UNIVERSIDAD POLITECNICA´ DE MADRID
ESCUELA TECNICA´ SUPERIOR DE INGENIEROS INDUSTRIALES
A voltage disturbances prototype for testing electrical generators connected to microgrids
TESIS DOCTORAL
Julia Merino Fern´andez Ingeniera Industrial
2015
DEPARTAMENTO DE AUTOMATICA,´ INGENIER´IA ELECTRICA´ Y ELECTRONICA´ EINFORMATICA´ INDUSTRIAL
ESCUELA TECNICA´ SUPERIOR DE INGENIEROS INDUSTRIALES
A voltage disturbances prototype for testing electrical generators connected to microgrids
Autora: Julia Merino Fern´andez
Ingeniera Industrial
Director: Dr. Carlos Veganzones Nicol´as
Dr. Ingeniero Industrial
Director: Dr. Francisco Bl´azquez Garc´ıa
Dr. Ingeniero Industrial
2015
Abstract
A VOLTAGE DISTURBANCES PROTOTYPE FOR TESTING ELECTRICAL GENERATORS CONNECTED TO MICROGRIDS
By
Julia Merino Fern´andez
The search for new energy models arises as a necessity to have a sustainable power supply. The inclusion of distributed generation sources (DG) allows to reduce the cost of facilities, increase the security of the grid or alleviate problems of congestion through the redistribution of power flows. In remote microgrids it is needed in a particular way a safe and reliable supply, which can cover the demand for a low cost; due to this, distributed generation is an alternative that is being widely introduced in these grids.
But the remote microgrids are especially weak grids because of their small size, low voltage level, reduced network mesh and distribution lines with a high ratio R/X. This ratio affects the coupling between grid voltages and phase shifts, and stability becomes an issue of greater importance than in interconnected systems. To ensure the appropriate behavior of generation sources inserted in remote microgrids -and, in general, any electrical equipment-, it is essential to have devices for testing and certification. These devices must, not only faithfully reproduce disturbances occurring in remote microgrids, but also to behave against the equipment under test (EUT) as a real weak grid. This also makes the device commercially competitive. To meet these objectives and based on the aforementioned, it has been designed, built and tested a voltage disturbances generator, in order to provide a simple, versatile, full and easily scalable device to manufacturers and laboratories in the sector.
Resumen
A VOLTAGE DISTURBANCES PROTOTYPE FOR TESTING ELECTRICAL GENERATORS CONNECTED TO MICROGRIDS
Por
Julia Merino Fern´andez
La b´usqueda de nuevos modelos energ´eticos surge como una necesidad para conseguir un abastecimiento el´ectrico sostenible. La inclusi´on de generaci´on distribuida (GD) permite una reducci´on del coste de las instalaciones, incrementando los niveles de seguridad de la red y aliviando problemas de congesti´on a trav´es de la redistribuci´on de los flujos de potencia.
En las microrredes remotas es especialmente necesario conseguir un abastecimiento fiable y seguro, que permita cubrir la demanda con un coste bajo; por ello, la generaci´on distribuida se presenta como una alternativa que, de manera masiva, se est´a introduciendo en este tipo de redes.
Pero las microrredes remotas son redes particularmente d´ebiles debido a su peque˜no tama˜no, sus bajos niveles de tensi´on, el escaso mallado y la presencia de l´ıneas de distribuci´on con un alto ratio R/X. Este ratio afecta al acomplamiento entre las tensiones de las red y susangulos ´ y la estabilidad se convierte en un problema de mayor importancia que en los grandes sistemas interconectados. Para asegurar el comportamiento apropiado de las fuentes de generaci´on antes de su inserci´on en microrredes remotas y, en general, de cualquier equipo el´ectrico es necesario disponer de equipos de ensayo y certificaci´on. Estos equipos deben, no s´olo reproducir fielmente las perturbaciones que ocurren en las microrredes remotas, sino tambi´en comportarte frente al equipo a ensayar como una red d´ebil real. Para cumplir estos objetivos y basado en lo anterior, se ha dise˜nado, construido y validado un generador de perturbaciones de red, con el objetivo de proveer de un equipo simple, vers´atil, completo y f´acilmente escalable para los fabricantes y laboratorios del sector.
Let the future tell the truth and evaluate each one according to his work and accomplish- ments. The present is theirs; the future, for which I really worked, is mine.
NIKOLA TESLA
A mis padres Antonio y Mary Luz y a mi hermano Antonio. A mi t´ıa Julia, que hubiera presumido tanto de m´ı.
vi
ACKNOWLEDGMENTS
Y por fin lleg´oeld´ıa. Al volver la vista atr´as, no puedo evitar sentir cierta satisfacci´on de haber llegado a esta cima, cuyo ascenso se me ha hecho a veces tan empinado, y es justo dar gracias a los que me han ayudado a conseguirlo. Hoy tambi´en son ellos parte de este triunfo.
A mis directores. A Carlos Veganzones, por todo el tiempo que me ha dedicado y por las ense˜nanzas que me ha transmitido estos a˜nos. Por prestarme su idea para el desarrollo de este trabajo. Por la ayuda en la configuraci´on y revisi´on final del documento de tesis. A
Francisco Bl´azquez por sus sugerencias para el dise˜no de las m´aquinas el´ectricas.
A Sergio Mart´ınez, por su implicaci´on desinteresada en mi formaci´on de posgrado. Por mar- car la diferencia y ser el que siempre me consider´o una compa˜nera y no una alumna.
To the professors and colleagues I was lucky to meet during my experiences as visiting scholar in UW-Madison and MSU. To Prof. Giri Venkataramanan and Patricio. To Dr. Strangas,
Dr. Foster and the Spartans (Andrew, Cristi´an, Reemon and Jorge). Thank you for your warmth and your friendship. Thank you very much for making me feel, at least for some months, part of a research group.
A otros profesores de la UPM, que me permitieron colaborar y aprender con ellos en sus
Departamentos durante esta etapa doctoral y que me trataron siempre con tanto afecto.
Gracias J. Angel´ S´anchez y gracias, Pablo Reina.
Al Departamento de Ingenier´ıa El´ectrica de la E.T.S.I. Industriales y al profesorado y per- sonal que lo componen. A los t´ecnicos de M´aquinas El´ectricas, por su soporte (bancada arriba, bancada abajo...). A Elena, por compartir conmigo losultimos ´ meses de laboratorio.
A mis compa˜neros de oficina, que en esta recta final me han aguantado con paciencia y comprensi´on mientras hablaba, casi obsesivamente, de esta tesis.
viii A mis padres, mi hermano y mis amigos, por su incondicional apoyo. Por soportar mi des´animo cuando, por primera vez en mi vida, me vi obligada a “tirar la toalla” y desistir de seguir persiguiendo mi sue˜no universitario. Gracias por compartir la alegr´ıa de verme hoy aqu´ı, m´as feliz, m´as fuerte y con nuevas metas que conquistar.
Julia
2015
ix x CONTENTS
LIST OF TABLES ...... xvii
LIST OF FIGURES ...... xix
LIST OF SYMBOLS ...... xxiii
Chapter 1 Introduction ...... 1 1.1Motivation...... 1 1.2 Objectives and contributions ...... 3 1.3 Outline of the thesis structure ...... 4 1.4 Dissemination ...... 5
Chapter 2 State of the Art ...... 7 2.1Microgrids...... 7 2.1.1 Definition and structure ...... 7 2.1.2 Classification...... 10 2.2 Remote microgrids with distributed generation ...... 13 2.2.1 Singularities ...... 13 2.2.2 Characterizationofdisturbances...... 17 2.2.2.1 Voltage dips ...... 17 2.2.2.2 Frequencydisturbances...... 18 2.2.2.3 Frequency disturbances associated with voltage dips .... 19 2.2.3 Worldwidesituationofremotemicrogrids...... 21 2.3 Regulations applicable to distributed generation sources connected to electri- calsystems.Gridcodes...... 23 2.3.1 Introduction...... 23 2.3.2 Gridcodesstructure...... 24 2.3.3 Requirementsingridcodes.Basicconcepts...... 25 2.3.4 Codesreview...... 28 2.3.4.1 Gridcodesofinterconnectedsystems...... 28 2.3.4.1.1 Introduction...... 28 2.3.4.1.2 Voltagerequirements...... 29 2.3.4.1.3 Frequencyrequirements...... 31 2.3.4.1.4 Phaseshift...... 32 2.3.4.2 Gridcodesofremotemicrogrids...... 33 2.3.4.2.1 Introduction...... 33 2.3.4.2.2 Major international codes applicable to remote sys- tems...... 33 2.3.4.3 Towardsharmonizedstandards...... 36 2.3.4.3.1 Introduction...... 36 2.3.4.3.2 ENTSO-Egridcode...... 37 2.3.4.3.3 Highlights of ENTSO-E grid code ...... 38 2.3.4.3.4 ENTSO-Eandremotemicrogrids...... 41 2.4Griddisturbancesgeneratorstotestelectricaldevices...... 42 2.4.1 Impedance-based...... 43 2.4.2 Electrical machines based ...... 44 2.4.3 Full-converter based ...... 45 2.4.4 Comparative between commercial topologies and the proposed device 46 2.5Conclusions...... 47
Chapter 3 General description and operating model of the voltage distur- bances generator prototype ...... 49 3.1 General description of the device ...... 49 3.1.1 The electrical machines ...... 51 3.1.1.1 Variablefrequencytransformer(VFT)...... 51 3.1.1.2 The induction regulator ...... 51 3.1.2 Thecontrolprogram...... 55 3.1.2.1 Cascadecontroldesign...... 55 3.1.2.2 ProgramI/O...... 56 3.1.2.3 Implementation in MATLAB/Simulink R ...... 57 3.2 Mathematical expressions ...... 58 3.2.1 Variablefrequencytransformer-EM1...... 59 3.2.1.1 Steady-stateequationsandequivalentcircuit...... 59 3.2.2 Inductionregulator-EM2...... 62 3.2.2.1 Steady-stateequationsandequivalentcircuit...... 62 3.2.3 Theveninequivalents...... 64 3.2.3.1 Voltagefrequencytransformer-EM1...... 64 3.2.3.2 Induction regulator - EM2 ...... 65 3.2.4 Simulationmodel...... 66
xii 3.2.5 Transientanalysis...... 71 3.3Conclusions...... 75
Chapter 4 Experimental setup, operational procedure and performance evaluation ...... 77 4.1Experimentalsetup...... 77 4.1.1 The electrical machines ...... 77 4.1.2 Controlandmonitoringsystem...... 78 4.1.3 The electric cabinet ...... 82 4.2Operationalprocedure...... 83 4.2.1 Setupofthevoltagedisturbancesgenerator...... 83 4.2.2 Preparationofthetest...... 84 4.2.2.1 Calibration ...... 84 4.2.2.2 PI controller tuning ...... 85 4.2.3 Testprocedure...... 86 4.3Performanceevaluationoftheprototype...... 87 4.3.1 Voltagedisturbances...... 87 4.3.2 Frequencydisturbances...... 89 4.3.3 Combined disturbances ...... 90 4.3.4 Harmonicbehaviour...... 91 4.4Conclusions...... 92
Chapter 5 Guidelines for the design of new prototypes ...... 93 5.1Problemapproach...... 93 5.1.1 Overview...... 93 5.1.2 Voltage drop evaluation of the preliminary design ...... 95 5.2 Minimization of the voltage drop in the induction regulator EM2 ...... 98 5.3Criteriadesignfornewprototypes...... 100 5.3.1 Prototype 2: Leakage reduction by redesigning the magnetic circuit . 100 5.3.1.1 Mutual inductance ...... 100 5.3.1.2 Leakage inductances ...... 101 5.3.1.2.1 Flux leakage components in wound rotor induction machines ...... 101 5.3.1.2.2 Mathematical expressions of the leakage inductances inEM2...... 103 5.3.1.2.3 Validation of leakage inductances in the prototype 1 106 5.3.1.3 Constantsandvariablesinthemagneticdesign...... 108 5.3.2 Prototype 3: Leakage reduction by redesigning the electric circuit . . 112
