3rd - tf.uni-kiel.de

3rd - tf.uni-kiel.de

Grid requirements to connect DPGS based on RES Grid requirements to connect DPGS based on RES Marco Liserre [email protected] Marco Liserre Grid requirements to connect DPGS based on RES Introduction Grid requirements for DPGS are stringent and subject to changes They are different for different renewable energy sources IEEE made an attempt, with IEEE 1547 series, to have a common approach for all DPGS below 10 MW In fact power level is maybe more important than source type

Grid operators consider low power DPGS as a kind of disturbance or negative load Higher power DPGS are starting to be consider a resource for grid stability Marco Liserre Grid requirements to connect DPGS based on RES Introduction Safety issues are also important due to the higher penetration of DPGS at low voltage level Power quality and EMC are stringent too In the following the grid requirements are reviewed with focus on:

Photovoltaic systems Wind systems However considerations on the influence of the power level will be made Marco Liserre Grid requirements to connect DPGS based on RES Photovoltaic systems Marco Liserre Grid requirements to connect DPGS based on RES Outline International Regulations Public Voltage Quality Response to abnormal grid conditions Power Quality Anti-islanding requirements References Conclusion

Marco Liserre Grid requirements to connect DPGS based on RES International Regulations Grid connection requirements IEEE 1547-2003 Standard for Interconnecting Distributed Resources with Electric Power Systems IEEE 1547.1- 2005 Standard for Conformance Tests Procedures for Equipment Interconnecting Distributed Resources with Electric Power Systems IEEE 929-2000, Recommended Practice for Utility Interface of Photovoltaic (PV) Systems incorporated in IEEE 1547 UL 1741, Standard for Inverters, Converters, and Controllers for Use in Independent Power Systems - elaborated by Underwriters Laboratories Inc. compatibilzed with IEEE 1547 IEC61727 [6] Photovoltaic (PV) systems - Characteristics of the utility interface - December 2004 IEC 62116 Ed.1 2005: Testing procedure of islanding prevention measures for utility interactive photovoltaic inverter (describes the tests for IEC 61727) approved in 2007 VDE0126-1-1 2006 Automatic disconnection device between a generator and the public low-voltage grid Safety issuesapplied on German Market EMC IEC 61000-3-2, Ed. 3.0 Electromagnetic compatibility (EMC) Part 3-2: Limits Limits for harmonic current emissions (equipment input current 16 A per phase), ISBN 2-8318-8353-9, November 2005

EN 61000-3-3, Ed. 1.2 Electromagnetic compatibility (EMC) Part 3-3: Limits Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems, for equipment with rated current 16 A per phase and not subject to conditional connection, ISBN 2-8318-8209-5, November 2005 IEC 61000-3-12, Ed. 1 Electromagnetic compatibility (EMC) Part 3-12:Limits Limits for harmonic currents produced by equipment connected to public low-voltage systems with input current >16 A and 75 A per phase , November 2004 IEC 61000-3-11, Ed. 1 Electromagnetic compatibility (EMC) Part 3-11: Limits Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems Equipment with rated current 75 A and subject to conditional connection , August 2000Standard EN 50160 Voltage Characteristics of Public Distribution System, CENELEC: European Committee for Electrotechnical Standardization, Brussels, Belgium, November 1999 Utility Voltage Quality Standard EN 50160 Voltage Characteristics of Public Distribution System, CENELEC: European Committee for Electrotechnical Standardization, Brussels, Belgium, November 1999 . Marco Liserre Grid requirements to connect DPGS based on RES Public Voltage Quality EN 50160 voltage unbalance for three phase inverters. Max unbalance is 3% voltage amplitude variations: max +/-10% frequency variations: max +/-1% voltage dips: duration < 1 sec, deep < 60%

voltage harmonic levels. Max voltage THD is 8% Odd harmonics Not multiple of 3 Order h Marco Liserre Even harmonics Multiple of 3 Relative (%) voltage Order h Relative (%) voltage Order h

