lower frequency deviation.
The comparison of frequency nadirs measured in IC-ST
and IC-ZG for the same scenario of IC-ZG load tripping is
presented in Fig. 5. In that figure, the effect of unequal
frequency deviation propagation throughout the system can
be observed. As can be expected, a higher deviation occurs
in the area with a smaller amount of RKE, which is IC-ST
with WTGs.
Fig. 5 Frequency nadir in IC-ST and IC-ZG with FFR

Fig. 6 shows the rate of change of frequency (RoCoF)
after the disturbance in the IC-ST. In the early stage of
disturbance, RoCoF is equal whether the FFR is enabled or
not. After several seconds, FFR starts to damp frequency
oscillations, when the deviation is close to nadir. An
interesting phenomenon is observed when IC-ZG trip and
IC-ST trip are compared. IC-ST trip instantly produces -0.4
Hz/s RoCoF in the IC-ST (orange curve), but IC-ZG trip
causes time delayed, higher amplitude RoCoF (purple
curve).
Fig. 6 Rate of change of frequency
Wind turbine power outputs are shown in Fig. 7. Initial
491 MW WTs output starts to increase after the controller’s
threshold limit is passed in the case with FFR enabled. The
rate of change of power output is determined by Rate limiter
in FFR control block. When the FFR is disabled, power
output passes through a disturbance period after the load
tripping and soon after returns to the initial state.
Fig. 7 WTG power output
In Fig. 8, sudden energy extraction from the WT is
shown, which causes turbine rotor speed decrease. After this
power increase period, the WT energy recovery manifests as
the decrease in output, while rotor speed lowers. Results
have shown that the WT peak power output is higher when
the trip is closer to WTs, in this case in IC-ST.
Fig. 8 Wind turbine rotor speed
Consequently, the rotor speed approaches lower values
but the WT speed recovery time is similar in both FFR
scenarios. WT rotor speed does not change during the
disturbance when the FFR is excluded.
Fig. 9 depicts the power curve for a disturbance in all
considered scenarios, at IC-ST bus. IC-ST initially exports
510 MW (Table III) until the load tripping in 50th second.
With FFR enabled, generated power in IC-ST starts to
increase at higher rates than with disabled FFR. Activation
of UFLS reduces the power generation in all scenarios,
especially when 2nd LS stage is reached in scenarios with
disabled FFR. Initial 120 MW active power disturbance in
IC-ST causes a sudden drop in power production, while the
distanced trip in Case 2 induces higher than initial power
export towards affected IC-ZG.
Fig. 9 Active power in IC-ST
Finally, last two figures (Fig. 10 - 11) show the impact
of FFR control of all the WTGs on the reactive power
output and point of common coupling (PCC) voltage. WTGs
initially operate as under-excited induction generators in
PCC voltage regulation mode, absorbing reactive power
from grid. After the trip, PCC voltage drops to a lower value
(Fig. 11), reducing WTG reactive current absorption during
the disturbance (Fig. 10). The close-to-PCC load tripping
results in a much higher initial voltage collapse (blue line),
but the steady-state after-trip voltage is higher when a trip
occurs in IC-ST. In Fig 10., the WTG reactive power
absorption affected by PCC voltage can be observed. Fig. 11

clearly shows that the first stage of load shedding occurs
earlier in the case of load tripping in low inertia IC-ST.
Fig. 10 WT reactive power output
Fig. 11 PCC voltage
IV. CONCLUSIONS
In this paper, the effectiveness of the GE wind turbine
fast frequency response control on mitigating active power
disturbances in the low-inertia power system was presented.
The simulations carried out in this paper showed that the
electrical distance of power disturbance has an impact on
the wind turbine generator frequency response effectiveness
and system transient dynamic. The proposed control method
proved to be successful in reducing the frequency nadir and
preventing higher stages of under-frequency load shedding
in both analyzed cases. The impact of FFR on the early
stage RoCoF is negligible due to converter limitations on
power ramping and control threshold, but after the FFR
initiation, a significant influence on maintaining frequency
deviation can be observed. Simulations have shown that the
location of high power disturbance can affect local
frequency stability in a manner that disturbances closer to a
higher concentration of conventional plants result in lower
frequency excursions. On the other hand, areas with high
shares of wind power production lead toward lower
frequency stability capabilities. However, wind turbines
with FFR can improve frequency stability which was
presented and analyzed in this paper. Although the wind
turbine energy recovery period is inevitable after the
response, the amount and duration of power increase in
initial stages of disturbance are enough to help conventional
primary frequency control to restrict initial frequency
degradation.
The future research will examine the power system
operation with higher shares of RES and determine the
critical share when wind turbines should be compelled to
provide primary frequency response, i.e., have to operate by
de-loaded tracking characteristics.
ACKNOWLEDGMENT
This work has been supported in part by the Croatian
Science Foundation under the project WINDLIPS – WIND
energy integration in Low Inertia Power System (grant No.
HRZZ-PAR-02-2017-03).
The work of the authors is a part of the H2020 project
CROSSBOW–CROSS Border management of variable
renewable energies and storage units enabling a
transnational Wholesale market (Grant No. 773430). This
document has been produced with the financial assistance of
the European Union. The contents of this document are the
sole responsibility of authors and can under no
circumstances be regarded as reflecting the position of the
European Union.
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Josip Đaković (S’18) received the M.Sc. degree from the University of Zagreb
Faculty of Electrical Engineering and Computing in 2017. He is currently
pursuing his Ph.D. in Electrical Engineering as a researcher in renewable energy
projects. His scientific interests include electric power system analysis and
renewable energy integration.
Perica Ilak received the Ph.D. degree from the University of Zagreb Faculty of
Electrical Engineering and Computing in 2016. He is currently working as a
researcher at the Department of Energy and Power System of University of
Zagreb. Ilak participated in many research studies in the energy sector and is
experienced modeler whose research of interests includes modeling large-scale
problems with stochastic elements
Tomislav Baškarad (S’18) received the B.Sc. and M.Sc. degrees in electrical
engineering from University of Zagreb Faculty of Electrical Engineering and
Computing. He began his Ph.D. studies in 2018 at Department of Energy and
Power Systems. His research interests include renewable energy sources with
emphasis on photovoltaic plants, mathematical modeling of a power system,
frequency stability and active power control.
Matej Krpan (S’17) received the M.Sc. degree in electrical engineering from
University of Zagreb in 2016. He is currently pursuing a Ph.D. degree at the
Department of Energy and Power Systems. His research interests include grid
frequency support from wind power plants, power system dynamics and control
and low-inertia power systems.
Igor Kuzle (S’94-M’97-SM’04) is a Professor at the University of Zagreb
Faculty of Electrical Engineering and the head of the Department of Energy and
Power Systems. He was the project leader for more than 60 technical projects for
industry. In period 2010-2015 he was the IEEE PES Chapter Representative for
Central Europe and Scandinavia in IEEE Region 8. His scientific interests
include electric power systems dynamics and control, maintenance of electrical
equipment, smart grids as well as power system analysis and integration of
renewable energy sources.