xiii 5.3.2.1 Optimization of the ampere-turns ratio ...... 112 5.4Conclusions...... 113
Chapter 6 Sizing, construction and assembly of the new prototypes .... 115 6.1 The finite-element methods (FEM) for electrical machines design ...... 115 6.2 Definition of new prototypes sizing by finite element analysis ...... 117 6.2.1 1.Slotdesign...... 117 6.2.2 2.Airgap...... 120 6.2.3 3. Transformation ratio & double-layer rotor winding ...... 122 6.3SimulationoftransientresponsebyFEManalysis...... 124 6.4 Construction and assembly ...... 126 6.5Conclusions...... 129
Chapter 7 Experimental results and comparative analysis of the prototypes131 7.1 Determination of the equivalent circuit parameters for new prototypes .... 131 7.2Experimentalresults.Comparativeanalysis...... 133 7.2.1 No-loadtest...... 133 7.2.2 Loadedtests...... 135 7.2.2.1 Testagainstapassiveload...... 135 7.2.2.2 Testagainstanactiveload...... 136 7.2.2.3 Testagainstgenerators...... 138 7.2.2.3.1 Asynchronousgenerator...... 138 7.2.2.3.2 Synchronousgenerator...... 140 7.3Conclusions...... 142
Chapter 8 Final conclusions and future work ...... 145
Appendix A Technical Data of the Experimental Setup Equipment ..... 149 A.1ServoMotors...... 149 A.1.1 Servo motor for EM1 machine ...... 150 A.1.2 Servo motor for EM2 machine ...... 150 A.2Drives...... 151 A.2.1AngledriveforEM1...... 151 A.2.2SpeeddriveforEM2...... 152 A.3Encoders...... 153 A.3.1AbsolutmagneticencoderforEM1...... 153 A.3.2IncrementalencoderforEM2...... 153 A.4DSPsdSPACE...... 154
xiv Appendix B Thevenin equivalent for the EM1+EM2 case ...... 157 B.1Theveninsource...... 158 B.2Theveninimpedance...... 158
Appendix C Calculation of Laplace residuals for transient regime solutions 161 C.1 Rotor current ir(s) ...... 161 C.2 Stator current is(s)...... 162
Appendix D Analytical calculation of slot leakage components in EM2 ... 165 D.1 Slot leakage inductance calculation ...... 165 D.1.1Rotorslotleakagecalculation...... 165 D.1.2Statorslotleakagecalculation...... 173 D.1.2.1Slotpermeanceduetothelowercoil...... 173 D.1.2.2Slotpermeanceduetotheuppercoil...... 173 D.1.2.3 Slot permeance due to the mutual effects between coils . . . 174
Appendix E Windings and steel sheets drawings ...... 177 E.1Magneticmaterial...... 177 E.2 Windings ...... 178 E.2.1 Rotor Windings ...... 178 E.2.2 Stator Winding ...... 178 E.3Electricsteelsheetsdrawings...... 179
BIBLIOGRAPHY ...... 182
xv xvi LIST OF TABLES
Table 2.1 PGM installed capacity limits according to ENTSO-E regions [1] . . 38
Table 2.2 Operating ranges of voltages. a) Voltages from 110 kV to 300 kV. b) Voltagesfrom300kVto400kV...... 40
Table2.3 PGMsfrequencyrequirements...... 41
Table 3.1 Electrical machine parameters ...... 66
Table4.1 Maincharacteristicsofprototype1...... 77
Table4.2 Basicdataofprototype1magneticcircuit...... 78
Table4.3 Basicdataofprototype1electricalcircuit...... 78
Table 5.1 Electrical machine parameters ...... 107
Table 6.1 Comparison between leakage reactances in prototype 1 and prototype 2 according to changes in the slot openings ...... 119
Table 6.2 Comparison between leakage reactances in original and improved pro- totype 2 according to the combined effect of the increment of the air-gapwidthplustheslotrefitting...... 122
Table6.3 Dataofprototype3electricalcircuit...... 123
Table 6.4 Comparison between leakage reactances in original and improved pro- totypes because of the change in the transformation ratio and the double-layer rotor winding design ...... 123
Table A.1 Data of Baum¨uller DS 56 S-3-R-K ...... 150
Table A.2 Motor data from Pujol Muntal´a IPCM 128/90L-4/148 ...... 151
Table A.3 Gearbox data from Pujol Muntal´a IPCM 128/90L-4/148 ...... 151
Table A.4 Main technical characteristics of Baum¨uller b maXX 4413 ...... 152
Table A.5 Main technical characteristics of Altivar 71 ...... 152 TableA.6 DataofRM36absolutencoder...... 153
Table A.7 Data of encoder Schneider XCC1506PS50X ...... 154
xviii LIST OF FIGURES
Figure2.1 Generalschemeofamicrogrid...... 8 Figure 2.2 Classification of microgrids according to the market segment . . . . 10 Figure 2.3 Distribution of microgrids due to the market segments [2] ...... 12 Figure 2.4 Requirements of energy reserves in a remote grid ...... 14 Figure 2.5 Number of unscheduled events recorded in La Palma island during 2008...... 16 Figure 2.6 Present and expected wind power generation in the isolated system ofGranCanaria...... 16 Figure 2.7 a) Voltage dip in the remote microgrid of El Hierro island; b) Voltage dipspreadinthegridofGranCanariaisland[3]...... 18 Figure2.8 Recordofafrequencydisturbanceinaremotemicrogrid[4]..... 19 Figure 2.9 Record of main electrical magnitudes in a dip in a 400 kV node . . . 20 Figure 2.10 Record of main electrical magnitudes in a dip in a spanish nonmain- landnode...... 21 Figure2.11Consequencesoftheuseofgridcodesinelectricalsystems...... 24 Figure 2.12 Classification of voltage disturbances according to IEEE Std. 1159-1995 26 Figure 2.13 Profile types of voltage dips. a) Rectangular profile. b) Profiles with recoveryramp...... 27 Figure2.14Voltagedipprofilesrequiredinmaininternationalcodes...... 29 Figure 2.15 Over/undervoltage and voltage swells requirements in main intercon- nectedgridcodes...... 31 Figure2.16Operatingfrequencyranges...... 32 Figure 2.17 a) Voltage dip profiles for microgrids up to 50MW. b) Voltage dip profiles for microgrids above 50MW ...... 34 Figure2.18Over/Undervoltagerequirementsinremotemicrogrids...... 35 Figure2.19Frequencyrequirements...... 36 Figure 2.20 Voltage dip profiles in ENTSO-E code. a) SPGMs type B and C; b) PPMs type B and C; c) SPGMs type D; d) PPM type D ...... 39 Figure2.21Impedance-basedvoltagedipgenerator...... 44 Figure2.22Transformer-basedvoltagedipgenerator...... 45 Figure2.23Voltagedipgeneratorbasedonfullpowerconverter...... 46
Figure3.1 Generalschemeofthedevice...... 50 Figure 3.2 Single-phase scheme of the wound rotor induction machine connection 52 Figure 3.3 Single-phase scheme of the induction regulator connection ...... 53 Figure3.4 Voltagephasordiagram...... 54 Figure3.5 ControlloopsforEM1andEM2...... 55 Figure3.6 ModelI/O...... 56
Figure 3.7 MATLAB/Simulink R control...... 57 Figure 3.8 Single-phase representation of the EM1 machine ...... 59
Figure 3.9 Single-phase representation of the EM1 machine reduced to fr frequency 60 Figure 3.10 Single-phase representation of the EM1 machine reduced to rotor winding ...... 61 Figure3.11Single-phasecircuitofEM2...... 62 Figure3.12EquivalentcircuitofEM2...... 63 Figure3.13Simulationmodelofthevoltagedisturbancesgenerator...... 67 Figure 3.14 Steady-state comparative between simulation and experimental results 67 Figure 3.15 Steady-state comparative between simulation and experimental results 68 Figure 3.16 Percentage errors between simulation and experimentation results . 69 Figure 3.17 Comparative between the simulation model and the experimental re- sultsintherecoveryramp...... 70 Figure 3.18 Equivalent circuit representation for transient analysis. a) Time- domain.b)Laplacedomain...... 72
Figure4.1 Schemeoftheelectricdrivesystem...... 79 Figure4.2 HMIofthevoltagedisturbancesprototype...... 81
xx Figure 4.3 Voltage disturbances generator cabinet ...... 82 Figure 4.4 Voltage magnitude output during calibration ...... 85 Figure 4.5 Reproduction of voltage swells and dips ...... 87 Figure4.6 Anglesetpointandtracking...... 89 Figure 4.7 Voltage dips profiles ...... 89 Figure4.8 Frequencydisturbances...... 90 Figure 4.9 Combined voltage, frequency and phase jump disturbance ...... 91 Figure4.10Harmonicspectraofvoltagewaveforms...... 91
Figure 5.1 No-load and full load voltage dips with the prototype 1 ...... 95 Figure5.2 Phasordiagramoftheprototype1...... 96 Figure 5.3 Output voltage at the induction regulator for a generator with cosφ =1 97 Figure5.4 Slotleakageflux...... 102 Figure 5.5 Leakage flux paths in the end-windings ...... 102 Figure5.6 Zigzagleakagefluxpaths...... 102 Figure 5.7 End-winding main dimensions ...... 104 Figure 5.8 Influence of the geometric parameters over the slot permeances . . . 111
Figure6.1 RotorLeakageReactancecontourplot(Ω)...... 118 Figure6.2 StatorLeakageReactancecontourplot(Ω)...... 119 Figure6.3 Cartercoefficientvariationduetorotorslotting...... 120 Figure 6.4 Variation of main parameters affected by air gap width ...... 121 Figure 6.5 Magnetic flux density in prototype 3 before and during voltage dip reproduction...... 125 Figure 6.6 Rotor and stator laminations for new prototype designs ...... 126 Figure 6.7 Electrical machines with taps to be used as EM1 ...... 127 Figure6.8 Mainstepsinprototypesconstruction...... 128
Figure7.1 Comparisonofparametersbetweentheprototypes...... 132
xxi Figure 7.2 Comparison of voltage dips for the prototypes at no-load ...... 134 Figure 7.3 Comparison of voltage dips against resistive load at full rated power 135 Figure7.4 Asynchronousmotor/generatortestbench...... 136 Figure7.5 Comparativebehaviouroftestsagainstasynchronousmotor..... 137 Figure7.6 Comparativebehaviouragainstasynchronousgenerator...... 139 Figure 7.7 DC machine and synchronous generator test bench ...... 140 Figure 7.8 Comparative of the behaviour of prototypes connected to synchronous generatorswithstaticexcitation...... 141 Figure 7.9 Comparative of the behaviour of prototypes connected to synchronous generatorswithstaticexcitation...... 142
Figure A.1 Servo motors involved in the disturbances generator prototype . . . 149 Figure A.2 Block diagram of dSPACE DS1104 R&D ...... 155
Figure B.1 Single-phase representation of the device ...... 157 Figure B.2 Single-phase representation of the device ...... 159
FigureD.1 Rotorslot...... 166 FigureD.2 Fractionofrotorslot...... 168 FigureD.3 Changeoftheturnsratiodependingontheslotdepth...... 169 FigureD.4 Region3oftherotorslot...... 170 Figure D.5 Stator slot geometric dimensions ...... 174
Figure E.1 BH curve of V600-50A magnetic steel ...... 177 Figure E.2 Rotor winding configuration for prototypes 0 and 1...... 178 Figure E.3 Double-layer lap winding design for stators ...... 179 FigureE.4 Designforprototype0 ...... 180 FigureE.5 Designforprototypes1&2 ...... 181
xxii LIST OF SYMBOLS
α Electrical angle between rotor and stator windings (deg)
ω Speed (p.u.)