Relative (%) voltage 5 6 3 5 2 2 7 5 9 1.5 4

1 11 3.5 15 0.5 6..24 0.5 13 3 21 0.5 17 2

19 1.5 23 1.5 25 1.5 Grid requirements to connect DPGS based on RES Response to abnormal grid conditions Voltage deviations IEEE 1547 IEC61727 VDE0126-1-1 Voltage range (%) Disconnection time (s)

Voltage range (%) Disconnection time (s) Voltage range (%) Disconnection time (s) V < 50 0.16 V < 50 0.10 110 V < 85 0.2 50 V < 88 2.00

50 V < 85 2.00 110 < V < 120 1.00 110 < V < 135 2.00 V 120 0.16 V 135 0.05 Obs. The purpose of the allowed time delay is to ride through short-term disturbances to avoid excessive nuisance tripping IEEE 1547 Frequency deviations

IEC61727 VDE0126-1-1 Frequency range (Hz) Disconnecti on time (s) Frequency range (Hz) Disconnecti on time (s) Frequency range (Hz) Disconnecti on time (s) 59.3 < f < 60.5* 0.16

fn-1 < f < fn+1 0.2 47.5 < f < 50.2 0.2 Obs. The VDE0126-1-1 allow much lower frequency limit and thus frequency adaptive synchronization is required. Reconnection after trip IEEE 1547 IEC61727 VDE0126-1-1 88 < V < 110 [%] AND 59.3 < f < 60.5 [Hz]

85 < V < 110 [%] AND fn-1 < f < fn+1 [Hz] AND Min. delay of 3 minutes N/A Obs. The time delay in IEC61727 is an extra measure to ensure resynchronization before reconnection in order to avoid possible damage Marco Liserre Grid requirements to connect DPGS based on RES DC Current Injection Power Quality IEEE 1574 IEC61727 VDE0126-1-1 Idc < 0.5 [%] of the rated RMS current

Idc < 1 [%] of the rated RMS current Idc < 1A Max Trip Time 0.2 s Obs. For IEEE 1574 and IEC61727 the dc component of the current should be measured by using harmonic analysis (FFT) and there is no maximum trip time condition IEEE 1547 and IEC 61727 Current harmonics Individual harmonic order (odd)* h < 11 11 h < 17 17 h < 23 23 h < 35 35 h Total harmonic

distortion THD (%) (%) 4.0 2.0 1.5 0.6 0.3 5.0 Obs. The test voltage for IEEE1574/IEC61727 should be produced by an electronic power source with a voltage THD < 2.5% (typically ideal sources) Odd harmonics Order h if IEC 61727 is not considered, the practice is that the harmonic limits are set by the IEC 61000-3-2 for class A equipments Current (A)

Even harmonics Order h Current (A) 3 2.30 2 1.08 5 1.14 4 0.43 7 0.77 6

0.30 9 0.40 8 h 40 0.23 x 8/h 11 0.33 13 0.21 13 h 39 0.15 x 15/h Obs. The current limits in IEC61000-3-2 are given in amperes and are in general higher than the ones in IEC61727. For equipments with a higher current than 16 A but lower than 75A another similar standard IEEE 61000

3-12 applies Marco Liserre Grid requirements to connect DPGS based on RES Power Quality Average Power Factor Only in IEC61727 it is stated that the PV inverter shall have an average lagging power factor greater than 0,9 when the output is greater than 50%. Most PV inverters designed for utility-interconnected service operate close to unity power factor. In IEEE1574 as this a general standard that should allow also distributed generation of reactive power there is no requirement for the power factor No power factor requirements are mentioned in VDE0126-1-1 Obs. Usually the power factor requirement for PV inverters should be interpreted now as a requirement to operate at quasi-unity power factor without the possibility of regulating the voltage by exchanging reactive power with the grid. For high power PV installations connected directly to the distribution level local grid requirements apply as they may participate in the grid control. For low power installations it is also expected that in the near future the utilities will allow them to exchange reactive power but new regulations are still expected. Marco Liserre Grid requirements to connect DPGS based on RES Anti-islanding Requirements

