Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System
Abstract
:1. Introduction
2. Pumped-Storage Hydro Plants (PSHPs)
2.1. Variable-Speed Operation of PSHP
2.2. Generator Technologies for Variable-Speed Operation of PSHP
- Doubly fed induction machines (DFIMs);
- Converter-fed synchronous machines (CFSMs).
2.2.1. Doubly Fed Induction Machines (DFIMs)
2.2.2. Converter-Fed Synchronous Machines (CFSMs)
3. Energy Storage System to Support Hydropower Sources in the NPS
Battery Energy Storage System
- Power conversion system: this subsystem consists of an electrical or an electromechanical device that allows converting electrical energy;
- Battery energy system: the principal element of this subsystem is an electromechanical energy storage technology (battery) to store/deliver the energy;
- The controllers associated to the BESS: this subsystem has a set of controllers that can be divided into two categories: (i) fast inner controller is directly connected to the power conversion system and is related to the control of the converter’s AC currents of the dq-axis, and (ii) slow outer controllers groups three controls P-Q control, fast active power control, and battery charge control.
4. Frequency Control Optimization
4.1. Frequency Control and TSO/DSO Interactions
4.2. Fast Active Power Controller (FAPC)
4.3. Optimization of the System Frequency Response
4.3.1. Frequency Response Indicators
- Minimum frequency (fmin): denotes the minimum value that the frequency reaches during the transient response after a frequency event. It is computed as the difference between the nominal frequency (f0) and the maximum frequency deviation (∆fmax) during the transient response, i.e., fmin = f0−∆fmax.
- Minimum time (tmin): is the time at which the frequency reaches its minimum value (fmin) and its maximum deviation (∆fmax). The inertial response begins from the disturbance start (ts) until the frequency reaches its minimum value at tmin; after that, the governor action initiates.
- Rate of Change of Frequency (ROCOF): represents the speed at which the frequency changes in one second, i.e., it is the time derivative of the frequency and it is described as ROCOF = df/dt (Hz/s).
- Steady-state frequency (fss): is the value at which the frequency settle, typically is after the inertia response and the governor action, at this point, the ROCOF is zero. This indicator gives a measure of the ability of the power system to recuperate after a frequency event.
4.3.2. Optimization Problem
Decision Variables
Objective Function
5. Defining of Future Scenarios
5.1. Nordic Power System (NPS)
- System flexibility;
- Generation adequacy;
- Frequency quality;
- System inertia;
- Transmission adequacy.
5.2. Future Scenarios
- Scenario 0: This scenario considers only the maintenance action of the existing hydropower units in the system. Therefore, new types of technologies are not integrated into the system; the purpose of this scenario is observing the performance of the NPS to a disturbance with the existing conventional power plants based on synchronous generators any other technology is assumed to be no frequency sensible.
- Scenario 1: In this scenario, some significant hydropower generation (greater than 100 MW) will be replaced with DFIM units and medium hydropower generation units (less than 100 MW) will be substituted with CFSM units. This will be done in two intervals: three units will be replaced in the year 2030, and an additional four will be replaced in the year 2040. This scenario will mainly focus on looking into how the implementation of variable-speed hydro will impact the overall system frequency stability.
- Scenario 2: This scenario follows the same pattern as Scenario 1, but also it will include the installation of five BESSs, one will be introduced in the year 2030, and the remaining four will be implemented in the year 2040. This scenario investigates the benefits related to the system stability installing BESS in the NPS.
