Design criteria for the energy management system in PV ... - APERe

Deliverable 6.1:Design criteria for the energymanagement system in PV plants with 3accumulation systems

Deliverable 6.1DELIVERABLE 6.1Design criteria for the energy management system in PV plantswith 3 accumulation systems.• ObjectiveThe incorporation of accumulation in PV generation plants will allow further mitigating powerfluctuations, allowing the power injection to be shifted from its generation by the PV modules, andadding other functionalities. This work package aims to integrate batteries into PV systems,developing hardware and software to manage the energy flows, and to optimize controlstrategies. Innovative technologies of batteries will be tested. Lead-acid batteries but alsoinnovative battery technologies, such as Vanadium Redox-Flow Batteries (VRB) or Lithium ionbatteries will be explored to be adapted to PV plants.In this context, the main objective of this first deliverable is to capture both technical andeconomical design criteria for the energy management systems in PV plants with threeaccumulation systems: lead-acid, VRB and lithium ion.• Design CriteriaThe design criteria are going to point to three main topics: technological, economical andmaintenance and reliability requirements.2

Deliverable 6.11. Technological requirementsRecently, there has been increased interest both in the stability and the security of the grid, aswell as power quality issues. Short-term fluctuation in the power generated by large PV plants hasalerted grid operators, promoting new grid codes that are going to play an important role in thefollowing years.In this way, a significative variety of new regulations have been published in several countries suchas Puerto Rico, South Africa or France at the same time that others like Spain has published draftregulations such as the PO12.2 (Operating Procedure 12.2) which is supposed to be applied in thenear future. [1-11]Specifically, these regulations have a bearing on the key points which are in connection with thegrid stability. The electrical power systems require ancillary services such as voltage and frequencyregulation, power quality improvement and energy balancing to operate efficient and reliable. In apower system, the DSO is responsible to maintain the correct operations and can purchaseancillary services directly from the PV generators. Until recently, the inverter was the responsiblefor keep the grid requirements in case of abnormal grid conditions and faults. The massivedevelopment in the PV sector faced not only new challenges for the inverter but also for theenergy storage system which is now required to contribute to grid stability. In essence, the aim isto endow PV systems with the same properties as traditional synchronous generators have, i.e.inertia emulation.The technological requirements shall be developed in accordance with the prevailing internationalregulatory framework. This means that the technological requirements must focus, including butnot limited to:- Frequency support.o Primary and secondary regulation: the frequency level in the grid represents afundamental criterion to determine the quality of the power delivered tocustomers. It is important that PV provide an immediate real power primaryfrequency response, proportional to frequency deviations from scheduledfrequency, similar to governor response. PV facility shall have controls that provideboth for down-regulation and up-regulation. In addition, the installation will havethe necessary requirements in order to remain connected to the grid when afrequency deviation appears.o Power curtailment: it is necessary to control local over load conditions. The PV plantmust have the ability to control PV generation to a specified rate of nominal powerrating. Energy management system should be capable to do this control effectivelyand, also, to accumulate the excess of energy to be injected when the loadconditions allow it.3

Deliverable 6.1Generally, regulations aim to deal with over-frequency problems. Figure 1 shows the activepower control as a function of frequency during an over-frequency that is required in somecountries.(a)(b)(c)Figure 1: Power curtailment during over-frequency graphic of voltage. A) Italy [7], B) South Africa [6], C) Germany [5]However, new regulations [1] and draft versions of them [2] are starting to take on boardfrequency responses for both down-regulation and up-regulation. Precisely in this contextis where the storage system takes an important part for the installation. During an underfrequencyevent is required to inject more active power to the grid and this will be possiblethanks to the batteries attached to the PV plant. Figure 2 shows the unit increase of poweras a function of the unit frequency deviation that is going to be required in Spain [2].4

Deliverable 6.1Figure 2: Unit increase of power as a function of the unit frequency deviation [2].According to the previous figure, it is possible to calculate the increase or decrease inpower that is required for compliance with the regulation. Figure 3 shows the increase ordecrease in power (%) as a function of the frequency deviation and for different “K” values(K is the slope of the variation of power according to the variation of frequency).Figure 3: increase and decrease in power (%) as a function of the frequency deviation and for different “K” values.5

Deliverable 6.1oFrequency ride through (FRT): it is necessary to adopt the necessary design andcontrol measures to remain connected to the grid while frequency problems appearin different ranges. These ranges vary depending on the country. As an example,the following table shows the characteristic ranges according to the Spain andPuerto Rico regulations.SpainPuerto RicoFrequency (Hz) Time Frequency (Hz) Time47,5

Deliverable 6.1Moreover, the following figure shows the different voltage support requirements whichmight be required depending on the regulation of each country. As it is shown in thisfigure, PV plants must not disconnect from the network in the event of voltage drops to 0%with a duration which vary from 0 to 600 ms.The energy storage management system should be helpful for correcting the voltage totheir normal value by means of injecting more or less active power to the grid.(a)(b)(c)(d)(e)(f)Figure 5: graphic of voltage vs time that the installation should be able to support, without disconnecting from the grid for differentcountries. A) Spain [2], B) Puerto Rico [1], C) France [4], D) Germany [5], E) South Africa [6], F) Italy [7]7

Deliverable 6.1- Reactive power capability and minimum power factor requirements: The total powerfactor range shall be controlled between a certain range depending on the differentregulations. The reactive power requirements provide flexibility for many types oftechnologies at the Renewable Energy Facility. The intent is that PV facilities (PVF) canramp the reactive power from one value to the other in a smooth continuous fashion. Thepower factor range should be dynamic and continuous. This means that the PVF has to beable to respond to power system voltage fluctuations by continuously varying the reactiveoutput of the plant within the specified limits. Generally, it is required that the PVF reactivecapability meets the Power Factor (PF) range based on the PV Facilities Aggregated MWOutput, which is the maximum MVAr capability corresponding to maximum MW Output. Itis understood that positive (+) PF is where the PVF is producing MVAr and negative (-) PF iswhere the PVF is absorbing MVAr. Figure 6 shows reactive power capability that is requiredin different countries.(a)(b)(c)(d)Figure 6: reactive power capability curve for different countries A) Puerto Rico [1], B) Spain [2], C) South Africa [6], D) Italy [7]8

Deliverable 6.1In spite of the fact that the reactive power requirements have no influence on the size ofthe energy storage system, it is necessary to take them into account for the charger design.The charger shall be the elements which controls the reactive power capability helping thePV inverters.- Ramp Rate control: ramp rate control is required to smoothly transition from one outputpower level to another. The PV facility shall be able to control the rate of change of poweroutput during some circumstances, including but not limited to: (1) rate of increase power,(2) rate of decrease power, (3) rate of increase of power when a curtailment of poweroutput is released, (4) rate of decrease in power when curtailment limit is engaged. A %per minute rate (depending on the country regulation and based on AC contractedcapacity) limitation shall be enforced. This ramp limit applies both to increase and decreaseof power output and is independent of meteorological conditions. Energy managementsystem should control the ramp rate to comply with the different regulations. The slope ofthe ramp and the control strategy will determine the size of the needed accumulationsystem.Little is known about the rate of changes in power output. In fact, there are somecountries, such as South Africa [6], that mention that a power gradient constraint shouldbe used to limit the maximum ramp rates but, currently, they do not provide any value.Figure 7 shows the active power constraint functions for South Africa but, as explainedbefore, without any data.Figure 7: Example of an active power control functions for a Renewable Power Plant. [6]9

Deliverable 6.1On the other hand, the only country that provides some values about the ramp rate controlis Puerto Rico [1]. In this case, a 10 % per minute rate (based on nameplate capacity)limitation shall be enforced and applied for both the increase and decrease of poweroutput. This data allow determining the minimum approximate capacity of the energystorage system. As an example, let us consider a 1’1 MW PV plant which maximum poweroutput can vary from 1’1 MW to 100 kW in a few seconds as appears in Figure 8 in blue (PFV). In order to comply with the regulation, the power output should be as the green line(P FV smoothed) that appears in the same figure. Consequently, the capacity of the storagemanagement system should be the area between the blue line and the green line, i.e. 70kWh in this case.Figure 8: PV power registered in a 1’1 MW plant during 2 hours (blue solid line) and PV power smoothed with the storage systemaccording to the Puerto Rico regulation [1]- Real-time communication: submission of real time data for voltage, V, active power, P, andreactive power, Q: the design must consider additional requirements for communicationsuch as submission of real time data for V, P and Q; remote setting of P and Q; and remoteshut down.10

Deliverable 6.12. Economical requirements:With the incorporation of energy storage systems to PV plants, economical requirements aregoing to be another key point to take into account. In this way, depending on the electricity priceand demand, new PV systems shall operate moving the energy production to the peak energydemand. The system operator should be able to manage the PV plant for maximum economicalreturn. This will include an energy storage control strategy which can be pre-determined byweather conditions and grid time-of-day pricing.The strategies of energy management shall be a compendium of the quantity of battery that canbe used for each requirement, both economic and technological. The analysis of the energymarket price evolution is going to take an important role as soon as PV plants start to operatewithout incentives, with the same conditions as the traditional electricity generators.Furthermore, the prediction of power fluctuations by means of new ad-hoc forecast using satelliteimages, in situ cameras and mathematic models shall help to reduce the average diary energystorage. Hence, this allows to use the storage system for other purposes and thus, optimizing itsvalue.11

Deliverable 6.13. Security and reliability requirements:Regarding to security and reliability, the main factors to take into account can be divided in fourpoints: power and energy ratings, maintenance; security; and site preparation or installationprovisions:• Power and energy ratings: attention must be paid to the different voltage and currentranges that use both the batteries and the converters. In addition, the working conditionssuch as maximum and minimum battery voltage, charge power and current are subjects tocontrol in order to maintain the optimal conditions. Although, battery characteristicsdepend on the different strategies that are going to be implemented, the following tablesummarizes some of these working conditions for the three battery technologies to beused in this project:Power and Energy ratings VRB Lithium ion Lead acidEnergy 600kWh 36 kWh 115 kWhMaximum voltageMinimum voltage300 V (Dischargemode)325 V (Charge mode)175 V (Normaloperation)0 V (First charge aftermaintenance)399 V 552 V535 V 414 VRated nominal voltage 220V 480 V -Current max1000 A (5 mins maxin 30mins)300 A 250 AMax Charge power 100 kW 90 kW 30 kWMax Discharge power200 (5 mins max in30mins)150 kW 115 kWRecommended charge power 100 kW 33 kW -Efficiency70% to 80% DC/DCround trip-At 100% SOH:99.4% on discharge / 99.3%on charge-At 80% SOH – 98.4% ondischarge / 98.2% on chargeAverage 83%Table 2: working conditions for the three battery technologies to be used in this project12

Deliverable 6.1• Maintenance: the main operations of preventive and corrective maintenance are related totheir frequency. Preventive maintenance: The goal of preventive maintenance is to limit the numberand duration of electrical failures resulting in a corrective maintenance task.Corrective maintenance: to carry out corrective maintenance shall be necessary remotecommunications through the converter allowing information feedback to the operator.Items such as fire system, air conditioning, parts replacement and battery module swapsmay require corrective maintenance.Table 3: summarizes some of the maintenancerequirements for the three battery technologies to be used in this project.SubsystemVRB Lithium ion Lead acidDescription ofmain tasksFrequencySubsystemDescriptionof maintasksFrequencySubsystemDescriptionof maintasksFrequencyBattery- RenewNitrogenBottles- Electrolytebalance,Remix andRecharge2times/yr.3/6times/yr.Battery-Isolationcheck-Groundmeasurement-Batteryperformance check1 time /year percontainerBatteryCheck andrecord theoverallfloatvoltage atthe batteryterminals(not at thecharger!),andmeasurethe pilotcell voltagequarterlyContainerand VRFBsystem- Isolationcheck, groundmeasurement-VRFBperformancecheckyearlyFireextinguisherPressurecheck2 times/yearBatteryRecord thevoltage,specificgravity andtemperatureof all cells.yearlyAirconditioningFire system-Clean filters-Checkpressure-Check firedetectionsystem2times/yrAirconditioning-Cleanfilters-Pressurecheck2 times /year percontainerElectrolyteCheck theelectrolytelevels in allcells and ifnecessarytop up withdistilledwaterregularlyTable 3: maintenance requirements for the three battery technologies.13

Deliverable 6.1• Security: it is necessary to pay attention at different levels: to prevent a safety event fromoccurring, to minimize the level at which an event occurs and to limit the consequences ofan event. This approach requires inter-linked efforts in areas like technology and materials,cell/battery design, system design and process control.The following table summarizes some of the security requirements for the three batterytechnologies to be used in this project.VRB Lithium ion Lead acidWorkingtemperatureAtmospherictemperature5ºC – 35ºC 20ºC -25ºC best results at 25ºC0ºC – 40ºC -20ºC - 55ºC -20ºC - 60ºCRelative humidity0-95%, noncondensing0-100% -Degree ofprotectionMinimum 3 waygalvanic isolationbetween AC mains,battery and controlinterface.33Comply with:• DIN 40736-1:1992• IEC 60896-11:2002•Norme CEI 21.6 fascicolo 1434Table 4: security requirements for the three battery technologies.• Site preparation or installation provisions: depending on the kind of battery it could benecessary special requirements. On the other hand, currently batteries are built incontainers to be quickly and easily accommodated being the site preparation quite simple.Table 5: summarizes some of the site preparation and installation provisions that arenecessary for the three battery technologies to be used in this project.SubsystemVRB Lithium ion Lead acidProvisionsContainerAir conditioning and firecontrolFree space for side andrear doors opening-2 m. of free space for aircooling condenser airexhaust-3 m. minimum of freespace for doors opening-Available roomNecessary space forheating/cooling ventsNecessary space forheating/cooling and gasexhaust ventsWith ventilation andsource of waterCabling/connectionsAvailable undergroundgalleriesAvailable undergroundgalleriesAvailable undergroundgalleriesSurrounding areaClean areaClean area free ofcombustible materials(grass, plants or shrubs)Clean areaTable 5: site preparation and installation provisions that are necessary for the three battery technologies14

Deliverable 6.1• ConclusionsTo sum up, the main criteria for the design of the energy management system in PV plants usingbatteries can be reflected in the following table:Technological requirements Economical Requirements Security and reliabilityPower curtailment Energy output Optimization Power and energy ratingsFrequency supportVoltage supportDynamic Grid Support/ Fault RideThrough (FRT)Short circuit ratio requirementsReal-time communicationReactive current capability andminimum power factor requirementsRamp Rate controlFluctuations PredictionMaintenanceSecuritySite preparation and installationprovisionsTable 6: criteria for the design of the energy management system in PV plants using batteriesThe main characteristics of the three battery technologies that must be taken into account whendesigning the energy management strategies are summarized in the following table:Power andenergy ratingsMaintenanceSecuritySite preparation orinstallationprovisionsEnergyMaximum voltageMinimum voltageRated nominalvoltageCurrent maxMax Charge powerMax DischargepowerRecommendedcharge powerEfficiencyBattery (checkisolation,performance, groundmeasurement,overall float voltage,nitrogen…)Fire extinguisherAir conditioningElectrolyteWorkingtemperatureAtmospherictemperatureRelativehumidityDegree ofprotectionContainerAvailable RoomCabling/connectionsSurrounding areaTable 7: Main characteristics of the three battery technologies to taken into account when designing the energy managementstrategies15

Deliverable 6.1• REFERENCES[1] Puerto Rico Electric Power Authority. “Minimum Technical Requirements for Photovoltaic Generation(PV) Projects. “[2] Red Eléctrica de España, “Instalaciones conectadas a la red de transporte y equipo generador: requisitosmínimos de diseño, equipamiento, funcionamiento, puesta en servicio y seguridad. P.O. 12.2”, September2010.[3] ENTSO-E Network Code for Requirements for Grid Connection Applicable to all Generators, June 2012.[4] Journal official de la republica française. Texte 8 sur 228. 25 avril 2008. “Décrets, arrêtes,circulaires”.[5] “Technical Guideline Generating Plants Connected to the Medium-Voltage Network. Guidelinefor generating plants connection to and parallel operation with the medium-voltage network”.bdew. June 2008.[6] Grid connection code for renewable power plants (RPPs) connected to the electricitytransmission system (TS) or the distribution system (DS) in South Africa. Version 2.6. November2012.[7] “Regola tecnica di riferimento per la connessione di Utenti attivi e passivi alle reti BT delleimprese distributrici di energia elettrica”Norma italiana CEI 0-21. 2011-2012.[8] Control of grid connected PV systems with grid support functions. Department of Energy Technology.Aalborg University, Denmark. Autumn-Spring 2011-2012.[9] “Cahier des charges de l’appel d’offres n° 332689-2010-FR portant sur des installationséoliennes terrestres de production d’électricité en Corse, Guadeloupe, Guyane, Martinique, à LaRéunion, à Saint-Barthélemy et à Saint-Martin”. Ministère de l’écologie, de l’énergie, dudéveloppement durable et de la mer en charge des technologies tertes et des négociations sur leclimat.[10] International grid codes and local requirements – the evolvement of standards for distributedenergy resources and inverter technology. SMA.[11] “Regolazione tecnica dei requisiti di sistema della generazione distribuita”. Guida técnica.Allegato A.70. March 2012.16

APPENDIX- Puerto Rico Electric Power Authority. “Minimum Technical Requirements forPhotovoltaic Generation (PV) Projects. “- Red Eléctrica de España, “ Instalaciones conectadas a la red de transporte y equipogenerador: requisitos mínimos de diseño, equipamiento, funcionamiento, puesta enservicio y seguridad. P.O. 12.2”, September 2010.- ENTSO-E Network Code for Requirements for Grid Connection Applicable to allGenerators, June 2012.- Journal official de la republica française. Texte 8 sur 228. 25 avril 2008. “Décrets,arrêtes, circulaires”.- “Cahier des charges de l’appel d’offres n° 332689-2010-FR portant sur des installationséoliennes terrestres de production d’électricité en Corse, Guadeloupe, Guyane,Martinique, à La Réunion, à Saint-Barthélemy et à Saint-Martin”. Ministère del’écologie, de l’énergie, du développement durable et de la mer en charge destechnologies tertes et des négociations sur le climat.- Grid connection code for renewable power plants (RPPs) connected to the electricitytransmission system (TS) or the distribution system (DS) in South Africa. Version 2.6.November 2012.- “Regola tecnica di riferimento per la connessione di Utenti attivi e passivi alle reti BTdelle imprese distributrici di energia elettrica”Norma italiana CEI 0-21. 2011-2012.- “Regolazione tecnica dei requisiti di sistema della generazione distribuita”. Guidatécnica. Allegato A.70. March 2012.- “Technical Guideline Generating Plants Connected to the Medium-Voltage Network.Guideline for generating plants connection to and parallel operation with the mediumvoltagenetwork”. bdew. June 2008.

_________________________________PUERTO RICO ELECTRIC POWER AUTHORITY

MINIMUM TECHNICAL REQUIREMENTS FORINTERCONNECTION OF PHOTOVOLTAIC (PV) FACILITIESThe proponent shall comply with the following minimum technical requirements:1. VOLTAGE RIDE-THROUGH:Figure 1 Low Voltage Ride-Through Requirementsa. PREPA’s Low Voltage Ride-Through (LVRT) Requirements:i. From Figure 1, PREPA requires all generation to remain online andbe able to ride-through faults down to 0.0 per-unit (measured atthe point of interconnection), for up to 600 ms.ii. All generation remains online and operating during and afternormally cleared faults on the point of interconnection, andiii. All generation remains online and operating during backupclearedfaults on the point of interconnection.Puerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects1

. PREPA’s Overvoltage Ride-Through (OVRT) Requirements:i. PREPA requires all generation to remain online and able to ridethroughovervoltage conditions specified by the following values:Overvoltage (pu)Minimum time to remainonline (seconds)1.4 – 1.25 11.25 – 1.15 31.15 or lower indefinitely2. VOLTAGE REGULATION SYSTEM (VRS)Constant voltage control shall be required. Photovoltaic Systemtechnologies in combination with Static Var Controls, such as Static VarCompensators (SVC), STATCOMs, DSTATCOMs are acceptable options tocomply with this requirement. A complete description of the VRS controlstrategy should be submitted for evaluation.a) Photovoltaic Facilities (PVF) must have a continuously-variable,continuously-acting, closed loop control VRS; i.e. an equivalent to theAutomatic Voltage Regulator in conventional machines.b) The VRS set-point must be adjustable by the PVF Operator following aPREPA System Controller dispatch. The set-point shall be adjustablebetween 95% to 105% of rated voltage at the POI.c) The VRS shall operate only in a voltage set point control mode.Controllers such as Power Factor or constant VAR are not permitted.d) The VRS shall be capable of adjustable Droop or adjustable gain. VRSthat utilize Droop shall be adjustable from 0 to 10%.e) The combined settings of Droop or gain are to achieve a steady-statevoltage regulation of +/- 0.5% of the voltage controlled by the VRS.f) The VRS shall be calibrated such that a change in reactive power willachieve 95% of its final value no later than 1 second following a stepPuerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects2

change in voltage. The change in reactive power should not causeexcessive voltage excursions or overshoot.g) The generator facility VRS must be in service at any time the PVF iselectrically connected to the grid regardless of MW output from thePVF.3. REACTIVE POWER CAPABILITY AND MINIMUM POWERFACTOR REQUIREMENTSThe total power factor range shall be from 0.85 lagging to 0.85 leading.The reactive power requirements provide flexibility for many types oftechnologies at the Renewable Energy Facility. The intent is that a PVFcan ramp the reactive power from 0.85 lagging to 0.85 leading in asmooth continuous fashion.The +/- 0.90 power factor range should be dynamic and continuous. Thismeans that the PVF has to be able to respond to power system voltagefluctuations by continuously varying the reactive output of the plantwithin the specified limits. The previously established power factordynamic range could be expanded if studies indicate that additionalcontinuous, dynamic compensation is required. It is required that thePVF reactive capability meets +/- 0.85 Power Factor (PF) range based onthe PVF Aggregated MW Output, which is the maximum MVAr capabilitycorresponding to maximum MW Output. It is understood that positive (+)PF is where the PVF is producing MVAr and negative (-) PF is where thePVF is absorbing MVAr.This requirement of MVAr capability at maximum output shall besustained throughout the complete range of operation of the PVF asestablished by Figure 2.Puerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects3

Figure 2 Reactive Power Capability Curve4. SHORT CIRCUIT RATIO (SCR) REQUIREMENTS:Short Circuit Ratio values (at the point of interconnection) under 5 shall notbe permitted. The constructor shall be responsible for the installation ofadditional equipment, such as synchronous condensers, and controlsnecessary to comply with PREPA’s minimum short circuit requirements.5. FREQUENCY RIDE THROUGH (FRT):• 57.5 - 61.5 Hz No tripping (continuous)• 61.5 - 62.5 Hz 30 sec• 56.5 - 57.5 Hz 10 sec• < 56.5 or > 62.5 Hz Instantaneous trip6. FREQUENCY RESPONSE/REGULATION:PV facility shall provide an immediate real power primary frequencyresponse, proportional to frequency deviations from scheduledfrequency, similar to governor response. The rate of real power responseto frequency deviations shall be similar to or more responsive than thePuerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects4

droop characteristic of 5% used by conventional generators. PV facilityshould have controls that provide both down-regulations and upregulationreserves. PV technologies, in combination with energy storagesystems such as BESS, flywheels, hybrid systems are acceptable optionsto comply with PREPA’s frequency regulation requirements.7. RAMP RATE CONTROL:Ramp Rate Control is required to smoothly transition from one outputlevel to another. The PV facility shall be able to control the rate of changeof power output during some circumstances, including but not limited to:(1) rate of increase of power, (2) rate of decrease of power, (3) rate ofincrease of power when a curtailment of power output is released; (4)rate of decrease in power when curtailment limit is engaged. A 10 % perminute rate (based on nameplate capacity) limitation shall be enforced.This limit applies both to the increase and decrease of power output.8. POWER QUALITY REQUIREMENTS:The developer shall address, in the design of their facilities potentialsources and mitigation of power quality degradation prior tointerconnection. Design considerations should include applicablestandards including, but not limited to IEEE Standards 142, 519, 1100,1159, and ANSI C84.1. Typical forms of power quality degradationinclude, but are not limited to voltage regulation, voltage unbalance,harmonic distortion, flicker, voltage sags/interruptions and transients.9. SPECIAL PROTECTION SCHEMES:PV facility shall provide adequate technology and implement specialprotection schemes as established by PREPA in coordination with powermanagement requirements.10. GENERAL INTERCONNECTION SUBSTATIONCONFIGURATION:An interconnecting generation producer must interconnect at an existingPREPA substation. The configuration requirements of theinterconnection depend on where the physical interconnection is tooccur and the performance of the system with the proposedinterconnection. The interconnection must conform, at a minimum, toPuerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects5

the original designed configuration of the substation. PREPA, at its solediscretion, may consider different configurations due to physicallimitations at the site.11. MODELING AND VALIDATIONThe Contractor shall submit to PREPA a Siemens - PTI certified PSS/Emathematical model and data related to the proposed PV facility. Whenreferred to the PV facility model, this shall include but is not limited to PVinverters, transformers, collector systems, plant controllers, controlsystems and any other equipment necessary to properly model the PVfacility for both steady-state and dynamic simulation modules. It isrequired that the Contractor submits both an aggregate and detailedversion of the PV facility model.The Contractor shall be required to submit user manuals for both the PVinverter and the PV Facility models. The mathematical models shall befully compatible with the latest and future versions of PSS/E. It ispreferred that the models are PSS/E standard models. In the case thatthe Contractor submits user written models, the Contractor shall berequired to keep these models current with the future versions of thePSS/E program until such time that PSS/E has implemented a standardmodel. The Contractor shall submit to PREPA an official report fromSiemens - PTI that validates and certifies the required mathematicalmodels, including subsequent revisions. The data and PSS/E model shallalso be updated and officially certified according to PREPA requirementswhen final field adjustments and parameters measurements and fieldtests are performed to the facility by the contractor. The mathematicalmodel (either PSS/E standard or user written model) of the PV facilityshall be officially certified by Siemens - PTI before a specific and validatedPSS/E mathematical model of the complete PV facility be submitted toPREPA. The Contractor shall be responsible of submitting the officialreports and certifications from Siemens – PTI, otherwise themathematical model shall not be considered valid.The Contractor shall be responsible to submit Siemens – PTI certifiedPSSE mathematical models of any kind of compensation devices (ie. SVC,STATCOMs, DSTATCOMs, BESS, etc.) used on the PV facility. It ispreferred that the models are standard models provided with PSS/E. Inthe case that the Contractor submits user written models, the PV facilityContractor shall be required to keep these models current with thefuture versions of the PSS/E program until such time that PSS/E hasimplemented a standard model. In its final form, the mathematicalPuerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects6

model shall be able to simulate each of the required control andoperational modes available for the compensation device and shall becompatible with the latest and future versions of PSSE. Final adjustmentsand parameters settings related with the control system commissioningprocess shall be incorporated to the PSSE mathematical model and testedaccordingly by the PV facility Contractor and PREPA system study groups.The Contractor shall also perform on-site field tests for the identification,development, and validation of the dynamic mathematical models andparameters required by PREPA for any kind of compensation devicesused at the PV facility. The mathematical models of the PV facility and itsrequired compensation devices shall be officially certified by Siemens -PTI before a specific and validated PSS/E mathematical model of thecomplete PV facility be submitted to PREPA. The Contractor shall beresponsible of submitting the official reports and certifications fromSiemens – PTI, otherwise the mathematical models shall not beconsidered valid.PV facility Owners that provide user written model(s) shall providecompiled code of the model and are responsible to maintain the userwritten model compatible with current and new releases of PSS/E untilsuch time a standard model is provided. PREPA must be permitted by thePV facility Owner to make available PV Facility models if required toexternal consultants with an NDA in place.12. TRANSIENT MATHEMATICAL MODELThe Contractor shall be responsible of providing a detailed transientmodel of the PV facility and to show that it is capable of complying withPREPA’s transient Minimum Technical Requirements.13. DYNAMIC SYSTEM MONITORING EQUIPMENTThe developer of the PV facility shall be required to provide and install adynamic system monitoring equipment that conforms to PREPA’sspecifications.Puerto Rico Electric Power AuthorityMinimum Technical Requirements for Photovoltaic Generation (PV) Projects7