What is Islanding? Islanding for grid connected PV systems takes place when the PV inverter does not disconnect very short time after the grid is tripped, i.e. it is continuing to operate with local load. In the typical case of residential electrical system co-supplied by a roof-top PV system, the grid disconnection can occur as a result of a local equipment failure detected by the ground fault protection, or of an intentional disconnection of the line for servicing. In both situations if the PV inverter does not disconnect the following consequences can occur: Retripping the line or connected equipment damaging due to of out-ofphase closure Safety hazard for utility line workers that assume de-energized lines during islanding In order to avoid these serious consequences safety measures called antiislanding (AI) requirements have been issued and embodied in standards Marco Liserre Grid requirements to connect DPGS based on RES Anti-islanding Requirements IEEE 1574 In IEEE 1574 the requirement is that after an unintentional islanding where the distributed resources (DR) continues to energize a portion of the power system (island) through the PCC, the DR shall detect the islanding and cease to energize the area within 2 seconds. S3 S1 Simulated Area EPS RLC

Load S2 EUT NOTES 1 Switch S1 may be replaced with individual switches on each of the RLC load components 2 Unless the EUT has a unity output p.f., the receiver power component of the EUT is considered to be a part of the islanding load circuit in the figure. V2 R P V2 L 2 f PQ f PQ f C 2 f V 2

Adjustable RLC load should be connected in parallel between the PV inverter and the grid. The resonant LC circuit should be adjusted to resonate at the rated grid frequency and to have a quality factor of 1 or in other words the reactive power generated by [VAR] should equal the reactive power absorbed by [VAR] and should equal the power dissipated in [W] The parameters of the RLC load should be fine tuned until the grid current through S3 should be lower than 2% of the rated value on a steady-state base. In this balanced condition, the S3 should be open and the time before disconnection should be measured and should be lower than 2 seconds. The UL 1741 standard in US has been harmonized with the anti-islanding requirements stated in IEEE 1547Marco Liserre Grid requirements to connect DPGS based on RES Anti-islanding Requirements IEC62116 In IEC 62116-2006 similar AI requirements as the IEEE1547 is proposed. The test can also be utilized by other inverter interconnected DER. In the normative reference IEC 61727-2004 the ratings of the system valid in this standard has a rating of 10 kVA or less, the standard is though subject to revision. The test circuit is the same as in the IEEE1547.1 test power balance is required before the island detection test. The requirement for passing the test contains more test cases but the conditions for confirming island detection do not have a significant deviation compared to the IEEE1547.1 test. The inverter is tested at three levels of output power (A 100-105%, B 50-66% and C 25-33% of inverters output power). Case A is tested under maximum allowable inverter input power, case C at minimum allowable inverter output power if > 33 %. The voltage at the input of the inverter also has specific conditions. All conditions are to be tested at no deviation in real and reactive load power consumption then for condition A in a step of 5%

both real and reactive power iterated deviation from -10% to 10% from operating output power of inverter. Condition B and C are evaluated by deviate the reactive load in an interval of 5 % in a step of 1 % of inverter output power. The maximum trip time is the same as in IEEE 1547.1 standards 2 s. In IEC61727, there is no specific description of the anti-islanding requirements. Instead reference to IEC62116 is done. Marco Liserre Grid requirements to connect DPGS based on RES Anti-islanding Requirements VDE-0126-1-1 The VDE0126-1-1 allows the compliance with one of the following anti-islanding methods: A. Impedance measurement S DC-AC Inverter Pgrid ~ B.

R1 L1 L1 R2 L2 L2 Grid R3 C1 Disconnection detection with RLC resonant load The test circuit is the same of the one reported in IEEE1547.1 and the test conditions are that the RLC resonant circuit parameters should be calculated for a quality factor bigger than 2 With balanced power the inverter should disconnect after the disconnection of S2 in maximum 5 seconds for the following power levels: 25%, 50% and 100%. For three-phase PV inverters a passive anti-islanding method is accepted by monitoring all three phases voltage with respect to the neutral. This method is conditioned by having individual current control in each of the three phases. Finding a software based anti-islanding method has been a very challenging task resulting in a large

number of research work and publications. Marco Liserre Grid requirements to connect DPGS based on RES Conclusions An overview of the most relevant standards related to the grid connection requirements of PV inverters is given. High efforts are done by the international standard bodies in order to harmonize the grid requirements for PV inverters worldwide. The IEEE1574 standard has done a big step in the direction of issuing a standard that includes grid requirements not only for PV inverters but for all distributed resources under 10 MVA. Underwriters Laboratories in US has revised this year the UL 1471 by accepting the grid requirements of IEEE1574 and also IEC62116 was revised to harmonize with the requirements of IEEE1574 in the anti-islanding requirements. Even the very specific German standard VDE0126-1-1 was revised in 2006 where the grid impedance measurement has become optional and an alternative requirement very similar to IEEE1574 was included. All these positive actions needs to be followed by adoption in different countries that still use their own local regulations. Marco Liserre Grid requirements to connect DPGS based on RES References [1]