φm Mutual flux σ Factor for harmonic leakage reactance calculation
τ Slot pitch
τp Pole pitch
Dor Rotor outer diameter
Ir Rotor current
Is Stator current K Transformation ratio
Uo Output voltage phasor
Ur Rotor voltage phasor
Us Stator voltage phasor
Xσ Leakage reactance
Xm Mutual reactance between rotor and stator referred to rotor side Z Impedance b Slots widths few Permeance factor associated to axial length fW Permeance factor associated to the coil span g Air gap width ge Effective gap considering effects of fringing and saturation H Inertia constant (s) h Slots heights Lew End-winding leakage inductance per unit of length Lh Harmonic leakage inductance per unit of length Lslot Slot leakage inductance per unit of length Lzz Zig-zag leakage inductance
Lew End-winding length P Poles p Permeance
Pe Sum of the power of the loads (p.u.)
Pm Sum of the power of the generators (p.u.) q Slots per pole and phase in rotor
R Resistance
S Number of slots s Slip
Wew End-winding width ξ Winding factor th ξh Winding factor for the h harmonic kb Back-calculation constant of the PI controller ki Integral constant of the PI controller kp Proportional constant of the PI controller kw Weighting constant of the PI controller m Number of phases
N Number of turns per phase n Number of turns per coil
Note: Additional subscripts r and s along the content refer to rotor and stator values
xxiv Chapter 1
Introduction
1.1 Motivation
The current power consumption involves the emission to the atmosphere of great amounts of
CO2 contributing to accelerated climate change. During the year 2012, 31.6 Gt of CO2 were emitted, of which 60% belonged to countries outside the OCDE (mainly to the emergent economies of China, India and Brazil). Due mainly to the growth of these countries, it is expected that by 2020 the world electricity consumption will be almost 30% higher than at present [5]. This evidences a crisis in the traditional energy model, posing serious problems of sustainability in the medium and long term. If we add that fossil fuels are finite and scarce, which in turn has untied a price war on the markets, it is clear the need to find new models for energy supply.
On the approach of new models two main objectives are pursued: the replacement of the conventional generation by renewable energy sources (RES) and the improvement of overall efficiency. Distributed generation (DG) is presented as the most appropriate alternative in order to achieve these goals. DG favors the inclusion of non-conventional generation, allowing the installation of groups located close to the natural resources, at distribution voltage levels.
It also allows an efficiency rise by bringing the generation towards the consumption points to reduce losses in the transportation of electrical energy.
The massive increasing of wind power plants in electrical systems has forced the deve- lopment of a more complete and rigorous regulation in terms of connection and operation requirements for electrical generators. From this new perspective, traditional electrical sys- tems are gradually fragmenting into smaller ones, with a high percentage of renewable en- ergy installed. Decentralized generation helps to improve grid security, because the supply no longer depends on a few critical nodes. The ultimate goal is have a grid formed by a set of smaller systems called microgrids, connected to each other, self-supplied and with the capacity of operating in isolated mode in the event they are required.
The needed electricity supply to remote areas, as islands or faraway locations in devel- oping countries provides a very particular configuration for their electrical systems. They are a subgroup of special microgrids -remote microgrids- that have a very weak link inter- connection or even a totally lacking link. In remote microgrids, low levels of short-circuit power, the weakness of the network, low inertia of the groups and accused variations in the load profile as main characteristics, make that any abnormal situation ocuring at a point can affect the whole of the network and can seriously compromise the security and stability of the system.
It is worth remarking that the availability of a strong link between a microgrid and the local electric distribution system allows continuity of supply in the microgrid in case of disconnection of several generators due to maintenance or fault. The absence of this option requires to establish higher levels of reserve groups to deal with contingencies and to adopt additional procedures in the management and operation protocols.
The remote microgrids are especially suitable for the inclusion of renewable energy but they are more vulnerable than any other type of microgrid. Hence the technical requirements in regulations applicable to these systems are generally more demanding. It is essential for manufacturers, electrical distributors and certifiers to have flexible equipment, useful to validate the behavior of their devices according to new grid codes requirements.
2 This thesis discusses the design and construction of a new voltage disturbances prototype, in order to be employed in the validation and certifying compliance with the grid codes. The requirements will be those currently in use or those that will foreseeably appear on new standards. In the previous literature search of this work, detailed in cha. 2, no device has been found that shares the characteristics and objectives of the one developed, so this new equipment covers a technological gap.
1.2 Objectives and contributions
The main objective pursued by this thesis involves the design, construction, programming, testing and validation of a voltage disturbances prototype. This equipment allows the cre- ation of frequency and voltage disturbances as well as phase jumps, so it can be used for the certification of electrical equipment prior to its inclusion in particularly weak electrical networks, as remote microgrids.
This main objetive can be furthered splitted into three intermediate targets that are listed below:
• Design of two electrical machines, improved from a commercial wound rotor induction
motor intended for operation as part of this prototype, with the aim of increasing
the performance of the device. These machines have modifications on some design
parameters in order to reduce, to a certain extent, the effect of current flow through
the prototype that can have on the disturbance to be created or on the equipment to
be tested.
• Programming of the real-time control system that allows the accurate reproduction of
the desired disturbances and whose main features are precision, speed of response and
flexibility.
3 • Implementation of a data acquisition system for control and monitoring of the variables
of interest, like the development of a human machine interface (HMI) to allow the user
an easy and intuitive handling of the test equipment.
The result of the fulfillment of these goals involves a contribution of knowledge to the research area that frames this work.
1.3 Outline of the thesis structure
Chapter 2 gathers the information concerning to the state of the art in the main topics constituting a framework of the work. It has been divided in three blocks of contents. First, main characteristics defining microgrids and definition of disturbances in these systems are studied. Second, it has been collected a wide study about grid codes: structure, requirements and main regulations for isolated grids as well as interconnected networks. And third, a literature search of commercial devices to reproduce voltage dips as test equipment have been compiled.
In Chapter 3 the conceptual idea underlying the device and the operational procedure of the equipment are drafted. The first performance results for the prototype built from commercial machines are also collected.
Chapter 4 develops the mathematical expressions, the Thevenin equivalents and the simulation model to represent the steady-state behaviour of the prototype and the equations to define the transient regime have been explored.
Chapter 5 clusters the main information concerning to the electrical machines design. The weak points of the commercial setup are analyzed and some improvements for the design of future prototypes are proposed.
4 Chapter 6 focuses on the final definition of new electrical machines. It also shows the transient model developed by finite elements and describes the process for construction and assembly of enhanced prototypes.
Chapter 7 shows the characterization of new prototypes by means of testing, the experi- mental results reached and the comparison between original prototypes and enhanced ones, in order to quantify the effectiveness of design changes applied to the electrical machines.
Chapter 8 collects the final conclusions of the dissertation and settles the basis for future improvements.
1.4 Dissemination
Papers in JCR journals:
• Merino, J.; Mendoza-Araya, P.; Venkataramanan, G.; Baysal, M.; Islanding Detection
in Microgrids using Ambient Harmonics. Power Delivery, IEEE Transactions on,vol.
PP, no. 99, pp.1,1, Dec. 2014.
• Merino, J.; Mendoza-Araya, P.; Veganzones, C. State of the Art and Future Trends in
Grid Codes Applicable to Isolated Electrical Systems. Energies, no. 7, pp. 7936-7954.
Nov. 2014.
• Merino, J.; Veganzones, C.; Sanchez, J.A.; Martinez, S.; Platero, C.A. Power System
Stability of a Small Sized Isolated Network Supplied by a Combined Wind-Pumped
Storage Generation System: A Case Study in the Canary Islands. Energies, no. 5, pp.
2351-2369. July 2012.
• Veganzones, C.; Sanchez,J.A,; Martinez, S.; Platero, C.A.; Blazquez, F.; Ramirez, D.:
Rodriguez, J.; Merino, J.; Herrero, J.; Gordillo. F. Voltage Dip Generator for Testing
5 Wind Turbines Connected to Electrical Networks. Renewable Energy, Vol. 36, no. 5,
pp. 1588-1594. May 2011.
Patent application:
• Rodr´ıguez, J.; Herrero, N.; Merino, J.; Platero, C.A.; Veganzones, C.; Bl´azquez, F.;
Mart´ınez, S.; S´anchez, J.A. “Generador de perturbaciones de tensi´on para ensayo de
equipos el´ectricos y su procedimiento de operaci´on en redes con generaci´on distribuida”.
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6 Chapter 2
State of the Art
This chapter collects a literature review of the topics on which this thesis focuses. First of all, microgrids are analyzed as a distinct structure within the electric power systems. Then, the particularities that define remote microgrids and the characteristics of disturbances occurring in them are studied. Later, it is examined the legislation that currently must meet generators
-especially wind turbines -before its insertion in electrical systems, and the tendency which is expected to be followed by new regulations. Eventually, is extensively analyzed the specific bibliography on voltage disturbances generators employed in the study or certification of DG systems. These devices are evaluated with the purpose of highlighting the contributions of the new device over other existing equipment.
2.1 Microgrids
2.1.1 Definition and structure
According to the definition given by the United States Department of Energy (DOE), a microgrid is an electrical system consisting of a set of generators, storage devices, loads and interconnection elements that has the ability to operate autonomously or grid-connected
[6]. Researchers at the Consortium for Electric Reliability Technology Solutions (CERTS) added, moreover, that a microgrid must be able to provide combined electrical and thermal energy to users [7]. The ability to work stably and safely in islanded and grid-connected modes, make mi- crogrids a highly flexible structures. They appear as the best alternative to promote the integration of DG sources in power systems. The microgrids have regulation systems over their generation units and loads so they provide, at every moment, a full and complete power flow control. From the utility grid side, a microgrid is an active electrical system which behaves like an individual generator or load at the point of common coupling (PCC).