ENTSO-E Network Code forRequirements for Grid ConnectionApplicable to all Generators26 June 2012NoticeThis document reflects the work done by ENTSO-E in line with the ACER Framework Guidelines onElectricity Grid Connections published on 20 July 2011 after the EC mandate letter was received byENTSO-E on 29 July 2011. This document takes into account the comments received by ENTSO-Eduring the public consultation of the “Draft Network Code for requirements for grid connectionapplicable to all generators” it has organised between 24 January and 20 March 2012 in an openand transparent manner in compliance with Article 10 of Regulation (EC) 714/2009. It furthermoreincludes the outcomes of numerous bilateral and common user group meetings and workingsessions with stakeholders, the DSOs Technical Expert Group, as well as bilateral/trilateralmeetings with ACER and with the EC.In addition, this document is based on the input of an extensive informal dialogue withstakeholders and of several public workshops that took place during the pilot period between theSummer of 2009 and 3 March 2011, the date on which Regulation (EC) 714/2009 entered intoforce.This document is now called “Network code for requirements for grid connection applicable to allgenerators” and is submitted to ACER for ACER’s reasoned opinion pursuant to Article 6 ofRegulation (EC) 714/2009.ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.eu

PURPOSE AND OBJECTIVESHaving regard to Directive 2009/72/EC of the European Parliament and of the Council of 13 July2009 concerning common rules for the internal market in electricity and repealing Directive2003/54/EC;Having regard to Regulation (EC) No 714/2009 of the European Parliament and of the Council of 13July 2009 on conditions for access to the network for cross-border exchanges in electricity andrepealing Regulation (EC) No 1228/2003 and especially Article 6;Having regard to the priority list issued by the European Commission on 22 December 2010;Having regard to the Framework Guidelines on Electricity Grid Connection issued by the Agency forthe Cooperation of Energy Regulators (ACER) on 20 July 2011;Whereas :(1) Directive 2009/72/EC of the European Parliament and of the Council of 13 July 2009 concerningcommon rules for the internal market in electricity and repealing Directive 2003/54/CE andRegulation 714/2009 of the European Parliament and of the Council of 13 July 2009 (whereassection 6) underline the need for an increased cooperation and coordination among transmissionsystem operators within a European network of transmission system operators for electricity(ENTSO-E) to create Network Codes for providing and managing effective and transparent access tothe transmission networks across borders, and to ensure coordinated and sufficiently forwardlookingplanning and sound technical evolution of the transmission system in the Community,including the creation of interconnection capacities, with due regard to the environment ;(2) Transmission system operators (TSOs) are according to Articles 2 and 12 of Directive 2009/72/ECresponsible for providing and operating high and extra-high voltage networks for long-distancetransmission of electricity as well as for supply of lower-level regional distribution systems anddirectly connected customers. Apart from this transmission and supply task it is also the TSOs’responsibility to ensure the system security with a high level of reliability and quality;(3) Distribution system operators (DSOs) are according to Articles 2 and 25 of Directive 2009/72/ECresponsible for providing and operating low, medium and high voltage networks for regionaldistribution of electricity as well as for supply of lower-level distribution systems and directlyconnected customers. Besides the regional distribution and supply task it is also the DSOs’responsibility to ensure the security of their networks with a high level of reliability and quality.(4) Secure system operation is only possible by close cooperation between Power Generating FacilityOwners and Network Operators. In particular, the system behaviour in disturbed operatingconditions depends upon the response of Power Generating Modules to deviations from nominalvalues of Voltage and Frequency. In the context of system security the Networks and the PowerGenerating Modules need to be considered as one entity from a systems engineering approach,respecting that the security of both parts of the system (network or generation) are interdependent`1 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

of the other part. It is therefore of crucial importance that Power Generating Modules are obliged tomeet the relevant technical requirements set out in the Network Code concerning system security asa prerequisite for grid connection. Appropriate dynamic behaviour of Power Generating Modulesand their protection and control facilities are necessary in normal operating conditions and in arange of disturbed operating conditions in order to preserve or to re-establish system security. Theclose cooperation between Power Generating Facility Owners and Network Operators shall takeplace in due compliance with the principle of confidentiality, such as further detailed in Article 16(1)of Directive 2009/72/EC.(5) ENTSO-E has drafted this Network Code for grid connection requirements aiming at setting outclear and objective requirements for Power Generating Modules for grid connection in order tocontribute to non-discrimination, effective competition and the efficient functioning of the internalelectricity market and to ensure system security.(6) Regulation (EC) 714/2009 in its Article 9(7) defines that “the network codes shall be developedfor cross-border network issues and market integration issues and shall be without prejudice to theMember States’ right to establish national network codes which do not affect cross-border trade”.For the purposes of this Network Code the definition of cross-border network issues and marketintegration issues is derived with due consideration to the targets of the EC 3 rd legislative packagefor the internal electricity market, namely: supporting the completion and functioning of the internal market in electricity and cross-bordertrade facilitating the targets for penetration of renewable generation maintaining security of supplyThe interconnected transmission system establishes the wholesale platform for the internalelectricity market. TSOs are responsible for maintaining, preserving and restoring security of theinterconnected system with a high level of reliability and quality, which in this context is the essencein facilitating cross-border trading.As indicated in (4) above, system security cannot be ensured independently from the technicalcapabilities of Power Generating Modules. Regular coordination at the level of generation andadequate performance of equipment connected to the networks with robustness to facedisturbances and to help to prevent any large disturbance or to facilitate restoration of the systemafter a collapse are fundamental prerequisites.Also as stated in (4) above, secure system operation is only possible by close cooperation of PowerGenerating Facility Owners with Network Operators in an appropriate way. Consequently, thetransmission system and the Power Generating Modules need to be considered as one entity from asystems engineering perspective. It is therefore of crucial importance that Power GeneratingModules are obliged to meet the requirements and to provide the technical capabilities withrelevance to system security.To ensure system security within the interconnected transmission system and to provide adequatesecurity level a common understanding on these requirements for Power Generating Modules isessential. All requirements that contribute to maintaining, preserving and restoring system securityin order to facilitate proper functioning of the internal electricity market within and betweensynchronous areas, and to achieving cost efficiencies through harmonization of requirements shallbe regarded as “cross-border network issues and market integration issues”.Pursuant to Article 6 of Regulation (EC) 714/2009, ENTSO-E shall submit this Network Code to ACER.`2 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Title 1GENERAL PROVISIONSArticle 1SUBJECT MATTERThis Network Code defines a common framework of grid connection requirements for PowerGenerating Facilities, including Synchronous Power Generating Modules, Power Park Modules andOffshore Generation Facilities. It also defines a common framework of obligations for NetworkOperators to appropriately make use of the Power Generating Facilities’ capabilities in a transparentand non-discriminatory manner ensuring a level-playing field throughout the European Union.`3 | P a g eArticle 2DEFINITIONS (glossary)For the purpose of this Network Code, the following definitions shall apply:Active Power - is the real component of the Apparent Power at fundamental Frequency, expressedin watts or multiples thereof (e.g. kilowatts (kW) or megawatts (MW)).Active Power Frequency Response - is an automatic response of Active Power output from a PowerGenerating Module, in response to a change in system Frequency from the nominal systemFrequency.Agency – The Agency for the Cooperation of Energy Regulators (ACER) as established by Regulation(EC) No 713/2009Alternator – is a device that converts mechanical energy into electrical energy by means of arotating magnetic field.Apparent Power - is the product of Voltage and Current at fundamental Frequency. It is usuallyexpressed in kilovolt-amperes (kVA) or megavolt-amperes (MVA) and consists of a real component(Active Power) and an imaginary component (Reactive Power).Authorised Certifier - is an entity to issue Equipment Certificates. The accreditation of theAuthorised Certifier shall be given from the national affiliation of the European co-operation forAccreditation (EA), established according to Regulation (EC) 765/2008.Automatic Voltage Regulator (AVR) - is the continuously acting automatic equipment controlling theterminal Voltage of a Synchronous Power Generating Module by comparing the actual terminalVoltage with a reference value and controlling by appropriate means the output of an ExcitationSystem, depending on the deviations.Black Start Capability - is the capability of recovery of a Power Generating Module from a totalshutdown through a dedicated auxiliary power source without any energy supply which is externalto the Power Generating Facility.ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Closed Distribution System Operator (CDSO) - is a natural or legal person operating, ensuring themaintenance of and, if necessary, developing a closed distribution Network according to Article 28 ofDirective 2009/72/CE.Compliance Monitoring - is the process to verify that the (technical) capabilities of PowerGenerating Modules are maintained compliant by the Power Generating Facility Owner with thespecifications and requirements of this Network Code.Compliance Simulation - is the process to verify that Power Generating Modules are compliant withthe specifications and requirements of this Network Code, for example before starting theiroperation. The verification should include, inter alia, the revision of documentation, the verificationof the requested capabilities of the Power Generating Module by simulation studies and the revisionagainst actual measurements.Compliance Testing - is the process to verify that Power Generating Modules are compliant with thespecifications and requirements of this Network Code, for example before starting their operation.The verification includes, inter alia, the revision of documentation, the verification of the requestedcapabilities of the Power Generating Module by practical tests.Connection Agreement - is a contract between the Relevant Network Operator and the PowerGenerating Facility Owner which includes the relevant site and technical specific requirements forthe Power Generating Facility.Connection Point - is the interface at which the Power Generating Module is connected to atransmission, distribution or closed distribution Network according to Article 28 of Directive2009/72/CE as identified in the Connection Agreement.Control Area - is a part of the interconnected electricity transmission system controlled by a singleTSO.Cost-Benefit Analysis – is a process by which the Relevant Network Operator weighs the expectedcosts of alternative actions aiming at the same objective against the expected benefits in order todetermine the alternative with the highest net socio-economic benefit. If applicable, the alternativesinclude network-based and market-based actions.Current - unless stated otherwise, Current refers to the root-mean-square value of the positivesequence of the phase Current at fundamental Frequency.Derogation - is a time limited or indefinite (as specified) acceptance in writing of a non-complianceof a Power Generating Module with regard to identified requirements of this Network Code.Droop - is the ratio of the steady-state change of Frequency (referred to nominal Frequency) to thesteady-state change in power output (referred to Maximum Capacity).Distribution System Operator (DSO) - is a natural or legal person responsible for operating, ensuringthe maintenance of and, if necessary, developing the distribution Network in a given area and,where applicable, its interconnections with other Networks and for ensuring the long-term ability ofthe Network to meet reasonable demands for the distribution of electricity.Energisation Operational Notification (EON) - is a notification issued by the Relevant NetworkOperator to a Power Generating Facility Owner prior to energisation of its internal Network. An EONentitles the Power Generating Facility Owner to energise its internal Network by using the gridconnection.`4 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Equipment Certificate - is a document issued by an Authorised Certifier for equipment used inPower Generating Modules confirming performance in respect of the requirements of this NetworkCode. In relation to those parameters, for which this Network Code defines ranges rather thandefinite values, the Equipment Certificate shall define the extent of its validity. This will identify itsvalidity at a national or other level at which a specific value is selected from the range allowed at aEuropean level. The Equipment Certificate can additionally include models confirmed against testresults for the purpose of replacing specific parts of the compliance process for Type B, C and DPower Generating Modules. The Equipment Certificate will have a unique number allowing simplereference to it in the Installation Document or the Power Generating Module Document.Excitation System - is the equipment providing the field Current of a synchronous electrical machine,including all regulating and control elements, as well as field discharge or suppression equipmentand protective devices.Existing Power Generating Module - is a Power Generating Module which is not a New PowerGenerating Module.Final Operational Notification (FON) - is a notification issued by the Relevant Network Operator to aPower Generating Facility Owner confirming that the Power Generating Facility Owner is entitled tooperate the Power Generating Module by using the grid connection because compliance with thetechnical design and operational criteria has been demonstrated as referred to in this Network Code.Frequency - is the Frequency of the electrical power system that can be measured in all Networkareas of the synchronous system under the assumption of a coherent value for the system in thetime frame of seconds (with minor differences between different measurement locations only); itsnominal value is 50 Hz.Frequency Control - is the capability of a Power Generating Module to control speed by adjustingthe Active Power Output in order to maintain stable system Frequency (also acceptable as speedcontrol for Synchronous Power Generating Modules).Frequency Response Deadband - is used intentionally to make the Frequency Control notresponsive. In contrast to (in)sensitivity, deadband has an artificial nature and basically is adjustable.Frequency Response Insensitivity - is the inherent feature of the control system defined as theminimum magnitude of the Frequency (input signal) which results in a change of output power(output signal).Frequency Sensitive Mode (FSM) - is a Power Generating Module operating mode which will resultin Active Power output changing, in response to a change in System Frequency, in a direction whichassists in the recovery to Target Frequency, by operating so as to provide Frequency Response.Houseload Operation - in case of Network failures resulting in disconnection of Power GeneratingModules from the Network and being tripped onto their auxiliary supplies, house-load operationensures that Power Generating Facilities are able to continue to supply their in-house loads.Inertia - is the fact that a rotating rigid body such as an Alternator maintains its state of uniformrotational motion. Its angular momentum is unchanged, unless an external torque is applied. In thecontext of this code, this definition refers to the technologies for which Alternator speed and systemFrequency are coupled.Installation Document - is a simple structured document (data/tick sheet) containing informationabout a Type A Power Generating Module and confirming compliance with the relevant`5 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

equirements of this Network Code. The blank Installation Document shall be available from theRelevant Network Operator for the Type A Power Generating Facility Owner or alternatively the siteinstaller on the owner’s behalf to fill in and submit to the Relevant Network Operator.Instruction - is a command given orally, manually or by automatic remote control facilities, e. g. aSetpoint, from a Network Operator to a Power Generating Facility Owner in order to perform anaction.Interim Operational Notification (ION) - is a notification issued by the Relevant Network Operator toa Power Generating Facility Owner confirming that the Power Generating Facility Owner is entitledto operate the Power Generating Module by using the grid connection for a limited period of timeand to undertake compliance tests to meet the technical design and operational criteria of thisNetwork Code.Island Operation - is the independent operation of a whole or a part of the Network that is isolatedafter its disconnection from the interconnected system, having at least one Power GeneratingModule supplying power to this Network and controlling the Frequency and Voltage.Limited Frequency Sensitive Mode – Overfrequency (LFSM-O) - is a Power Generating Moduleoperating mode which will result in Active Power output reduction in response to a change inSystem Frequency above a certain value.Limited Frequency Sensitive Mode – Underfrequency (LFSM-U) - is a Power Generating Moduleoperating mode which will result in Active Power output increase in response to a change in SystemFrequency below a certain value.Limited Operational Notification (LON) - is a notification issued by the Relevant Network Operatorto a Power Generating Facility Owner which has previously reached FON status, but is temporarilysubject to either a significant modification or loss of capability which has resulted in non-complianceto the Network Code.Maximum Capacity - is the maximum continuous Active Power which a Power Generating Modulecan feed into the Network as defined in the Connection Agreement or as agreed between theRelevant Network Operator and the Power Generating Facility Owner. It is also referred to in thisNetwork Code as P max .Minimum Regulating Level - is the minimum Active Power as defined in the Connection Agreementor as agreed between the Relevant Network Operator and the Power Generating Facility Owner, thatthe Power Generating Module can regulate down to and can provide Active Power control.Minimum Stable Operating Level - is the minimum Active Power as defined in the ConnectionAgreement or as agreed between the Relevant Network Operator and the Power Generating FacilityOwner, at which the Power Generating Module can be operated stably for unlimited time.Network - is plant and apparatus connected together in order to transmit or distribute electricalpower.Network Operator - is an entity that operates a Network. These can be either a TSO, a DSO or CDSO.New Power Generating Module - is a Power Generating Module for which with regard to the provisions of the initial version of this Network code, a final and bindingcontract of purchase of the main plant has been signed after the day, which is two yearsafter the day of the entry into force of this Network Code, or,`6 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

with regard to the provisions of the initial version of this Network code, no confirmation isprovided by the Power Generating Facility Owner, with a delay not exceeding thirty monthsas from the day of entry into force of this Network Code, that a final and binding contract ofpurchase of the main plant exists prior to the day, which is two years after the day of theentry into force of this Network Code, or,with regard to the provisions of any subsequent amendment to this Network Code and/orafter any change of thresholds pursuant to the re-assessment procedure of Article 3(6), afinal and binding contract of purchase of the main plant has been signed after the day, whichis two years after the entry into force of any subsequent amendment to this Network Codeand/or after the entry into force of any change of thresholds pursuant to the re-assessmentprocedure of Article 3(6).Offshore Connection Point - is a Connection Point located offshore.Offshore Grid Connection System - is the complete interconnection between the OffshoreConnection Point and the connection to the interconnected onshore system at the Onshore GridInterconnection Point.Offshore Power Park Module - is a Power Park Module located offshore with an OffshoreConnection Point.Onshore Grid Interconnection Point - is the point at which the Offshore Grid Connection System isconnected to the onshore Network of the Relevant Network Operator.Overexcitation Limiter - is a control device within the AVR which prevents the rotor of an Alternatorfrom overload by limiting the excitation Current.Power Factor - is the ratio of Active Power to Apparent Power.Power Generating Facility - is a facility to convert primary energy to electrical energy which consistsof one or more Power Generating Modules connected to a Network at one or more ConnectionPoints.Power Generating Facility Owner - is a natural or legal entity owning a Power Generating Facility.Power Generating Module - is either a Synchronous Power Generating Module, or a Power Park Module.Power Generating Module Document (PGMD) - is a document issued by the Power GeneratingFacility Owner to the Relevant Network Operator for a Type B or C Power Generating Module. ThePGMD is intended to contain information confirming that the Power Generating Module hasdemonstrated compliance with the technical criteria as referred to in this Network Code andprovided the necessary data and statements including a Statement of Compliance.Power Park Module (PPM) - is a unit or ensemble of units generating electricity, which is connected to the Network non-synchronously or through power electronics, and has a single Connection Point to a transmission, distribution or closed distribution Network.Power System Stabilizer (PSS) - is an additional functionality of the AVR of a Synchronous PowerGenerating Module with the purpose of damping power oscillations.Pump-Storage - is a hydro unit in which water can be raised by means of pumps and stored to beused later for the generation of electrical energy.`7 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

P-Q-Capability Diagram - describes the Reactive Power capability of a Power Generating Module incontext of varying Active Power at the Connection Point.Reactive Power - is the imaginary component of the Apparent Power at fundamental Frequency,usually expressed in kilovar (kvar) or megavar (Mvar).Relevant National Regulatory Authority - is the regulatory authority as referred to in Article 35(1) ofDirective 2009/72/EC.Relevant CDSO - is the CDSO to whose Network a Power Generating Module is or will be connected.Relevant DSO - is the DSO to whose Network a Power Generating Module is or will be connected.Relevant Network Operator - is the operator of the Network to which a Power Generating Module isor will be connected.Relevant TSO - is the TSO in whose Control Area a Power Generating Module is or will be connectedto the Network at any Voltage level.Secured Fault - is defined as a fault, which is successfully cleared by Network protection according tothe Network Operator’s planning criteria.Setpoint - is a target value for any parameter typically used in control schemes.Significant Power Generating Module - is a Power Generating Module which is deemed significanton the basis of its impact on the cross-border system performance via influence on the control area’ssecurity of supply, which is identified according to the criteria set forth in this Network Code andfalls within one of the categories provided in Article 3(6).Slope - is the ratio of the change in Voltage, based on nominal Voltage, to a change in ReactivePower infeed from zero to maximum Reactive Power, based on maximum Reactive Power.Statement of Compliance - is a document provided by the Power Generating Facility Owner to theNetwork Operator stating the current status with respect to compliance itemised for each relevantelement of this Network Code.Steady-State Stability - if the Network or a Synchronous Power Generating Module previously in thesteady-state reverts to this state again following a sufficiently minor disturbance, it has Steady-StateStability.Synchronous Compensation Operation - is the operation of an Alternator without prime mover toregulate Voltage dynamically by production or absorption of Reactive PowerSynchronous Power Generating Module - is an indivisible set of installations which can generateelectrical energy. It is either a a single synchronous unit generating power within a Power Generating Facility directlyconnected to a transmission, distribution or closed distribution Network, or an ensemble of synchronous units generating power within a Power Generating Facilitydirectly connected to a transmission, distribution or closed distribution Network with acommon Connection Point, or an ensemble of synchronous units generating power within a Power Generating Facilitydirectly connected to a transmission, distribution or closed distribution Network that cannotbe operated independently from each other (e. g. units generating in a combined-cycle gasturbine facility), or`8 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

a single synchronous storage device operating in electricity generation mode directlyconnected to a transmission, distribution or closed distribution Network, oran ensemble of synchronous storage devices operating in electricity generation modedirectly connected to a transmission, distribution or closed distribution Network with acommon Connection Point.Synthetic Inertia - is a facility provided by a Power Park Module to replicate the effect of Inertia of aSynchronous Power Generating Module to a prescribed level of performance.Transmission System Operator (TSO) - is a natural or legal person responsible for operating,ensuring the maintenance of and, if necessary, developing the transmission system in a given areaand, where applicable, its interconnections with other systems, and for ensuring the long-termability of the system to meet reasonable demands for the transmission of electricity.U-Q/P max -profile - is a profile representing the Reactive Power capability of a Power GeneratingModule in context of varying Voltage at the Connection Point.Underexcitation Limiter - is a control device within the AVR, the purpose of which is to prevent theAlternator from losing synchronism due to lack of excitation.Voltage - unless stated otherwise, Voltage refers to the root-mean-square value of the positivesequence of the phase-to-phase Voltages at fundamental Frequency.1 pu grid Voltage - for the 400 kV grid Voltage level (or alternatively commonly referred to as 380 kVlevel) the reference 1 pu value is 400 kV, for other grid Voltage levels the reference 1 pu Voltagemay differ for each TSO in the same synchronous area i.e. the Voltage range in kV for all TSOs withina synchronous area may not be the same.`9 | P a g eArticle 3SCOPE1. The requirements set forth by this Network Code shall apply to New Power Generating Modulesin a Member State which are significant according to the provisions of this Network Code unlessotherwise provided in this Network Code.2. The requirements set forth by this Network Code shall apply to Existing Power GeneratingModules in a Member State which are significant according to the provisions of this NetworkCode, to the extent their applicability has been decided by the National Regulatory Authority ofthe Member State, and if this has been proposed by the Relevant TSO, following a publicconsultation. The proposal by the Relevant TSO shall be made in particular on the basis of asound and transparent quantitative Cost-Benefit Analysis, including the costs of requiringcompliance that shall demonstrate the socio-economic benefit of application of therequirements set forth by this Network Code to Existing Power Generating Modules. TheRelevant TSO shall have the right to re-assess, in case of factual change such as the evolution ofsystem requirements (e.g. penetration of renewable energy sources, smart grids, distributedgeneration, demand response, etc.), the applicability of the requirements set forth by thisNetwork Code to Existing Power Generating Modules regularly, but not more often than everythree years and respecting the provisions of Article 4(3). The relevant TSO shall notify the launchof the procedure for re-assessment on its website. The date of notification on the website shallENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

constitute the first day of the launch of the procedure for re-assessment. A public consultationshall be conducted in the frame of the procedure for re-assessment. Prior to the Relevant TSOcarrying out the quantitative Cost-Benefit Analysis an initial qualitative comparison of costs andbenefits shall be undertaken in order to determine the cases of sizes of Power GeneratingModules or types of Power Generating Modules or locations of Power Generating Modules orclauses of this Network Code for which there may be a viable case for application to ExistingPower Generating Modules. Where this preparatory stage demonstrates that a subsequentanalytical Cost-Benefit Analysis has a reasonable prospect of demonstrating positive costbenefit,the Relevant TSO may proceed with the full transparent quantitative Cost-BenefitAnalysis. Where the preparatory stage or later stage demonstrate that applicability of theNetwork Code to Existing Power Generating Modules is not required no further action is to beundertaken.3. Existing Power Generating Modules not covered by Article 3(2) shall continue to be bound bysuch technical requirements that apply to them pursuant to legislation in force in the respectiveMember States or contractual arrangements in force. Should national legislation be repealed orcease to be in force, the Existing Power Generation Module not covered by Article 3(2) shallcontinue to be bound by such technical requirements that applied to it pursuant to therespective national legislation such as it was the day prior to it ceasing to be in force.4. With regard to Power Generating Modules not yet connected to the Network:a) Within a delay not exceeding thirty months as from the day of entry into force of thisNetwork Code, the Power Generating Facility Owner shall provide the Relevant NetworkOperator with a confirmation of final and binding contracts it has concluded for theconstruction, assembly or purchase of the main plant of a Power Generating Module withrelevance to the provisions of this Network Code and which exists prior to the day, which istwo years after the day of entry into force of this Network Code.b) The confirmation shall at least indicate the contract title, its date of signature and of entryinto force, and the specifications of the main plant to be constructed, assembled orpurchased.c) The Relevant Network Operator may demand that the National Regulatory Authorityconfirms the existence, relevance and finality of such a contract, i.e. that its material termscan no longer be changed by one of the parties to the contract unilaterally and that no partyto the contract has the right to terminate it at will. The Power Generating Facility Ownershall supply the National Regulatory Authority with all documents the National RegulatoryAuthority requests in order to ascertain that a binding and final contract exists.d) The Power Generating Module shall be considered as an Existing Power Generating Module,provided that:`10 | P a g e1) In accordance with Article 3(4) (a) and (b) above, the Relevant Network Operator isprovided with sufficient evidence of the existence of binding and final contracts for theconstruction, assembly or purchase of the main plant of a Power Generating Moduleexists prior to the day, which is two years after the day of entry into force of thisNetwork Code; or2) Following the verification performed by the National Regulatory Authority in accordancewith Article 3(4) (c), it is ascertained that binding and final contracts for the construction,assembly or purchase of the main plant of a Power Generating Module exist prior to theday, which is two years after the day of entry into force of this Network Code.ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

