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Increase of the Rate of Change of Frequency (RoCoF) and its impact to
the Conventional Power Generation in the Island of Ireland
or
Transient stability of conventional generating stations during times of
high wind penetration on the Island of Ireland
September 2015, International Energy Studies Workshop, Rome, Italy
Marios Zarifakis, Electricity Supply Board, Dublin, Ireland
www.esb.ie
TCD
© 2015 ESB, TCD
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Real Frequency Event, 27.04.2014, DBP
Frequency and
Power traces
Pnom=390MWFrequencyPower Output
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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ESB – Electricity Supply Board
• Vertically Integrated Utility
• Involved in most types of generation
• The first ESB generation plant (in 1927) was a hydro
station at Ardnacrusha
• The ESB group is one of the largest wind
generators in Ireland, and ESB has been involved in
development, construction and management of
Irelands wind resources since the 1980s.
• Large international business.
• ESB owns a number of international power stations
and has O&M contracts for several other generation
stations.
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Transmission System Ireland
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European Transmission System
ROCOF Project Board Meeting
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Increase of sustainable energy sources
EU 2020 Policy
20% of the EU’s energy demand to be from renewable sources by 2020
Irish Government Targets
40% of Ireland’s total electricity consumption to be met by renewables
TSO’s DS3 Programme
Safe and secure power system with high levels of renewable generation
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Operating Zones
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System and Wind Generation
ROCOF Project Team Meeting
Areas where Wind Generation had to be curtailed
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Timeline
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ESB Generation
Focus
Perspectives and Dependencies
EirGrid & SONI
Focus
Mechanical Issues
Turbine Integrity
Generator Integrity
Security of supply
Voltage Stability
Loading of Lines
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Frequency Scale
50Hz
49Hz51Hz
Generation Consumers
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Generation-Load Balance
Generation
Load
48.5
49.0
49.5
50.0
50.5
51.0
-2 -1 0 1 2 3 4 5 6 7 8
Fre
qu
en
cy (
Hz)
Time (s)
Sample Low Frequency RoCoF
Frequency (Hz)
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Frequency and the Rate of Change of Frequency
Frequency
RoCoF=𝑑𝑓
𝑑𝑡
RoCoF
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RoCoF mathematical definition
(simplistic view)
𝒅𝒇
𝒅𝒕=
𝒇𝒏𝑷
𝟐𝑯𝒔𝒚𝒔𝒕𝒆𝒎𝑺𝒃With:
𝑓𝑛= System Frequency
𝐻𝑠𝑦𝑠𝑡𝑒𝑚= System Inertia
𝑃 = Lost load or generation
𝑆𝑏= MVA rating of the system
GenerationConsumers
50Hz
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Proposed Definition of RoCoF
The new definition by both TSOs, EirGrid and SONI, for the Grid Code is:
“remain synchronised to the Transmission System for a Rate of Change of Frequency
up to and including 1 Hz per second as measured over a rolling 500 millisecond
period”
Mathematical Definition of RoCoF
𝑹𝒐𝑪𝒐𝑭𝑨𝑽𝑬𝑹𝑨𝑮𝑬 =∆𝒇
∆𝒕
𝑹𝒐𝑪𝒐𝑭𝑰𝒏𝒔𝒕𝒂𝒏𝒕𝒂𝒏𝒆𝒐𝒖𝒔 =𝒅𝒇
𝒅𝒕
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RoCoF Trace
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Definition of RoCoF (500ms window)
Ardnacrusha (AA), Aghada (AD), Cathaleen’s Fall (CF), Louth (LOU), Carrickmines (CKM), Great Island
(GI), Ballylumford (BALLY) and Poolbeg (PB) (*1)
Maximum RoCoF measurements for different time windows
RoCoF values at various substations (trip of EWIC) (Eirgrid Study 2012)
Problem: Generator sees actual values…
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RoCoFAverage with Δt = 100ms and Δt = 500ms
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Conventional Swing Equation
𝜏𝑎 = 𝜏𝑚 − 𝜏𝑒𝑙 = 0
𝐽𝑔𝑒𝑛 𝜔𝑚 𝑡 = 𝜏𝑚 − 𝜏𝑒𝑙
with 𝜔𝑚(𝑡) = 𝛿(𝑡)
𝐽𝑔𝑒𝑛 𝛿 𝑡 = 𝜏𝑚– 𝜏𝑒𝑙
Introducing 𝐻 =1
2𝐽𝜔2
𝑆𝑁
2𝐻
𝜔0
𝛿 𝑡 +𝐾𝐷𝜔0
𝛿 𝑡 = 𝜏𝑚 − 𝜏𝑒𝑙
And with 𝜏𝑒𝑙 =𝑘
𝜔0𝐵𝑅𝐵𝑆 sin 𝛿 𝑡
2𝐻
𝜔0
𝛿 𝑡 +𝐾𝐷𝜔0
𝛿 𝑡 +𝑘
𝜔0𝐵𝑅𝐵𝑆 sin 𝛿 𝑡 = 𝜏𝑚
2𝐻
𝜔0
𝛿 𝑡 +𝐾𝐷𝜔0
𝛿 𝑡 + 𝑘𝐵𝑅𝐵𝑆𝛿 𝑡 = 𝜏𝑚
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Negative ROCOF, Steam Turbine
0.25 Hz/s & 4 s 0.5 Hz/s & 2s 1 Hz/s & 1s 2 Hz/s & 0.5s
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Positive ROCOF, Steam Turbine
0.25 Hz/s & 4 s 0.5 Hz/s & 2s 1 Hz/s & 1s 2 Hz/s & 0.5s
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Real Frequency Event, 27.04.2014, DBP
Frequency and
Power traces
Pnom=390MWFrequencyPower Output
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Magnetic Field in a Synchronous Generator
Stable conditions:
Tel=Tmech
or
0=Tmech - Tel
Dynamic conditions:
J𝛼 = Tmech-Tel
J 𝜔 = Tmech-Tel - KD𝜔J 𝜔 = Tmech - kBSBRsin𝛿 - KD𝜔
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BR
BS
No gravity!!!