In Fig. 2.1 the general scheme of a microgrid can be observed with the elements that typically comprise it, although it is not necessary for all of them to be present simultaneously.
The generators can be rotating electrical machines directly connected to the grid, thermal or hydraulic synchronous units, asynchronous machines or renewable energy sources connected to the utility grid through electronic converters -wind generators, PV generators, etc-. The storage systems such as batteries, flywheels or supercapacitors, help stabilize the grid in case of transient disturbances. They also contribute to restore the equilibrium when generation- load imbalances take place. The advantages provided by storage are especially needed when the microgrid is working in islanded mode.
GRID
PCC MICROSWITCH
M MOTORS
LOADS
G STORAGE DEVICES G CONVENTIONAL GENERATOR
MICROGRID Figure 2.1: General scheme of a microgrid
8 According to the standard IEEE P1547 [8], the power limit of a source to be considered as a DG source is 10 MVA and it has to be connected to a distribution grid. This unique generation/storage unit with their associated controls would already form a microgrid. This value must be taken as an indicative manner since, in practice, the inclusion of a grid in the microgrid group is based on topology and functional criteria.
As a summary of the different definitions in the literature, it could be concluded that there are four common characteristics that a grid must meet to be classified as a microgrid:
• Ability to supply combined electricity and heat.
• Physical proximity between generation and consumption centers.
• Stability in its operation in islanded and grid-connected modes and in the transitions
between them.
• Real-time control and management of power flows.
A microgrid, from the operational point of view, must fulfill two conditions. On the one hand, any component in the assembly can be critical, i.e., the stability and security of the grid has to be maintained regardless of the failure of any element of the system. This shows a similarity with the N-1 safety criterion applicable to the conventional electrical systems.
This first condition means necessarily that each generation/storage unit must have its own power-frequency controls and its associated protections. On the other hand, within the microgrid, any two units can be exchangeable without making necessary the redesign of the grid [9].
The isolated power systems can be considered as a particular case of microgrids, which do not have the possibility of connection to the mains. These microgrids are known as remote microgrids.
9 There are unresolved aspects that pose barriers to the bulk introduction of microgrids in electrical systems. From the technical perspective, those are linked to complex control of multiple generating sources, detection of abnormal islanding events and the subsequent re- connection process. In terms of regulations, there are shortcomings in the specific legislation in a large number of countries, such as Spain. There are difficulties in defining the connec- tion requirements, who are the agents responsible for the grid management and the trade of surplus power -if connected to the utility grid - and what will be the suitable remuneration regime.
2.1.2 Classification
The microgrids can be classified according to several criteria. The most common is to establish the organization in terms of demand characteristics established by the needs of the users or according to the market segment, as seen in Fig. 2.2:
Figure 2.2: Classification of microgrids according to the market segment
The institutional microgrids assemble a set of public buildings, and are intended to supply areas of administrative, medical or educational services. They have a specific design accor- ding to the required function and are State-owned. This aspect facilitates the technical
10 management of the grid, makes it easily centralized and dependent from a single adminis- trator in generation and demand. This also happens with economic management, since the resulting benefits have a direct impact on citizens. A fundamental aspect of their operation is the need to ensure the continuity of supply especially in buildings, such as, for example, hospitals.
The industrial or commercial microgrids are, in the essence of their structure, similar to the institutional, so that in many articles appear as a single group [10, 11, 12]. Technical management of the grid is more complicated since various stakeholders are involved, for example, in the case of a commercial complex where there are several types of businesses with different administration models.
The military microgrids tend to have a strong support of renewable generation sources, since they are in remote areas and they often operate isolated from the mains. Most of them are temporary facilities. In these grids the reliability factor is a priority over the quality of the service.
The community microgrids are intended to supply residential areas. These microgrids will be an important part of its operation time connected to a larger grid. Being completely private properties, its development will generally depend on the existence of advantageous specific legislation for owners. They can serve to palliate congestion problems that exist in the low- or medium-voltage grids. A planned disconnection of these microgrids from the utility grid can avoid load shedding in case of an abnormal situation.
And the last group are the remote microgrids, of special interest in this thesis. Its structure is similar to the community or commercial microgrids. They present the main difference that unless further developments of the infrastructures, they will never operate connected to the mains. Compared to the military microgrids, that also operate in islanded
11 mode, the remote microgrids are designed to fulfill additional requirements of reliability, efficiency and quality of service, because they are intended for permanent installations.
Reduced Off-grid energy 2012: (5%, 110 MW) cost 2020: 16% CAGR
Commercial & Industrial 2012: (25%, 510 MW) 2020: 17% CAGR Communies & Ulity 2012: (20%, 420 MW) 2020: 12% CAGR
Instuonal & Campus 2012: (42%, 870 MW) 2020: 11% CAGR Military 2012: (9%, 180 MW) 2020: 17% CAGR
Reduced emissions Improvedd PowerP Quality / Reliability Figure 2.3: Distribution of microgrids due to the market segments [2]
The idea of remote microgrid is not novel itself. Many rural areas had for years a electri-
fication grid that according to the the current standards would come within the definition of microgrid. It is relatively recent the discovery of the technical and economic advantages they offer and the establishment of common criteria that are the basis for its development. Com- pared to very extended models of microgrids, the remote microgrids have a wide progression ahead.
In the bubble chart in Fig. 2.3 it is observed the current (2012) and planned distribution
(2020) of microgrids according to the segment market. In the figure it can be appreciated that remote microgrids are the least polluting, by the high proportion of renewable energy installed, and those which get a cheaper energy supply. At the other end they are the military microgrids. In them the most important is the security of supply in exchange for high
12 investment costs which would be unacceptable in other contexts. For the remote microgrids it is expected a compound annual growth rate (CAGR) of 16% up to 2020. Institutional and commercial microgrids are the most implemented (almost 70% of them belong to these two groups). They use a smaller proportion of renewable energy than the community or remote microgrids, because the security of supply required forces, in some cases, to the use of back-up diesel units. This reserve of energy required to face up with potential failures of the microgrid increases the final cost of the installation.
2.2 Remote microgrids with distributed generation
2.2.1 Singularities
Remote microgrids are electrically isolated systems, weak networks that are in geographically far-off locations -especially on islands or small populations of developing countries-. They currently remain largely dependent on the use of fossil fuels. Until recently, only diesel generators were able to ensure a secure and reliable supply in exchange for very high prices in the transportation of fuel and in the operation of the system. They are in areas of high ecological interest, which forces to search for the trade-off between energy efficiency and environmental friendliness. Existing solutions involve a mixed supply, maintaining the support of conventional generation groups with the advantages provided by RES.
As remote microgrids do not have connection to the mains, the system has to be designed to autonomously meet the criteria of reliability and quality of service. In addition, a high percentage of the supply depends on renewable energy, i.e. intermittent energy sources is necessary to establish new protocols for management of such microgrids. Below, three areas that make clear the need of operation procedures that gather the incidences derived from the management of these grids are highlighted:
13 • The reserves managment
• The the security criteria
• The generation and demand forecasting
It becomes clear that the operation is strongly influenced by the impact that contingen- cies have on the system. This impact is much higher in remote microgrids compared with interconnected systems, making necessary the establishment of higher reserve levels. The conventional groups are forced to work below their rated power, leading to cost overruns.
This reserve value tends to be the minimum allowed by the country’s legislation and it is often insufficient. Due to this, in isolated systems or remote microgrids, it is usual that in case of an unscheduled failure, load has to be shed in order to retrieve the normal operating condition.
To emphasize the importance of the need for a proper management of the energy reserves in an isolated system it is described, as an example, a contingency registered on the Spanish island of Gran Canaria on November 7, 2006 (Fig. 2.4). Electricity Demand (MW)
+ 75 MW Wind power (MW) Wind power - 40 MW
Source: REE Figure 2.4: Requirements of energy reserves in a remote grid
14 It can be observed that in the period between 16.48h and 18.40h -less than two hours- there was a simultaneous increase in demand for 75 MW and a sudden decrease of wind power generation of about 40 MW. The wind power lost had to be compensated by the reserve planned in the system, assigned to the back-up conventional generation.
In remote microgrids it is difficult to foresee any incidents as they possess a high degree of uncertainty due to the grid variability of voltage levels. This makes difficult the compliance regards to security criteria. The lines offer a high impedance which causes a voltage drop highly dependent on the degree of load, seriously influencing the power quality in the PCC.
In systems that have not yet implemented DG, there is a risk of operation because the electrical generation is condensed in a few nodes. They are also poorly meshed grids with low voltage level (< 66kV ). For all the above, in these grids it is usually registered a high number of breaches of the N-1 safety criteria. As an example, in the Fig. 2.5 data of the unscheduled events which were recorded during the year 2008 in the Canary Island of La
Palma are shown [13]. The variability in the number of failures that occur in the system is very high, which complicates the management of the microgrid.
For a proper operation of the remote microgrids it is needed some improvements in the forecasting systems of the production of the non-dispatchable resources and the demand. It is also required a good estimation of the ratio between conventional and renewable generation necessary to ensure stability.
In each graph shown in Fig. 2.6 appears, simultaneously, the value of wind power gene- rated (in MW) respect to the predicted value by the estimation model and for different time horizons. The gap between the forecast and the actual generation reaches maximum errors of up to 80% with 24h in advance.
15 Unscheduled events (2008) 45 40 39 35 30 25 20 15 14 9 10 8 6 5 2 2 2 2 2 0 0 0
Figure 2.5: Number of unscheduled events recorded in La Palma island during 2008.
Real Max. 30.73 MW at 16.00 p.m. Real Min. 1.13 MW at 10.00 a.m. Est. Max. 17.78 MW at 13.00 p.m. Est. Min. 3.56 MW at 1.00 a.m. (24h before)
Est. Max. 13.87 MW at 15.00 p.m. Est. Min. 3.56 MW at 1.00 a.m. (6h before)
Est. Max. 37 MW at 15.00 p.m. Est. Min. 1.32 MW at 9.00 a.m. (1h before)
Source: REE
Figure 2.6: Present and expected wind power generation in the isolated system of Gran Canaria
16 2.2.2 Characterization of disturbances
2.2.2.1 Voltage dips
The contingency that most affects the power quality is the voltage dip since it represents almost 80% of short-term disturbances in the grid [14].
A voltage dip, as defined in the reference [15], is a sudden decrease in the voltage at a grid node followed by their subsequent recovery and whose duration is between 10 ms and 1 min.
There are many causes that can lead to the appearance of a voltage dip. These causes are related to the connection or disconnection of elements in the system, either for operational reasons or as a result of short-circuits. The remote microgrids are usually reduced power, nodes are physically close together, connected through very short distribution lines and are electrically equivalent points. In addition, the relative power of the groups of generation/load with respect to the total power of the system is important.
These circumstances determine the characteristics that usually present voltage dips in remote microgrids: they are very deep and their propagation area is very broad. As an example, in Fig. 2.7a, it is shown the temporal profile of a voltage dip characteristic of those produced in the distribution grid of 20 kV in El Hierro island. It is noted that the voltage in several nodes of the grid is almost the same because of the small size of the microgrid.