e) In case the Power Generating Facility Owner does not provide the Relevant NetworkOperator with the confirmation within the delay set forth in Article 3(4) (a), the PowerGenerating Module shall be considered as a New Power Generating Module.5. The applicability and extent of the requirements a Power Generating Modules has to complywith depends on the Voltage level of their Connection Point and their Maximum Capacityaccording to the categories defined in Article 3 (6).6. Power Generating Modules which are considered to be Significant Power Generating Moduleswithin the scope of this Network Code are categorized as follows:a) A Power Generating Module is of Type A if its Connection Point is below 110 kV and itsMaximum Capacity is 0.8 kW or more. Requirements applicable to Type A Power GeneratingModules are the basic level requirements, necessary to ensure capability of generation overoperational ranges with limited automated response and minimal system operator control ofgeneration. They ensure there is no wide scale loss of generation over system operationalranges, thereby minimizing critical events, and include requirements necessary for widespread intervention during system critical events.b) A Power Generating Module is of Type B if its Connection Point is below 110 kV and itsMaximum Capacity is at or above a threshold defined by each Relevant TSO while respectingthe provisions of Article 4(3). This threshold shall not be above the threshold for Type BPower Generating Modules according to table 1. The definition of the threshold shall becoordinated with adjacent TSOs and DSOs and shall be reviewed by the National RegulatoryAuthority. Power Generating Facility Owners shall assist and contribute to thisdetermination of the threshold and provide the relevant data as requested by the RelevantTSO. The Relevant TSO shall have the right to re-assess the determination of the thresholdregularly, if relevant circumstances have changed materially, but not more often than everythree years and respecting the provisions of Article 4(3). A public consultation shall beconducted in the frame of the procedure for re-assessment. Following any change tothresholds any Power Generating Module that has been moved to a new type will notautomatically have to comply retroactively with the additional requirements but will besubject to the same procedure as applied to Existing Power Generating Modules in line withArticle 33. Requirements applicable to Type B Power Generating Modules provide a widerlevel of automated dynamic response with higher resilience to more specific operationalevents to ensure use of this higher dynamic response and a higher level system operatorcontrol and information to utilize these capabilities. They ensure automated response toalleviate and maximize dynamic generation response to system events, greater PowerGenerating Module resilience of these events to ensure this dynamic response and bettercommunication and control to leverage these capabilities.c) A Power Generating Module is of Type C if its Connection Point is below 110 kV and itsMaximum Capacity is at or above a threshold defined by each Relevant TSO while respectingthe provisions of Article 4(3). This threshold shall not be above the threshold for Type CPower Generating Modules according to table 1. The definition of the threshold shall becoordinated with adjacent TSOs and DSOs and shall be reviewed by the National RegulatoryAuthority. Power Generating Facility Owners shall assist and contribute to thisdetermination of the threshold and provide the relevant data as requested by the RelevantTSO. The Relevant TSO shall have the right to re-assess the determination of the thresholdregularly, if relevant circumstances have changed materially, but not more often than everythree years and respecting the provisions of Article 4(3). A public consultation shall beconducted in the frame of the procedure for re-assessment. Following any change to`11 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

thresholds any Power Generating Module that has been moved to a new type will notautomatically have to comply retroactively with the additional requirements but will besubject to the same procedure as applied to Existing Power Generating Modules in line withArticle 33. Requirements applicable to Type C Power Generating Modules provide refined,stable and highly controllable (real time) dynamic response to provide principle ancillaryservices to ensure security of supply. These requirements cover all operational Networkstates with consequential detailed specification of interactions of requirements, functions,control and information to utilize these capabilities. They ensure real time system responsenecessary to avoid, manage and respond to system events. These requirements providesufficient generation functionality to respond to both intact and system disturbed situations,and the need for information and control necessary to utilise this generation over thisdiversity of situations.Synchronous Areamaximum capacitythreshold fromwhich on a PowerGenerating Moduleis of Type Bmaximum capacitythreshold fromwhich on a PowerGenerating Moduleis of Type Cmaximum capacitythreshold fromwhich on a PowerGenerating Moduleis of Type DContinental Europe 1 MW 50 MW 75 MWNordic 1.5 MW 10 MW 30 MWGreat Britain 1 MW 10 MW 30 MWIreland 0.1 MW 5 MW 10 MWBaltic 0.5 MW 10 MW 15 MWTable 1: Thresholds for Type B, C and D Power Generating Modulesd) A Power Generating Module is of Type D if its Connection Point is at 110 kV or above. ASynchronous Power Generating Module or Power Park Module is of Type D as well if itsConnection Point is below 110 kV and its Maximum Capacity is at or above a thresholddefined by each Relevant TSO while respecting the provisions of Article 4(3). This thresholdshall not be above the threshold for Type D Power Generating Modules according to table 1.The definition of the threshold shall be coordinated with adjacent TSOs and DSOs and shallbe reviewed by the National Regulatory Authority. Power Generating Facility Owners shallassist and contribute to this determination of the threshold and provide the relevant data asrequested by the Relevant TSO. The Relevant TSO shall have the right to re-assess thedetermination of the threshold regularly, if relevant circumstances have changed materially,but not more often than every three years and respecting the provisions of Article 4(3). Apublic consultation shall be conducted in the frame of the procedure for re-assessment.Following any change to thresholds any Power Generating Module that has been moved to anew type will not automatically have to comply retroactively with the additionalrequirements but will be subject to the same procedure as applied to Existing PowerGenerating Modules in line with Article 33. Requirements applicable to Type D PowerGenerating Modules are in particular specific for higher Voltage connected generation withimpact on entire system control and operation. They ensure stable operation of theinterconnected Network, allowing the use of ancillary services from generation Europe wide.`12 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

e) For offshore connected Synchronous Power Generating Modules the requirements foronshore synchronous Power Generating Modules shall apply unless modified by theRelevant Network Operator while respecting the provisions of Article 4(3). The categories tobe taken into account for Offshore Power Park Modules for the purpose of this NetworkCode are defined in Article 18(3).f) Pump-storage Power Generating Modules shall fulfil all requirements in both generating andpumping operation mode. Synchronous Compensation Operation of Pump-Storage PowerGenerating Modules shall not be limited in time by technical design of the Power GeneratingModules. Pump-Storage variable speed Power Generating Modules shall fulfil allrequirements applicable to synchronous Power Generating Modules and in addition thoseset forth in Article 15(2) (b), if they are of Type B, C or D.g) Without prejudice to the general applicability of the requirements set forth in this NetworkCode, a Power Generating Facility Owner, the Network Operator of an industrial site and theRelevant Network Operator to whose Network the Network of the industrial site isconnected to, shall have the right in coordination with the Relevant TSO, with respect toPower Generation Modules which are embedded in the Networks of industrial sites, to agreewhile respecting the provisions of Article 4 (3) on conditions for disconnection of such PowerGenerating Modules together with critical loads, which secure production processes, fromthe Relevant Network Operator’s Network. The only objective of such an agreement shall beto secure production processes of such a site in case of disturbed conditions in the RelevantNetwork Operator’s Network. The requirements of this Network Code, notwithstanding suchan agreement, shall apply to Power Generating Modules embedded in the Networks of suchindustrial sites.h) Without prejudice to the general applicability of the requirements set forth in this NetworkCode, a requirement of this Network Code shall not apply to Power Generating Modules offacilities for combined heat and power production (CHP) embedded in the Networks ofindustrial sites in the following cumulative circumstances:- the primary purpose of these facilities is to produce steam for production processes ofthis industrial site;- the generation of steam and power are rigidly coupled to each other, i. e. any change ofsteam generation results inadvertently in a change of Active Power generation and viceversa;- the Power Generating Modules are of Type A, B or C according to Article 3(6) (a) to (c);and- the requirement is related to the capability maintain constant Active Power output or tomodulate Active Power output other than Article 8(1) (c) and (e).i) For the avoidance of doubt, combined heat and power generating facilities will be regardedon their electrical Maximum Capacity.`13 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Title 2REQUIREMENTSChapter 1GENERAL REQUIREMENTSArticle 8GENERAL REQUIREMENTS FOR TYPE A POWER GENERATING MODULES1. Type A Power Generating Modules shall fulfil the following requirements referring to Frequencystability:a) With regard to Frequency ranges:1) A Power Generating Module shall be capable of staying connected to the Network andoperating within the Frequency ranges and time periods specified by table 2.2) While respecting the provisions of Article 4(3), wider Frequency ranges or longerminimum times for operation can be agreed between the Relevant Network Operator incoordination with the Relevant TSO and the Power Generating Facility Owner to ensurethe best use of the technical capabilities of a Power Generating Module if needed topreserve or to restore system security. If wider Frequency ranges or longer minimumtimes for operation are economically and technically feasible, the consent of the PowerGenerating Facility Owner shall not be unreasonably withheld.3) While respecting the provisions of Article 8(1) (a) point 1) a Power Generating Moduleshall be capable of automatic disconnection at specified frequencies, if required by theRelevant Network Operator. While respecting the provisions of Article 4(3), Terms andsettings for automatic disconnection shall be agreed between the Relevant NetworkOperator and the Power Generating Facility Owner.b) With regard to the rate of change of Frequency withstand capability, a Power GeneratingModule shall be capable of staying connected to the Network and operating at rates ofchange of Frequency up to a value defined by the Relevant TSO while respecting theprovisions of Article 4(3) other than triggered by rate-of-change-of-Frequency-type of loss ofmains protection. This rate-of-change-of-Frequency-type of loss of mains protection will bedefined by the Relevant Network Operator in coordination with the Relevant TSO.`16 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

SynchronousAreaFrequency RangeTime period for operationContinentalEuropeNordicGreat BritainIrelandBaltic47.5 Hz – 48.5 Hz48.5 Hz – 49.0 HzTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than 30 minutesTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than the period for47.5 Hz – 48.5 Hz49.0 Hz – 51.0 Hz Unlimited51.0 Hz – 51.5 Hz 30 minutes47.5 Hz – 48.5 Hz 30 minutes48.5 Hz – 49.0 HzTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than 30 minutes49.0 Hz – 51.0 Hz Unlimited51.0 Hz – 51.5 Hz 30 minutes47.0 Hz – 47.5 Hz 20 seconds47.5 Hz – 48.5 Hz 90 minutes48.5 Hz – 49.0 HzTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than 90 minutes49.0 Hz – 51.0 Hz Unlimited51.0 Hz – 51.5 Hz 90 minutes51.5 Hz – 52.0 Hz 15 minutes47.5 Hz – 48.5 Hz 90 minutes48.5 Hz – 49.0 HzTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than 90 minutes49.0 Hz – 51.0 Hz Unlimited51.0 Hz – 51.5 Hz 90 minutes47.5 Hz – 48.5 Hz48.5 Hz – 49.0 HzTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than 30 minutesTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than the period for47.5 Hz – 48.5 Hz49.0 Hz – 51.0 Hz Unlimited51.0 Hz – 51.5 HzTo be defined by each TSO while respecting theprovisions of Article 4(3), but not less than 30 minutesTable 2: Minimum time periods for which a Power Generating Module shall be capable ofoperating for different frequencies deviating from a nominal value without disconnectingfrom the Network.c) With regard to the Limited Frequency Sensitive Mode - Overfrequency (LFSM-O) thefollowing shall apply:`17 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

1) The Power Generating Module shall be capable of activating the provision of ActivePower Frequency Response according to figure 1 at a Frequency threshold between andincluding 50.2 Hz and 50.5 Hz with a Droop in a range of 2 – 12 %. The actual Frequencythreshold and Droop settings shall be determined by the Relevant TSO. The PowerGenerating Module shall be capable of activating Active Power Frequency Response asfast as technically feasible with an initial delay that shall be as short as possible andreasonably justified by the Power Generating Facility Owner to the Relevant TSO ifgreater than 2 seconds. The Power Generating Module shall be capable of eithercontinuing operation at Minimum Regulating Level when reaching it or furtherdecreasing Active Power output in this case, as defined by the Relevant TSO whilerespecting the provisions of Article 4(3).PP reff 1f nff n• Synchronous Power Generating Modules:P ref is the Maximum Capacitys 2• Power Park Modules:P ref is the actual Active Power output at the momentthe LFSM-O threshold is reached or the MaximumCapacity , as defined by the Relevant TSO, whilerespecting the provisions of Article 4(3)Figure 1: Active Power Frequency Response capability of Power Generating Modules inLFSM-O. P ref is the reference Active Power to which P is related and may be defineddifferently for Synchronous Power Generating Modules and Power Park Modules. P isthe change in Active Power output from the Power Generating Module. f n is the nominalFrequency (50 Hz) in the Network and f is the Frequency change in the Network. Atoverfrequencies where f is above f 1 the Power Generating Module has to provide anegative Active Power output change according to the Droop S 2 .2) The Power Generating Module shall be capable of stable operation during LFSM-Ooperation. When LFSM-O is active, the LFSM-O Setpoint will prevail over any otherActive Power Setpoints.d) The Power Generating Module shall be capable of maintaining constant output at its targetActive Power value regardless of changes in Frequency, unless output shall follow thedefined changes in output in the context of Article 8(1) (c), (e) or Article 10(2) (b), and Article10(2) (c) where applicable.`18 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

e) The Relevant TSO shall define admissible Active Power reduction from maximum outputwith falling Frequency within the boundaries, given by the full lines in Figure 2:- Below 49 Hz falling by a reduction rate of 2 % of the Maximum Capacity at 50 Hz per 1Hz Frequency drop;- Below 49.5 Hz by a reduction rate of 10 % of the Maximum Capacity at 50 Hz per 1 HzFrequency drop.Applicability of this reduction is limited to a selection of affected generation technologiesand may be subject to further conditions defined by the Relevant TSO while respecting theprovisions of Article 4(3).`19 | P a g eFigure 2 – Maximum power capability reduction with falling Frequency. The diagramrepresents the boundaries defined by the Relevant TSO while respecting the provisionsof Article 4(3).f) The Power Generating Module shall be equipped with a logic interface (input port) in orderto cease Active Power output within less than 5 seconds following an Instruction from theRelevant Network Operator. The Relevant Network Operator shall have the right to definewhile respecting the provisions of Article 4(3) the requirements for further equipment tomake this facility operable remotely.g) The Relevant TSO shall define while respecting the provisions of Article 4(3) the conditionsunder which a Power Generating Module shall be capable of connecting automatically to theNetwork. These conditions shall include:- Frequency ranges, within which an automatic connection is admissible, and acorresponding delay time- maximum admissible gradient of increase of Active Power outputAutomatic connection is allowed unless determined otherwise by the Relevant NetworkOperator in coordination with the Relevant TSO.ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

`20 | P a g eArticle 9GENERAL REQUIREMENTS FOR TYPE B POWER GENERATING MODULES1. In addition to fulfilling the requirements listed in Article 8, Type B Power Generating Modulesshall fulfil the requirements in this Article.2. Type B Power Generating Modules shall fulfil the following requirements referring to Frequencystability:a) In order to be able to control Active Power output, the Power Generating Module shall beequipped with a interface (input port) in order to be able to reduce Active Power output asinstructed by the Relevant Network Operator and/or the Relevant TSO. The RelevantNetwork Operator shall have the right to define while respecting the provisions of Article4(3) the requirements for further equipment to make this facility operable remotely.3. Type B Power Generating Modules shall fulfil the following requirements referring to robustnessof Power Generating Modules:a) With regard to fault-ride-through capability of Power Generating Modules:1) Each TSO shall define while respecting the provisions of Article 4(3) a voltage-againsttime-profileaccording to figure 3 at the Connection Point for fault conditions whichdescribes the conditions in which the Power Generating Module shall be capable ofstaying connected to the Network and continuing stable operation after the powersystem has been disturbed by Secured Faults on the Network.2) This voltage-against-time-profile shall be expressed by a lower limit of the course of thephase-to-phase Voltages on the Network Voltage level at the Connection Point during asymmetrical fault, as a function of time before, during and after the fault. This lowerlimit is defined by the TSO using parameters in figure 3 according to tables 3.1 and 3.2.3) Each TSO shall define and make publicly available while respecting the provisions ofArticle 4(3) defining the pre-fault and post-fault conditions for the fault-ride-throughcapability in terms of:- conditions for the calculation of the pre-fault minimum short circuit capacity at theConnection Point;- conditions for pre-fault active and Reactive Power operating point of the PowerGenerating Module at the Connection Point and Voltage at the Connection Point;and- conditions for the calculation of the post-fault minimum short circuit capacity at theConnection Point.4) Each Relevant Network Operator shall provide on request by the Power GeneratingFacility Owner the pre-fault and post-fault conditions to be considered for fault-ridethroughcapability as an outcome of the calculations at the Connection Point as definedin Article 9 (3) (a) point 3) regarding:- pre-fault minimum short circuit capacity at each Connection Point expressed inMVA;ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

- pre-fault operating point of the Power Generating Module expressed in ActivePower output and Reactive Power output at the Connection Point and Voltage atthe Connection Point; and- post-fault minimum short circuit capacity at each Connection Point expressed inMVA.Alternatively generic values for the above conditions derived from typical cases may beprovided by the Relevant Network Operator.U/p.u.1.0U rec2U rec1U clearU ret0 t clear t rec1 t rec2 t rec3t/secFigure 3 – Fault-ride-through profile of a Power Generating Module. The diagramrepresents the lower limit of a voltage-against-time profile by the Voltage at theConnection Point, expressed by the ratio of its actual value and its nominal value in perunit before, during and after a fault. U ret is the retained Voltage at the Connection PointDuring a fault, t clear is the instant when the fault has been cleared. U rec1 , U rec2 , t rec1 , t rec2and t rec3 specify certain points of lower limits of Voltage recovery after fault clearance.Voltage parameters [pu]Time parameters [seconds]U ret : 0.05 – 0.3 t clear : 0.14 – 0.25U clear : 0.7 – 0.9 t rec1 : t clearU rec1 : U clear t rec2 : t rec1 – 0.7U rec2 : 0.85 – 0.9 and ≥ U clear t rec3 : t rec2 – 1.5Table 3.1 – Parameters for figure 3 for fault-ride-through capability of SynchronousPower Generating Modules.`21 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Voltage parameters [pu]Time parameters [seconds]U ret : 0.05 – 0.15 t clear : 0.14 – 0.25U clear : U ret – 0.15 t rec1 : t clearU rec1 : U clear t rec2 : t rec1U rec2 : 0.85 t rec3 : 1.5 – 3.0`22 | P a g eTable 3.2 – Parameters for figure 3 for fault-ride-through capability of Power ParkModules.5) The Power Generating Module shall be capable of staying connected to the Network andcontinue stable operation when the actual course of the phase-to-phase Voltages on theNetwork Voltage level at the Connection Point during a symmetrical fault, given the prefaultand post-fault conditions according to Article 9(3) (a) points 3) and 4), remainsabove the lower limit defined in Article 9(3) (a) point 2), unless the protection schemefor internal electrical faults requires the disconnection of the Power Generating Modulefrom the Network. The protection schemes and settings for internal electrical faults shallbe designed not to jeopardize fault-ride-through performance.6) While still respecting Article 9(3) (a) point 5), undervoltage protection (either fault-ridethroughcapability or minimum Voltage defined at the connection point Voltage) shall beset by the Power Generating Facility Owner to the widest possible technical capability ofthe Power Generating Module unless the Relevant Network Operator requires less widesettings according to Article 9(5) (b). The settings shall be justified by the PowerGenerating Facility Owner in accordance with this principle.7) Fault-ride-through capabilities in case of asymmetrical faults shall be defined by eachTSO while respecting the provisions of Article 4(3).4. Type B Power Generating Modules shall fulfil the following requirement referring to systemrestoration:a) With regard to capability of reconnection after an incidental disconnection due to a Networkdisturbance, the Relevant TSO shall adopt a decision while respecting the provisions ofArticle 4(3) defining the conditions under which a Power Generating Module shall becapable of reconnecting to the Network after an incidental disconnection has taken placedue to a Network disturbance. Installation of automatic reconnection systems shall besubject to prior authorization by the Relevant Network Operator subject to reconnectionconditions specified by the Relevant TSO.5. Type B Power Generating Modules shall fulfil the following general system managementrequirements:a) With regard to control schemes and settings1) While respecting the provisions of Article 4(3), schemes and settings of the differentcontrol devices of the Power Generating Module relevant for transmission systemENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

stability and to enable emergency actions shall be coordinated and agreed between theRelevant TSO, the Relevant Network Operator and the Power Generating Facility Owner.2) While respecting the provisions of Article 4(3), any changes to the schemes and settingsof the different control devices of the Power Generating Module, relevant fortransmission system stability and to enable emergency actions, shall be coordinated andagreed between the Relevant TSO, the Relevant Network Operator and the PowerGenerating Facility Owner, especially if they concern the circumstances referred tounder Article 9(5) (a) point 1).b) With regard to electrical protection schemes and settings:1) The Relevant Network Operator shall define the schemes and settings necessary toprotect the Network taking into account the characteristics of the Power GeneratingModule. While respecting the provisions of Article 4(3), protection schemes relevant forthe Power Generating Module and the Network and settings relevant for the PowerGenerating Module shall be coordinated and agreed between the Relevant NetworkOperator and the Power Generating Facility Owner. The protection schemes and settingsfor internal electrical faults shall be designed not to jeopardize the performance of aPower Generating Module according to this Network Code requirements otherwise.2) Electrical protection of the Power Generating Module shall take precedence overoperational controls taking into account system security, health and safety of staff andthe public and mitigation of the damage to the Power Generating Module.3) Protection schemes can protect against the following aspects:- external and internal short circuit;- asymmetric load (Negative Phase Sequence);- stator and rotor overload;- over-/underexcitation;- over-/undervoltage at the Connection Point;- over-/undervoltage at the Alternator terminals;- inter-area oscillations;- inrush Current;- asynchronous operation (pole slip);- protection against inadmissible shaft torsions (for example, subsynchronousresonance);- Power Generating Module line protection;- unit transformer protection;- backup schemes against protection and switchgear malfunction;- overfluxing (U/f);- inverse power;- rate of change of Frequency; and- neutral Voltage displacement.4) While respecting the provisions of Article 4(3), any changes to the protection schemesrelevant for the Power Generating Module and the Network and to the setting relevantfor the Power Generating Module shall be agreed between the Network Operator andthe Power Generating Facility Owner and be concluded prior to the introduction ofchanges.`23 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

c) With regard to priority ranking of protection and control, the Power Generating FacilityOwner shall organize its protections and control devices in compliance with the followingpriority ranking, organized in decreasing order of importance:- Network system and Power Generating Module protection;- Synthetic Inertia, if applicable;- Frequency control (Active Power adjustment);- Power Restriction; and- Power gradient constraint.d) With regard to information exchange:1) Power Generating Facilities shall be capable of exchanging information between thePower Generating Facility Owner and the Relevant Network Operator and/or theRelevant TSO in real time or periodically with time stamping as defined by the RelevantNetwork Operator and/or the Relevant TSO while respecting the provisions of Article4(3).2) The Relevant Network Operator in coordination with the Relevant TSO shall define whilerespecting the provisions of Article 4(3) the contents of information exchanges and theprecise list and time of data to be facilitated.Article 10GENERAL REQUIREMENTS FOR TYPE C POWER GENERATING MODULES1. In addition to fulfilling the requirements listed in Articles 8 and 9, except for Article 8(1) (f) andArticle 9(2) (a), Type C Power Generating Modules shall fulfil the requirements in this Article.2. Type C Power Generating Modules shall fulfil the following requirements referring to Frequencystability:a) With regard to Active Power controllability and control range, the Power Generating Modulecontrol system shall be capable of adjusting an Active Power Setpoint as instructed by theRelevant Network Operator or the Relevant TSO to the Power Generating Facility Owner. Itshall be capable of implementing the Setpoint within a period specified in the aboveInstruction and within a tolerance defined by the Relevant Network Operator or theRelevant TSO (subject to the availability of the prime mover resource). Manual, localmeasures shall be possible in the case that any automatic remote control devices are out ofservice.b) In addition to Article 8(1) (c) the following shall apply accumulatively with regard to LimitedFrequency Sensitive Mode – Underfrequency (LFSM-U):1) The Power Generating Module shall be capable of activating the provision of ActivePower Frequency Response according to figure 4 at a Frequency threshold between andincluding 49.8 Hz and 49.5 Hz with a Droop in a range of 2 – 12 %. In the LFSM-U modethe Power Generating Module shall be capable of providing a power increase up to itsMaximum Capacity. The actual delivery of Active Power Frequency Response in LFSM-Umode depends on the operating and ambient conditions of the Power Generating`24 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Module when this response is triggered, in particular limitations on operation nearMaximum Capacity at low frequencies according to Article 8(1) (e) and available primaryenergy sources. The actual Frequency threshold and Droop settings shall be determinedby the Relevant TSO. The Active Power Frequency Response shall be activated as fast astechnically feasible with an initial delay that shall be as short as possible and reasonablyjustified by the Power Generating Facility Owner to the Relevant TSO if greater than 2seconds.• Synchronous Power Generating Modules:P ref is the Maximum CapacityPP ref• Power Park Modules:P ref is the actual Active Power output at the momentthe LFSM-O threshold is reached or the MaximumCapacity , as defined by the Relevant TSO, whilerespecting the provisions of Article 4(3)s 2f 1f nff nFigure 4: Active Power Frequency Response capability of Power Generating Modules inLFSM-U. P ref is the reference Active Power to which P is related and may be defineddifferently for Synchronous Power Generating Modules and Power Park Modules. P isthe change in Active Power output from the Power Generating Module. f n is the nominalFrequency (50 Hz) in the Network and f is the Frequency change in the Network. Atunderfrequencies where f is below f 1 the Power Generating Module has to provide apositive Active Power output change according to the Droop S 2 .2) Stable operation of the Power Generating Module during LFSM-U operation shall beensured. The LFSM-U reference Active Power shall be the Active Power output at themoment of activation of LFSM-U and shall not be changed unless triggered by frequencyrestoration action.c) In addition to Article 10(2) (b) the following shall apply accumulatively, when operating inFrequency Sensitive Mode (FSM):1) The Power Generating Module shall be capable of providing Active Power FrequencyResponse with respect to figure 5 and in accordance with the parameters specified byeach TSO within the ranges shown in table 4.2) In case of overfrequency the Active Power Frequency Response is limited by theMinimum Regulating Level.3) In case of underfrequency the Active Power Frequency Response is limited by MaximumCapacity. The actual delivery of Active Power Frequency Response depends on theoperating and ambient conditions of the Power Generating Module when this response`25 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

is triggered, in particular limitations on operation near Maximum Capacity at lowfrequencies according to Article 8(1) (e) and available primary energy sources.PP maxPP1maxs 1ff nP1PmaxFigure 5: Active Power Frequency Response capability of Power Generating Modules inFSM illustrating the case of zero deadband and insensitivity. P max is the MaximumCapacity to which P is related. P is the change in Active Power output from the PowerGenerating Module. f n is the nominal Frequency (50 Hz) in the Network and f is theFrequency deviation in the Network.ParametersRangesP1Active Power range related to Maximum Capacity 1.5 – 10 %PmaxFrequency Response InsensitivityFrequency Response Deadbandf iffni10 – 30 mHz0.02 – 0.06 %0 – 500 mHzDroop 2 – 12 %s 1Table 4: Parameters for Active Power Frequency Response in FSM (explanation for figure5)`26 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