Dugan, R.C.; Key, T.S.; Ball, G.J., "Distributed resources standards," Industry Applications Magazine, IEEE , vol.12, no.1, pp. 27-34, Jan.-Feb. 2006 [2] IEEE Std 929-2000 IEEE Recommended Practice for Utility Interface of Photovoltaic (PV) Systems,", ISBN 0-7381-1934-2 SH94811, April 2000. [3] UL standard 1741, Inverters, Converters, and controllers for Use in Independent Power Systems, Underwriters Laboratories Inc. US, 2001 [4] IEEE Std 1547-2003 Standard for Interconnecting Distributed Resources with Electric Power Systems," ISBN 0-7381-3720-0 SH95144, IEEE, June 2003 [5] IEEE Std 1547.1-2005 Standard Conformance Test Procedures for Equipment Interconnecting Distributed Resources with Electric Power Systems ISBN 0-7381-4736-2 SH95346, IEEE, July 2005 [6] IEC 61727 Ed.2 Photovoltaic (PV) Systems - Characteristics of the Utility Interface, December, 2004 [7] IEC 62116 CDV Ed. 1 Test procedure of islanding prevention measures for utility-interconnected photovoltaic inverters, IEC 82/402/CD:2005

[8] VDE V 0126-1-1 Automatic disconnection device between a generator and the public low-voltage grid,VDE Verlag, Doc nr. 0126003, 2006 [9] IEC 61000-3-2, Ed. 3.0 Electromagnetic compatibility (EMC) Part 3-2: Limits Limits for harmonic current emissions (equipment input current 16 A per phase), ISBN 2-8318-8353-9, November 2005 [10] EN 61000-3-3, Ed. 1.2 Electromagnetic compatibility (EMC) Part 3-3: Limits Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems, for equipment with rated current 16 A per phase and not subject to conditional connection, ISBN 2-8318-8209-5, November 2005 [11] Standard EN 50160 Voltage Characteristics of Public Distribution System, CENELEC: European Committee for Electrotechnical Standardization, Brussels, Belgium, November 1999 . [12] IEC 61000-3-12, Ed. 1 Electromagnetic compatibility (EMC) Part 3-12:Limits Limits for harmonic currents produced by equipment connected to public low-voltage systems with input current >16 A and 75 A per phase , November 2004 [13] IEC 61000-3-11, Ed. 1 Electromagnetic compatibility (EMC) Part 3-11: Limits Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems Equipment with rated current 75 A and subject to conditional connection , August 2000 Marco Liserre Grid requirements to connect DPGS based on RES Wind systems Marco Liserre

Grid requirements to connect DPGS based on RES Outline Grid codes, description and purpose Transmission system operator demands Active power control, frequency control Reactive power control, voltage control Ride-Through Capabilities Conclusion Marco Liserre Grid requirements to connect DPGS based on RES Grid Codes description and purpose Operate a wind farm/wind turbine like a power station/plant Grid Code: Technical document containing the rules governing the operation, maintenance, & development of the system defined at the Point of Common Coupling PCC (not turbine specific) Steady state Frequency /Power control Low/high frequency support Voltage support/reactive power compensation Power Quality, flicker, harmonics Transient /dynamic state