In addition, in Fig. 2.7b it is displayed the spread of a voltage dip in the isolated electrical system of Gran Canaria island. Even the latter is a relatively large electrical system within the remote microgrids, a short circuit at the output of one of the major power plants affects the entire electrical system (of 66 kV). In these conditions no node is able to stay within the allowable voltage limits of the system.
17 1.25 MUELLE GRANDE
0.8 GUIA GUANARTEME ARUCAS 1 BUENAVISTA LOMO APOLINARIO 070.7
C.T. JINAMAR BARRANCO SECO 0.75 0.6 MARZAGAN
SAN MATEO TELDE 0.5 0.5 CINSA 0.4
Voltage (p.u) Voltage CARRIZAL 0.25 0.3
0.2 0 ALDEA BLANCA 0 2.5 5 7.5 10 MATORRAL Time (s) 0.1
C.T. BCO. TIRAJANA ARGUINEGUIN SAN AGUSTIN 0
LOMO MASPALOMAS CEMENTOS ESPECIALES
(a) (b)
Figure 2.7: a) Voltage dip in the remote microgrid of El Hierro island; b) Voltage dip spread in the grid of Gran Canaria island [3]
2.2.2.2 Frequency disturbances
In any electrical system, often frequency disturbances appear as the result of imbalances between generation and load. The swing equation of the rotor of electrical machines, in
(p.u.) over the base power is shown in Eq. 2.1:
dω P − P =2· H · (2.1) m e dt
where
Pm = Sum of the power of the generators (p.u.)
Pe = Sum of the power of the loads (p.u.) H = Inertia constant (s)
ω =Speed(p.u.)
From the previous equation it follows that the change in the rotational speed of the generator, and therefore the frequency of the network, is directly proportional to the in- stantaneous imbalance between generation and demand and inversely proportional to the sum of the inertia provided by the groups. In the remote microgrids there are mostly diesel
18 groups of low inertia. This means that in case of a disturbance, the frequency deviations are noticeably greater than those that would occur in an interconnected system.
f (Hz)
50
49.75
49.50
49.25
0 50 100 150 200 250 300 t/s
Source: REE Figure 2.8: Record of a frequency disturbance in a remote microgrid [4]
Figure 2.8 shows a typical frequency disturbance pattern in a remote microgrid, which corresponds to an event on the island of Tenerife on April 7, 2011. The trip of one of the larger generation units caused a sudden drop in frequency. Since the frequency kept outside of normal operation ranges after an extended time (150 s), the System Operator shed interruptible load, in order to accelerate grid recovery.
2.2.2.3 Frequency disturbances associated with voltage dips
The changes that happen on the voltage and frequency magnitudes during a disturbance are not independent from each other.
In interconnected grids a sudden voltage dip creates small frequency deviations. As an example, in Fig. 2.9 it is displayed the records of main electrical magnitudes in a 400 kV node of the Spanish grid when a severe fault takes place (a three-phase short circuit).
19 Trip 07/05/2009 22:27:05.253
I/ A K1:Current phase A Baixas K1:K1:Current phase B Baixas K1:Current phase C Baixas
0 -0.20 -0.15 -0.10 -0.05 0.00 0.05 0.10 0.15 0.20 0.25 0.30 t/s
-10000
U/ V K1:Voltage phase A Baixas K1:Voltage phase B Baixas K1:Voltage phase C Baixas 300000 200000 100000 t/s -0.20 -0.15 -0.10 -0.05 0.00 0.05 0.10 0.15 0.20 0.25 0.30 0 -100000 -200000 -300000
I/ A K2:Current phase A Pierola K2:Current phase B Pierola K2:Current phase C Pierola
5000
t/s -0.20 -0.15 -0.10 -0.05 0.00 0.05 0.10 0.15 0.20 0.25 0.30 0
-5000
U/ V K2:Voltage phase A Pierola K2:Voltage phase B Pierola K2:Voltage phase C Pierola 300000 200000 100000 t/s -0.20 -0.15 -0.10 -0.05 0.00 0.05 0.10 0.15 0.20 0.25 0.30 0 -100000 -200000 -300000
K1:Frequency bar 1A / Hz
50.5
50.0
49.5
t/s -0.20 -0.15 -0.10 -0.05 0.00 0.05 0.10 0.15 0.20 0.25 0.30 49.0 Figure 2.9: Record of main electrical magnitudes in a dip in a 400 kV node
The frequency disturbance associated with a harsh voltage dip in the Spanish mainland grid does not reach the value of 0.1 Hz. Moreover, in Fig. 2.10 it can be observed a voltage dip recorded in a node of the Spanish nonmainland territory. The fault provokes a very deep voltage dip (4% of residual voltage) and a frequency change in the node of about 2 Hz. The comparison of these logs allows to check the statements of the preceding Subsections 2.2.2.1 and 2.2.2.2, i.e., voltage dips are deeper in remote microgrids and frequency deviations are more pronounced than in interconnected systems.
20 In the interest of this thesis concerns,it has to be highlighted the interdependence between voltage and frequency which occurs in remote microgrids. This needs the establishment of devices that can jointly represent both disturbances, such as the one developed in this work.
T1: -0:00.15 T2: 0:02.86 TD:0:03.01 min:seg 51.820 x43 Frec: Ten.UST Bar. A1 49.832 51.816 1.984 Hz 47.571 17184 x6 Ten.URS Bar. A1 14978 15027 48.07 V 3869.9 17165 x6 Ten.UST Bar. A1 14972 15027 54.93 V 3961.9 17140 x6 Ten.UTR Bar. A1 14991 15031 39.83 V 3867.2
Pot Act G11 8783.6 5644.0 -3139.6- KW
Pot React G11
-2448.3- -4385.3- -1937.0- KVA
-0:00.50 0:00.00 0:00.50 0:01.00 0:01.50 0:02.00 0:02.50 0:03.00 0:03.50 0:04.00 0:04.50 0:05.00 min:seg Figure 2.10: Record of main electrical magnitudes in a dip in a spanish nonmainland node
2.2.3 Worldwide situation of remote microgrids
The progress in the development of submarine interconnections using HVDC/HVAC links is making it possible that many of the systems that were remote -islands- have been progres- sively connected to other grids with similar characteristics or the Mainland. As an example of the first cases it may be mentioned the North and South islands of New Zealand, Lan- zarote and Fuerteventura or the main islands of Hawaii. In this sense, there is also projected
21 an interconnection between the islands of Guadeloupe, Martinique and Dominica [16]. As an example of the second situation, as islands connected to Mainland, it is intended a connec- tion of the Italian Islands (Island Project) to the continental Italy [17] as it already occurs in the interconnection of Sri Lanka to India [18].
Also, within this second case, it is important to draw attention to two projects currently being implemented due to its scale and the technological challenge they pose. The first one is the Eurasia Interconnector Project, which is developing a link of almost 1000 km long, with a capacity of 2000 MW, which will join the microgrids of Cyprus and Crete to the continental territory of Greece and Israel. Its entry into service is scheduled for 2016 [19].
The second project, not yet started, will connect Iceland to the United Kingdom. Iceland has a very important geothermal, hydraulic and wind potentials, so it is able to generate nearly five times the energy it consumes at a very low price. The United Kingdom would take the economic advantage of importing cheap energy from Iceland and, consequently, it would not need to expand its offshore wind generation capacity [20].
For other remote microgrids their interconnection cannot be planned either because of the high cost of the construction of the link (not affordable for the remote places in developing countries) or because of the geographical location. This occurs, for example, in the Canary
Islands: the distance between the islands and the Mainland and the depth of ocean floor do not make viable the efficient connection at an affordable cost. As solutions for the future, although unlikely, have been raised inter-connections of islands by means of offshore wind farms with HVDC links [21]. In this type of grids, without the possibility of later connection, it is essential the development of codes to allow the replacement of the current energy model for another, based on RES. It is also in this type of systems in which the work developed in this thesis is focused.
22 2.3 Regulations applicable to distributed generation
sources connected to electrical systems. Grid codes
2.3.1 Introduction
The increasing integration of non-conventional sources in power systems -mainly wind power
- has forced the transmission and distribution system operators (TSOs and DSOs) to update and redesign its grid codes. The grid codes are, essentially, sets of rules governing the connection and behavior that must meet the generators connected in electrical systems. The regulations are different in each country and the corresponding operator is responsible for the establishment of such conditions and verification of compliance.
The grid codes take as a reference the electrical characteristics and the design of the network itself. Their degree of demand is directly linked to the unmanageable power present in the system and the expected penetration rate. With the new policy it is pursued, as an end goal, to equate the behavior of renewable generation to the conventional groups already in service, and to ensure that the replacement of generation units in the system by others, means no additional risks in reliability.
There is a close relationship between standards, and the consequences they establish for manufacturers. The graphical summary of this idea can be seen in Fig. 2.11.
Increasing demands on the grid codes requires manufacturers to make improvements on their devices, thus resulting in an evolution of technology generation system and con- trol drives. With these improvements, an effective contribution to the maintenance of the equipment in the network is achieved and the inclusion of new sources of non-conventional generation is favored.
23 Higher requirements in grid codes
Renewable Technology energy evoluon increase
Figure 2.11: Consequences of the use of grid codes in electrical systems
2.3.2 Grid codes structure
All grid codes are structured in a similar way. In them it can be found three groups of standards, according to the aspects they regulate [22]:
• Connection requirements: These standards establish the conditions and connection
procedures for generators and consumers.
• Operation and safety procedures: These standards fix the action schemes for the elec-
trical system in normal operation and emergency (disconnection of generators, load
shedding plans, etc.). In addition, the regulation and managment of energy reserves is
included.
• Regulation of the electricity market: They settle the mechanisms of the day-ahead,
intraday and balancing electricity markets, as well as the conditions to access to the
market.
The distinction between the first two groups of standards, which have the most technical characteristics and are interrelated, is difficult in many regulations. For example, in the
24 Spanish case, all regulations are gathered in the so-called “Operation procedures”, that include the norms of the three previous groups.
In every country, the regulation framework is particular, complex and changing. In some cases, the corresponding grid code is equally applicable to the whole generation, as it happens in India [23]. In others, it is only defined the required response to the wind installations, as in the P.O.12.3 [15] in Spain, in China [24] o in the procedure still in draft in India [25]. The
German code [26] distinguishes between synchronous generators and the other technologies that do not employ a synchronous generator directly coupled to the grid. In the same way, it will be done in the draft Spanish code P.O.12.2 [27]. The code P.O.12.2 includes other generation sources such as photovoltaics, whenever they are connected to the transport grid, or to the distribution grids if they are greater than 10 MW. In other relevant grid codes, such as the Danish, the requirements are different not only in terms of the technology used, but also depending on the voltage level and the power of the generating plant [28, 29, 30].
2.3.3 Requirements in grid codes. Basic concepts.
This section addresses the general aspects that relate the requirements in grid codes. These criteria establish the disturbances that the developed test equipment must be able to repro- duce accurately. Therefore they have been left out of the analysis the obligations of active or reactive power contribution from generators and, in general, all aspects that depend on the generator control.