4) The Frequency Response Deadband of Frequency deviation and Droop are selected bythe TSO and must be able to be reselected subsequently (without requiring to be onlineor remote) within the given frames in the table 4.5) As a result of a frequency step change, the Power Generating Module shall be capable ofactivating full Active Power Frequency Response, at or above the full line according tofigure 6 in accordance with the parameters specified by each TSO (aiming at avoidingActive Power oscillations for the Power Generating Module) within the ranges accordingto table 5. The combination of choice of the parameters according to table 5 shall takeinto account possible technology dependent limitations. The initial delay of activationshall be as short as possible and reasonably justified by the Power Generating FacilityOwner to the Relevant TSO, by providing technical evidence for why a longer time isneeded, if greater than 2 seconds or a shorter time if specified by the Relevant TSOwhile respecting the provisions of Article 4(3) for generation technologies withoutInertia.PP maxPP1maxt 1t 2tsFigure 6: Active Power Frequency Response capability. P max is the Maximum Capacity towhich P is related. P is the change in Active Power output from the Power GeneratingModule. The Power Generating Modules have to provide Active Power Output P up tothe point P 1 in accordance with the times t 1 and t 2 with the values of P 1 , t 1 and t 2 beingspecified by the Relevant TSO according to Table 5. t 1 is the initial delay. t 2 is the time forfull activation.6) The Power Generating Module shall be capable of providing full Active Power FrequencyResponse for a period specified by the TSOs, considering the technical feasibility, foreach Synchronous Area between 15 min and 30 min, considering the Active Powerheadroom and primary energy source of the Power Generating Module.7) As long as a Frequency deviation continues Active Power control shall not have anyadverse impact on the Frequency response within the time limits of Article 10(2) (c)point 6).`27 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

ParametersRanges or valuesActive Power range related to Maximum Capacity (FrequencyP1response range) 1.5 – 10 %PmaxMaximum admissible initial delay unless justified otherwise forgeneration technologies with InertiaMaximum admissible initial delay unless justified otherwise forgeneration technologies without InertiaMaximum admissible choice of full activation time t 2, unlesslonger activation times are admitted by the Relevant TSO due tosystem stability reasonst 1t 12 secondsas specified bythe Relevant TSOwhile respectingthe provisions ofArticle 4(3)30 secondsTable 5: Parameters for full activation of Active Power Frequency Response resultedfrom Frequency step change (explanation for figure 6).d) With regard to Frequency restoration control, the Power Generating Module shall providefunctionalities compliant to specifications defined by the Relevant TSO while respecting theprovisions of Article 4(3), aiming at restoring Frequency to its nominal value and/ ormaintain power exchange flows between control areas at their scheduled values.e) With regard to disconnection due to underfrequency, any Power Generating Facility beingcapable of acting as a load except for auxiliary supply, including hydro Pump-Storage PowerGenerating Facilities, shall be capable of disconnecting its load in case of underfrequency.f) With regard to real-time monitoring of FSM:1) To monitor the operation of Active Power Frequency Response the communicationinterface shall be equipped to transfer on-line from the Power Generating Facility to theNetwork control centre of the Relevant Network Operator and/or the Relevant TSO onrequest by the Relevant Network Operator and/or the Relevant TSO at least thefollowing signals:- status signal of FSM (on/off);- scheduled Active Power output;- actual value of the Active Power output;- actual parameter settings for Active Power Frequency Response; and- Droop and dead band.2) The Relevant Network Operator and the Relevant TSO shall define while respecting theprovisions of Article 4(3) additional signals to be provided by the Power GeneratingFacility for monitoring and/or recording devices in order to verify the performance of`28 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

the Active Power Frequency Response provision of participating Power GeneratingModules.3. Type C Power Generating Modules shall fulfil the following requirements referring to Voltagestability:a) The Relevant Network Operator in coordination with the Relevant TSO shall have the right tospecify while respecting the provisions of Article 4(3) Voltages at the Connection Point atwhich a Power Generating Module shall be capable of automatic disconnection. The termsand settings for this automatic disconnection shall be defined by the Relevant NetworkOperator in coordination with the Relevant TSO while respecting the provisions of Article4(3).4. Type C Power Generating Modules shall fulfil the following requirements referring to robustnessof Power Generating Modulesa) In case of power oscillations, Steady-state Stability of a Power Generating Module isrequired when operating at any operating point of the P-Q-Capability Diagram. A PowerGenerating Module shall be capable of staying connected to the Network and operatingwithout power reduction notwithstanding the provisions of Article 8(1) (e), as long asVoltage and Frequency remain within the admissible limits pursuant to this Network Code.b) Single-phase or three-phase auto-reclosures on meshed Network lines, if applicable to thisNetwork, shall be withstood by Power Generating Modules without tripping. Details of thiscapability shall be subject to coordination and agreements on protection schemes andsettings according to Article 9(5) (b).5. Type C Power Generating Modules shall fulfil the following requirements referring to systemrestoration:a) With regard to Black Start Capability:1) Black Start Capability is not mandatory. If the Relevant TSO deems system security to beat risk due to a lack of Black Start Capability in a Control Area, the Relevant TSO shallhave the right to obtain a quote for Black Start Capability from Power Generating FacilityOwners.2) A Power Generating Module with a Black Start Capability shall be able to start from shutdown within a timeframe decided by the Relevant Network Operator in coordinationwith the Relevant TSO while respecting the provisions of Article 4(3), without anyexternal energy supply. The Power Generating Module shall be able to synchronisewithin the Frequency limits defined in Article 8(1) and Voltage limits defined by theRelevant Network Operator or defined by Article 11(2) where applicable.3) The Power Generating Module Voltage regulation shall be capable of regulating loadconnections causing dips of Voltage automatically.The Power Generating Module shall:- be capable of regulating load connections in block load;- control Frequency in case of overfrequency and underfrequency within the wholeActive Power output range between Minimum Regulating Level and MaximumCapacity as well as at houseload level;`29 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

`30 | P a g e- be capable of parallel operation of a few Power Generating Modules within oneisland; and- control Voltage automatically during the system restoration phase.b) With regard to capability to take part in Island Operation:1) The capability to take part in Island Operation, if required by the Relevant NetworkOperator in coordination with the Relevant TSO while respecting the provisions ofArticle 4(3), shall be possible within the Frequency limits defined in Article 8(1) andVoltage limits according to Article 10(3) or Article 11(2) where applicable.2) If required, the Power Generating Module shall be able to operate in FSM during IslandOperation, as defined in Article 10(2) (b). In the case of a power surplus, it shall bepossible to reduce the Active Power Output of the Power Generating Module from itsprevious operating point to any new operating point within the P-Q-Capability Diagramas much as inherently technically feasible, but at least a Active Power output reductionto 55 % of its Maximum Capacity shall be possible.3) Detection of change from interconnected system operation to Island Operation shall notrely solely on the Network Operator’s switchgear position signals. The detection methodshall be agreed between the Power Generating Facility Owner and the Relevant NetworkOperator in coordination with the Relevant TSO while respecting the provisions ofArticle 4(3).c) With regard to quick re-synchronization capability:1) Quick re-synchronization capability is required in case of disconnection of the PowerGenerating Module from the Network in line with the protection strategy agreedbetween the Relevant Network Operator in coordination with the Relevant TSO and thePower Generation Facility Owner in the event of disturbances to the system.2) The Power Generating Module whose minimum re-synchronization time after itsdisconnection from any external power supply exceeds 15 minutes shall be designed fortripping to houseload from any operating point in its P-Q-Capability Diagram. Foridentifying houseload operation any Network Operator’s switchgear position signals maybe used only as additional information which cannot be solely relied on.3) Power Generating Modules shall be capable of continuing operation following trippingto houseload, irrespective of any auxiliary connection to the external Network. Theminimum operation time shall be defined by the Relevant Network Operator incoordination with the Relevant TSO taking into consideration the specific characteristicsof the prime mover technology .6. Type C Power Generating Modules shall fulfil the following general system managementrequirements:a) With regard to loss of angular stability or loss of control, a Power Generating Module shallbe capable of disconnecting automatically from the Network in order to supportpreservation of system security and/or to prevent damage from the Power GeneratingModule. The Power Generating Facility Owner and the Relevant Network Operator incoordination with the Relevant TSO shall agree on the criteria to detect loss of angularstability or loss of control.b) With regard to instrumentation:ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

1) Power Generating Facilities shall be equipped with a facility to provide fault recordingand dynamic system behaviour monitoring of the following parameters:- Voltage;- Active Power;- Reactive Power; and- Frequency.The Relevant Network Operator shall have the right to define while respecting theprovisions of Article 4(3) quality of supply parameters to be complied with provided areasonable prior notice is given.2) While respecting the provisions of Article 4 (3), the settings of the fault recordingequipment, including triggering criteria and the sampling rates shall be agreed betweenthe Power Generating Facility Owner and the Relevant Network Operator incoordination with the Relevant TSO.3) The dynamic system behaviour monitoring shall include an oscillation trigger, specifiedby the Relevant Network Operator in coordination with the Relevant TSO, detectingpoorly damped power oscillations.4) The facilities for quality of supply and dynamic system behaviour monitoring shallinclude arrangements for the Power Generating Facility Owner, the Relevant NetworkOperator and/or the Relevant TSO to access the information. While respecting theprovisions of Article 4 (3) the communications protocols for recorded data shall beagreed between the Power Generating Facility Owner and the Relevant NetworkOperator and Relevant TSO.c) With regard to the simulation models:1) The Relevant Network Operator in coordination with the Relevant TSO shall have theright to require while respecting the provisions of Article 4(3) the Power GeneratingFacility Owner to provide simulation models, that shall properly reflect the behaviour ofthe Power Generating Module in both steady-state and dynamic simulations (50 Hzcomponent) and, where appropriate and justified, in electromagnetic transientsimulations.The decision shall include:- the format in which models shall be provided- the provision of documentation of models structure and block diagramsThe models shall be verified against the results of compliance tests as of Title 4 Chapters2, 3 and 4. They shall then be used for the purpose of verifying the requirements of thisNetwork Code including but not limited to Compliance Simulations as of Title 4 Chapters5, 6 and 7 and for use in studies for continuous evaluation in system planning andoperation.2) For the purpose of dynamic simulations, the models provided shall contain the followingsub-models, depending on the existence of the mentioned components:- Alternator and prime mover;- Speed and power control;`31 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

- Voltage control, including, if applicable, Power System Stabilizer (PSS) function andexcitation system;- Power Generating Module protection models as agreed between the RelevantNetwork Operator and the Power Generating Facility Owner, while respecting theprovisions of Article 4(3); and- Converter models for Power Park Modules.3) The Relevant Network Operator shall deliver to the Power Generating Facility Owner anestimate of the minimum and maximum short circuit capacity at the connection point,expressed in MVA, as an equivalent of the Network.4) The Relevant Network Operator or Relevant TSO shall have the right to require whilerespecting the provisions of Article 4(3) Power Generating Module recordings in order tocompare the response of the models with these recordings.d) With regard to the installation of devices for system operation and/or security, if theRelevant Network Operator or the Relevant TSO considers additional devices necessary tobe installed in a Power Generating Facility in order to preserve or restore system operationor security, the Relevant Network Operator or Relevant TSO and the Power GeneratingFacility Owner shall investigate this request and, while respecting the provisions of Article4(3), agree on an appropriate solution .e) The Relevant Network Operator in coordination with the Relevant TSO shall define whilerespecting the provisions of Article 4(3) minimum and maximum limits on rates of change ofActive Power output (ramping limits) in both up and down direction for a Power GeneratingModule taking into consideration the specific characteristics of the prime mover technology.f) With regard to earthing arrangement of the neutral-point at the Network side of step-uptransformers, it shall be in accordance with the specifications of the Relevant NetworkOperator.g) With regard to changes to, modernization of or replacement of equipment of PowerGenerating Modules, any Power Generating Facility Owner intending to change plant andequipment of the Power Generating Module that may have an impact on the gridconnection and on the interaction, such as turbines, Alternators, converters, high-voltageequipment, protection and control systems (hardware and software), shall notify in advance(in accordance with agreed or decided national timescales) the Relevant Network Operatorin case it is reasonable to foresee that these intended changes may be affected by therequirements of this Network Code and shall, while respecting the provisions of Article 4(3),agree on these requirements before the proposals are implemented with the RelevantNetwork Operator in coordination with the Relevant TSO. In case of modernisation orreplacement of equipment in existing Power Generating Modules the new equipment shallcomply with the respective requirements which are relevant to the planned work. Whilerespecting the provisions of Article 4 (3), the use of existing spare components that do notcomply with the requirements has to be agreed with the Relevant Network Operator incoordination with the Relevant TSO in each case.`32 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Article 11GENERAL REQUIREMENTS FOR TYPE D POWER GENERATING MODULES1. In addition to fulfilling the requirements listed in Articles 8, 9 and 10 unless referred tootherwise in this Article, except for Article 8(1) (f), (g), Article 9(2) (a) and Article 10(3) (a), TypeD Power Generating Modules shall fulfil the requirements in this Article.2. Type D Power Generating Modules shall fulfil the following requirements referring to Voltagestability:a) With regard to Voltage ranges:1) While still respecting the provisions according to Articles 9(3) (a) and 11(3) (a), a PowerGenerating Module shall be capable of staying connected to the Network and operatingwithin the ranges of the Network Voltage at the Connection Point, expressed by theVoltage at the Connection Point related to nominal Voltage (per unit), and the timeperiods specified by tables 6.1 and 6.2.Synchronous Area Voltage Range Time period foroperation0.85 pu – 0.90 pu 60 minutes0.90 pu – 1.118 pu UnlimitedContinental EuropeNordic1.118 pu – 1.15 pu To be decided by eachTSO while respecting theprovisions of Article 4(3),but not less than 20minutes0.90 pu – 1.05 pu Unlimited1.05 pu – 1.10 pu 60 minutesGreat Britain 0.90 pu–1.10 pu UnlimitedIreland 0.90 pu – 1.118 pu Unlimited0.85 pu – 0.90 pu 30 minutesBaltic0.90 pu – 1.12 pu Unlimited1.12 pu – 1.15 pu 20 minutesTable 6.1: This table shows the minimum time periods a Power Generating Module shallbe capable of operating for Voltages deviating from the nominal value at the ConnectionPoint without disconnecting from the Network. (The Voltage base for pu values is from110 kV to 300 kV (excluding).)`33 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Synchronous AreaVoltage RangeTime period foroperation0.85 pu – 0.90 pu 60 minutes0.90 pu – 1.05 pu UnlimitedContinental Europe1.05 pu – 1.0875 puTo be decided by eachTSO while respecting theprovisions of Article 4(3),but not less than 60minutes1.0875 pu – 1.10 pu 60 minutesNordicGreat Britain0.90 pu – 1.05 pu Unlimited1.05 pu – 1.10 pu 60 minutes0.90 pu – 1.05 pu Unlimited1.05 pu – 1.10 pu 15 minutesIreland 0.90 pu – 1.05 pu Unlimited0.88 pu – 0.90 pu 20 minutesBaltic0.90 pu – 1.10 pu Unlimited1.10 pu – 1.15 pu 20 minutes`34 | P a g eTable 6.2: This table shows the minimum time periods a Power Generating Module shallbe capable of operating for Voltages deviating from the nominal value at the ConnectionPoint without disconnecting from the Network. (The Voltage base for pu values is from300 kV to 400 kV.)2) While respecting the provisions of Article 4(3), wider Voltage ranges or longer minimumtimes for operation can be agreed between the Relevant Network Operator incoordination with the Relevant TSO and the Power Generating Facility Owner to ensurethe best use of the technical capabilities of a Power Generating Module if needed topreserve or to restore system security. If wider Voltage ranges or longer minimum timesfor operation are economically and technically feasible, the consent of the PowerGenerating Facility Owner shall not be unreasonably withheld.3) While still respecting the provisions of Article 11(2) (a) point 1), the Relevant NetworkOperator in coordination with the Relevant TSO shall have the right to specify whilerespecting the provisions of Article 4(3) Voltages at the Connection Point at which aPower Generating Module shall be capable of automatic disconnection. The terms andsettings for automatic disconnection shall be agreed between the Relevant NetworkOperator and the Power Generating Facility Owner, while respecting the provisions ofArticle 4(3).ENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

3. Type D Power Generating Modules shall fulfil the following requirements referring to robustnessof Power Generating Modules:a) With regard to fault-ride-through capability of Power Generating Modules:1) The voltage-against-time-profile shall be defined by the TSO using parameters in figure 3according to tables 7.1 and 7.2.2) Each TSO shall define and make publicly available while respecting the provisions ofArticle 4(3) the pre-fault and post-fault conditions for the fault-ride-through capabilityaccording to Article 9(3) (a) point 3).Voltage parameters [pu]Time parameters [seconds]U ret : 0 t clear : 0.14 – 0.25U clear : 0.25 t rec1 : t clear – 0.45U rec1 : 0.5 – 0.7 t rec2 : t rec1 – 0.7U rec2 : 0.85 – 0.9 t rec3 : t rec2 – 1.5Table 7.1 – Parameters for figure 3 for fault-ride-through capability of SynchronousPower Generating Modules.Voltage parameters [pu]Time parameters [seconds]U ret : 0 t clear : 0.14 – 0.25U clear : U ret t rec1 : t clearU rec1 : U clear t rec2 : t rec1U rec2 : 0.85 t rec3 : 1.5 – 3.0Table 7.2 – Parameters for figure 3 for fault-ride-through capability of Power ParkModules.3) Each Relevant Network Operator shall provide on request by the Power GeneratingFacility Owner the pre-fault and post-fault conditions to be considered for fault-ridethroughcapability as an outcome of the calculations at the Connection Point as definedin Article 9 (3) (a) point 3) regarding:- pre-fault minimum short circuit capacity at each Connection Point expressed inMVA;`35 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

- pre-fault operating point of the Power Generating Module expressed in ActivePower output and Reactive Power output at the Connection Point and Voltage atthe Connection Point; and- post-fault minimum short circuit capacity at each Connection Point expressed inMVA.4) Fault-ride-through capabilities in case of asymmetrical faults shall be defined by eachTSO while respecting the provisions of Article 4(3).4. Type D Power Generating Modules shall fulfil the following general system managementrequirements:a) With regard to synchronization, when starting a Power Generating Module, synchronizationshall be performed by the Power Generating Facility Owner after authorization by theRelevant Network Operator. The Power Generating Module shall be equipped with thenecessary synchronization facilities. Synchronization of Power Generating Modules shall bepossible for frequencies within the ranges set out in table 2. While respecting the provisionsof Article 4(3), the Relevant Network Operator and the Power Generating Facility Ownershall agree on the settings of synchronization devices to be concluded prior to operation ofthe Power Generating Module. An agreement shall cover the following matters: Voltage,Frequency, phase angle range, phase sequence, deviation of Voltage and Frequency.Chapter 2REQUIREMENTS FOR SYNCHRONOUS POWER GENERATING MODULESArticle 12REQUIREMENTS FOR TYPE B SYNCHRONOUS POWER GENERATING MODULES1. In addition to fulfilling the requirements listed in Articles 8 and 9, Type B Synchronous PowerGenerating Modules shall fulfil the requirements in this Article.2. Type B Synchronous Power Generating Modules shall fulfil the following requirements referringto Voltage stability:a) With regard to Reactive Power capability the Relevant Network Operator shall have the rightto define while respecting the provisions of Article 4(3) the capability of a SynchronousPower Generating Module to provide Reactive Power.b) With regard to the Voltage control system, a Synchronous Power Generating Module shallbe equipped with a permanent automatic excitation control system in order to provideconstant Alternator terminal Voltage at a selectable Setpoint without instability over theentire operating range of the Synchronous Power Generating Module.3. Type B Synchronous Power Generating Modules shall fulfil the following requirements referringto robustness of Power Generating Modules:`36 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Chapter 3REQUIREMENTS FOR POWER PARK MODULESArticle 15REQUIREMENTS FOR TYPE B POWER PARK MODULES1. In addition to fulfilling the general requirements listed in Articles 8 and 9, Type B Power ParkModules shall fulfil the requirements in this Article.2. Type B Power Park Modules shall fulfil the following requirement referring to Voltage stability:a) With regard to Reactive Power capability the Relevant Network Operator shall have the rightto define while respecting the provisions of Article 4(3) the capability of a Power ParkModule to provide Reactive Power.b) The Relevant Network Operator in coordination with the Relevant TSO shall have the right torequire while respecting the provisions of Article 4(3) fast acting additional reactive Currentinjection at the Connection Point to the pre-fault reactive Current injection in case ofsymmetrical (3-phase) faults:1) The Power Park Module shall be capable of activating this additional reactive Currentinjection during the period of faults. The Power Park Module shall be capable of either:a. ensuring the supply of the additional reactive Current at the Connection Pointaccording to further specifications by the Relevant Network Operator incoordination with the Relevant TSO of the magnitude of this Current, dependingon the deviation of the Voltage at the Connection point from its nominal value;orb. alternatively, measuring Voltage deviations at the terminals of the individualunits of the Power Park Module and providing an additional reactive Current atthe terminals of these units according to further specifications by the RelevantNetwork Operator in coordination with the Relevant TSO of the magnitude ofthis Current, depending on the deviation of the Voltage at units’ terminals fromits nominal value.2) The Power Park Module (Article 15(2) (b) point 1) option a.) or the individual units of thePower Park Module (Article 15(2) (b) point 1) option b.) shall be capable of providing atleast 2/3 of the additional reactive Current within a time period specified by theRelevant TSO, which shall not be less than 10 milliseconds. The target value of thisadditional reactive Current defined by Article 15(2) (b) point 1) shall be reached with anaccuracy of 10% within 60 milliseconds from the moment the Voltage deviation hasoccurred as further specified according to Article 15(2) (b) point 1).3) The total reactive Current contribution shall be not more than 1 pu of the short termdynamic Current rating (covering up to 0.4 seconds) of the Power Park Module (Article`40 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

15(2) (b) point 1) option a.) or of the individual units of the Power Park Module (Article15(2) (b) point 1) option b.) taking into account the pre-fault reactive Current. Ifadditional real Current injection is given priority over additional reactive Currentinjection, the total Current contribution can be further limited by the real Current basedon limiting the apparent Current (vector addition of real and reactive Current) to 1 pu ofthe short term dynamic Current rating of the Power Park Module (Article 15(2) (b) point1) option a.) or the individual units of the Power Park Module (Article 15(2) (b) point 1)option b.).c) With regard to fast acting additional reactive Current injection in case of asymmetrical (1-phase or 2-phase) faults the Relevant Network Operator in coordination the Relevant TSOshall have the right to introduce while respecting the provisions of Article 4(3) a requirementfor asymmetrical Current injection.3. Type B Power Park Modules shall fulfil the following requirements referring to robustness ofPower Generating Modules:a) With regard to post fault Active Power recovery after fault-ride-through, the Relevant TSOshall specify while respecting the provisions of Article 4(3) magnitude and time for ActivePower recovery the Power Park Module shall be capable of providing.`41 | P a g eArticle 16REQUIREMENTS FOR TYPE C POWER PARK MODULES1. In addition to fulfilling the requirements listed in Articles 8, 9, 10 and 15, except for Article 8(1)(f), Article 9(2) (a), and Article 15(2) (a) unless referred to otherwise in Article 16(3) (d) points 3)and 4), Type C Power Park Modules shall fulfil the requirements in this Article.2. Type C Power Park Modules shall fulfil the following requirements referring to Frequencystability:a) With regard to the capability of providing Synthetic Inertia to a low Frequency event:1) The Relevant TSO shall have the right to require while respecting the provisions ofArticle 4(3), in co-operation with other TSOs in the relevant Synchronous Area, a PowerPark Module, which is not inherently capable of supplying additional Active Power to theNetwork by its Inertia and which is greater than a MW size to be specified by theRelevant TSO, to install a feature in the control system which operates the Power ParkModule so as to supply additional Active Power to the Network in order to limit the rateof change of Frequency following a sudden loss of infeed.2) The operating principle of this control system and the associated performanceparameters shall be defined by the Relevant TSO while respecting the provisions ofArticle 4(3).3. Type C Power Park Modules shall fulfil the following requirements referring to Voltage stability:a) With regard to Reactive Power Capability, for Power Park Modules where the ConnectionPoint is not at the location of the high-voltage terminals of its step-up transformer nor at theterminals of the high-voltage line or cable to the Connection Point at the Power ParkENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Module, if no step-up transformer exists, supplementary Reactive Power may be required bythe Relevant Network Operator while respecting the provisions of Article 4(3) to compensatefor the Reactive Power demand of the high-voltage line or cable between these two pointsfrom the responsible owner of this line or cable.b) With regard to Reactive Power capability at Maximum Capacity:1) The Relevant Network Operator in coordination with the Relevant TSO shall define whilerespecting the provisions of Article 4(3) the Reactive Power provision capabilityrequirements in the context of varying Voltage. For doing so, it shall define a U-Q/P max -profile that shall take any shape within the boundaries of which the Power Park Moduleshall be capable of providing Reactive Power at its Maximum Capacity.2) The U-Q/P max -profile is defined by each Relevant Network Operator in coordination withthe Relevant TSO while respecting the provisions of Article 4(3) in conformity with thefollowing principles:- the U-Q/P max -profile shall not exceed the U-Q/P max -profile envelope, represented bythe inner envelope in figure 8, its shape does not need to be rectangular;- the dimensions of the U-Q/P max -profile envelope (Q/P max range and Voltage range)are defined for each Synchronous Area in table 9; and- the position of the U-Q/P max -profile envelope within the limits of the fixed outerenvelope in figure 8.Figure 8 – U-Q/P max -profile of a Power Park Module. The diagram represents boundariesof a U-Q/P max -profile by the Voltage at the Connection Point, expressed by the ratio of itsactual value and its nominal value in per unit, against the ratio of the Reactive Power (Q)and the Maximum Capacity (P max ). The position, size and shape of the inner envelope areindicative.`42 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Synchronous AreaMaximum range ofQ/P maxMaximum range of steadystateVoltage level in PUContinental Europe 0.75 0.225Nordic 0.95 0.150Great Britain 0.66 0.100Ireland 0.66 0.218Baltic States 0.80 0.220Table 9: Parameters for the inner envelope in figure 83) The Reactive Power provision capability requirement applies at the Connection Point.For profile shapes other than rectangular, the Voltage range represents the highest andlowest values. The full Reactive Power range is therefore not expected to be availableacross the range of steady-state Voltages.c) With regard to Reactive Power capability below Maximum Capacity:1) The Relevant Network Operator in coordination with the Relevant TSO shall define whilerespecting the provisions of Article 4(3) the Reactive Power provision capabilityrequirements. For doing so, it shall define a P-Q/P max -profile that shall take any shapewithin the boundaries of which the Power Park Module shall be capable of providingReactive Power below Maximum Capacity.2) The P-Q/P max -profile is defined by each Relevant Network Operator in coordination withthe Relevant TSO while respecting the provisions of Article 4(3), in conformity with thefollowing principles:- the P-Q/P max -profile shall not exceed the P-Q/P max -profile envelope, represented bythe inner envelope in figure 9;- the Q/P max range of the P-Q/P max -profile envelope is defined for each SynchronousArea in table 9;- the Active Power range of the P-Q/P max -profile envelope at zero Reactive Power shallbe 1 pu;- the P-Q/P max -profile can be of any shape and shall include conditions for ReactivePower capability at zero Active Power; and- the position of the P-Q/P max -profile envelope within the limits of the fixed outerenvelope in figure 9.3) When operating at an Active Power output below the Maximum Capacity (P