Fault ride through, to stay connected during low voltage on the grid Ramp rate Communication /power dispatch Reliable communication Wind forecasting Participate power market Marco Liserre Grid requirements to connect DPGS based on RES Recent Grid Codes Europe: The grid codes of Europe are affected by the fact that the grid has traditionally been strong and stable but the fact that the wind power penetration has been increasing - LVRT (Low Voltage Ride Through) has entered the scene and most grid codes at least specifies LVRT requirements as defined by the German E.ON. In Spain, Scotland and Ireland the grid codes exceeds the standard requirements. Australia & New Zealand: Are characterised by a weak and unstable grid with frequency variations from -10 % to +6 % (in extreme) and -6 % to +4 % (more common). Voltage control and site dependent requirements are standard North America: Characterised by a large number of smaller power systems requiring local control capabilities such as voltage control. The PF range is more standardised as 0.9c to 0.9i. Marco Liserre

Grid requirements to connect DPGS based on RES Grid Codes Trends Voltage control: Future demands is going towards operation in a voltage set point control mode; with a continuously-variable, continuously-acting, closed loop control voltage regulation system, acting like a synchronous generator, where reactive power changes are based on measured voltage. Power control: The trend in power control is fast ramp rates both up and down, in order to support the frequency of the grid. The latest comments for GB grid codes for power recovery after grid faults states power restoration of 90 % within 1 s. Further frequency control is required in some countries, both under frequency and over frequency support. Plant control: Having wind power plants tending the capabilities of primary control units, traditional power system control features are indisputable. As the need for more dynamical response will increase, the needs for fast and reliable control-infrastructure between the turbines in a park facility are increasing. Marco Liserre Grid requirements to connect DPGS based on RES Grid Codes Trends Low voltage ride-through: Is becoming standard for all grid codes! In addition to symmetrical faults, which are three-phased, new trend setting grid requirements will be covering single and two-phase faults ride-through capability. Voltage support during grid disturbances is becoming a common requirement. An increase in the low voltage duration is foreseen today GB

codes mention 3 min. at 85 % voltage. Simulation models: Validated park control models with full disclosure are already defined for various grid code drafts. Park simulation models are an integrated part of the tender phase in more and more projects. Most connection agreements are decided on background of simulation studies. Also nonconfidential block diagrams are required, mainly Australia and New Zeeland, but US are also requiring open-source models. PSCAD, DigSilent and PSS/E are preferred tools. Marco Liserre Grid requirements to connect DPGS based on RES Different National Grid Codes [AESO] Canada Wind Power Facility - Technical Requirements (Draft proposal) [CER] Ireland Wind farm Transmission Grid Code Provisions - A Direction by the Commission for Energy Regulation [Eltra] Denmark Vindmlleparker tilsluttet net med spndinger over 100 kV [E.ON] Netz Germany

Netzanschlussregeln- Hoch- und Hchstspannung [ESB] National Grid Ireland [REE] Spain Wind Code Changes - Distribution Code Modification Proposal Form Operation procedures for the electrical system. PO 12.1, 12.2 and 12.3 [NECA] Australia National Electricity Code - Version 1.0 Amendment 8.6 [NGC] National Grid The Grid Code - Issue 2, revision 16 [Vattenfall] Germany Netzanschluss- und Netznutzungsregeln der Vattenfall Europe Transmission GmbH [VDN] Germany Transmission Code 2003- Netz- und Systemregeln der deutschen bertragungsnetzbetreiber [Western Power] Australia

Technical Code Version 1 Marco Liserre Grid requirements to connect DPGS based on RES Voltage and Frequency limits Eltra Denmark. Voltages and frequencies used for design of a wind turbine with voltages below 100 kV Marco Liserre Grid requirements to connect DPGS based on RES Voltage and Frequency limits E-On Germany. Voltage and frequency range for generating units in the E-On grid. Marco Liserre Grid requirements to connect DPGS based on RES Voltage and Frequency limits Great Britain Voltages and frequencies in GB grid

Marco Liserre Grid requirements to connect DPGS based on RES Transmission System Operator demands Primary control: Maintain the balance between generation and demand in the network using turbine speed regulators Automatic control to stabilize the grid frequency in seconds Secondary control: Secure import/export balancing with neighbouring areas with reserve generating capacities. Control within minutes In case of a steady major deviation in the control area, to restore the frequency and to free capacity for the primary control Can be manual or automatic Tertiary control: As automatic or manual change in the working points of generators in order to restore adequate secondary control reserve at the right time Marco Liserre Grid requirements to connect DPGS based on RES NORDEL Transmission System Operator demands