- Requirements facing voltage disturbances
For the proper functioning of the electrical system with DG, system operators (SOs) must keep the voltage levels within acceptable limits under normal operating conditions in all grid nodes. Moreover, the generation groups are responsible for helping SOs to meet those
25 requirements, staying connected if unusual circumstances in the system (failures that can cause voltage dips and over/under voltages) and restoring its previous operating condition as quickly as possible after clearance of the fault. The standard IEEE Std. 1159-1995
[31] establishes the classification of voltage disturbances that can occur in a power system by magnitude and duration, as shown in Fig. 2.12. The voltage dip -as defined in [15]- and voltage sag terms are usually used interchangeably [31, 32, 33]. They will also be equivalent along this thesis. Care must be taken because in some contexts, sag and dip refer, respectively, to the voltage drop or the remaining voltage after the fault according to the pre-fault value [34].
Figure 2.12: Classification of voltage disturbances according to IEEE Std. 1159-1995
Usually, the voltage ride-through requirements (VRT) are defined as patterns, which relate the admissible voltage levels and the associated duration times. In Fig.2.13 it can be observed the two types of existing profiles in the codes:
1. - Rectangular profiles: they are set according to the tripping steps of the protection
systems.
26 Figure 2.13: Profile types of voltage dips. a) Rectangular profile. b) Profiles with recovery ramp
2. - Profiles with recovery ramp: they represent the most severe envelopes obtained by
statistical analysis of the grid failures.
For over/undervoltage and transient overvoltage situations (voltage swells), the require- ments are always fixed with reference to the different steps and times set for protection systems.
- Requirements facing frequency disturbances
The frequency of the system is an indicator of the degree of stability, since any instan- taneous imbalance between the generation and the demand results in a variation of this magnitude. Furthermore, it is directly related to the obligations of active power input to the control systems of generation. The amplitude and period of the frequency oscillations depends on the characteristics of loads connected and the transient response of the gener- ation groups regulators. Both conventional and renewable generation sources must be able to stay connected and in operation if disturbances in steady-state or transient regime do appear. In some regulations, additional rate of change of frequency (ROCOF) requirements are requested to the groups.
27 - Requirements facing phase shifts
The phase shifts naturally happen in electrical power systems after a fault in the grid and as a result of a change in the impedance of the equivalent circuit. A phase jump is a displacement that occur in a voltage wave with respect to a reference that has the same frequency and harmonic content which is usually the voltage existing in the PCC prior to disturbance. The phase shift requirements are very specific and are only included in the most advanced grid codes.
2.3.4 Codes review
In this section several grid codes are analyzed. Firstly, an analysis of the grid codes applicable to interconnected electrical systems will be made, since they are the most complete and point the way to future developments in regulations. Later, the inquiry will focus on the codes in use nowdays in remote microgrids. They are, in number, much smaller. This is due to the fact that small-sized electrical systems located, sometimes, in developing countries, have not specific regulations or the reduced number of renewable energy sources installed does not justify the creation of a code that regulates its integration into the electrical system.
2.3.4.1 Grid codes of interconnected systems
2.3.4.1.1 Introduction
In the review of the literature relevant to the interconnected systems, the grid codes con- sidered have been those in countries with more wind power installed by the end of 2012 (by order: China = 75.324 MW; E.E.U.U. = 60.007 MW; Germany = 31.315 MW and India =
18.421 MW) [35]. For the United States it has been selected the code of the North Amer- ican Electrical Reliability Corporation (NERC) [36]. NERC brings together the users and operators not only of virtually the whole of the country, but also Canada and a small part
28 of the North of Mexico. For Spain, which remains by its wind power installed in 4th position worldwide (22.796 MW) has been compared the existing legislation P.O.12.3 [15] and the one pending approval P.O.12.2. [27]. Eventually, it has been considered of interest the inclusion of the Danish code. Denmark’s installed wind power is greater in comparison with the total system generating capacity (30% over the total, 4162 MW is wind power [35]).
2.3.4.1.2 Voltage requirements
- Voltage ride-through requirements (VRT)
In Fig.2.14 it is shown the voltage dip profiles required in the main international codes. Voltage_RMS (p.u.) Voltage_RMS
Time (s) Voltage_RMS (p.u.)
Time (s) P.O.12.2 Spain China India Denmark P.O.12.3 Spain USA_NERC Germany
Figure 2.14: Voltage dip profiles required in main international codes
29 Only some regulations include the zero ride-through (ZRT) requirement. Sources co- nnected through electronic converters are less able to contribute to the short circuit current compared to conventional units. This causes a more severe requirement regarding the mi- nimum depth of the voltage dip appearing in electrical systems when conventional sources are massively replaced by other technologies. To validate this statement it is compared the current and proposed profiles for the Spanish Peninsular territory which are represented in
Fig. 2.14:
1. The P.O.12.3 came into operation in the year 2006. The profile was the envelope of
voltage dips of a system with a total installed capacity of 83.198 MW. The 13.9%
corresponded to wind power generation [37, 38]. The depth of the voltage dip was set
for the given circumstances in 20% (0.2 p.u.).
2. The profile of the draft PO12.2 was proposed for the new situation in Spain, which in
the late 2012 had an installed capacity of 107,615 MW. Out of these, 25% corresponded
to technologies that do not use a synchronous generator directly connected to the grid
(22.785 MW of wind power and 4.298 MW of photovoltaic solar energy [39]). The
forecasts of the Government set the growth of these energies as values to be reached
the 35,000 MW of wind power and 7.250 MW of photovoltaic solar energy in 2020 [40].
According to this scenario the profile has been modified to include a ZRT requirement
of 150 ms.
- Over/undervoltage and voltage swells
For the other over/undervoltage and voltage swells, depending on their magnitude and duration and corresponding to the standard IEEE Std. 1159-1995 (Fig. 2.12) the require- ments are displayed in Fig. 2.15.
30 Dra P.O.12.2- Spain P.O.12.3 - Spain Germany USA_NERC Denmark China India
P > 11 kW y P < 25 kW P > 25 kW y P < 25 MW P > 25 MW
1,2 200 ms <100 ms 1,175 Defined in figures 8.2.1.b 500 ms <100 ms 1,15 2 s 1 h 1 s 1,115 30 min* 100 ms 1,1 200 ms 1,07 60 s 60 s 1,06 60 s Always 1 Not defined Always if U<400kV. If U =400kV, 0,97 Always Always Always Always Umax= 1.05.p.u. 0,95
0,9 1 s 10 s - 60 s 3 h 0,875 30 min 0,85 *Depending on system frequency up to 30 min Figure 2.15: Over/undervoltage and voltage swells requirements in main interconnected grid codes
2.3.4.1.3 Frequency requirements
- Allowable frequency ranges
In Fig. 2.16 it is shown the conditions required to generation sources in several grid generation codes to remain connected when frequencies outside the normal operating limits appear in the system.
- ROCOF requirements
In some grid codes the generators are required to remain connected to the mains not only when the frequency is outside normal ranges for a given time but also when facing to
ROCOF events. Thus it occurs, for example, with the new P.O.12.2.It will oblige the plants with synchronous generators not directly connected to the grid to withstand variations in the frequency for up to ±2Hz/s without disconnection. The Danish legislation sets a higher value of ±2.5Hz/s but only for those wind farms with a rated power between 11 kW and 25 kW. The current code in India [23] makes no reference to this requirement, but nevertheless,
31 Dra P.O.12.2- Spain P.O.12.3 - Spain Germany USA_NERC Dermark China India Eastern Western Quebec Ercot
66 5s 63 62,5 62 61,8 90 s 30 s 61,7 30 s 61,6 61,5 180 s 540 s 660 s 61 60,6 60,5 60 Always Always Always Always 59,5 59,4 59 180 s 660 s 540 s 58,5 58,4 30 s 30 s 58 90 s 57,8 2 s 7,5 s 57,5 57,3 0,75 s 2 s 57 56,5 0,35 s 55,5
53 52,5 f > 52 Hz - 200 ms 52 51,5 2 min 51 Not defined. 30 min 50,5 0.85 p.u. < U < 0,875 p.u. - 30 m 50,3 P.O.1.6 establishes Always 50 0,875 p.u. < U < 0,9 p.u. - 3 h the disconnecon Always 49,5 Always Always 49,2 0,9 p.u. < U < 1.115 p.u. - Siempre condion if frequency 49 drops to 48 Hz for 3s. 1.115 p.u. < U < 1.5 p.u. - 1 h 48,5 30 min 10 min 48 20 min 47,5 10 min 47 f < 47 Hz - 200 ms Figure 2.16: Operating frequency ranges wind farms will be asked to support ROCOF events when it the new regulation currently in draft [25] enters into force.
2.3.4.1.4 Phase shift
The most advanced code up to the date, the Danish, is the only one that includes the requirement of withstanding with an instantaneous 20o phase shift. The P.O. 12.2 will be even more strict, establishing a phase shift criterion of up to 30o. Note also that in this code, the requirement for the DG is more severe than for conventional generators, which are forced to remain connected to phase jumps of 20o and only occasionally to 30o, as a result of transport lines switches closures.
32 2.3.4.2 Grid codes of remote microgrids
2.3.4.2.1 Introduction
The current regulations in remote microgrids are scattered and incomplete. It has been identified two countries which host a significant number of isolated grids in their electrical system, Spain and France. This has forced them to develop specific grid codes for these remote microgrids.
In the island territories of Spain, very small systems can be identified as, for example, El
Hierro island with just 11.180 MW [41]. In the nonmainland territories of France some islands have installed capacities between 27 MW and 435 MW -C´orcega, Guadaloupe, Martinica,
Reuni´on, St. Pierre et Miquelon y St. Martin & St. Barthelemy- [42].
In all these remote microgrids it is essential to maintain a high proportion of conventional generation to ensure security. The French SO can order the shedding of RES when they reach a 30% instant penetration[43]. Under Spanish law the limit depends on each territory, but in no case may exceed 40% of the instantaneous production [44]. By the year 2015 in Canary islands it is expected a rate of renewable energy penetration both in peak and off-peak hours that can reach 100% of demand [45] and that will oblige, either a search of efficient storage solutions, or significant wind energy spills.
2.3.4.2.2 Major international codes applicable to remote systems
- Voltage ride-through
Figure 2.17 shows different profiles of voltage ride-through required by the different SOs of the aforementioned power systems. In the upper and lower part of the figure it is distin- guished depending on the size of the grid between systems up to and below 50 MW.
33 Figure 2.17: a) Voltage dip profiles for microgrids up to 50MW. b) Voltage dip profiles for microgrids above 50MW
In general it can be concluded that the voltage dip profiles are demanding as smaller the size of the microgrid is since virtually all include the ZRT capability. In contrast, the interconnected systems only have to withstand a zero voltage dip in those systems with a higher proportion of wind power installed, such as us (NERC), Germany or Spain (P.O.12.2).
In the EDF-SEI code in service, the required voltage dip depth is 0.05 p.u. [46]. To allow for the increase of RES, it is in process a modification of the profile for future regulations requiring the VRT with a depth of 0.01 p.u [47]. It is also expected the next approval
34 of a new profile in an amendment to the standard IEEE P1547 (IEEE P1547a/D2). In the
P.O.12.2-SEIE, applied to the Spanish Canary islands, it is demanded a pattern of 0 p.u. and lasting 500 ms. For the rest of the island territories, the profile is the same as in Mainland.