Figure 9 - P-Q/P max -profile of a Power Park Module. The diagram represents boundariesof a P-Q/P max -profile at the Connection Point by the Active Power, expressed by the ratioof its actual value and the Maximum Capacity in per unit, against the ratio of theReactive Power (Q) and the Maximum Capacity (P max ). The position, size and shape of theinner envelope are indicative.4) The Power Park Module shall be capable of moving to any operating point within its P-Q/P max profile in appropriate timescales to target values requested by the RelevantNetwork Operator.d) With regard to Reactive Power control modes:1) The Power Park Module shall be capable of providing Reactive Power automatically byeither Voltage Control mode, Reactive Power Control mode or Power Factor Controlmode.2) For the purposes of Voltage Control mode, the Power Park Module shall be capable ofcontributing to Voltage control at the Connection Point by provision of Reactive Powerexchange with the Network with a Setpoint Voltage covering at least 0.95 to 1.05 pu insteps no greater than 0.01 pu with a Slope with a range of at least 2 to 7 % in steps nogreater than 0.5 %. The Reactive Power output shall be zero when the grid Voltage valueat the Connection Point equals the Voltage Setpoint.The Setpoint may be operated with or without a deadband selectable in a range fromzero to +-5 % of nominal Network Voltage in steps no greater than 0.5 %.Following a step change in Voltage, the Power Park Module shall be capable of achieving90 % of the change in Reactive Power output within a time t 1 to be specified by RelevantNetwork operator while respecting the provisions of Article 4(3) in the range of 1 - 5seconds and settle at the value defined by the operating Slope within a time t 2 to bespecified by Relevant Network Operator while respecting the provisions of Article 4(3) inthe range of 5 - 60 seconds, with a steady-state reactive tolerance no greater than 5 % ofthe maximum Reactive Power.`44 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

3) For the purposes of Reactive Power Control mode, the Power Park Module shall becapable of setting the Reactive Power Setpoint anywhere in the Reactive Power range,defined by Article 15(2) (a) and by Article 16(3) (a) and (b), with setting steps no greaterthan 5 Mvar or 5 % (whichever is smaller) of full Reactive Power, controlling the ReactivePower at the Connection Point to an accuracy within +-5 Mvar or +-5 % (whichever issmaller) of the full Reactive Power.4) For the purposes of Power Factor Control mode, the Power Park Module shall becapable of controlling the Power Factor at the Connection Point within the requiredReactive Power range, defined by the Relevant Network Operator according to Article15(2) (a) or defined by Article 16(3) (a) and (b), with a target Power Factor in steps nogreater than 0.01. The Relevant Network Operator shall define while respecting theprovisions of Article 4(3) the target Power Factor value and the tolerance expressed inMvar or % on the Reactive Power value issued from conversion of Power Factor value,within a period of time, following a sudden change of Active Power output.5) The Relevant Network Operator in coordination with the Relevant TSO shall define whilerespecting the provisions of Article 4(3) which of the above three reactive power controlmode options and associated Setpoints shall apply and further equipment to make theadjustment of the relevant Setpoint operable remotely.e) With regard to priority to Active or Reactive Power contribution, the Relevant TSO shalldefine while respecting the provisions of Article 4(3), whether Active Power contribution orReactive Power contribution has priority during faults for which fault-ride-through capabilityis required. If priority is given to Active Power contribution, its provision shall be establishedno later than 150 ms from the fault inception.f) With regard to power oscillations damping control, if required by the Relevant TSO, whilerespecting the provisions of Article 4(3), a Power Park Module shall be capable ofcontributing to damping power oscillations. The voltage and reactive power controlcharacteristics of Power Park Modules shall not adversely affect the damping of poweroscillations.Article 17REQUIREMENTS FOR TYPE D POWER PARK MODULESType D Power Park Modules shall fulfil the requirements listed in Articles 8, 9, 10, 11, 15 and 16,except for Article 8(1) (f), Article 9(2) (a), Article 10(3) (a), and Article 15(2) (a).`45 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Connection Point related to nominal Voltage (per unit), and within the time periods specified bytable 10.Synchronous AreaVoltage RangeTime period foroperation0.85 pu – 0.90 pu 60 minutes0.9 pu – 1.118 pu* UnlimitedContinental Europe1.118 pu – 1.15 pu*To be decided by eachTSO while respecting theprovisions of Article 4(3),but not less than 20minutes0.90 pu – 1.05 pu** Unlimited1.05 pu – 1.0875 pu**To be defined by eachTSO while respecting theprovisions of Article 4(3),but not less than 60minutes1.0875 pu – 1.10 pu** 60 minutesNordic0.90 pu – 1.05 pu Unlimited1.05 pu – 1.10 pu 60 minutes0.90 pu – 1.10 pu* UnlimitedGreat Britain0.90 pu – 1.05 pu** Unlimited1.05 pu – 1.10 pu** 15 minutesIreland 0.90 pu – 1.10 pu Unlimited0.85 pu – 0.90 pu* 30 minutes0.90 pu – 1.12 pu* UnlimitedBaltic1.12 pu – 1.15 pu* 20 minutes0.88 pu – 0.90 pu** 20 minutes* The Voltage base for pu values is below 300 kV.** The Voltage base for pu values is from 300 kV to 400 kV.0.90 pu – 1.10 pu** Unlimited1.10 pu – 1.15 pu** 20 minutes`47 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

Table 10: This table shows the minimum period an Offshore Power Park Module shall be capableof operating for different Voltage ranges deviating from a nominal value without disconnecting.2. The Voltage stability requirements defined respectively in Article 15(2) (b) and (c) as well as inArticle 16(3) (a), (c), (d), (e) and (f) shall apply to any Offshore Power Park Module.3. The Reactive Power capability at Maximum Capacity as defined in Article 16(3) (b) shall apply toany Offshore Power Park Module, except for table 9, which shall be replaced by table 11.Synchronous Area Range of Q/P max Maximum range of steadystateVoltage level in PUContinental Europe 0.75 0.225Nordic 0.95 0.150Great Britain0 *0.33 ** 0.100Ireland 0.66 0.218Baltic States 0.8 0.22* ) at the Offshore Connection Point for configuration 1** ) at the Offshore Connection Point for configuration 2Table 11: Parameters for figure 8Article 21ROBUSTNESS OF POWER GENERATING MODULES REQUIREMENTS APPLICABLE TO OFFSHOREPOWER PARK MODULES1. The robustness of Power Generating Modules requirements as defined in Article 10(4) (a) and(c), and Article 15 (3) shall apply to any Offshore Power Park Module.2. The fault-ride-through capability requirements as defined in Articles 9(3) (a) and 11(3) (a) shallapply to any Offshore Power Park Module.Article 22SYSTEM RESTORATION REQUIREMENTS APPLICABLE TO OFFSHORE POWER PARK MODULESThe system restoration requirements defined respectively in Articles 9(4) and 10(5) shall apply toany Offshore Power Park Module.`48 | P a g eENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51 info@entsoe.eu • www.entsoe.euENTSO-E AISBL • Avenue Cortenbergh 100 • 1000 Brussels • Belgium • Tel +32 2 741 09 50 • Fax +32 2 741 09 51

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Décrets, arrêtés, circulairesTEXTES GÉNÉRAUXMINISTÈRE DE L’ÉCOLOGIE, DE L’ÉNERGIE, DU DÉVELOPPEMENTDURABLE ET DE L’AMÉNAGEMENT DU TERRITOIREArrêté du 23 avril 2008 relatif aux prescriptions techniques de conception et de fonctionnementpour le raccordement à un réseau public de distribution d’électricité en basse tension ou enmoyenne tension d’une installation de production d’énergie électriqueNOR : DEVE0808815ALe ministre d’Etat, ministre de l’écologie, de l’énergie, du développement durable et de l’aménagement duterritoire,Vu le décret n o 2000-877 du 7 septembre 2000 relatif à l’autorisation d’exploiter les installations deproduction d’électricité, notamment son article 1 er ;Vu le décret n o 2001-410 du 10 mai 2001 relatif aux conditions d’achat de l’électricité produite par desproducteurs bénéficiant de l’obligation d’achat, notamment son article 9 ter ;Vu le décret n o 2006-1278 du 18 octobre 2006 relatif à la compatibilité électromagnétique des équipementsélectriques et électroniques, notamment son article 3 ;Vu le décret n o 2007-1280 du 28 août 2007 relatif à la consistance des ouvrages de branchement etd’extension des raccordements aux réseaux publics d’électricité, notamment son article 2 ;Vu le décret n o 2008-386 du 23 avril 2008 relatif aux precriptions techniques générales de conception et defonctionnement pour le raccordement d’installations de production aux réseaux publics d’électricité ;Vu l’avis du comité technique de l’électricité en date du 25 septembre 2007 ;Vu l’avis du Conseil supérieur de l’énergie en date du 27 novembre 2007 ;Vu l’avis de la Commission de régulation de l’énergie en date du 28 février 2008,Arrête :Art. 1 er .−Le présent arrêté fixe les dispositions constructives et organisationnelles que doivent respecter lesinstallations de production d’énergie électrique pour leur raccordement au réseau public de distributiond’électricité dans les domaines de tension BT et HTA, à l’exclusion du domaine de tension HTB. Cesdispositions s’appliquent aux installations de production qui livrent en permanence, ou par intermittence, toutou partie de leur production à un réseau public de distribution d’électricité, ou qui sont couplées à ce réseau enétant susceptibles de lui livrer de l’énergie.Pour l’application des dispositions du présent arrêté, « P max » désigne la puissance installée définie àl’article 1 er du décret du 7 septembre 2000 susvisé. Par convention, la puissance P max est la puissance activepour les installations de production raccordées en HTA et la puissance apparente pour les installations deproduction raccordées en BT.Art. 2. − I.–1 o Les prescriptions du présent arrêté s’appliquent aux installations de production devant fairel’objet d’un premier raccordement ainsi qu’aux installations de production existantes subissant une modificationsubstantielle dans les conditions définies ci-après.Constituent, notamment, une modification substantielle de l’installation :– toute modification qui a pour effet de majorer de 10 % ou plus, la puissance P max, à elle seule ou ens’ajoutant à de précédentes augmentations de puissance intervenues depuis le raccordement initial ;– les investissements de rénovation mentionnés à l’article 9 ter du décret du 10 mai 2001 susvisé ;2 o Les prescriptions de l’arrêté s’appliquent à l’ensemble de l’installation de production modifiée lorsque :a) La modification substantielle a pour but ou conséquence de majorer de 50 % ou plus, la puissance P max, àelle seule ou en s’ajoutant à de précédentes augmentations de puissance intervenues depuis le raccordementinitial ;b) La modification substantielle consiste en les investissements de rénovation mentionnés au I-1 ;3 o Dans les autres cas de modification substantielle que ceux visés au I-2, les prescriptions des articles 3, 4,16 et 17 de l’arrêté sont applicables à la totalité de l’installation de production et ses autres prescriptions sontapplicables uniquement aux parties nouvelles ou modifiées de l’installation de production.

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228II. – Sans préjudice des dispositions du I, les prescriptions fixées au chapitre II du présent arrêtés’appliquent dans le cas général et celles fixées au chapitre III dans le cas particulier où l’installation deproduction est située dans une zone du territoire non interconnectée au réseau métropolitain continental.CHAPITRE I erEtude et tension de raccordementArt. 3. − Après en avoir attesté l’exactitude, le producteur communique au gestionnaire du réseau public dedistribution d’électricité les caractéristiques techniques de son installation de production qui sont nécessaires àla définition du raccordement ainsi que, à la demande du gestionnaire, les éléments justificatifs de cettecertification. Les éléments de base à fournir sont précisés dans la documentation technique de référence dugestionnaire de réseau.L’attestation précitée porte a minima sur :– l’aptitude de l’installation de production à fonctionner dans les conditions normales de tension (c’est-à-direpour une tension au point de livraison ne s’écartant pas de la tension contractuelle de plus ou de moins de5 %) et de fréquence (c’est-à-dire pour une fréquence comprise entre 49,5 Hz et 50,5 Hz) rencontrées surle réseau public de distribution d’électricité et sans limitation de durée ;– l’aptitude de l’installation de production à rester en fonctionnement lorsque la fréquence ou la tension surle réseau public de distribution d’électricité atteint des valeurs exceptionnelles et pendant des duréeslimitées ;– la conformité de l’installation de production avec les obligations réglementaires et les normes relatives à lacompatibilité électromagnétique des équipements électriques et électroniques, en vigueur.Sur la base des renseignements visés au premier alinéa et conformément aux méthodes, aux hypothèses desûreté, qui concernent notamment le schéma normal d’alimentation et la surcharge temporaire admissible suiteà une indisponibilité d’éléments du réseau public de distribution d’électricité et aux caractéristiques de cedernier, qui sont mentionnées dans sa documentation technique de référence, le gestionnaire du réseau publicde distribution d’électricité effectue une étude des conditions techniques du raccordement.Le raccordement de l’installation de production doit être compatible avec les prescriptions du présent arrêté,avec les autres obligations réglementaires auxquelles le gestionnaire du réseau public de distributiond’électricité est lui-même soumis et avec les autres engagements contractuels auxquels ce dernier a souscrit,notamment en matière de qualité de l’électricité. A cette fin, l’étude identifie les éventuelles contraintes que leraccordement de l’installation de production est susceptible de faire peser, notamment sur :– l’intensité maximale admissible dans les ouvrages du réseau public de distribution d’électricité ;– le pouvoir de coupure des disjoncteurs, la tenue thermique et la tenue aux efforts électrodynamiques desouvrages du réseau public de distribution d’électricité ainsi que, d’une façon générale, sur lefonctionnement des dispositifs de protection de ce réseau ;– le pouvoir de coupure des disjoncteurs, la tenue thermique et la tenue aux efforts électrodynamiques desouvrages du poste de livraison de l’installation de production à raccorder ;– le pouvoir de coupure des disjoncteurs, la tenue thermique et la tenue aux efforts électrodynamiques desouvrages des postes de livraison des autres utilisateurs du réseau public de distribution d’électricité déjàraccordés ;– le niveau de la tension au point de livraison de l’installation de production ;– le niveau de la tension aux points de livraison des autres utilisateurs du réseau public de distributiond’électricité déjà raccordés, y compris les postes HTA/BT ;– le fonctionnement du plan de protection du réseau public de distribution d’électricité ;– le fonctionnement de la transmission des signaux tarifaires.Sur la base de son étude, et suite à une concertation préalable, le gestionnaire du réseau public dedistribution d’électricité propose au producteur une solution de raccordement respectant les prescriptions duprésent arrêté. Cette solution peut comporter des modalités techniques de raccordement et des adaptationstechniques du réseau public de distribution d’électricité et du réseau public de transport d’électricité à effectuerpréalablement à ce raccordement. Elle peut également être subordonnée à des adaptations techniques del’installation de production à raccorder et à des conditions à respecter pour son exploitation. Dans tous les cas,cette solution précise au producteur dans la convention de raccordement les éléments qui lui sont nécessairespour adapter l’installation de production, y compris ses divers dispositifs de protection. Le réglage de cesderniers est précisé dans la convention d’exploitation.Art. 4. − I. – La tension de raccordement de référence est déterminée en fonction de la puissance P maxconformément aux limites figurant dans le tableau ci-après :DOMAINE DE TENSION PUISSANCE P max LIMITEBT monophasé. 18 kVA

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228DOMAINE DE TENSION PUISSANCE P max LIMITEBT triphasé. 250 kVAHTA. 12 MWII. − Des raccordements dérogatoires aux domaines de tension de raccordement de référence de ce tableaupeuvent être effectués sous réserve du respect des conditions fixées aux III à VI ci-après et des autresprescriptions du présent arrêté.III. − Pour une installation de production qui n’est pas située dans une zone du territoire non interconnectéeau réseau métropolitain continental, un producteur peut solliciter, à titre dérogatoire et exceptionnel, unraccordement en HTA si la puissance P maxde l’installation est comprise entre 12 MW et 17 MW. Legestionnaire du réseau public de distribution d’électricité n’est tenu d’y donner une suite favorable que dans lecas où, au vu des résultats de l’étude mentionnée à l’article 3, le raccordement s’avère possible sur un départdirect depuis le poste source au regard des prescriptions du présent arrêté.Lorsqu’un tel raccordement est effectué en HTA dans le cadre des prescriptions du présent arrêté et non enHTB conformément aux prescriptions de raccordement propres à ce dernier domaine de tension, ceraccordement est réputé s’effectuer à la tension de raccordement qualifiée d’« inférieure au domaine de tensionde raccordement de référence » au sens des dispositions de l’article 2 du décret du 28 août 2007 susvisé.IV. − Aucune installation de production ne peut être raccordée à un réseau public de distributiond’électricité en BT monophasée lorsque sa puissance P maxexcède 18 kVA.V. − Aucune installation de production ne peut être raccordée à un réseau public de distribution d’électricitéen BT lorsque sa puissance P maxexcède 250 kVA.VI. − Aucune installation de production ne peut être raccordée à un réseau public de distributiond’électricité en HTA lorsque sa puissance P maxexcède 17 MW dans le cas général ou 12 MW lorsquel’installation est située dans une zone du territoire non interconnectée au réseau métropolitain continental. Cesinstallations de production doivent être raccordées à un réseau public d’électricité disposant du domaine detension HTB dans le cadre des prescriptions propres à ce domaine de tension.CHAPITRE IIPrescriptions techniques applicables dans le cas généralSection 1Sécurité des personnes et des biensArt. 5. − I. – L’installation de production doit être mise à la terre conformément aux prescriptions duguide C 15-400 dans les conditions suivantes :Lorsqu’elle est couplée au réseau public de distribution d’électricité, l’installation de production bénéficie durégime de neutre établi par ce réseau et doit respecter les prescriptions suivantes :a) Installation de production raccordée au réseau public de distribution d’électricité BT : de manièregénérale, le neutre du réseau public de distribution d’électricité BT ne doit pas être relié à la terre dansl’installation de production. Toutefois, si le réseau le permet, la connexion du neutre du réseau public dedistribution d’électricité BT à la terre dans l’installation de production est possible, après accord dugestionnaire du réseau public de distribution d’électricité ;b) Installation de production raccordée au réseau public de distribution d’électricité HTA : aucun régime deneutre HTA ne doit être créé (même par un générateur homopolaire) dans l’installation de production.II. − Toute installation de production doit disposer par conception d’une fonction de protection permettantde la séparer automatiquement du réseau public de distribution d’électricité en cas d’apparition, sur cetteinstallation de production, de l’un ou plusieurs des défauts explicités ci-après :a) Dans le cas d’un raccordement en HTA, défaut entre phases HTA et défaut HTA à la terre, selon lesdispositions de la norme NFC 13-100 ;b) Dans le cas d’un raccordement en BT, défaut entre conducteurs, selon les dispositions des normes NFC14-100 et NFC 15-100.Art. 6. − Le raccordement de l’installation de production ne doit pas entraîner, en situation de défaut, dedépassement du courant de court-circuit au-delà de la limite que les matériels HTA ou BT du réseau public dedistribution d’électricité peuvent supporter. La vérification de cette condition est faite par le gestionnaire duréseau public de distribution d’électricité en appliquant les méthodes données dans les publications de laCommission électrotechnique internationale (CEI 60-909 et ses différentes parties) avec des temps de courtcircuitsupérieurs ou égaux à 250 ms.

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Art. 7. − I. – Toute installation de production doit disposer, par conception, d’une fonction de protection,dite « protection de découplage », permettant de séparer automatiquement l’installation de production du réseaupublic de distribution d’électricité en cas d’apparition sur ce dernier de l’un ou plusieurs simultanément desdéfauts suivants :a) Défaut HTA à la terre ;b) Défaut entre phases pour la HTA ;c) Défaut entre conducteurs pour la BT ;d) Création d’un sous-réseau séparé ;e) Tout défaut autre que les défauts susmentionnés survenant pendant le régime spécial d’exploitationinstauré lors de travaux sous tension effectués sur le réseau aérien HTA.II. − Les prescriptions techniques fonctionnelles minimales de la fonction de protection visée au I sontconformes à la documentation technique de référence du gestionnaire du réseau public de distributiond’électricité et au guide C 15-400. Elles sont communiquées au producteur par le gestionnaire précité. Cesprescriptions prennent en compte les différents régimes d’exploitation du réseau public de distributiond’électricité, y compris le régime spécial d’exploitation instauré pour les travaux sous tension effectués sur leréseau aérien HTA.III. − La fonction de protection visée au I ne doit pas interférer avec le fonctionnement normal desprotections et automatismes installés par le gestionnaire du réseau public de distribution d’électricité. En outre,les seuils des phénomènes qui la déclenchent doivent être coordonnés avec ceux du dispositif de protection dugestionnaire du réseau public de distribution d’électricité de manière à respecter l’aptitude de l’installation deproduction à poursuivre son fonctionnement en cas d’atteinte des valeurs extrêmes de fréquence et de tensiondu réseau (régime exceptionnel) qui sont précisées aux articles 11 à 14. Toutefois, le réglage des seuils dedéclenchement de la fonction de protection pourra être adapté à la demande du gestionnaire du réseau dedistribution d’électricité en cas de présence d’automatismes de réenclenchement sur le réseau public dedistribution d’électricité (réseau aérien).Art. 8. − Aucun des dispositifs de protection de l’installation de production, y compris les éventuelsdispositifs internes des divers équipements parties prenantes à cette installation, ne doit, par sa conception ouson réglage :a) Perturber le fonctionnement normal des dispositifs de protection du réseau public de distributiond’électricité mis en œuvre par le gestionnaire de celui-ci ;b) Etre activé dans des conditions moins sévères que celles qui déclenchent la fonction de protection dedécouplage visée à l’article précédent.Section 2Domaine de fonctionnement de l’installationArt. 9. − Les installations de production raccordées en basse tension ne doivent pas absorber de puissanceréactive.Art. 10. − Toute installation de production raccordée au réseau public de distribution d’électricité HTA doitpouvoir fournir ou absorber, au point de livraison, les puissances réactives minimales fixées comme ci-après :a) Lorsque la tension au point de livraison est égale à la tension contractuelle plus ou moins 5 %,l’installation de production qui délivre la puissance P max doit pouvoir également, sans limitation de durée,fournir une puissance réactive au moins égale à 0,4 × P maxou absorber une puissance réactive au moins égaleà 0,35 × P max;b) Lorsque la tension au point de livraison s’écarte de la tension contractuelle comme il est dit à l’article 13,l’installation de production doit pouvoir moduler sa production ou sa consommation de puissance réactive dansles limites d’un domaine de fonctionnement minimal défini dans la documentation technique de référence dugestionnaire du réseau public de distribution d’électricité sous la forme d’un diagramme [U, Q].Toutefois, lorsque la capacité de l’installation de production à fournir ou à absorber de la puissance réactiven’est acquise, en totalité ou pour partie, que par l’intermédiaire de l’adjonction d’équipements accessoires, soità l’intérieur du site de l’installation de production, soit, à titre exceptionnel, en complément des équipementsexistants du réseau public de distribution d’électricité, l’installation de production peut être initialementraccordée sans ces équipements accessoires, dès lors que l’étude mentionnée à l’article 3 démontre que ceux-cine sont pas immédiatement nécessaires. Cette dérogation est subordonnée à l’engagement du producteur àpourvoir ultérieurement à l’adjonction des équipements accessoires susmentionnés à la demande, assortie d’unpréavis, du gestionnaire du réseau public de distribution d’électricité. Cet engagement, les cas pouvantnécessiter sa mise en œuvre, ainsi que le préavis précité doivent figurer dans la convention de raccordement.Dans tous les cas, la puissance réactive réellement fournie ou absorbée par l’installation de production dansles limites mentionnées aux a et b et le mode de régulation sont déterminés par le gestionnaire du réseau dedistribution d’électricité conformément aux principes mentionnés dans sa documentation technique de référenceen fonction des impératifs de gestion du réseau. Les dispositions du présent alinéa sont précisées en tant que debesoin dans les conventions de raccordement et d’exploitation.

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Art. 11. − I. – Toute installation de production dont la puissance P maxest supérieure ou égale à 5 MW doitrester en fonctionnement lorsque la fréquence du réseau public de distribution d’électricité prend des valeursexceptionnelles, dans les conditions de durée et de perte maximale de puissance fixées dans le tableau ci-après :PLAGE DE FRÉQUENCEDURÉE MINIMALE DE FONCTIONNEMENTPERTE MAXIMALE DE PUISSANCE(pourcentage)Entre 49,5 Hz et 49 Hz. 5 heures 10Entre 49 Hz et 48 Hz. 3 minutes 10Entre 48 Hz et 47,5 Hz. 3 minutes 15Entre 47,5 Hz et 47 Hz. 20 secondes 20Entre 50,5 Hz et 51 Hz. 60 minutes 10Entre 51 Hz et 51,5 Hz. 15 minutes selon IIEntre 51,5 Hz et 52 Hz. 20 secondes selon IIEn outre, lorsque la fréquence excède 52 Hz, le producteur peut, de sa propre initiative, déconnecterl’installation de production du réseau public de distribution d’électricité. S’il décide de la maintenir connectée,il doit s’assurer au préalable qu’elle est capable de supporter des excursions de fréquence entre 52 Hz et 55 Hzpendant au moins soixante secondes.II. − Toute installation de production visée par les dispositions du I doit être dotée d’un système decontrôle-commande permettant de réduire sa puissance lorsque la fréquence dépasse un seuil réglable entre50,5 Hz et 52 Hz. La performance de ce contrôle-commande ainsi que le réglage du seuil précité sont convenusentre le producteur et le gestionnaire du réseau public de distribution d’électricité dans le respect desprescriptions détaillées dans la documentation technique de référence de ce gestionnaire et sont mentionnésdans les conventions de raccordement et d’exploitation.Art. 12. − Toute installation de production doit rester en fonctionnement pendant au moins vingt minutes,sans perte de puissance supérieure à 5 %, lorsque la tension (U) au point de livraison de l’installation deproduction s’écarte de la tension contractuelle (Uc) de la façon suivante :0,9 U c U 0,95 U cou1,05 U c U 1,1U c .Art. 13. − Lorsque, simultanément, la tension U s’écarte de U ccomme il est dit à l’article 12 et un régimeexceptionnel de fréquence apparaît, la durée minimale de fonctionnement de toute installation de productiondont la puissance P maxest supérieure ou égale à 5 MW, est la plus petite des valeurs de durée fixées à l’articleprécédent et dans le tableau de l’article 11. En outre, les pertes maximales de puissance admissibles secumulent.Art. 14. − Toute installation de production dont la puissance P maxest supérieure ou égale à 5 MW doitrester en fonctionnement lors de l’apparition, au point de livraison de l’installation de production, d’un creuxde tension HTA défini comme ci-dessous.Creux de tension sur réseau HTA

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Nota. – Au delà de 2 500 ms, la tension au point de livraison est réputée rejoindre au moins le niveau 0,95 U c en moinsde vingt minutes.Section 3Prescriptions diversesArt. 15. − Les obligations du producteur résultant des dispositions de l’article 3 du décret du 18 octobre 2006susvisé sont réputées satisfaites, pour ce qui concerne le raccordement de toute installation de production auréseau public de distribution d’électricité, lorsque les perturbations provoquées par celle-ci restent dans leslimites fixées ci-après.I. – Raccordement au réseau BT.Fluctuation de tension. – Le niveau de contribution de l’installation de production au papillotement longuedurée (Plt) doit être limité au point de livraison à 1.II. – Raccordement au réseau HTA.Harmoniques. – Pour toute installation de production dont la puissance P maxest supérieure ou égale à100 kW, les courants harmoniques injectés sur le réseau public de distribution d’électricité sont limités, pourchaque harmonique de rang n, à la valeur, exprimée en ampère :où U c , la valeur de la tension contractuelle, est exprimée en V, P max est exprimée en W et où la valeur de k n , enfonction du rang n de l’harmonique, est donnée dans le tableau ci-dessous :RANGS IMPAIRS k nRANGS PAIRS k n3 4 % 2 2 %5 et 7 5 % 4 1 %9 2 % 4 0,5 %11 et 13 3 % 13 2 %Déséquilibre. – La contribution au taux de déséquilibre en tension au point de livraison de toute installationde production dont la charge monophasée équivalente est supérieure à 500 kVA est inférieure ou égale à 1 %.