5.2.1. Year 2020
5.2.2. Year 2030
Scenario 0
Scenario 1
Scenario 2
5.2.3. Year 2040
Scenario 0
Scenario 1
Scenario 2
6. Simulation and Results
6.1. Vestfold and Telemark System
6.2. Base Case: Scenario 0
6.3. Optimized Response: Scenario 1 and Scenario 2
6.3.1. Year 2030
6.3.2. Year 2040
7. Conclusions
Author Contributions
Funding
Acknowledgments
Conflicts of Interest
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Source | 2020 (GW) | 2030 (GW) | 2040 (GW) | Change 2020–2040 (%) |
---|---|---|---|---|
Wind | 20 | 30 | 45 | +125 |
Thermal | 8 | 5 | 3.5 | −56 |
Nuclear | 12 | 10.5 | 2.5 | −79 |
Level | 2020 | 2030 | 2040 |
---|---|---|---|
High | 260 | 255 | 190 |
Low | 174 | 159 | 105 |
Level | 2020 | 2030 | 2040 |
---|---|---|---|
High | 72.6 | 75.8 | 79 |
Low | 28.6 | 31.8 | 35 |
Power Station | Installed Capacity (MVA) | New Technology |
---|---|---|
Såheim | 189 | DFIM |
Hjartdøla | 130 | DFIM |
Fjone | 55 | CFSM |
Power Station | Installed Capacity of the Plant [MVA] | BESS Capacity (MVAh) |
---|---|---|
Fjone | 38 | 55 |
Power Station | Installed Capacity (MVA) | New Technology |
---|---|---|
Såheim | 189 | DFIM |
Hjartdøla | 130 | DFIM |
Mår | 190 | DFIM |
Fjone | 55 | CFSM |
Mæl | 38 | CFSM |
Skollenborg | 99 | CFSM |
Svelgfoss | 93 | CFSM |
Power Station | Installed Capacity of the Plant (MVA) | BESS Capacity (MVAh) |
---|---|---|
Fjone | 38 | 55 |
Mæl | 38 | 38 |
Fritzøe | 7 | 7 |
Skollenborg | 99 | 99 |
Svelgfoss | 93 | 93 |
Year | Total Kinetic Energy (GW∙s) | ∆fCOI, max (Hz) | fCOI, min (Hz) | tmin (s) | ROCOFCOI, max (Hz/s) | fCOI, ss (Hz) |
---|---|---|---|---|---|---|
2020 | 174 | 0.738 | 49.265 | 8.132 | −0.186 | 49.723 |
2030 | 159 | 0.806 | 49.194 | 7.912 | −0.204 | 49.697 |
2040 | 105 | 1.258 | 48.742 | 9.182 | −0.318 | 49.536 |
Power Station | Technology | Scenario 1 | Scenario 2 |
---|---|---|---|
Såheim | DFIM | 0.0001 | 0.0001 |
Hjartdøla | DFIM | 0.0072 | 0.0001 |
Fjone | CFSM | 0.052 | 0.0001 |
Fjone | BESS | - | 0.0001 |
Scenario | ∆fCOI, max (Hz) | fCOI, min (Hz) | tmin (s) | ROCOFCOI, max (Hz/s) | fCOI, ss (Hz) |
---|---|---|---|---|---|
0 | 0.806 | 49.194 | 7.912 | −0.204 | 49.697 |
1 | 0.759 | 49.241 | 7.912 | −0.195 | 49.720 |
2 | 0725 | 49.275 | 7.995 | −0.196 | 49.734 |
Power Station | Technology | Scenario 1 | Scenario 2 |
---|---|---|---|
Såheim | DFIM | 0.0001 | 0.0001 |
Hjartdøla | DFIM | 0.0975 | 0.0001 |
Mår | DFIM | 0.0001 | 0.0001 |
Fjone | CFSM | 0.0126 | 0.0001 |
Mæl | CFSM | 0.0001 | 0.0001 |
Skollenborg | CFSM | 0.0152 | 0.0001 |
Svelgfoss | CFSM | 0.0298 | 0.0001 |
Fjone | BESS | - | 0.0001 |
Mæl | BESS | - | 0.0001 |
Fritzøe | BESS | - | 0.0001 |
Skollenborg | BESS | - | 0.0001 |
Svelgfoss | BESS | - | 0.0001 |
Scenario | ∆fCOI, max (Hz) | fCOI, min (Hz) | tmin (s) | ROCOFCOI, max (Hz/s) | fCOI, ss (Hz) |
---|---|---|---|---|---|
0 | 1.258 | 48.742 | 9.182 | −0.318 | 49.536 |
1 | 1.131 | 48.869 | 6.905 | −0.282 | 49.609 |
2 | 0.850 | 49.150 | 7.223 | −0.274 | 49.660 |
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Acosta, M.N.; Pettersen, D.; Gonzalez-Longatt, F.; Peredo Argos, J.; Andrade, M.A. Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System. Energies 2020, 13, 3377. https://doi.org/10.3390/en13133377
Acosta MN, Pettersen D, Gonzalez-Longatt F, Peredo Argos J, Andrade MA. Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System. Energies. 2020; 13(13):3377. https://doi.org/10.3390/en13133377
Chicago/Turabian StyleAcosta, Martha N., Daniel Pettersen, Francisco Gonzalez-Longatt, Jaime Peredo Argos, and Manuel A. Andrade. 2020. "Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System" Energies 13, no. 13: 3377. https://doi.org/10.3390/en13133377