UCTE Marco Liserre Grid requirements to connect DPGS based on RES Transmission System Operator demands UCTE: Primary control Insensitive dead band 10 mHz Frequency deviation of 200 mHz it must be possible to activate the total primary control power range required by the power plant in 30 sec and to supply it for at least 15 min. Primary control must be again available after 15 min of activation. Dispatch 2-8% of rated capacity for primary frequency control. Secondary control It restores the frequency to its rated value and releases engaged primary reserves Start within 30 sec. Fully activated within 15 min. N-1 network security Ability to re-establish supply after black out Marco Liserre Grid requirements to connect DPGS based on RES Transmission System Operator demands

NORDEL: Decoupling of power plants Lowering generation Emergency power by HVDC connections Frequency control/primary control The reserve is activated Emergency power by HVDC connections Load shedding, diconnection of connection lines Marco Liserre Disconnection of large combined power plants Primary control

0 MW in frequency control reserve (50,149,9 Hz) 192 MW in momentarily disturbance reserve (49,9-49,5 Hz) 50% (5sek),100 % (30 sek), HVDC emergency power, Re-established within 15 min. Secondary control Fast reserve 600 MW within 15 min Grid requirements to connect DPGS based on RES Transmission System Operator demands Power control Production Reduction limit control both on transmission and distribution below 20% of maximum power in less than 2s on transmission level Automatic

power control after faults up to full power reduction or increase within 30s on transmission level Distribution per minute Marco Liserre level decrease and increase in power from 10-100% of rated power Grid requirements to connect DPGS based on RES Regulation functions for active power System protection Protection function that shall be able to perform automatic down-regulation of the power production to an acceptable level for electrical network. In order to avoid system collapse it should act fast. Frequency control Frequency control All production units shall contribute to the frequency control. Automatic control of power production based on frequency measurement to reestablish the rated frequency.

Stop control Wind farm shall keep the production on the actual level even if it is an increase in the wind speed Marco Liserre Grid requirements to connect DPGS based on RES Regulation functions for active power Balance control The power production shall be adjusted downwards or upwards in steps at constant levels. Production rate Sets how fast the power production can be adjusted upwards or downwards Absolute production limit Limit the maximum production level in the PCC in order to avoid the overloading of the system. Marco Liserre Grid requirements to connect DPGS based on RES Regulation functions for active power Delta control

The wind farm shall operate with a certain constant reserve capacity in relation to its momentary possible power production capacity. Horns Reef offshore windfarm 10*8*2MW=160MW: Operates with 10% Delta Control Marco Liserre Grid requirements to connect DPGS based on RES Regulation functions for active power Horns Reef Marco Liserre Grid requirements to connect DPGS based on RES Frequency control Eltra Denmark Requirements for wind turbines connected to grids with voltages below 100 kV fd-=48.70

fd+=51.30 fn=49.85 Marco Liserre fu=50.15 Grid requirements to connect DPGS based on RES Frequency control E-On: power reduction at over frequencies Marco Liserre Grid requirements to connect DPGS based on RES Frequency control Ireland: Frequency control characteristic Marco Liserre Grid requirements to connect DPGS based on RES Reactive power control Eltra Denmark The reactive power flow between the wind turbine including the transformer and the electrical network must be calculated as an average value over 5 min

within the control band Marco Liserre Grid requirements to connect DPGS based on RES Reactive power control E-On Germany Every generating units shall provide in the connection point the range of reactive power provision shown in the figure without limiting delivered active power Type of regulation Power factor Mvar regulation Voltage regulation Marco Liserre Grid requirements to connect DPGS based on RES Reactive power control Great Britain Every generating unit other than synchronous one with a completion date after 1 January 2006 should be able to support an active reactive power flow shown in the figure.