- Overvoltage/Undervoltage/Voltage swell
Ranges of operation at over/undervoltage regimes required on remote microgrids are shown in Fig. 2.18. The wider operation limits applicable to an interconnected system are collected in the new Spanish procedure P.O.12.2. According to this standard, the generating source must remain connected during 30 min when the voltage level drops to 0.8 p. u. and
50 ms if the voltage is maintained at 1.20 p.u. Up to 1.40 p.u. during 1s is required for the
Puerto Rico island. It can be observed that, in general, the required operating limits are greater in nonmainland territories.
EDF- SEI Spain - SEIE IEEE P1547 Hawaii - HECO Iceland Cyprus Jamaica PREPA NZ_North NZ-South
1.4 P< 100 kVA P>100 kVA 1.25 1.23 1 s 1.21 1.2 5 s U=1.23-0.125t 1.18 Instantaneous trip U=1.21-0.167t 0.16 s 1.175 2 s 1 s 1.16 1.15 0.4 s 1 s 0.2 s 1.115 3 s 1.1 Inst.Trip 1.5 s 1.07 Always 1.06 60 min 1.05 Always 1 Always Always Always Always 0.97 Always Always UNE 50160 Always Always 0.95 0.9 0.875 60 min 0.85 60 s Voltage dip 0.8 Instantaneous trip Voltage dip Voltage dip 5 s Figure 2.18: Over/Undervoltage requirements in remote microgrids
- Frequency requirements
Figure 2.19 shows the different bands of frequency operation due to different SOs req- uisites. In some countries it is appreciable the variations in frequency that must withstand
35 the generators in steady-state regime. This is the case, for example, of the South Island of
New Zealand, where the steady-state frequency may vary up to 8 Hz.
EDF- SEI Spain - SEIE NZ - North NZ - South Jamaica Iceland Cyprus IEEE 1547 IEEE 1547a Hawaii - HECO PREPA
55 53 P ≤ 30 kW P > 30 kW 52.5 5 s 52 63 3 min 51.5 Abnormal 62.5 51 60 min 62 0.16 s 6 s (P condions) 30 s 50.5 61.5 30 min 50.3 61 20 s 50 Always A Always 60.5 0.16 s 0.16 s Always * Always Always 49.5 l 60 ***Always Always 49.2 59.8 Always Always 49 59.5 Always Abnormal Always 48.5 (P condions) 60 min 59.3 0.16 s Adjustable 48 30 min 59 0.16 s to 20 s 47.5 **120 s 58.5 300 s 47.33 min 3 s **20 s 5 s 58 47.1 **5 s** Intermediate values 57.5 0.16 s 0.16 s 10 s 47 60 s **0.1 sobtained by interpolaon 57 46 0.4 s30 s ***If 0.9
Figure 2.19: Frequency requirements
- Derivatives of frequency
The requirement for generation sources to remain connected under derivatives of fre- quency is not common to all analyzed codes, but it is reflected in some of them. For example,
ROCOF requirements up to 0.37 Hz/s in Hawaii, 0.75 Hz/s in New Zealand, and up to 1.3
Hz/s in Cyprus are obliged.
2.3.4.3 Towards harmonized standards
2.3.4.3.1 Introduction
The dependence of the legislation in each country forces to manufacturers to certify their equipment according to every grid code of the territories in which their products are installed.
36 That is why it seems more necessary to harmonize the different regulations. The creation of a common European code will increase the levels of security and the stability in the grid and will facilitate the insertion of new RES in the system.
2.3.4.3.2 ENTSO-E grid code
The European Network of Transmission System Operators (ENTSO-E) brings together the technical operators of the European electrical systems and it is responsible for both coordi- nation between different TSOs and control of energy exchanges through European borders.
This organization, in collaboration with the Agency for the Cooperation of Energy Reg- ulators (ACER) and the operators of the electricity markets, have been working on the development of a joint code [48].
By means of adopting a common grid code among the members of the European Union it is intended to achieve several benefits [49]:
• To assure a few requirements that must be specified in all the codes of the member
states.
• To unify terminology, parameters and conditions between the different grid codes.
• To establish compliance obligations and exceptions equal to all European countries.
In the section on Requirements for Grid connection (NC RfG) the new pan-european code defines what are called “not exhaustive requirements”. Not exhaustive requirements
flexible operating limits that each national TSO must adapt and supplement. The ENTSO-E grid code will prevail over the national regulations and it will be only applicable to the new generators that want to get connected to the European transport system. The obligation of compliance or not by the existing wind power plants will depend on each national TSO.
37 The code is complex, and consists of several regulations that will be adopted with a temporal sequence still not defined, so the final schedule is not fixed. It is expected the NC
RfG entry into force throughout 2015. Since then, there will be a three-year period for the adaptation of the national codes to the new common framework.
2.3.4.3.3 Highlights of ENTSO-E grid code
It table 2.1 the classification of power plants, named Power Generation Modules (PGMs), in four categories according to the ENTSO-E code is shown. PGMs go from A to D taking into account several factors like power installation, location and the generation technology -power plants with conventional synchronous generators (SPGMs) or power plants with generators connected to the grid through electronic converters (PPMs).
Synchronous area Maximum capacity Maximum capacity Maximum capacity threshold from which threshold from which threshold from which whichonaPGM whichonaPGM whichonaPGM is of Type B is of Type C is of Type D Continental Europe 1MW 50 MW 75 MW Nordic 1.5 MW 10 MW 30 MW Great Britain 1MW 10 MW 30 MW Ireland 0.1 MW 5MW 10 MW Baltic 0.5 MW 10 MW 15 MW
Table 2.1: PGM installed capacity limits according to ENTSO-E regions [1]
It can also be noticed how the requirements increase when the installation power incre- ments. The PGMs type A, with a power over 0.8 kW, must remain connected within the normal operating limits of voltage and frequency in steady state. For the D-type, it is also demanded controls over active and reactive power, response against disturbances, etc., as the loss of a PGM would be a potential risk for grid security.
38 The following paragraphs show the margin requirements that establish the limits inside every TSO must define the voltage and frequency requirements.
- Requirements related to voltage disturbances
As one of the not exhaustive requirements, it is defined a feasible region of operating
RMS voltage-time, in which each SO must fix its own profile according to the particular conditions of its power system. The maximum and minimum limits to frame the profiles, depending on the technology and the power of the plant are depicted in Fig. 2.20:
Figure 2.20: Voltage dip profiles in ENTSO-E code. a) SPGMs type B and C; b) PPMs type B and C; c) SPGMs type D; d) PPM type D
For the PGMs type A and B it is not specified normal operating ranges against voltage variations. These limits will be set directly by the grid aggregator and for type C, the levels shall be fixed by agreement between the grid aggregator and the national SO. As an example, allowable ranges for voltages in type D PGMs are shown in tab.2.2:
39 Synchronous area Voltage Range Time period for operation 0.85 p.u. — 0.9 p.u. 60 min 0.9 p.u. — 1.118 p.u. Unlimited Continental Europe 1.118 p.u. — 1.15 p.u. To be decided by each TSO while respecting the provisions of Art. 4(3) but not less than 20 min
a) Synchronous area Voltage Range Time period for operation 0.85 p.u. — 0.9 p.u. 60 min 0.9 p.u. — 1.05 p.u. Unlimited Continental Europe 1.05 p.u. — 1.0876 p.u. To be decided by each TSO while respecting the provisions of Art. 4(3) but not less than 60 min 1.0875 p.u. — 1.10 p.u. 60 min b) Table 2.2: Operating ranges of voltages. a) Voltages from 110 kV to 300 kV. b) Voltages from 300 kV to 400 kV
- Requirements facing to frequency disturbances
In Table 2.3 the minimum times that the PGMs must remain connected depending on the frequency in the continental region are collected:
It can be seen that the code only establishes the minimum times of operation at several frequencies in which the system should continue working. It is required a continuous oper- ation of the wind farm for frequencies between 49 Hz to 51 Hz and they have to withstand during 30 min for an overfrequency of up to 51.5 Hz before disconnection. According to the location, these requirements will be different. It remains for the Regulatory Authorities the responsibility for setting the bottom time limits for unassigned frequency steps. These values must be labeled with sufficient time prior to the entry into force of the code to make the necessary investments in order to ensure the system reliability.
40 Synchronous area Frequency range Time period for operation 47.5 Hz — 48.5 Hz To be decided by each TSO while respecting the provisions of Art. 4(3) but not less than 30 min Continental Europe 48.5 Hz — 49.0 Hz To be decided by each TSO while respecting the provisions of Art. 4(3) but not less than the period for 47.5 Hz — 48.5 Hz 49.0 Hz — 51.0 Hz Unlimited 51.0 Hz — 51.5 Hz 30 min
Table 2.3: PGMs frequency requirements
It is also a condition in the code for the generators to stay connected and operating when facing frequency ramps. It is the responsibility of the National Operator the setting of the limit values.
2.3.4.3.4 ENTSO-E and remote microgrids
According to the European directive 2009/72/EC a small isolated network had a power con- sumption of less than 3000 GWh in the year 1996 and obtained by means of interconnections, less than 5% of annual consumption [50].
There are various European territories that meet the characteristics of isolated systems such as the Canary Islands, Cyprus, Malta, Madeira or the Aland Islands. ENTSO-E code aims at the harmonization of the grid codes for the future construction of a unified European electrical system. The isolated power systems would presuppose a very small impact on the global system (if they could lately be connected to the Mainland) or no impact if they would keep isolated because of geographical circumstances. In either case, the effects of electrical systems will be minimal and it is excluded in this initial version of the ENTSO-E code.
41 Nevertheless the importance of the harmonization between the different territories has forced the creation of a group within the structure of ENTSO-E, focused on isolated systems: the Regional Voluntary Group Isolated Systems (VRG IS). It is composed by four large
European operators: REE (Spain), Terna (Italy), Landsnet (Iceland) and CTSO (Cyprus).
Its mission is to ensure the proper management and operation of the isolated power systems and the provision of its expertise in the development and updating of the grid codes. The experience provided by the VRG IS is expected to be included in future versions of the code. This is also intended to also advance the harmonization status in grid codes applied to isolated systems [51].
2.4 Grid disturbances generators to test electrical de-
vices
In Subsection 2.2.2.1 the differential characteristics have been described that define the disturbances that appear in remote microgrids respect to other electrical power systems of larger size and strongly meshed. It is essential to have devices to test and predict the behavior of the generating plants against combined voltage and frequency disturbances. This will be needed to certify its operation in accordance with the requirements set by the relevant SO before being installed.
The aspects related to the certification of distributed generation sources have been broadly addressed in the scientific sphere, where many examples of technical papers on this topic can be found.
Most of the papers and patents found in literature search raise the physical constitution and the development of equipment that exclusively generate voltage dips. Only some of the latest devices allows the reproduction of more than one disturbance type. The development
42 validation and certification devices have always been closely linked to the evolution of the requirements demanded by the grid codes. Voltage dips are the most severe disturbances that can occur in the system. In the past they were responsible for massive disconnection of wind power plants. Hence the SOs modified the grid codes to establish new requirements for the response of the wind generation plants when facing voltage dips.