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G
1G
2Grid
Turbine Torque
Turbine Torque
To create the equation of motion using Lagrange
Damping depends on speed deviation!
Asynchronous effect!
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Swing Equation for light systems
𝑑
𝑑𝑡
𝜕𝐾𝑒𝜕(𝑞 11)
𝜕𝐾𝑒𝜕(𝑞 12)
𝜕𝐾𝑒
𝜕(𝑞 13)
𝜕𝐾𝑒
𝜕(𝑞 14)
⋮
𝜕𝐾𝑒𝜕(𝑞 𝑛1)
𝜕𝐾𝑒𝜕(𝑞 𝑛2)
𝜕𝐾𝑒
𝜕(𝑞 𝑛3)
𝜕𝐾𝑒
𝜕(𝑞 𝑛4)
−
𝜕𝐾𝑒𝜕𝑞11
𝜕𝐾𝑒𝜕𝑞12
𝜕𝐾𝑒𝜕𝑞13
𝜕𝐾𝑒𝜕𝑞14
⋮
𝜕𝐾𝑒𝜕𝑞𝑛1
𝜕𝐾𝑒𝜕𝑞𝑛2
𝜕𝐾𝑒𝜕𝑞𝑛3
𝜕𝐾𝑒𝜕𝑞𝑛4
+
𝜕𝑃
𝜕(𝑞 11)
𝜕𝑃
𝜕(𝑞 12)
𝜕𝑃
𝜕(𝑞 13)
𝜕𝑃
𝜕(𝑞 14)
⋮
𝜕𝑃
𝜕(𝑞 𝑛1)
𝜕𝑃
𝜕(𝑞 𝑛2)
𝜕𝑃
𝜕(𝑞 𝑛3)
𝜕𝑃
𝜕(𝑞 𝑛4)
+
𝜕𝑉
𝜕𝑞11
𝜕𝑉
𝜕𝑞12
𝜕𝑉
𝜕𝑞13
𝜕𝑉
𝜕𝑞14
⋮
𝜕𝑉
𝜕𝑞𝑛1
𝜕𝑉
𝜕𝑞𝑛2
𝜕𝑉
𝜕𝑞𝑛3
𝜕𝑉
𝜕𝑞𝑛4
=
𝑄11
𝑄12
𝑄13
𝑄14
⋮
𝑄𝑛1
𝑄𝑛2
𝑄𝑛3
𝑄𝑛4
=
𝑢𝑑
𝑢1𝑞
𝜏𝑚𝑔𝑒𝑛
0
⋮
𝑢𝑑
𝑢𝑛𝑞
𝜏𝑛𝑚𝑔𝑒𝑛
0
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Model verification
ROCOF Project Board Meeting
Real event
Model
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Frequency trace depends on system inertia
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Swings depend on electromagnetic torque
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Restrictions
Updated?!
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Reactive power influences swings (MP1)
ROCOF Project Board Meeting
305MW
100MW
with higher reactive power
the damping is stronger
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Calculations with parameters ± 1Hz/s & 1.2s
Operational Point RoCoF,
duration
Remarks
1.) P=305 MW; Q=180Mvar -1Hz/s;
1.2s
The generated active power increases to 540MW. Generator
experiences 150% of rated stator current. The stator current limiter
in the AVR is triggered.
2.) P=305MW; Q=0Mvar The generated active power increases to 503MW. Generator
experiences 140% rated stator current. The stator current limiter in
the AVR is triggered.
3.) P=305MW; Q=-120Mvar The generated active power increases to 530MW. The stator
current limiter in the AVR is triggered. The reactive power triggers
the under-excitation limiter and under-excitation protection. I>
protection picks up.
4.) P=100MW; Q=-160Mvar The reactive power triggers the under-excitation limiter and the
under-excitation Protection.
1.) P=305 MW; Q=180Mvar +1Hz/s;
1.2s
ΔP/Δt is substantial and can lead to trigger the “Remote Breaker
Opening” logic which would close the control valves.