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Fluctuation de tension. – Le niveau de contribution de l’installation de production au papillotement doit êtrelimité au point de livraison à 0,35 en Pst et à 0,25 en Plt. Toutefois, des limites supérieures peuvent êtreadmissibles en fonction des caractéristiques locales du réseau public de distribution d’électricité dans les casspécifiés dans la documentation technique de référence du gestionnaire de ce réseau.Les prescriptions du présent II sont établies sur la base d’une puissance de court-circuit minimale deréférence de 40 MVA au point de livraison HTA. Si la puissance de court-circuit effectivement mise àdisposition par le gestionnaire du réseau public de distribution d’électricité est inférieure, les limites desperturbations de tension produites par le producteur sont multipliées par le rapport entre la puissance de courtcircuitde référence (40 MVA) et la puissance de court-circuit effectivement fournie.Art. 16. − Le couplage et le découplage des installations de production au réseau public de distributiond’électricité doivent se faire selon les modalités de la convention d’exploitation dans le respect desprescriptions du présent article.Sur le réseau HTA, les vitesses des prises en charge et des cessations de charge qui résultent de l’actionvolontaire du producteur ne doivent pas dépasser 4 MW/minute.Les à-coups de tension au point de livraison dus à l’installation de production, consécutivement par exempleaux opérations de couplage et de découplage ou à la mise sous tension de l’installation, ne doivent pas dépasser5 %. Cette limite est établie sur la base d’une puissance de court-circuit minimale de référence de 40 MVA aupoint de raccordement HTA. Si la puissance de court-circuit effectivement mise à disposition du producteur parle gestionnaire du réseau public de distribution d’électricité est inférieure à 40 MVA, la limite précitée de 5 %est multipliée par un coefficient égal au rapport entre la puissance de court-circuit de référence (40 MVA) et lapuissance de court-circuit fournie.Art. 17. − I. – Si la puissance P maxde l’installation de production n’est pas marginale en terme de gestion etde conduite du réseau public de distribution d’électricité suivant la définition donnée au II, le producteur doit,conformément aux préconisations détaillées dans la documentation technique de référence du gestionnaire de ceréseau et selon des modalités précisées dans les conventions de raccordement et d’exploitation :– relier l’installation de production au centre de conduite du gestionnaire du réseau public de distributiond’électricité dans le but d’échanger des informations et des demandes d’action d’exploitation relativesnotamment à la gestion des puissances active et réactive de l’installation de production, de ses connexionset déconnexions du réseau public de distribution d’électricité et de la valeur de la tension au point delivraison. Les informations et demandes d’action précitées sont précisées dans les conventions deraccordement et d’exploitation ;– communiquer au gestionnaire du réseau public de distribution d’électricité le programme defonctionnement de l’installation de production ; le contenu de ce programme, sa fréquence de mise à jouret le préavis avec lequel ces informations sont transmises au gestionnaire du réseau public de distributiond’électricité sont déterminés par accord entre les deux parties et sont mentionnés dans la conventiond’exploitation.II. − Il est considéré que la puissance P maxd’une installation de production n’est pas marginale si l’une aumoins des conditions ci-après est remplie :– l’installation de production est raccordée au réseau public de distribution d’électricité par un départ HTAdirect depuis le poste source et sa puissance P max atteint au moins 25 % de la puissance nominale dutransformateur HTB/HTA auquel il est prévu de relier le départ HTA précité ;– l’installation de production est raccordée au réseau public de distribution d’électricité par un départ HTAdesservant d’autres utilisateurs et sa puissance P maxatteint au moins 25 % de la puissance de la chargemoyenne de ce départ HTA, cette charge moyenne étant calculée à partir du constat effectué sur les troisannées précédant celle de la demande du raccordement de l’installation de production ;– la puissance P max est supérieure ou égale à 5 MW.CHAPITRE IIIPrescriptions techniques particulières applicables aux installations de productionsituées dans une zone du territoire non interconnectée au réseau métropolitain continentalArt. 18. − Les dispositions du présent chapitre ainsi que celles du chapitre II, à l’exception des articles 11et 13, s’appliquent au raccordement de toute installation de production située dans une zone du territoire noninterconnectée au réseau métropolitain continental.Toutefois, pour l’application des dispositions du III de l’article 7, le réglage des seuils de déclenchement dela fonction de protection doit être adapté en fonction des valeurs extrêmes de la fréquence pouvant êtrerencontrées sur le réseau public de distribution d’électricité telles qu’elles sont fixées à l’article 19. Ce réglagedoit également être adapté à la demande du gestionnaire du réseau public de distribution d’électricité en cas deprésence d’automatismes de réenclenchement sur le réseau public de distribution d’électricité (réseau aérien)ainsi qu’en cas de participation de l’installation de production à la reconstitution du réseau public dedistribution d’électricité.De même, pour l’application des dispositions des articles 14 et 17, les critères relatifs à la puissance P max quiy figurent sont à remplacer par le critère relatif à la puissance P maxmentionné au I de l’article 19.

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Art. 19. − I. – Toute installation de production dont la puissance P maxatteint au moins 1 % de la puissanceminimale transitant sur le réseau public de distribution d’électricité, cette puissance minimale correspondant àla valeur moyenne des minima constatés pendant les trois années précédant le raccordement de l’installation deproduction, doit fonctionner sans limitation de durée dans la plage de fréquence de 48 Hz à 52 Hz.II. – Toute installation de production visée par les dispositions du I doit rester en fonctionnement lorsque lafréquence du réseau public de distribution d’électricité prend des valeurs exceptionnelles, dans les conditions dedurée et de perte maximale de puissance fixées dans le tableau ci-après :PLAGE DE FRÉQUENCEDURÉE MINIMALE DE FONCTIONNEMENTPERTE MAXIMALE DE PUISSANCE(pourcentage)Entre 48 Hz et 47 Hz. 3 minutes 10Entre 47 Hz et 46 Hz. 60 secondes 15Fréquence inférieure à 46 Hz. 0,4 seconde 20Entre 52 Hz et 53 Hz. 5 secondes 20En outre, lorsque la fréquence excède 53 Hz, le producteur ne doit pas, de sa propre initiative, maintenirl’installation de production connectée au réseau public de distribution d’électricité.Art. 20. − Lorsque, simultanément, la tension U s’écarte de U ccomme il est dit à l’article 12 et un régimeexceptionnel de fréquence apparaît, la durée minimale de fonctionnement de toute installation de productionvisée par les dispositions du I de l’article 19, est la plus petite des valeurs de durée fixées à l’article 12 et dansle tableau de l’article 19. En outre, les pertes maximales de puissance admissibles se cumulent.Art. 21. − Toute installation de production visée par les dispositions du I de l’article 19, à l’exception decelles mettant en œuvre de l’énergie fatale telles les fermes éoliennes, les installations photovoltaïques, lescentrales hydrauliques « fil de l’eau », doit, par conception, disposer d’une capacité de réglage de la puissanceactive d’une amplitude correspondant au moins à 20 % de la puissance P max et être équipée d’un régulateur quiajuste la puissance fournie en fonction de l’écart entre la valeur réelle de la fréquence et sa valeur de consigne.Les performances de ce régulateur sont spécifiées dans la documentation technique de référence du gestionnairedu réseau public de distribution d’électricité et précisées dans la convention de raccordement.Toute installation de production visée par les dispositions de l’alinéa précédent doit maintenir en permanenceà la disposition du gestionnaire du réseau public de distribution d’électricité une marge de puissance active,dite « réserve primaire », en plus ou en moins, correspondant à 10 % de la puissance P max.Art. 22. − Toute installation de production visée par les dispositions du I de l’article 19 et mettant enœuvre de l’énergie fatale à caractère aléatoire telles les fermes éoliennes et les installations photovoltaïquespeut être déconnectée du réseau public de distribution d’électricité à la demande du gestionnaire de ce réseaulorsque ce dernier constate que la somme des puissances actives injectées par de telles installations atteint 30 %de la puissance active totale transitant sur le réseau. Les circonstances dans lesquelles ces déconnectionspeuvent être demandées sont précisées dans la convention de raccordement et les modalités selon lesquelleselles sont effectuées le sont dans la convention d’exploitation.Art. 23. − Pour les réseaux publics de distribution d’électricité dont la fréquence nominale est différente de50 Hz, les dispositions du présent chapitre faisant intervenir la fréquence sont adaptées en conséquence.CHAPITRE IVDispositions finales et transitoiresArt. 24. − I. – Les dispositions du présent arrêté s’appliquent à toute installation de production devant fairel’objet d’un premier raccordement à un réseau public de distribution d’électricité dès lors que le gestionnaire dece réseau n’a pas transmis au producteur, pour ce raccordement, d’offre de raccordement antérieurement au25 avril 2008. Elles s’appliquent également aux installations de production existantes subissant unemodification substantielle dès lors que le gestionnaire du réseau public de distribution d’électricité n’a pastransmis au producteur, pour cette modification, d’offre de raccordement antérieurement à cette même date.II. – Pour toute installation de production visée par les dispositions de l’article 11, lorsque l’offre deraccordement a été transmise au producteur au plus tard le 30 septembre 2009, le tableau de cet article estremplacé par le tableau ci-après :PLAGE DE FRÉQUENCEDURÉE MINIMALE DE FONCTIONNEMENTPERTE MAXIMALE DE PUISSANCE(pourcentage)Entre 49,5 Hz et 49 Hz. 5 heures 10

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228PLAGE DE FRÉQUENCEDURÉE MINIMALE DE FONCTIONNEMENTPERTE MAXIMALE DE PUISSANCE(pourcentage)Entre 49 Hz et 48,5 Hz. 3 minutes 10Entre 48,5 Hz et 48 Hz. 3 minutes 15Entre 48 Hz et 47,5 Hz. 3 minutes 20Entre 50,5 Hz et 51 Hz. 60 minutes 50Entre 51 Hz et 51,5 Hz. 15 minutes selon IIEn outre, pour ces installations, le seuil de 52 Hz mentionné dans le dernier alinéa du I de l’article 11 etdans son II est remplacé par le seuil de 51,5 Hz.III. – Pour toute installation de production visée par les dispositions de l’article 14, lorsque l’offre deraccordement a été transmise au producteur au plus tard le 30 septembre 2009, le creux de tension HTA àconsidérer est celui défini comme ci-après :Creux de tension sur réseau HTA(mesure provisoire jusqu’au 30 septembre 2009)Nota. – Au-delà de 2 500 ms, la tension au point de livraison est réputée rejoindre au moins le niveau 0,95 U c en moinsde vingt minutes.Art. 25. − Les arrêtés ci-après sont abrogés sauf en tant qu’ils concernent des demandes de raccordement etdes modifications substantielles pour lesquelles le gestionnaire du réseau public de distribution d’électricitéconcerné a transmis au pétitionnaire une offre de raccordement antérieurement au 25 avril 2008 :– l’arrêté du 17 mars 2003 relatif aux prescriptions techniques de conception et de fonctionnement pour leraccordement à un réseau public de distribution d’une installation de production d’énergie électrique ;– l’arrêté du 22 avril 2003 modifiant l’arrêté du 17 mars 2003 relatif aux prescriptions techniques deconception et de fonctionnement pour le raccordement à un réseau public de distribution d’une installationde production d’énergie électrique ;– l’arrêté du 27 octobre 2006 modifiant l’arrêté du 17 mars 2003 modifié relatif aux prescriptions techniquesde conception et de fonctionnement pour le raccordement à un réseau public de distribution d’uneinstallation de production d’énergie électrique.Art. 26. − Le directeur de la demande et des marchés énergétiques est chargé de l’exécution du présentarrêté, qui sera publié au Journal officiel de la République française.Fait à Paris, le 23 avril 2008.

. .25 avril 2008 JOURNAL OFFICIEL DE LA RÉPUBLIQUE FRANÇAISE Texte 8 sur 228Pour le ministre et par délégation :Le directeur de la demandeet des marchés énergétiques,P. ABADIE

MINISTÈRE DE L’ÉCOLOGIE, DE L’ÉNERGIE,DU DÉVELOPPEMENT DURABLE ET DE LA MERen charge des Technologies Vertes et des Négociations sur le ClimatCahier des charges de l’appel d’offres n° 332689-2010-FRportant sur des installations éoliennes terrestresde production d’électricitéen Corse, Guadeloupe, Guyane, Martinique, à La Réunion,à Saint-Barthélemy et à Saint-Martin1 Contexte et objet de l’appel d’offresLe ministre d’Etat, ministre de l’Ecologie, de l’Energie, duDéveloppement durable et de la Mer a présenté le 17 novembre 2008 leplan de développement des énergies renouvelables de la France issu duGrenelle de l’Environnement. Celui-ci vise à augmenter de 20 millionsde tonnes équivalent pétrole (Mtep) la production annuelle d’énergiesrenouvelables pour porter la part des énergies renouvelables à au moins23 % de la consommation d’énergie finale d’ici à 2020. Cet objectif aété inscrit dans la loi n°2009-967 du 3 août 2009 de programmationrelative à la mise en œuvre du Grenelle de l’environnement. L’article 56 de cette loi fixe parailleurs des orientations spécifiques particulièrement ambitieuses pour les collectivitésd’outre-mer. En effet, notamment pour les collectivités visées par le présent appel d’offres,celles-ci sont appelées à parvenir à l’autonomie énergétique, en atteignant, dès 2020, unobjectif de 50 % au minimum d’énergies renouvelables dans la consommation finale età développer les technologies de stockage de l’énergie et de gestion du réseau pour augmenterla part de la production d’énergie renouvelable intermittente afin de conforter l’autonomieénergétique.Le rapport de programmation pluriannuelle des investissements de production d’électricitépour la période 2009-2020, remis en juin 2009 au Parlement, prévoit le développement de19 000 MW d’éolien terrestre en France (métropole et DOM) à l’horizon 2020, contre environ4 500 MW raccordés au réseau à fin 2009. A fin 2009, des installations éoliennes cumulantenviron 60 MW de puissance installée étaient raccordées au réseau dans les zones noninterconnectées au territoire métropolitain. Depuis 2008, le parc éolien a très peu évolué dansces zones.Concernant les perspectives de développement de l’éolien, le rapport de programmationpluriannuelle des investissements souligne l’importance d’assurer une bonne intégration del’électricité intermittente dans les réseaux électriques. Cet enjeu revêt une grande importancepour les zones non interconnectées au territoire métropolitain, qui présentent des faiblessesparticulières étant donné la taille et les sources limitées de leur parc de production électrique.En vue de l’atteinte des objectifs fixés par l’article 56 de la loi n°2009-967 du 3 août 2009 deprogrammation relative à la mise en œuvre du Grenelle de l’environnement, ainsi que parl’arrêté du 15 décembre 2009 relatif à la programmation pluriannuelle des investissements de1/43

production d'électricité, et en application des dispositions de l’article 8 de la loi n°2000-108du 10 février 2000 relative à la modernisation et au développement du service public del’électricité, le ministre d’Etat a décidé de lancer des appels d’offres, portant sur laconstruction d’installations éoliennes terrestres équipées de dispositifs de stockage d’énergieélectrique et de prévision de production dans les régions de Corse, Guadeloupe, Guyane,Martinique, La Réunion et les collectivités de Saint-Barthélemy et Saint-Martin. Ces appelsd’offres visent à :- d’une part, relancer la dynamique du développement des installations éoliennesterrestres dans les départements et collectivités d’outre-mer et en Corse afind’atteindre les objectifs fixés dans la loi de programmation relative à la mise en œuvredu Grenelle de l’environnement ;- d’autre part, faire émerger des technologies permettant de réduire l’impact desinstallations éoliennes sur le réseau électrique, afin de rendre possible uneaugmentation significative de la part des énergies renouvelables intermittentes dans laproduction d’électricité de ces territoires, actuellement limitée à 30%.Le présent cahier des charges définit les règles applicables au premier appel d’offres qui seralancé en 2010 et qui portera sur l’installation d’une capacité maximale de 95 MW, répartie en5 tranches comme suit :- tranche 1 : dans le département de la Guadeloupe et les collectivités de Saint-Barthélemy et Saint-Martin, au plus 3 projets ne pouvant dépasser une capacitéinstallée cumulée de 20 MW ;- tranche 2 : dans le département de la Martinique, au plus 3 projets ne pouvant dépasserune capacité installée cumulée de 20 MW ;- tranche 3 : dans le département de La Réunion, au plus 3 projets ne pouvant dépasserune capacité installée cumulée de 20 MW ;- tranche 4 : dans le département de la Guyane, un projet ne pouvant dépasser unecapacité installée de 15 MW ;- tranche 5 : dans les départements de la Corse, au plus 3 projets ne pouvant dépasserune capacité installée cumulée de 20 MW.Les installations objet du présent appel d’offres, sous réserve du respect des conditions dudispositif de garantie de production telles que spécifiées à l’annexe 3 du cahier des charges,ne sont pas considérées comme mettant en oeuvre de l’énergie fatale et aléatoire au sens del’article 22 de l’arrêté du 23 avril 2008 relatif aux prescriptions techniques de conception etde fonctionnement pour le raccordement à un réseau public de distribution d'électricité enbasse tension ou en moyenne tension d'une installation de production d'énergie électrique.Les installations objet du présent appel d’offres ne respectant pas les conditions du dispositifde garantie de la production définies à l’annexe 3 du cahier des charges feront l’objet dessanctions prévues au paragraphe 6.2.Peut participer à cet appel d’offres toute personne exploitant ou désirant construire etexploiter une installation de production, sous réserve des dispositions des articles L.2224-32et L.2224-33 du code général des collectivités territoriales.En application du décret n°2002-1434 du 4 décembre 2002 modifié, la Commission derégulation de l’énergie (CRE) est chargée de la mise en oeuvre de la procédure d’appel2/43

d’offres : sur la base des conditions définies par le ministre chargé de l’énergie, elle proposeun projet de cahier des charges, que le ministre peut modifier avant de l’arrêter. Elle répondaux questions éventuelles des candidats, reçoit, instruit et note les dossiers de candidature,puis donne un avis motivé sur le choix qu’envisage d’arrêter le ministre.Il est rappelé que le fait pour un candidat d’être retenu dans le cadre du présent appel d’offresne préjuge en rien du bon aboutissement des autres procédures administratives qu’il luiappartient de conduire et, en particulier, de celles destinées à obtenir toutes les autorisationsnécessaires relatives, notamment, à la conformité technique des installations et à la protectionde l’environnement.2 Dispositions administratives2.1 Formes de l’offreUne offre doit respecter les dispositions du présent cahier des charges, conformément auxparagraphes 2, 3 et 4 et au formulaire de candidature joint en annexe 1 ; toutes lesinformations, la documentation et les pièces justificatives requises pour un projet, dont la listefigure en annexe 2, doivent être fournies au format demandé et en français. L’absence d’unepièce 1 entraîne le rejet du dossier concerné, conformément au paragraphe 2.8.Le candidat qui présente plus d’une offre doit réaliser autant de dossiers de candidature qued’offres et les adresser sous enveloppes séparées.En plus de la copie papier demandée, le candidat doit fournir, sur CD-ROM, le formulaireélectronique de candidature dûment rempli ainsi qu’une reproduction au format « pdf » de sondossier de candidature. Le formulaire électronique de candidature est à télécharger sur le siteinternet de la CRE (www.cre.fr). L’ensemble du formulaire de l’annexe 1 doit être imprimédirectement à partir de ce formulaire électronique.Le candidat est informé qu’il n’aura droit à aucune indemnité pour les frais qu’il a pu engagerpour participer au présent appel d’offres et à l’élaboration de son dossier.2.2 Exploitation du moyen de productionConformément aux dispositions de l’article 8 de la loi n°2000-108 du 10 février 2000, lecandidat, s’il est retenu, devra exploiter lui-même l’installation.2.3 Engagement de mise en service du candidatConformément à l’article 7 du décret n°2002-1434 du 4 décembre 2002, la remise d’une offrevaut engagement du candidat à mettre en service l’installation. En conséquence, le candidatn’est pas autorisé à proposer des offres sur lesquelles porte une condition d’exclusion. Le caséchéant, de telles offres seront rejetées.Conformément à ce même article, l’absence de mise en service de l’installation dans le délaiprévu pourra faire l’objet des sanctions prévues à l’article 41 de la loi du 10 février 2000.1 Une pièce envoyée après la date limite d’envoi ou non conforme aux spécifications du cahier des charges estconsidérée comme absente du dossier3/43

Annexe 3 : Conditions du dispositif de garantie de la production électriqueLes zones concernées par le présent appel d’offres sont des territoires insulaires pour lesquels la questionde l’intermittence de la production des installations éoliennes et de la variation de la puissance disponibleà court terme est un enjeu important pour la gestion du système électrique. Une diminution del’intermittence des moyens de production éolienne n’est possible que si le projet intègre une dimension deprévision de production, associée à des dispositifs permettant la mise en œuvre de services système(régulation de fréquence, tenue de la tension, etc.), par exemple grâce à un stockage de l’énergie produite.Chaque installation éolienne devra intégrer un dispositif de garantie d’injection de l’électricité produite.Ce dispositif devra respecter les exigences énoncées ci-après. Son dimensionnement devra être optimiséde sorte à minimiser les coûts de production.Le respect de ces exigences permettra aux projets de s’affranchir des dispositions applicables auxinstallations mettant en œuvre de l’énergie fatale à caractère aléatoire prévues par l’article 22 de l’arrêtédu 23 avril 2008 relatif aux prescriptions techniques de conception et de fonctionnement pour leraccordement à un réseau public de distribution d’électricité en basse tension ou en moyenne tensiond’une installation de production d’énergie électrique.a. Prévisions de productionPour diminuer l’intermittence des moyens de production éolienne, le candidat proposant l’installationéolienne doit mettre en place un système de prévision de la production éolienne basée sur les données devent disponibles dans la zone concernée.Le producteur doit fournir au gestionnaire du système électrique, 3 jours à l’avance (J-3), avec correctionà J-1 un gabarit de puissance qu’il prévoit d’injecter sur le réseau sur une durée de 24 heures, avec despériodes stables d’au moins 30 minutes. La prévision devra être donnée pour chacune des tranches d’aumoins 30 minutes de la période couverte par la prévision.Une prédiction à 3 heures, en complément de celle à J-1 (par pas de 30 mn) pourra être proposée pouraffiner la dynamique de prédiction.La variation de la puissance réalisée par rapport au gabarit à J-1 doit rester inférieure à plus ou moins25 % de la puissance maximale de l’installation pendant la première année d’exploitation de l’installationéolienne, 20 % pendant la deuxième année d’opération, puis 15 % pendant toutes les années suivantes.L’écart par rapport au gabarit prévisionnel peut être géré par un moyen de stockage dimensionné enconséquence ou par une limitation de la puissance produite.b. Variation de la puissanceLe système de prévision de production défini au (a) doit permettre la stabilité de la puissance électriquedélivrée par l’installation éolienne sur une durée égale à celle déterminée pour la prévision de production.Il n’inclut pas les phases de démarrage et d’arrêt prévus de l’installation éolienne.Lors des montées ou des baisses de la puissance produite liées au passage d’une tranche du gabarit depuissance à la suivante (passage des valeurs P1 à P2, puis P2 à P3, etc. dans le schéma ci-dessous),l’installation éolienne doit respecter les vitesses de variation de la puissance suivantes :- augmentation de la puissance : vitesse de variation correspondant à un passage de 0 à Pmax en untemps réglable entre 30 s et 5 min ;- diminution de la puissance : vitesse de variation correspondant à un passage de Pmax à 0 en untemps réglable entre 1 min et 10 min.26/43