This section is a review of the current state of the art in the existing solutions for certification of DG sources. Three are the common topologies of voltage dip generators: those based on impedance, those using an electric machine, static (transformer) or rotating and those which use electronic converters.
2.4.1 Impedance-based
The insertion of a ground impedance allows an alternative path to the current and generates a voltage variation on the point of common coupling (PCC).These generators are the simplest and, therefore, they are widely used. The adjustment by using electronic devices of the impedance value, determines the voltage dip depth in the experiment. They are easily scalable up to the usual power of the devices to be tested. By using a precise control over the electromechanical or static contactors, they can generate single-phase, two-phase and three-phase voltage dips. In [52] it is displayed the most common setup of this voltage dip generator type that schematically can be seen in Fig. 2.21. In [53] the impedances are the ones of a transformer, but the equipment maintains the usual T-configuration. Because of this, it has been considered as belonging to the first group.
In Spain, this voltage dip configuration is recommended by the Asociaci´on Empresarial
E´olica (AEE) in their document titled “Procedimientos de verificaci´on, validaci´on y certi-
ficaci´on de los requisitos del P.O.12.3 sobre la respuesta de las instalaciones e´olicas y foto-
43 Zs EUT
Grid Zg
Figure 2.21: Impedance-based voltage dip generator voltaicas ante huecos de tensi´on” [54] for testing wind turbines. In [55] it is specified for this topology that if the short-circuit power in the PCC is less than five times the rated power of the EUT, there are effects in the dynamic response of the device due to the series impedance. This is its main drawback and therefore the operation code of the AEE requires the adjustment of the certification equipment at no-load or loaded according to relationship between the PCC and the EUT powers.
2.4.2 Electrical machines based
This voltage dip generator type uses as main element an electric machine, either static or rotating. There has only been found two references [56, 57] in which voltage dip generators with synchronous machines, which reproduce the voltage dip profile by modification of the excitation voltage are mentioned. The implementation at a larger scale of voltage dip gene- rators with synchronous machine involves a very high cost and, as a consequence, it has not been a widespread topology.
Most of voltage dip generators based on electrical machine use a transformer in combi- nation with any kind of electronic switches (SCRs or IGBTs) [58, 59] as observed in Fig.
2.22.
44 Stac switches
EUT
Tapped transformer Grid Figure 2.22: Transformer-based voltage dip generator
These systems are easy to scale, because the component elements exist commercially up to the required levels of voltage and power to test the available wind turbines. Its main disadvantage is that the voltage dip depth is fixed by the value of the transformers inductance. It is common to install tapped transformers, which allow the testing of various voltage dip patterns. Within this topology it is convenient to emphasize the model proposed in cite [60, 61]. In it, the authors described a voltage dip generator oriented to microgrids.
Through simulation, it is checked the analysis of the interaction between a conventional voltage dip generator based on transformers and the SCRs with the SCRs of the microswitch that connects the microgrid to the mains. Reference [62] shows a device consisting of a tapped transformer with also tapped inductances, so both voltage dips and phase jumps disturbances are defined in various steps depending on the number of connected inductances. This device is versatile, and it allows to testing in high voltage and power of the EUT up to 10 MW. It reproduces voltage sags, frequency disturbances and phase jumps, but never simultaneously.
It is perhaps the device found throughout the literature revision that better approaches to the objectives defined for this thesis device.
2.4.3 Full-converter based
This is up to the present the type on which has been done a greater number of developments
[63, 64, 65, 66, 67, 68] The scheme of a device with this topology can be seen in Fig.
45 2.23. It has two back to back converters between the grid and the EUT which permits a complete control over the dip to be generated. However, the full-converter based voltage disturbances generators distort the wave and the devices are more expensive than the other classes abovementioned. The electronic components themselves have a high price and they also require a complex control system. Therefore, the implementation of such equipment remains in low voltage levels, and there are no commercial devices based on this technology.
EUT
Figure 2.23: Voltage dip generator based on full power converter
2.4.4 Comparative between commercial topologies and the pro-
posed device
The prototype developed in this thesis fits into the second class (voltage dip generators with electrical machines), but it is based on an induction regulator and is the only one that uses this type of machine. By making the voltage changes through an induction regulator, continuous adjustment is achieved. This gives the device the possibility of reproducing any profile, any depth and any recovery ramp settled with independence of the grid code, eliminating the main disadvantage linked to disturbances generators based on transformers.
It is also the first device whose design has been specifically oriented to be used in the certification of equipment before its connection to remote microgrids. The use of a second electric machine in cascade allows simultaneous reproduction of more than one disturbance.
In remote microgrids, as described in Subsection 2.2.2.3, disturbances are characterized by
46 synchronous changes in voltage, frequency and phase. As the device can synchronously reproduce all these disturbances, and no other commercial equipment with this characteristic has been found, it is specially suitable to emulate the real behavior of remote microgrids and, therefore, to test devices before its connection to such grids.
2.5 Conclusions
In this chapter three main points of interest have been analyzed in regard to this thesis. The progressive integration of DG in power systems has led to two main consequences, addressed in the first two parts of the chapter. On one hand, the evolution of the topology of power systems, from large electric systems interconnected to smaller, decentralized systems, which can operate in isolated or grid-connected mode, called microgrids. On the other hand, increased requirements in the grid codes, derived from the replacement of the conventional groups by intermittent generation. In particular, the microgrid is a very suitable structure for isolated areas (such as islands or populations of developing countries). But in dealing with especially weak grids, there are also greater requirements on the grid codes for remote microgrids. The need to certify DG sources before its insertion into the power systems has led to the search of different technological solutions, collected in the third part of the chapter.
47 48 Chapter 3
General description and operating model of the voltage disturbances generator prototype
3.1 General description of the device
The device proposed along this dissertation is mainly composed by two electrical wound rotor machines, their associated electrical drives, the set of electromagnetic contactors and the control & monitoring system. The two major advantages of this equipment are the absence of electronic power components (so there is no additional distortion of the voltage waveform) and its capacity to reproduce any voltage dip profile existing in the grid codes, including their recovery ramps.
A general scheme of the device is displayed in figure 3.1.
The voltage disturbances prototype is located between the undisturbed grid (input of contactor KM1) and the EUT (output of contactor KM7). Throughout this section, the operational information, the control system description and the mathematical models for static and dynamic regimes are gathered. Wind turbine Electrical grid
1 3 5 1 3 5 135 135
K1 KM7 K1 KM1 246 246
2 4 6 2 4 6 KM4 KM6 – KMT1 K1 K1 5 6 5 6 1 2 1 2 4 3 4 3 3 4 3 4 1 2 1 2 5 6 5 6 1 3 5 135
1 3 5 KM5 K1 135 246
KM2 K1 2 4 6 246 KM3 K1 2 4 6 5 6 1 2 3 4 3 4 1 2 5 6 ω MAGNITUDE (EM2) ROTOR
ROTOR STATOR α STATOR FREQUENCY Rlim KMT2 K1
PHASE 5 6 (EM1) 1 2 3 4 3 4 1 2 5 6
KMT3 KMT4 Rcc K1 K1 5 6 5 6 1 2 1 2 3 4 3 4 3 4 3 4 1 2 1 2 5 6 5 6
Figure 3.1: General scheme of the device
50 3.1.1 The electrical machines
3.1.1.1 Variable frequency transformer (VFT)
Identified as EM1 in Fig. 3.1, this machine is powered by the mains with a voltage of a settled frequency. The output is connected to the PCC of EM2, as presented in Fig. 3.2.
The variable frequency transformer it is a relative new electrical machine. The first one in service started its operation in 2004 to interconnect the USA and Canadian power systems, with different frequencies [69, 70]. By means of a continuous and controlled phase shift, the
VFT can regulate the power flows between asynchronous grids.
Even if EM1 has the same design that a regular VFT, in the voltage disturbances genera- tor it has two other functions not directly related with the power flow control. The first one is to modify the frequency of the input voltage and the second is to set up an initial phase to obtain the controlled phase jump. The modifications of the frequency and the phase are achieved through the control system, which adjusts the initial angle between the rotor and the stator axis as well as the rotational speed.
3.1.1.2 The induction regulator
The induction regulator, identified as EM2 in Fig. 3.1 is the electrical machine responsible for creating voltage magnitude disturbances. Because of the importance that voltage dips have in power systems, justified in Subsection 2.2.2.1, the production of voltage dips will be the main task of the voltage disturbances generator and in which primarily will focus subsequent design targets.
The induction regulator is constructed like a wound rotor induction machine. Due to this, it is an economical, robust and easily scalable device. Despite these advantages, it has never been a industrially relevant machine. In its nascency, at the first half of the 20th century, it
51 Ug EM2 Ui ω Ur Us
WOUND ROTOR INDUCTION MACHINE
Figure 3.2: Single-phase scheme of the wound rotor induction machine connection was used to control voltages in railway traction, but the development of tapped transformers definitely relegated it to the background [71, 72]. With this dissertation it is intended to recover the induction regulator as a suitable machine with a commercial purpose.
EM2 is placed between the grid and the EUT. The grid can be directly the PCC of the distribution network or the output of the machine responsible of the frequency and phase changes, located upstream. To use the induction regulator in this device, windings have to be connected in parallel and to the PCC, as observed in Fig. 3.3. The rotor is also linked to a servo motor controlled by a servo drive. The servo drive takes action over the relative angle position between the windings (α). Voltage applied to the EUT is always the difference of rotor voltage phasor (Ur), which is equal to the input voltage (Ui), and stator voltage phasor (Us). Equation 3.1 shows this relationship.
Uo = Ur − Us (3.1)
52 Us
EUT Uo Ui Ur α
INDUCTION REGULATOR
Figure 3.3: Single-phase scheme of the induction regulator connection
With the use of an induction regulator can be achieved a simple buck-boost voltage device. A graphical image of the machine phasor diagram is represented in Fig. 3.4 for two shaft angles. It can be observed that depending on the physical position, it is obtained a different output voltage in both magnitude and angle [73].
Using the Law of Cosines applied to the phasor diagram it can be easily deduced the Eq.
3.2:
2 2 2 Uo = Ur + Us − 2 · Ur · Us · cos (α) (3.2)
Magnitudes of rotor and stator voltages are related through the module of the transfor- mation ratio, expressed in terms of the number of phases in rotor (mr) and stator (ms)and the corresponding effective turns en each winding (kws · Ns for the stator and kwr · Nr for the rotor), as shown in Eq. 3.3:
U m · ξ · N s = s s s = k (3.3) Ur mr · ξr · Nr
53 Ur α Us Uo
Figure 3.4: Voltage phasor diagram
With this expression, above equation 3.2 it can be rewritten as Eq. 3.4 to present the output voltage magnitude of the prototype as a function that depends on the input magnitude value.
2 2 2 Uo = Ur · (1 + k − 2 · k · cos (α)) (3.4)
The transformation ratio is close to unity, so without committing an excessive error, the
Eq. 3.4 can approach the more simple expression 3.5. It can be ascertained that depending on the mechanical angle turned by the shaft, output voltage can vary approximately from zero to double of the input value.