2.) P=305MW; Q=0Mvar ΔP/Δt is substantial and can lead to trigger the “Remote Breaker
Opening” logic which would close the control valves.
3.) P=305MW; Q=-120Mvar ΔP/Δt is substantial and can lead to trigger the “Remote Breaker
Opening” logic which would close the control valves.
4.) P=100MW; Q=-160Mvar ΔP/Δt is substantial and can lead to trigger the “Remote Breaker
Opening” logic which would close the control valves. Reverse
Power Pick up (-125MW). Torsional Oscillations become more
evident on low loads.
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Shaft line, exact modelling required for all stations
Higher RoCoF values might trigger
Eigen-Frequencies
Analysis for impact at turbine
and generator components
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Risks related to mechanical integrity
Torsional oscillations can create stresses to:
• Couplings
• Rotors and shafts
• Turbine blades
• Generator rotor end bells
• Generator stator end windings
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Impact on lifetime is unknown
Life time and maintenance
analysis to be undertaken
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Technical Risks
Technical Risks
• Controller & Operational Issues
• Turbine/Governor Controller
• AVR/PSS Controllers
• Protection Systems
• Turbine Protection
• Generator & Transformer Protection
• Mechanical Integrity
• Turbine Components
• Generator Components
• Lifetime Assessments
• Electrical Integrity
• Impact of Auxiliary Systems
• Motors, Fans, Pumps
Action
• Studies to be completed to assess impact
• Modelling Scenarios
• Rotor Dynamic Analysis
• Operational Analysis
• Internal Modelling work
• Torsional Probes
• Matlab/Simulink Model Build
• Digsilent Study
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Mechanical Integrity Consequences
RoCoF Event
Reduced Component Life Time
Consequential Machine Damage
Decreased overhaul intervals and
Increased Inspection Requirements
Forced Outage
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Operational Consequences
ROCOF Event
Further loss of Electrical Power Generations
Cascade Tripping Event
Load Shedding in the system
System Brown/Black Out
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Real Event, Poolbeg CT 15 @ 65 MW
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Study Scope
Type MW
(Exp)
Unit
#
Studies
Required
Study
Priority
CCGT 2094 4 4* 1
Peat 228 2 1 1
Coal 855 3 1 1
Gas 258 1 1 3
OCGT 517 6 2 3
Pump Storage 292 4 1 1
Hydro 206 17 2 3
12 studies to be completed
Timeframe for Priority 1 Units 18 months
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Timeline going forward
● Studies required to demonstrate compliance
– High priority – 18 months - high run hours, frequently constrained on, frequently run during high
wind
– Mid priority – 24 months - units not in other categories
– Low priority – 36 months - low run hours, infrequently constrained on, infrequently run during
high wind
– Exempt units – units soon to retire, very low runs hours or units which in EirGrid’s operational
experience have ridden through high RoCoF events in the past
ESB will need to be compliant (or derogated/exempted) by these dates to
ensure it incurs zero penalties.
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Project Timeline
2010 – 2012Consultation Period
• Risk Paper
• OEM Engagement
• Understanding & Education
• Financial Appraisal
• Regulatory
2013 – 2014CER ROCOF Paper
• Consultation Paper
• Decision Paper
• KEMA Challenge Study
• No Cost Recovery Position
• Procurement Strategy
2014 – 2016Studies•Tender Process•Priorities 1 studies•Digsilent Study•Matlab/Simulink Model•Torsional Probe Analysis• Quality & Validation
2016 – 2018Post Studies
• Level of Compliance
• Level of Investment
• Development of individual Business Cases
• Implementation
That’s it??
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Contents
1. Introduction of the Irish Grid and ESB
2. Government targets and policies
3. Rate of Change of Frequency (RoCoF) and the Grid Code Definition
4. Mathematical models
5. Impact to generating plant and grid
6. RoCoF impact studies with manufacturers
7. Frequency oscillations
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Real Event, DBP, 26.12.2014
• C30 in Coolkeeragh Trip at 22:38
• DB1 MW; Hz
• 7 Min Oscillation
• Pk-Pk: ~0.3 – 0.4 Hz
• Period of Osc: 15 s (0.066 Hz)
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Typical Turbine Generator control circuit
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Response to a sinusoidal disturbance
Currently installed turbine controllers need major attention….
Output of controllers
swing almost in
phase with
disturbance which
amplifies the
disturbance
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Real event in Germany (Rhein-Ruhr Region)
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Questions?
Fragen?
ErwthseiV;
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Thank You
and
Grazie
Footer
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Acknowledgements
Models used:
Matlab from Mathworks with Simulink and SimPowerSystem
Literature:
“Power System Stability and Control”, Prabha Kundur
“Handbook of Electrical Power System Dynamics”, M. Eremia, M. Shahidehpour
“Elektrische Schaltvorgaenge”, Reinhold Ruedenberg
Various publications by Eirgrid and CER (www.eirgrid.com and www.cer.ie)
DNV GL Study on ESB Fleet
Some animations were used from www.wikipedia.de, Dreiphasenwechselstrom
Contributions by:
Prof. Dr. William T. Coffey, Trinity College Dublin, Ireland