En fonction du retour d’expérience, le gestionnaire du système électrique pourra être amené à demanderau producteur de faire évoluer ces réglages, à l’intérieur des plages mentionnées ci-dessus.P_éolP1P2P3TTTtc. Tenue en fréquence et en tensionLes conditions de tenue en tension et en fréquence que doit respecter l’installation sont définies auchapitre III de l’arrêté du 23 avril 2008 relatif aux prescriptions techniques de conception et defonctionnement pour le raccordement à un réseau public de distribution d’électricité en basse tension ouen moyenne tension d’une installation de production d’énergie électrique ou, le cas échéant, au chapitre IIIde l’arrêté du 4 juillet 2003 relatif aux prescriptions techniques de conception et de fonctionnement pourle raccordement au réseau public de transport d'une installation de production d'énergie électrique, et dansla documentation technique de référence (dite « référentiel technique ») du gestionnaire du systèmeélectrique concerné.Les conditions (i) et (ii) suivantes sont liées et doivent être appréhendées conjointement.i. Réserve primaire de puissanceEtant donné le caractère insulaire des systèmes électriques des territoires concernés par le présent appeld’offres, ceux-ci peuvent se montrer plus fragiles que les réseaux métropolitains interconnectés. Lesinstallations éoliennes doivent contribuer à la stabilité du système électrique afin d’éviter des coupuresd’électricité générales.La chute de fréquence du réseau au-delà de la bande morte des régulations des groupes de productionclassiques (cf. graphe ci-après) est un événement révélateur du besoin en puissance active du systèmeélectrique pour éviter des coupures par délestage fréquencemétrique.Ainsi le fonctionnement avec une réserve primaire effectivement disponible égale à 10 % de la puissancede raccordement de l’installation éolienne doit être assuré. La durée pendant laquelle cette réserveprimaire peut être délivrée au réseau doit être d’au moins 15 min. Cette règle s’applique comme suit :- lorsque l’installation éolienne produit entre 0 % et 90 % inclus de sa puissance de raccordement,elle doit fonctionner avec une réserve primaire de 10 % ;- lorsque l’installation éolienne produit plus de 90 % de sa puissance de raccordement, elle doitfonctionner avec une réserve primaire égale à la différence entre la puissance de raccordement etla puissance réalisée, comprise entre 10 % (exclus) à 0 % (inclus). Une réserve primaire de 0 %correspond au fonctionnement à la puissance de raccordement.27/43

ii. Conditions d’appel de la puissance de réserveEtant donné les exigences du paragraphe (i) ci-dessus, un fonctionnement en régulation primaire defréquence doit être prévu.PmaxPEn bleu, caractéristique sans bande morteEn rouge, caractéristique avec bande mortePc = puissance de consigne (puissance à 50 Hz)PcF (Hz)La puissance instantanée (puissance de fonctionnement à 50 Hz en régime stable) doit correspondre à lapuissance prévue dans le programme prévisionnel transmis à J-1 au gestionnaire du système électrique.Le statisme du dispositif de régulation de fréquence (asservissement de la puissance fournie au réseau à lavaleur de la fréquence) doit pouvoir être réglé entre 5 et 10 %. La valeur à mettre en œuvre à un instantdonné, fonction du système insulaire considéré, est précisée par le gestionnaire du système électriqueconcerné.La bande morte du dispositif de régulation de la fréquence ne doit pas être supérieure à 0,4 Hz, centrée surla valeur de 50 Hz.Lorsqu’elle est sollicitée, la réserve primaire doit être dégagée dans un intervalle de temps inférieur à0,5 s.iii. Régulation de la tension49,80 50,20L’installation éolienne doit participer à la tenue de la tension au point de raccordement. A cette fin, elledevra être équipée d’un dispositif asservissant la valeur de la puissance réactive à la valeur de la tensionmesurée au point de livraison, selon le principe indiqué dans le schéma ci-dessous.28/43

GRID CONNECTION CODE FOR RENEWABLE POWERPLANTS (RPPs) CONNECTED TO THE ELECTRICITYTRANSMISSION SYSTEM (TS) OR THE DISTRIBUTIONSYSTEM (DS) IN SOUTH AFRICAVersion 2.6November 2012

This document is approved by the National Energy Regulatorof South Africa (NERSA)Issued by:RSA Grid Code SecretariatContact: Mr. B. Magoro or Mr. T. KhozaEskom Transmission DivisionP.O Box 103, Germiston 1400Tell: +27 (0)11 871 2774 / 2368Fax: +27 (0)86 663 8418Email: magorotb@eskom.co.za orthemba.khoza@eskom.co.zaPage 2Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

1. Grid Connection Code Basis1.1 Legislation(1) The legal basis for this grid connection code is specified in terms of the ElectricityRegulation Act (Act 4 of 2006), as amended.1.2 Handling of Non-compliances and Deviations(1) Amendments, derogations or exemptions shall be processed as specified in the RSAGrid Code, as amended.2. Objectives(1) The primary objective of this grid connection code is to specify minimum technical anddesign grid connection requirements for Renewable Power Plants (RPPs) connected to orseeking connection to the South African electricity transmission system (TS) or distributionsystem (DS).(2) This document shall be used together with other applicable requirements of the code (i.e.the Grid Code, the Distribution Code and the Scheduling and Dispatch Rules), as compliancecriteria for RPPs connected to the TS and the DS.3. Scope(1) The grid connection requirements in this code shall apply to all RPPs connected orseeking connection to the TS or DS, the SO, as well as to the respective electrical NetworkService Providers (NSPs).(2) This grid connection code shall, at minimum, apply to the following RPP technologies:(a) Photovoltaic(b) Concentrated Solar Power(c) Small Hydro(d) Landfill gas(e) Biomass(f) Biogas(g) WindPage 5Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(3) All thermal and hydro units shall also comply with the design requirements specified inthe SA Grid Code (specifically section 3.1. of the Network Code). This RPP grid connectioncode shall take precedence whenever there is a conflict between this code and other codes.(4) Unless otherwise stated, the requirements in this grid connection code shall applyequally to all RPP technologies and categories.(5) The RPP shall, for duration of its generation licence issued by National Energy Regulatorof South Africa (NERSA), comply with the provisions of this grid connection code and all otherapplicable codes, rules and regulations approved by NERSA.(6) Where there has been a replacement of or a major modification to an existing RPP, theRPP shall be required to demonstrate compliance to these requirements before being allowedto operate commercially.(7) Compliance with this grid connection code shall be applicable to the RPP depending onits rated power and, where indicated, the nominal voltage at the POC. Accordingly, RPPs aregrouped into the following three categories:(a) Category A: 0 – 1 MVA (Only LV connected RPPs)This category includes RPPs with rated power of less than 1 MVA and connected to theLV voltage (typically called 'small or micro turbines'). This category shall further bedivided into 3 sub-categories:(i) Category A1: 0 - 13.8 kVAThis sub-category includes RPPs of Category A with rated power in the range of0 to 13.8 kVA.(ii) Category A2: 13.8 kVA – 100 kVAThis sub-category includes RPPs of Category A with rated power in the rangegreater than 13.8 kVA but less than 100 kVA.(iii) Category A3: 100 kVA – 1 MVAThis sub-category includes RPPs of Category A with rated power in the range100 kVA but less than 1 MVA.Note: RPPs with a rated power greater than 4.6 kVA must be balanced three-phase.(b) Category B: 1 MVA – 20 MVA and RPPs less than 1 MVA connected to the MVPage 6Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

This category includes RPPs with rated power in the range equal or greater than 1 MVAbut less 20 MVA and RPPs with rated power less than 1 MVA connected to the MV.(c) Category C: 20 MVA or higherThis category includes RPPs with rated power equal to or greater than 20 MVA.(8) The requirements of this grid connection code are organized according to above definedcategories. Unless otherwise stated, requirements in this grid connection code shall applyequally to all categories of RPPs.(9) Compliance with this and other codes requirements will depend on the interactionbetween the RPP and the grid to which it is connected. The NSP shall supply the RPPGenerator with a reasonable detail of their TS or DS that is sufficient to allow an accurateanalysis of the interaction between the RPP and the NIPS, including other generationfacilities.4. Definitions and Abbreviations(1) Unless otherwise indicated, words and terminology in this document shall have the samemeaning as those in the codes. The following definitions and abbreviations are used in thisdocument.Active Power Curtailment Set-pointThe limit set by the SO, NSP or their agent for the amount of active power that the RPP ispermitted to generate. This instruction may be issued manually or automatically via a telecontrolfacility. The manner of applying the limitation shall be agreed between the parties.Available Active PowerThe amount of active power (MW), measured at the POC, that the RPP could produce basedon plant availability as well as current renewable primary energy conditions (e.g. wind speed,solar radiation).CodeThe Distribution Code, the Transmission Grid Code or any other Code, approved by NERSA.Connection AgreementAs defined in the Code,Communication Gateway EquipmentAs defined in the Code,Page 7Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

Curtailed Active PowerThe amount of Active Power that the RPP is permitted to generate by the SO, NSP or theiragent subject to network or system constrains.Distribution System (DS)As defined in the CodeDistributorAs defined in the CodeDroopA percentage of the frequency change required for an RPP to move from no-load to ratedpower or from rated power to no-load.Extra High Voltage (EHV)The set of nominal voltage levels greater than 220 kV.Frequency controlThe control of active power with a view to stabilising frequency of the NIPS.GeneratorAs defined in the CodeHigh voltage (HV)The set of nominal voltage levels greater than 33 KV up to and including 220 kV.Low voltage (LV)Nominal voltage levels up to and including 1 kV.Medium voltage (MV)The set of nominal voltage levels greater than 1 kV up to and including 33 kV.National Energy Regulator of South Africa (NERSA)The legal entity established in terms of the National Energy Regulator Act, 2004 (Act 40 of2004), as amended.National Interconnected Power Systems (NIPS)The electrical network comprising components that have a measurable influence on eachother as they are operating as one system, this includes:Page 8Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

• the TS;• the DS;• assets connected to the TS and DS;• power stations connected to the TS and DS;• international interconnectors;• the control area for which the SO is responsible.National Transmission Company (NTC)As defined in the CodeNetwork Service Provider (NSP)As defined in the CodeNominal voltageThe voltage for which a network is defined and to which operational measurements arereferred.ParticipantsAs defined in the Code,Point of Common Coupling (PCC)As defined in the Code,Point of Connection (POC)As defined in the CodePower QualityCharacteristics of the electricity at a given point on an electrical system, evaluated against aset of reference technical parameters. These characteristics include:• voltage or current quality, i.e. regulation (magnitude), harmonic distortions, flicker,unbalance;• voltage events, i.e. voltage dips, voltage swells, voltage transients;• (supply) interruptions;• frequency of supply.Rated power (of the RPP)The highest active power measured at the POC, which the RPP is designed to continuouslysupply.Page 9Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

Rated wind speedThe average wind speed at which a wind power plant achieves its rated power. The averagerenewable speed is calculated as the average value of renewable speeds measured at hubheight over a period of 10 minutes.Renewable Power Plant (RPP)One or more unit(s) and associated equipment, with a stated rated power, which has beenconnected to the same POC and operating as a single power plant.Notes:It is therefore the entire RPP that shall be designed to achieve requirements of this code atthe POC. A RPP has only one POC.In this code, the term RPP is used as the umbrella term for a unit or a system of generatingunits producing electricity based on a primary renewable energy source (e.g. wind, sun,water, biomass etc.). A RPP can use different kinds of primary energy source. If a RPPconsists of a homogeneous type of generating units it can be named as follows:• PV Power Plant (PVPP)A single photovoltaic panel or a group of several photovoltaic panels with associatedequipment operating as a power plant.• Concentrated Solar Power Plant (CSPP)A group of aggregates to concentrate the solar radiation and convert the concentratedpower to drive a turbine or a group of several turbines with associated equipmentoperating as a power plant.• Small Hydro Power Plant (SHPP)A single hydraulic driven turbine or a group of several hydraulic driven turbines withassociated equipment operating as a power plant.• Landfill Gas Power Plant (LGPP)A single turbine or a group of several turbines driven by landfill gas with associatedequipment operating as a power plant.• Biomass Power Plant (BMPP)A single turbine or a group of several turbines driven by biomass as fuel withassociated equipment operating as a power plant.• Biogas Power Plant (BGPP)Page 10Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

A single turbine or a group of several turbines driven by biogas as fuel with associatedequipment operating as a power plant.• Wind Power Plant (WPP)A single turbine or a group of several turbines driven by wind as fuel with associatedequipment operating as a power plant. This is also referred to as a wind energy facility(WEF)Renewable Power Plant (RPP) ControllerA set of control functions that make it possible to control the RPP at the POC. The set ofcontrol functions shall forma part of the RPP.RPP GeneratorMeans a legal entity that is licensed to develop and operate a RPP.System Operator (SO)As defined in the CodeTransmission Network Service Provider (TNSP)As defined in the CodeTransmission System (TS)As defined in the CodeUnit / Generation facilityAs defined in the CodeVoltage QualitySubset of power quality referring to steady-state voltage quality, i.e. voltage regulation(magnitude), voltage harmonics, voltage flicker, voltage unbalance, voltage dips. The currentdrawn from or injected into the POC is the driving factor for voltage quality deviations.Voltage Ride Through (VRT) CapabilityCapability of the RPP to stay connected to the network and keep operating following voltagedips or surges caused by short-circuits or disturbances on any or all phases in the TS or DS.5. Tolerance of Frequency and Voltage DeviationsPage 11Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(1) The RPP shall be able to withstand frequency and voltage deviations at the POC undernormal and abnormal operating conditions described in this grid connection code whilereducing the active power as little as possible.(2) The RPP shall be able to support network frequency and voltage stability in line with therequirements of this grid connection code.(3) Normal operating conditions and abnormal operating conditions are described in section5.1 and section 5.2, respectively.5.1 Normal Operating Conditions(1) Unless otherwise stated, requirements in this section shall apply to all categories ofRPPs.(2) RPPs of Category A shall be designed to be capable of operating within the voltagerange of -15% to +10% around the nominal voltage at the POC. The actual operating voltagediffers from location to location, and this shall be decided by the NSP in consultation with theaffected customers (including the RPP generator), and implemented by the RPP generator.(3) RPPs of Category B and C shall be designed to be capable of operating within thevoltage range of ±10% around the nominal voltage at the POC. The actual operating voltagediffers from location to location, and this shall be decided by the NSP in consultation with theaffected customers (including the RPP generator), and implemented by the RPP generator.(4) The nominal frequency of the National Integrated Power System (NIPS) is 50 Hz and isnormally controlled within the limits as defined in the Grid Code. The RPP shall be designedto be capable of operating for the minimum operating range illustrated in Figures 1 (totalcumulative over the life of the RPP) and Figure 2 (during a system frequency disturbance).(5) When the frequency on the NIPS is higher than 52 Hz for longer than 4 seconds, theRPP shall be disconnected from the grid.(6) When the frequency on the NIPS is less than 47.0 Hz for longer than 200ms, the RPPmay be disconnected.(7) The RPP shall remain connected to the NIPS during rate of change of frequency ofvalues up to and including 1.5 Hz per second, provided the network frequency is still withinthe minimum operating range indicated in Figures 1 and 2.Page 12Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

SystemFrequency[Hz]5352H2Nominal[50 Hz]5150494847H1MINIMUM OPERATING RANGE FOR RPPsL1L2L3L4ContinuousOperating range(49.0 Hz to 51.0Hz)46200ms0.001 0.01 0.1 1 10 100 1000 10000Time (Minutes)Figure 1: Minimum frequency operating range for RPP (Cumulative over the life of theRPP)80min5251Frequency[Hz]5049MINIMUM OPERATING RANGE FOR RPPsContinuousoperating range(49.0 Hz to 51.0 Hz)484746200ms4 6600.1 1 10 100 1000Duration of the incident, SecondsFigure 2: Minimum frequency operating range of a RPP (during a system frequencydisturbance)5.1.1 Synchronising to the NIPS(1) RPPs of Category A shall only be allowed to connect to the NIPS, at the earliest, 60seconds after:(a) The voltage at the POC is in the range -15% to +10% around the nominal voltage,Page 13Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(b) Frequency in the NIPS is within the range of 49.0Hz and 50.2Hz, or otherwise asagreed with the SO.(2) RPPs of Category B and C shall only be allowed to connect to the NIPS, at the earliest, 3seconds after:(a) (for TS connected RPPs), the voltage at the POC is within ±5% around the nominalvoltage,(b) (for DS connected RPPs), the voltage at the POC is within ±10% around thenominal voltage,(c) frequency in the NIPS is within the range of 49.0Hz and 50.2Hz, or otherwise asagreed with the SO.5.2 Abnormal Operating Conditions(1) The RPP shall be designed to withstand sudden phase jumps of up to 40° at the POCwithout disconnecting or reducing its output. The RPP shall after a settling period resumenormal production not later than 5 sec after the operating conditions in the POC have revertedto the normal operating conditions.5.2.1 Tolerance to sudden voltage drops and peaks(a) RPPs of Category A1 and A2(1) RPPs of Categories A1 and A2 shall be designed to withstand and fulfil, at the POC,voltage ride through conditions illustrated in Figure 3 below.Page 14Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

Figure 3: Voltage Ride Through Capability for the RPPs of Category A1 and A2(2) In addition, the maximum disconnection times for RPPs of Category A1 and A2 is givenin Table 1 below.Table 1: Maximum disconnection times for RPPs of Categories A1 and A2.Voltage range(at the POC)V < 50 %Maximum trip time[Seconds]0,2 s50 % ≤ V < 85 % 2 s85 % ≤ V ≤ 110 % Continuous operation110 % < V < 120 % 2 s120 % ≤ V 0,16 s(b) RPPs of Categories A3, B and C(1) RPPs of Categories A3, B and C shall be designed to withstand and fulfil, at the POC,voltage conditions described in this section and illustrated in Figures 4 and 5 below.(2) The RPP shall be designed to withstand voltage drops and peaks, as illustrated in Figure4 and supply or absorb reactive current as illustrated in Figure 5 without disconnecting.(3) The RPP shall be able to withstand voltage drops to zero, measured at the POC, for aminimum period of 0.150 seconds without disconnecting, as shown in Figure 4.Page 15Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(4) The RPP shall be able to withstand voltage peaks up to 120% of the nominal voltage,measured at the POC, for a minimum period of 2 seconds without disconnecting, as shown inFigure 4.(5) Figure 4 shall apply to all types of faults (symmetrical and asymmetrical i.e. one-, two- orthree-phase faults) and the bold line shall represent the minimum voltage of all the phases.Figure 4: Voltage Ride Through Capability for the RPPs of Category A3, B and C(6) If the voltage (U) reverts to area A during a fault sequence, subsequent voltage dropsshall be regarded as a new fault condition. If several successive fault sequences occur withinarea B and evolve into area C, disconnection is allowed, see Figure 4.(7) In connection with symmetrical fault sequences in areas B and D of Figure 4, the RPPshall have the capability of controlling the reactive power, as illustrated in Figure 5. Thefollowing requirements shall be complied with:(a) Area A: The RPP shall stay connected to the network and uphold normal production.(b) Area B: The RPP shall stay connected to the network. In addition, the RPP shallprovide maximum voltage support by supplying a controlled amount of reactive current soas to ensure that the RPP helps to stabilise the voltage, see Figure 5.(c) Area C (Figure 4): Disconnecting the RPP is allowed.(d) Area D: The RPP shall stay connected to the network and provide maximum voltagesupport by absorbing a controlled amount of reactive current so as to ensure that the RPPhelps to stabilise the voltage within the design capability offered by the RPP, see Figure 5.Page 16Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(e) Area E (Figure 5): Once the voltage at the POC is below 20%, the RPP shallcontinue to supply reactive current within its technical design limitations so as to ensurethat the RPP helps to stabilise the voltage. Disconnection is only allowed after conditionsof Figure 4 have been fulfilled.(8) Control shall follow Figure 5 so that the reactive power follows the control characteristicwith a tolerance of ±20% after 100 ms.(9) The supply of reactive power has first priority in area B, while the supply of active powerhas second priority. If possible, active power shall be maintained during voltage drops, but areduction in active power within the RPP's design specifications is acceptable.Figure 5: Requirements for Reactive Power Support, I Q , during voltage drops orpeaks at the POCPage 17Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

6. Frequency Response(1) In case of frequency deviations in the NIPS, RPPs shall be designed to be capable toprovide power-frequency response in order to stabilise the grid frequency. The meteringaccuracy for the grid frequency shall be at least ±10mHz.6.1 Power-frequency response curve for RPPs of Category A(1) This subsection applies to category A RPPs.(2) During high frequency operating conditions, RPPs shall be able to provide mandatoryactive power reduction requirement in order to stabilise the frequency in accordance withFigure 6 below. The metering accuracy for the grid frequency shall be ± 10 mHz or better.(3) When the frequency on the NIPS exceeds 50.5 Hz, the RPP shall reduce the activepower as a function of the change in frequency as illustrated in Figure 6 below.(4) Once the frequency exceed 52Hz for longer than 4 seconds the RPP shall be tripped toprotect the NIPS.Figure 6: Power curtailment during over-frequency for Category A RPPs6.2 Power-frequency response curve for RPPs of Categories B & C(1) This subsection applies to RPPs of category B and C.Page 18Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(2) RPPs shall be designed to be capable to provide power-frequency response asillustrated in Figure 7.(3) Except for the mandatory high frequency response (above 50.5 Hz), the RPP shall notperform any frequency response function (i.e. there shall be no P Delta , dead-band and controlbandfunctions implement) without having entered into a specific agreement with the SO.(4) It shall be possible to set the frequency response control function for all frequency pointsshown in Figure 7. It shall be possible to set the frequencies f min , f max , as well as f 1 to f 6 to anyvalue in the range of 47 - 52 Hz with a minimum accuracy of 10 mHz.(5) The purpose of frequency points f 1 to f 4 is to form a dead band and a control band for forRPPs contracted for primary frequency response. The purpose of frequency points f 4 to f 6 isto supply mandatory critical power/frequency response.(6) The RPP shall be equipped with the frequency control droop settings as illustrated infigure 7. Each droop setting shall be adjustable between 0% and 10%. The actual droopsetting shall be as agreed with the SO.(7) The SO shall decide and advise the RPP generator (directly or through its agent) on thedroop settings required to perform control between the various frequency points.(8) If the active power from the RPP is regulated downward below the unit’s design limit P min ,shutting-down of individual RPP units is allowed.(9) The RPP (with the exception of RPPPV) shall be designed with the capability of providinga P Delta of not less than 3% of P available. P Delta is the setpoint to which the available active powerhas been reduced in order to provide frequency stabilisation (primary frequency response) inthe case of falling grid frequency.(10) It shall be possible to activate and deactivate the frequency response control function inthe interval from f min to f max .(11) If the frequency control setpoint (P Delta ) is to be changed, such change shall becommenced within two seconds and completed no later than 10 seconds after receipt of anorder to change the setpoint.(12) The accuracy of the control performed (i.e. change in active power output) and of thesetpoint shall not deviate by more than ±2% of the setpoint value or by ±0.5% of the ratedpower, depending on which yields the highest tolerance.Page 19Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

Figure 7: Frequency response requirement for RPPs of category B and C(13) The default settings for f min , f max , f 4, f 5 and f 6 shall be as shown in Table 2, unlessotherwise agreed upon between the SO and the RPP generator. Settings for f 1 , f 2 and f 3 shallbe as agreed with the SO.Table 2: Frequency Default SettingsParameter Magnitude (Hz.)f min 47f max 52f 1f 2f 3f 4 50.5f 5 52f 6 50.2As agreed with SOAs agreed with SOAs agreed with SO6.3 Procedure for setting and changing the power-frequency response curves forRPPs of Categories B & C(1) The SO or its agent shall give the RPP generator a minimum of 2 weeks if changes toany of the frequency response parameters (i.e. f 1 to f 6 ) are required. The RPP generator shallPage 20Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

confirm with the SO or its agent that requested changes have been implemented within twoweeks of receiving the SO’s request.7. Reactive Power Capabilities7.1 RPPs of Category A(1) RPPs of category A shall be designed with the capability to supply rated power (MW) forpower factors ranging between 0.95 lagging and 0.95 leading, available from 20% of ratedpower, measured at the POC.(2) The RPP shall be designed to operate according to a power factor characteristic curve,which will be determined by the NSP or the SO.(3) The default power factor setting shall be unity power factor, unless otherwise specifiedby the NSP or the SO.7.2 RPPs of Category B(1) RPPs of category B shall be designed with the capability to operate in a voltage (V),power factor or reactive power (Q or Mvar) control modes as described in section 8 below.The actual operating mode (V, power factor or Q control) as well as the operating point shallbe agreed with the NSP.(2) RPPs shall be designed to supply rated power (MW) for power factors ranging between0.975 lagging and 0.975 leading, available from 20% of rated power, measured at the POC.This is illustrated in Figure 8 below.(3) In addition the RPP shall be designed in such a way that the operating point can lieanywhere within the hatched area in Figure 8 & 9.(4) With regard to Figure 8, point A is equivalent (in MVar) to –5% rated MW output andpoint B is equivalent (in MVar) to 5% rated MW output, and point C is equivalent (in MW) to5% rated MW output.Page 21Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

+Figure 8: Reactive power requirements for RPPs of category BFigure 9: Requirements for voltage control range for RPPs of category B.7.3 RPPs of Category C(1) RPPs of category C shall be designed with the capability to operate in a voltage, powerfactor or, reactive power (Q or Mvar) control modes. The actual control operating mode(V, power factor or Q control) as well as operating point shall be agreed with the NSP.(2) The RPP shall be designed to supply rated power output (MW) for power factors rangingbetween 0.95 lagging and 0.95 leading available from 20% of rated power measured atthe POC. This is illustrated in Figure 10 below.Page 22Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(3) The RPP shall be designed in such a way that the operating point can lie anywhere withinthe hatched area in Figure 10 & 11.(4) With reference to Figure 10, point A is equivalent (in MVar) to –5% rated MW output andpoint B is equivalent (in MVar) to 5% rated MW output, and point C is equivalent (in MW)to 5% rated MW output.+Figure 10: Reactive power requirements for RPPs of category CFigure 11: Requirements for voltage control range for RPPs of category CPage 23Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

8. Reactive Power and Voltage Control Functions(1) The following requirements shall apply to RPPs of category B and C.(2) The RPP shall be equipped with reactive power control functions capable of controllingthe reactive power supplied by the RPP at the POC as well as a voltage control functioncapable of controlling the voltage at the POC via orders using setpoints and gradients.(3) The reactive power and voltage control functions are mutually exclusive, which meansthat only one of the three functions mentioned below can be activated at a time.(a) Voltage control(b) Power Factor control(c) Q control(4) The control function and applied parameter settings for reactive power and voltagecontrol functions shall be determined by the NSP in collaboration with the SO, andimplemented by the RPP generator. The agreed control functions shall be documented in theoperating agreement.8.1 Reactive power (Q) Control(1) Q control is a control function controlling the reactive power supply and absorption at thePOC independently of the active power and the voltage. This control function is illustrated inFigure 12 as a vertical line.(2) If the Q control setpoint is to be changed by the NSP, SO or their agent, the RPPgenerator shall update its echo analog set point value in response to the new value within twoseconds. The RPP shall respond to the new set point within 30 seconds after receipt of anorder to change the setpoint.(3) The accuracy of the control performed and of the setpoint shall not deviate by more than±2% of the setpoint value or by ±0.5% of maximum reactive power, depending on whichyields the highest tolerance.(4) The RPP shall be able to receive a Q setpoint with an accuracy of at least 1kVar.Page 24Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