Marco Liserre Grid requirements to connect DPGS based on RES Voltage quality Eltra Denmark. Requirements for wind turbines to grids with voltages below 100 kV Marco Liserre Grid requirements to connect DPGS based on RES Ride-through capability Eltra Denmark. Requirements for wind turbines to grids with voltages below 100 kV The wind turbine shall be disconnected from the electrical grid according to the figure. Under some special situations a WT shall not be disconnected from the electrical network Marco Liserre Grid requirements to connect DPGS based on RES Eltra Denmark

Ride-through capability Requirements for wind turbines to grids with voltages below 100 kV The wind turbine shall stay connected in the following cases. 3-phase short-circuit for 100 msec; 2-phase short-circuit with or without ground for 100 msec followed after 300-500 msec by a new short-circuit of 100 msec duration. Sequences in which WT should keep connected: At least two 2-phases short-circuits within 2 min interval; At least two 3-phases short-circuit within 2 min interval.

Energy reserve to remain connected when: At least six 2-phases short-circuits with 5 min interval; At least six 3-phases short-circuit with 5 min interval. Marco Liserre Grid requirements to connect DPGS based on RES E-On - Germany Ride-through capability Three-phase short-circuits or fault related symmetrical voltage dips must not lead to instability above the red line Between lines red and blue: All generating plants should experience the fault without disconnection from the grid. If, due to the grid connection concept, a generating plant cannot fulfill this

requirement, it is permitted with agreement from E-On to shift the limit line while at the same time reducing the resynchronisation time and ensuring a minimum reactive power injection during the fault If, when experiencing the fault, the individual generators becomes unstable or the generator protection responds, a brief disconnection of the generating plant from the grid is allowed by agreement with E-On. At the start of a brief disconnection resynchronisation of the generating plant shall take place within 2 seconds at the latest. The active power infeed must be increased to the original value with a gradient of at least 10% of the rated generator power per second. The highest value of the 3phase line-toline grid voltage is considered in this figure Marco Liserre Grid requirements to connect DPGS based on RES E-On - Germany Ride-through capability The generating plants shall support the grid voltage with additional reactive current during a voltage dip.

The voltage control shall act within 20 msec after fault recognition. The generator unit shall provide a reactive current on the low voltage side of the transformer equal to at least 2% from the rated current for each percent of the voltage dip. If necessary the generating unit shall be able to provide full rated reactive current. Marco Liserre Grid requirements to connect DPGS based on RES REE Spain Ride-through capability The wind turbines shall remain connected during three-phase, two-phase or single-phase to ground faults with a voltage profile as shown in this figure.

In the case of isolated two-phase faults the valley of the voltage profile is set to 60%. Marco Liserre Grid requirements to connect DPGS based on RES Ride-through capability REE Spain. No active/reactive power will be consumed at the PCC neither during the fault period nor during the grid voltage recovery period after the fault clearance. The wind turbine should inject maximum reactive current both during the fault and after the fault is cleared and the grid voltage is in the recovering process with maximum delay of 150ms. Marco Liserre Grid requirements to connect DPGS based on RES Ride-through capability Comparison of different national voltage profiles for fault ride-through capability

Marco Liserre Grid requirements to connect DPGS based on RES Resume of several national grid codes Marco Liserre Grid requirements to connect DPGS based on RES Conclusions Few European countries have dedicated grid codes for interconnection requirements of RES and in most of the cases these requirements reflects the penetration of renewable sources into the electrical network. Many different grid codes around the world focusing on: Frequency /Power control Voltage support/reactive power compensation Power Quality, flicker, harmonics Fault ride through

All considered grid codes requires fault ride-through capabilities. Voltage profiles are given by the depth and the clearance time of the voltage dip. In some of the grid codes the calculation of the voltage during all types of unsymmetrical faults is very well defined e.g Ireland, while others does not define clearly this procedure. On the other hand Germany and Spain requires grid support during faults by reactive current injection up to 100% from the rated current. This demand is relative difficult to meet by some type of wind turbines. Marco Liserre Grid requirements to connect DPGS based on RES References 1. S. Heier, Grid Integration of Wind Energy Conversion Systems. John Wiley & Sons, 1998. 2. T. Ackermann, Wind Power in Power Systems. John Wiley & Sons, Ltd., 2005, iSBN: 0-470-85508-8. 3. L. H. Hansen, L. Helle, F. Blaabjerg, E. Ritchie, S. Munk-Nielsen, H. Bindner, P. Srensen and B. Bak-Jensen, Conceptual survey of Generators and Power Electronics for Wind Turbines Ris National Laboratory, December 2001, 106 p., ISBN 87-550-2745-8 http://www.risoe.dk/rispubl/VEA/ris-r-1205.htm

4. IEEE15471, IEEE standard for interconnecting distributed resources with electric power systems, July 2003. 5. Eltra and Elkraft, Wind turbines connected to grids with voltage below 100 kV, http://www.eltra.dk, 2004. 6. E.ON-Netz, Grid code high and extra high voltage, E.ON Netz GmbH, Tech. Rep., 2003. [Online]. Available: http://www.eon-netz.com/EONNETZ eng.jsp 7. S. M. Bolik, Grid requirements challenges for wind turbines Fourth International Workshop on Large Scale Integration of Wind Power and Transmission Networks for Offshore Wind Farms, Oct. 2003. 8. Geza Joos, Review of grid codes First International Conference on the integration of RE and DER, 1-3 december, Brussel, Belgium. http://cetc-varennes.nrcan.gc.ca/fichier.php/38852/2004-153e.pdf 9. P.B. Eriksen, T. Ackermann, H. Abildgaard, P. Smith, W. Winter, J.R. Garcia, System operation with high wind penetration IEEE Power and Energy Magazine,

Vol. 3, No. 6, Nov.-Dec. 2005 pp. 65 - 74 10. I. Erlich, U. Bachmann, Grid Code Requirements Concerning Connection and Operation of Wind Turbines in Germany IEEE Power Engineering Society General Meeting, June 12-16, 2005 pp. 2230 - 2234 Marco Liserre Grid requirements to connect DPGS based on RES Conclusions: the role of the grid converter Grid requirements constraints on the grid converter: Harmonic limits -> hardware (dc voltage rating) and control Dc current and leakage current -> hardware (converter structure, transformer, filter) and control (modulation) Islanding detection -> control

Operation within a frequency range -> control (PLL) Operation under over/voltage condition -> hardware (dc voltage and semiconductor rating) Reactive power injection (set/point, voltage control or power factor control) -> hardware (dc voltage rating, filter design) and control Frequency control -> control (PLL) Fault Ride-through capability -> hardware (semiconductor rating) and control (estimation and control of inverse sequence) Marco Liserre Grid requirements to connect DPGS based on RES Acknowledgment

Part of the material is or was included in the present and/or past editions of the Industrial/Ph.D. Course in Power Electronics for Renewable Energy Systems in theory and practice Speakers: R. Teodorescu, P. Rodriguez, M. Liserre, J. M. Guerrero, Place: Aalborg University, Denmark The course is held twice (May and November) every year Marco Liserre

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    Watching the user Look for goals, intentions, mental models, understandings of action sequences, etc. End of class review What we covered: Norman's Seven Stages of Action model The two Gulfs - execution and evaluation Foley and van Dam's Four Level...
  • SCEL Framework for Educational Leadership Objectives During the

    SCEL Framework for Educational Leadership Objectives During the

    Mapped to GTCS standards, activities support effective self-evaluation, PRD and Professional Update. Maintains a personal record of progress. Learning activities are available for educators at all levels - you do not require a formal leadership role to benefit from the...
  • PowerPoint Presentation

    PowerPoint Presentation

    People have various restraints: internal controls, such as conscience, values, integrity, morality, and the desire to be a "good person". They have outer controls, such as police, family, friends, and religious authorities. Sanctions - consequences
  • Creating the Secondary Mortgage Market - Players and History

    Creating the Secondary Mortgage Market - Players and History

    Creating the Secondary Mortgage Market:Players and History. Erica Liu. ... Fannie Mae becomes a government sponsored enterprise (GSE) sold to private shareholders. ... Creating the Secondary Mortgage Market - Players and History
  • National Decision Making Model - Sodon Vision

    National Decision Making Model - Sodon Vision

    Cleveland Police Other titles: Arial Calibri Default Design National Decision Making Model (NDM) Aim Why? Why? Legal Advice Three outcomes of NDM The Model Five Headings Statement of Mission and Values (ACPO 2011) Continued Statement of Mission & Values Slide...