Figure 12: Reactive power control functions for the RPP8.2 Power Factor Control(1) Power Factor Control is a control function controlling the reactive power proportionally tothe active power at the POC. This is illustrated in Figure 12 by a line with a constant gradient.(2) If the power factor setpoint is to be changed by the NSP, SO or their agent, the RPPshall update its echo analog set point value to in response to the new value within twoseconds. The RPP shall respond to the new set point within 30 seconds after receipt of anorder to change the setpoint.(3) The accuracy of the control performed and of the setpoint shall not deviate by more than±0.02.8.3 Voltage Control(1) Voltage control is a control function controlling the voltage at the POC.(2) If the voltage setpoint is to be changed, such change shall be commenced within twoseconds and completed no later than 30 seconds after receipt of an order to change thesetpoint.(3) The accuracy of the voltage setpoint shall be within ±0.5% of nominal voltage, and theaccuracy of the control performed shall not deviate by more than ±2% of the required injectionor absorption of reactive power according to droop characteristics as defined in Figure 13.Page 25Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(4) The individual RPP shall be able to perform the control within its dynamic range andvoltage limit with the droop configured as shown in Figure 13. In this context, droop is thevoltage change (p.u.) caused by a change in reactive power (p.u.).(5) When the voltage control has reached the RPP’s dynamic design limits, the controlfunction shall await possible overall control from the tap changer or other voltage controlfunctions.(6) Overall voltage coordination shall be handled by the NSP in collaboration with the SO.Figure 13: Voltage control for the RPP9. Power Quality(1) The following requirements shall apply to all categories of RPPs.(2) Power quality and voltage regulation impact shall be monitored at the POC and shallinclude an assessment of the impact on power quality from the RPP concerning the followingdisturbances at the POC:(a) voltage fluctuations:(i) rapid voltage changes(ii) flicker(b) high-frequency currents and voltages:(i) harmonicsPage 26Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(c)(d)(ii) inter-harmonics(iii) disturbances greater than 2 kHz.unbalanced currents and voltages:(i) deviation in magnitude between three phases(ii) deviation in angle separation from 120° between three phases.RPP will generally follow the supply network frequency:(i) Any attempt by the RPP to change the supply frequency may result in severedistortion of the voltage at the POC, PCC and other points in the network.(3) Power quality and voltage regulation impact shall be monitored at the POC.(4) Voltage and current quality distortion levels emitted by the RPP at the POC shall notexceed the apportioned limits as determined by the relevant NSP. The calculation of theseemission levels shall be based on international and local specifications. The allocation shallbe fair and transparent.(5) The RPP generator shall ensure that the RPP is designed, configured and implementedin such a way that the specified emission limit values are not exceeded.(6) The maximum allowable voltage change at the POC after a switching operation by theRPP (e.g. of a compensation devices) shall not be greater than 2%.(7) The RPP can assume that the network harmonic impedance at the POC will be less than3 times the base harmonic impedance for the range of reference fault levels at the POC, i.e.the network harmonic impedance shall not exceed a harmonic impedance of:Z h 3* V 2( ) = * hwhere h is the harmonic number, V is the nominal voltage in kV, and S is the fault level inMVA.10. Protection and Fault levelsS(1) Unless otherwise stated, requirements in this section apply to all categories of RPPs.(2) Protection functions shall be available to protect the RPP and to ensure a stable TS andDS.(3) The RPP generator shall ensure that a RPP is dimensioned and equipped with thenecessary protection functions so that the RPP is protected against damage due to faults andincidents in the TS and DS.Page 27Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(4) The RPP of category A shall be equipped with effective detection of islanded operation inall system configurations and capability to shut down generation of power in such conditionwithin 0.2 seconds. Islanded operation with part of the TS or DS is not permitted unlessspecifically agreed with the NSP(5) The RPP of category B and C shall be equipped with effective detection of islandedoperation in all system configurations and capability to shut down generation of power in suchcondition within 2 seconds. Islanded operation with part of the TS or DS is not permittedunless specifically agreed with the NSP.(6) The NSP or the SO may request that the set values for protection functions be changedfollowing commissioning if it is deemed to be of importance to the operation of the TS and DS.However, such change shall not result in the RPP being exposed to negative impacts fromthe TS and DS lying outside of the design requirements.(7) The NSP shall inform the RPP generator of the highest and lowest short-circuit currentthat can be expected at the POC as well as any other information about the TS and DS asmay be necessary to define the RPP's protection functions.11. Active Power Constraint Functions(1) This section shall apply to RPPs of categories A3, B & C(2) For system security reasons it may be necessary for the SO, NSP or their agent to curtailthe RPP active power output.(3) The RPP generator shall be capable of:(a) operating the RPP at a reduced level if active power has been curtailed by the SO,NSP or their agent for network or system security reasons.(b) receiving a telemetered MW Curtailment set-point sent from the SO, NSP or theiragent. If another operator is implementing power curtailment, this shall be inagreement with all the parties involved.(4) The RPP shall be equipped with constraint functions, i.e. supplementary active powercontrol functions. The constraint functions are used to avoid imbalances in the NIPS oroverloading of the TS and DS in connection with the reconfiguration of the TS and DS incritical or unstable situations or the like, as illustrated in Figure 14.Page 28Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(5) Activation of the active power constraint functions shall be agreed with the SO or NSP.The required constraint functions are as follows:(a) Absolute production constraint(b) Delta production constraint(c) Power gradient constraint(6) The required constraint functions are described in the following sections.11.1 Absolute Production Constraint(1) An Absolute Production Constraint is used to constrain the output active power from theRPP to a predefined power MW limit at the POC. This is typically used to protect the TS andDS against overloading.(2) If the setpoint for the Absolute Production Constraint is to be changed, such change shallbe commenced within two seconds and completed not later than 30 seconds after receipt ofan order to change the setpoint.(3) The accuracy of the control performed and of the setpoint shall not deviate by more than±2% of the setpoint value or by ±0.5% of the rated power, depending on which yields thehighest tolerance.11.2 Delta Production Constraint(1) A Delta Production Constraint is used to constrain the active power from the RPP to arequired constant value in proportion to the possible active power.(2) A Delta Production Constraint is typically used to establish a control reserve for controlpurposes in connection with frequency control.(3) If the setpoint for the Delta Production Constraint is to be changed, such change shall becommenced within two seconds and completed no later than 30 seconds after receipt of anorder to change the setpoint.(4) The accuracy of the control performed and of the setpoint shall not deviate by more than±2% of the setpoint value or by ±0.5% of the rated power, depending on which yields thehighest tolerance.11.3 Power Gradient Constraint(1) A Power Gradient Constraint is used to limit the maximum ramp rates by which the activepower can be changed in the event of changes in primary renewable energy supply or thePage 29Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

setpoints for the RPP. A Power Gradient Constraint is typically used for reasons of systemoperation to prevent changes in active power from impacting the stability TS or the DS.(2) If the setpoint for the Power Gradient Constraint is to be changed, such change shall becommenced within two seconds and completed no later than 30 seconds after receipt of anorder to change the setpoint.(3) The accuracy of the control performed and of the setpoint shall not deviate by more than±2% of the setpoint value or by ±0.5% of the rated power, depending on which yields thehighest tolerance.(4) The active power constraint functions are illustrated on Figure 14.Figure 14: Active power control functions for a Renewable Power Plant12. Control Function Requirements(1) RPPs shall be equipped with the control functions specified in Table 3. The purposeof the various control functions is to ensure overall control and monitoring of the RPP’sgeneration.(2) The RPP control system shall be capable of controlling the ramp rate of its activepower output with a maximum MW per minute ramp rate set by SO or NSP.(3) These ramp rate settings shall be applicable for all ranges of operation includingpositive ramp rate during start up, positive ramp rate only during normal operation andnegative ramp rate during controlled shut down. They shall not apply to frequencyregulation.Page 30Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(4) The RPP generator shall not perform any frequency response or voltage controlfunctions without having entered into a specific agreement to this effect with the NSP.(5) The specifications and regulation functions specified shall comply with theinternational standard IEC 61400-25-2Table 3: Control functions required for RPPsControl function Category A3 Category B Category CFrequency control X X XAbsolute production constraint X X XDelta production constraint - X XPower gradient constraint - X XQ control - X XPower factor control X X XVoltage control - X X13. Signals, Communications & Control(1) All signals shall be made available at the POC by the RPP generator.(2) Requirements for the exchange of signals between RPPs of category A and the NSP orSO shall be limited to a start and stop signals.(3) Requirements for the exchange of signals between RPPs of category B and C, and theNSP, SO or their agent are described in the following sections.13.1 Signals from the RPP available at the POC(1) This section shall apply to RPPs of category B and C.(2) Signals from the RPP to the SO or NSP or their agent shall be broken up into a numberof logical groups depending on functionality.(3) The following signal list groups shall apply:(a) Signals List #1 – GeneralPage 31Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

In addition, RPPs shall be required to provide certain signals from Signals Lists 2, 3, 4and 5. These lists relate to:(b) Signals List #2 - RPP Availability Estimate;(c) Signals List #3 - RPP MW Curtailment Data;(d) Signals List #4 - Frequency Response System Settings;(e) Signals List #5 - RPP Meteorological Data.13.1.1 Signals List #1 – General(1) The RPP generator shall make the following signals available at a SO or NSP designatedcommunication gateway equipment located at the RPP site:(a) Actual sent-out (MW) at the POC(b) Active Power Ramp rate of the entire RPP(c) Reactive Power Import/Export (+/-Mvar) at the POC(d) Reactive power range upper and lower limits(e) Power Factor(f) Voltage output(g) Echo MW set point(h) Echo Mvar set point(i) Echo Voltage set point13.1.2 Signals List #2 – RPP Availability Estimates(1) RPP generator shall make available the following signals at a SO or NSP designatedcommunication gateway equipment located at the RPP site:(a) Available MW and forecast MW for the next 6 hours updated hourly on the hour.(b) Available Mvar and forecast Mvar for the next 6 hours updated hourly on the hour.13.1.3 Signals List #3 – RPP MW Curtailment Data(1) The RPP generator shall make the following signals available at a designatedcommunication gateway equipment located at the RPP site:(a) RPP MW Curtailment facility status indication (ON/OFF) as a double bit point. This isa controllable point which is set on or off by the SO. When set “On” the RPP shallthen clarify and initiate the curtailment based on the curtailment set point value below.Page 32Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(b) Curtailment in progress digital feedback. This single bit point will be set high by theRPP while the facility is in the process of curtailing its output.(c) RPP MW Curtailment Set-point value (MW- feedback).(2) In the event of a curtailment, the SO will pulse the curtailment set point value down. TheRPP response to the changed curtailment value will be echoed by changing thecorresponding echo MW value. This will provide feedback that the RPP is responding to thecurtailment request.13.1.4 Signals List #4 – Frequency Response System Settings(1) The RPP generator shall make the following signals available at a SO or NSPdesignated communication gateway equipment located at the RPP site:(a) Frequency Response System mode status indication (ON/OFF) as a double bit point13.1.5 Signals List #5 – RPP Meteorological Data.(1) RPP generator shall make the following signals available at a SO or NSP designatedcommunication gateway equipment located at the RPP site:(a) Wind speed (within 75% of the hub height) – measured signal in meters/second (forWPP only)(b) Wind direction within 75% of the hub height) – measured signal in degrees from truenorth(0-359) (for WPP only)(c) Air temperature- measured signal in degrees centigrade (-20 to 50);(d) Air pressure- measured signal in millibar (800 to 1400).(e) Air density (for WPP only)(f) Solar radiation (for PVPP only)(2) The meteorological data signals shall be provided by a dedicated Meteorological Mastlocated at the RPP site or, where possible and preferable to do so, data from a means of thesame or better accuracy.(3) Energy resource conversion data for the facility (e.g. MW/ wind speed) for the variousresource inputs to enable the SO to derive a graph of the full range of the facilities outputcapabilities. An update will be sent to the SO following any changes in the output capability ofthe facility.(4) For RPP where the units are widely dispersed over a large geographical area and ratherdifferent weather patterns are expected for different sections of the RPP, the meteorologicalPage 33Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

data shall be provided from a number of individual Meteorological Masts, or where possibleand preferable to do so, data from a source of the same or better reliability for groups of units.It is expected that units within an individual group shall demonstrate a high degree ofcorrelation in Active Power output at any given time. The actual signals required shall bespecified by the SO. There shall be at least one Meteorological Mast for every 10x10 squarekm area of the facility13.2 Update Rates(1) Signals shall be updated at the following rates:(a) Analog Signals at a rate of 2 seconds.(b) Digital Signals at the rate of 1 second.(c) Meteorological data once a minute13.3 Control Signals Sent from SO to the RPPs(1) The control signals described below shall be sent from SO to the RPP. The RPP shall becapable of receiving these signals and acting accordingly.13.3.1 Active-Power Control(1) An Active-Power Control set-point signal shall be sent by SO to the RPP control system.This set-point shall define the maximum Active Power output permitted from the RPP. TheRPP control system shall be capable of receiving this signal and acting accordingly to achievethe desired change in Active Power output. See (a) in Figure 15 below(2) This value is controlled by raise or lower pulses.(3) The RPP generator shall make it possible for the SO to remotely enable/disable theActive-Power control function in the RPP control system.13.3.2 Connection Point CB Trip facility(1) A facility shall be provided by the NSP to facilitate the disconnection of the RPP. It shallbe possible for SO, NSP or their agent to send a trip signal to the circuit breaker at the HVside of the POC. This is currently implemented via the breaker shown as (b) in Figure 15below.13.4 MW Forecast(1) This section applies only to RPPs of category B and C.Page 34Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(2) The RPP generator shall have the capability to produce and submit to the SO the dayaheadand week-ahead hourly MW production forecast.(3) The forecasts shall be provided by RPP generator. These forecasts shall be provided by10:00 a.m. on a daily basis for the following 24 hours and 7 days for each 1 hour time-period,by means of an electronic interface in accordance with the reasonable requirements of SO’sdata system.13.5 RPP MW availability declaration(1) The RPP generator shall submit RPP MW availability declarations whenever changes inMW availability occur or are predicted to occur. These declarations shall be submitted bymeans of an electronic interface in accordance with the requirements of SO’s data system.13.6 Data Communications Specifications(1) The RPP shall have external communication gateway equipment that can communicatewith a minimum of three simultaneous SCADA Masters, independently from what is doneinside the RPP.(2) The location of the communication gateway equipment shall be agreed between affectedparticipants in the connection agreement.(3) The necessary communications links, communications protocol and the requirement foranalogue or digital signals shall be specified by the SO as appropriate before a connectionagreement is signed between the RPP generator and the Distributor or TNSP.(4) Active Power Curtailment or Voltage Regulation facilities at the RPP shall be tested oncea month. It is essential that facilities exist to allow the testing of the functionality withouttripping the actual equipment.(5) Where signals or indications required to be provided by the RPP generator becomeunavailable or do not comply with applicable standards due to failure of the RPP equipment orany other reason under the control of the RPP, the RPP generator shall restore or correct thesignals and/or indications within 24 hours.Page 35Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

Sierra (Wind)(b)Avail Fore120 105120 100120 90120 80120 70120 60(e)StopP Mode97 MWQ Mode30 Mvar100 30NRNR(f)(a)Curtail0 MW10NR100301355(c)Voltage401 kV400Q Mode Limits : -40 : 40 MvarWeather5.5 m/s35 °22 C875 mB(f)(d)Muldr 18010Bacch 12020Figure 15: Example of one line Human Machine Interface layout14. Testing and Compliance Monitoring(1) All RPP generators shall demonstrate compliance to all applicable requirementsspecified in this grid connection code and any other applicable code or standard approved byNERSA, as applicable, before being allowed to connect to the DS or the TS and operatecommercially.(2) The RPP generator shall review, and confirm to the SO and NERSA, compliance by theRPP with every requirements of this code.(3) The RPP generator shall conduct tests or studies to demonstrate that the RPP complieswith each of the requirements of this code.(4) The RPP generator shall continuously monitor its compliance in all material respects withall the connection conditions of this code.(5) Each RPP generator shall submit to the SO a detailed test procedure, emphasisingsystem impact, for each relevant part of this code prior to every test.Page 36Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(6) If RPP generator determines, from tests or otherwise, that the RPP is not complying withone or more sections of this code, then the RPP Generator shall (within 1 hour of beingaware):(a) notify the SO of that fact(b) advise the SO of the remedial steps it proposes to take to ensure that the relevantRPP can comply with this code and the proposed timetable for implementing thosesteps(c) diligently take such remedial action to ensure that the relevant RPP can complywith this code; the RPP generator shall regularly report in writing to the SO on itsprogress in implementing the remedial action, and(d) after taking remedial action as described above, demonstrate to the reasonablesatisfaction of the SO that the relevant RPP is then complying with this code.(7) The SO may issue an instruction requiring the RPP generator to carry out a test todemonstrate that the relevant RPP complies with the code requirements. A RPP generatormay not refuse such an instruction, provided it is issued timeously and there are reasonablegrounds for suspecting non-compliance.(8) The RPP generator shall keep records relating to the compliance of the RPP with eachsection of this grid connection code, or any other code applicable to that RPP, setting outsuch information that the SO reasonably requires for assessing power system performance,including actual RPP performance during abnormal conditions. Records shall be kept for aminimum of 5 years (unless otherwise specified in the code) commencing from the date theinformation was created.15. Reporting to NERSA(1) The RPP generator shall design the system and maintain records so that the followinginformation can be provided to the NERSA on a monthly basis in an electronic spread sheetformat:(a) Non-renewable/supplementary fuel used by the power plant as outlined underSupplementary Fuel Specification schedule of the PPA during the month.(b) Day ahead forecast output energy to the grid and hourly availability as specified in13.4 and 13.5 above.(c) Actual hourly availability and output energy to the grid that occurred and theaverage primary resource for that hour (i.e. Wind speed for wind generators andsolar radiation for solar generation)(d) Actual hourly electricity imports from all sources as applicable.(e) Direct monthly emissions per unit of electricity generated by the RPP (tCO2/kWh).Page 37Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

(f) Any curtailed energy during the month.(2) These reports are to be submitted before the 15 th of the following month toIPSreports@nersa.org.za(3) These reports should also include details of incidents relating any unavailability of thenetwork which prevented the RPP from generating and any incidents where their right to selfdispatchwas impinged upon where the PPA gives them a right to self-dispatch.16. Provision of Data and Electrical Dynamic SimulationModels(1) The SO, Distributors and TNSPs require suitable and accurate dynamic models, in thetemplate specified by the requesting party applying for a connection to the DS or TS, in orderto assess reliably the impact of the RPP proposed installation on the dynamic performanceand security and stability of the power system.(2) The required dynamic models must operate under RMS and EMT simulation to replicatethe performance of the RPP facility or individual units for analysis of the following networkaspects:(a) RPP impact on network voltage stability(b) RPP impact on QOS at POC(c) RPP switching transients impact on network performance(d) RPP impact on breakers TRV (Transient Recovery Voltage)(e) RPP impact on network insulation co-ordination requirements(f) RPP impact on network protection co-ordination(g) RPP FRT (Fault Ride Through) capability for different types of faults and positions(h) RPP response to various system phenomena such as:(i) switching on the network(ii) power swings(iii) small signal instabilities(3) RPP data exchange shall be a time-based process.(a) First stage (during the application for connection)(i)The following information shall be submitted by the RPP generator to theSO and Distributor or TNSP, as applicable:• Physical location of the RPP (including the GPS coordinates)• Site PlanPage 38Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

• Number of wind turbines or units to be connected• MW output per turbine or unit• Initial phase MW value• Final phase MW value and timelines• Any other information that the service provider may reasonably require(ii)For the detailed RPP design, the NSP shall make available to the RPPgenerator or its agent at least the following information:• Point of Connection and the Point of Common Coupling including thenominal voltages,• Expected fault levels• The network service provider’s connection between the Point ofconnection and the RPP,• The busbar layout of the PCC and POC substations,• The portion of the network service provider’s grid that will allowaccurate and sufficient studies to design the RPP to meet the GridCode. This information shall include:,o Positive and zero sequence parameters of the relevant networkservice provider’s transmission and distribution, transformers,reactors, capacitors and other relevant equipmento The connection of the various lines transformers, reactors andcapacitors etc.(b) Second stage (after detailed RPP designs have been completed but beforecommissioning the RPP).(i)During this stage, the RPP generator shall provide information on:• Selected RPP technology data.• Fault ride through capability and harmonic studies test report• Generic test model and dynamic modelling data per wind turbine orunit as from the type approval and tests result(c) Third stage (after commissioning and optimisation of the RPP)(i)During this stage, the RPP generator is compelled to provide informationon:Page 39Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

• A validated RPP electrical dynamic simulation model usingcommissioning test data and measurements• Test measurement data in the format agreed between the RPPgenerator and the Distributor, NTC or SO, as applicable.(4) The dynamic modelling data shall be provided in a format as may be agreed between theRPP generator and the Distributor, NTC or SO, as applicable.(5) In addition, the RPP Generator shall provide the SO with operational data as prescribedin Appendix 8.Page 40Grid Connection Code for RPPs in South Africa Version 2.6 – November 2012

N O R M A I T A L I A N A C E INorma ItalianaData PubblicazioneCEI 0-21 2011-12TitoloRegola tecnica di riferimento per la connessione di Utenti attivi epassivi alle reti BT delle imprese distributrici di energia elettricaTitleReference technical rules for the connection of active and passive users tothe LV electrical UtilitiesSommarioLa presente Norma CEI è stata elaborata da un Gruppo di lavoro specialistico del CEI.Essa è stata elaborata di concerto con l'Autorità per l'energia elettrica e il gas (AEEG) ed esplicita le regoletecniche di connessione alle reti di distribuzione di energia elettrica in BassaTensione (BT) su tutto ilterritorio nazionale: ciò a seguito della liberalizzazione del mercato interno per l'energia che oggi presentaun non trascurabile numero di Imprese in concessione per la distribuzione suddetta.La presente Norma fornisce le prescrizioni di riferimento per la corretta connessione degli impianti degliUtenti tenendo conto delle caratteristiche funzionali, elettriche e gestionali della maggior parte delle reti inBT italiane. Le prescrizioni tengono conto sia delle esigenze della distribuzione dell'energia elettrica e dellasicurezza funzionale delle reti, sia delle esigenze degli Utenti che dovranno essere connessi a questeultime.Tutti i Distributori, nel formulare in dettaglio ai loro Utenti le prescrizioni di connessione, attenendosi allapresente Norma, mettono in pratica un comportamento uniforme, trasparente e non discriminatorio sulterritorio nazionale.Le prescrizioni della presente Norma sono finalizzate alla connessione alle reti di distribuzione purché gliimpianti dei relativi Utenti siano conformi ad essa.La presente Norma si applica alle nuove utenze e parzialmente anche alle esistenti: le regole per questeultime sono fissate dall'AEEG.Allo scopo di acquisire esperienza sull'applicazione di alcuni paragrafi particolarmente innovativi dellapresente Norma è previsto che entrino in vigore in date scaglionate successive alla pubblicazione di essa(si veda la Prefazione Nazionale).© CEI COMITATO ELETTROTECNICO ITALIANO - Milano 2011. Riproduzione vietataTutti i diritti sono riservati. Nessuna parte del presente Documento può essere riprodotta, messa in rete o diffusacon un mezzo qualsiasi senza il consenso scritto del CEI. Concessione per utente singolo. Le Norme CEI sonorevisionate, quando necessario, con la pubblicazione sia di nuove edizioni sia di varianti. È importante pertantoche gli utenti delle stesse si accertino di essere in possesso dell’ultima edizione o variante.

NORMA TECNICA CEI 0-21:2011-121 Oggetto e scopo della NormaParte 1 – Oggetto, scopo e definizioniLa presente Norma ha lo scopo di definire i criteri tecnici per la connessione degli Utenti allereti elettriche di distribuzione con tensione nominale in corrente alternata fino a 1 kVcompreso. 1)Inoltre, per gli Utenti attivi, la presente Norma ha lo scopo di:definire l’avviamento, l’esercizio ed il distacco dell’impianto di produzione;evitare che gli impianti di produzione possano funzionare in isola su porzioni di reti BT delDistributore; definire alcune prescrizioni relative agli impianti di produzione funzionanti in servizioisolato sulla rete interna del Produttore. Le suddette prescrizioni non riguardano laconnessione dell’impianto di produzione alla rete del Distributore e pertanto non risultanorilevanti ai fini della predetta connessione.Le soluzioni tecniche indicate nel presente documento rappresentano lo stato dell’arteattualmente praticabile. Soluzioni alternative rispetto a quelle qui indicate, in grado diottenere le stesse prestazioni richieste in termini di affidabilità e di sicurezza, possono esseresottoposte al CEI ed eventualmente recepite nella presente Norma su proposta di un appositoorgano tecnico in accordo con l’Autorità per l’Energia Elettrica e il Gas (nel seguito AEEG).Gli impianti oggetto della presente Norma devono essere costruiti a regola d’arte e a tal fine èsufficiente la rispondenza alle norme del Comitato Elettrotecnico Italiano (CEI). I riferimenti atutte le norme CEI nel presente testo devono essere intesi in tal senso.Nel seguito, ove viene indicato un riferimento a una delibera dell’AEEG, tale riferimento èinteso alla data di pubblicazione della presente Norma.2 Campo di applicazioneLa presente Norma si applica a tutte le reti delle imprese distributrici di energia elettrica.La presente Norma si applica agli impianti elettrici degli Utenti dei servizi di distribuzione e diconnessione alle reti di distribuzione, nel seguito denominati Utenti della rete (Utenti). GliUtenti della rete sono i soggetti titolari di:impianti di utilizzazione (Utenti passivi) connessi alle reti BT di distribuzione dell’energiaelettrica, tra cui anche, impianti destinati all’alimentazione di veicoli elettrici (stazioni di carica batterie perveicoli elettrici); impianti destinati all’alimentazione di impianti di illuminazione pubblica (impiantiinsistenti in tutto o in parte su suolo pubblico); impianti temporanei/provvisori (forniture per cantieri, circhi, ecc.);impianti di produzione (Utenti attivi) connessi alle reti di distribuzione dell’energia elettricariguardanti installazioni fisse, mobili o trasportabili, che convertono ogni forma di energiautile in energia elettrica, collegati in parallelo alle reti BT del Distributore in modocontinuativo, di breve durata, oppure funzionanti in isola su una rete del produttore 2) ;reti di distribuzione nell’ambito della realizzazione e del mantenimento della connessionetra reti di distribuzione.1) Le prescrizioni della presente Norma si applicano sia alle connessioni monofase, sia alle connessioni trifase.2) Per impianti con potenza di generazione inferiore a 1 kW, valgono le sole prescrizioni relative agli impiantipassivi.6

NORMA TECNICA CEI 0-21:2011-12Quando a seguito dell’intervento delle protezioni SPI viene aperto il dispositivo di interfaccia odel generatore, deve essere previsto un tempo di attesa di almeno 180 s decorrentidall’istante in cui i parametri elettrici controllati dalle suddette protezioni hanno ripreso i valorinominali, prima di azionare nuovamente in chiusura il dispositivo di interfaccia o delgeneratore.8.4.1.3 Impianti di produzione indirettamente connessiIn impianti di produzione con generatori statici, il collegamento alla rete e la riconnessione, aseguito d’intervento delle protezioni di interfaccia, può avvenire esclusivamente qualora latensione sia compresa tra l’85 % e il 110 % del valore nominale e la frequenza di rete si trovientro un range prefissato (ad esempio tra 49,95 Hz e 50,05) 41) per una durata minima di300 secondi. L’impianto deve effettuare il parallelo con la rete automaticamente aumentandol’erogazione di potenza da vuoto alla massima potenza erogabile in modo graduale con ungradiente positivo massimo non superiore al 20 % al minuto della potenza massima.In caso di comandi manuali in loco (ad esempio, per motivi di manutenzione ordinaria ostraordinaria) è possibile derogare alle disposizioni di ricollegamento descritte nel presenteparagrafo relativamente all’attesa dei 300 s.8.4.2 Funzionamento di breve durata in paralleloIl funzionamento di breve durata in parallelo alla rete BT del Distributore è consentito perqualsiasi impianto di produzione, statico o rotante, anche privo del SPI, purché la durata delparallelo non ecceda, tramite relè temporizzatore, 30 s per gli impianti trifase e 10 s per quellimonofase. Trascorso tale tempo, la condizione di parallelo deve essere interrotta.Il suddetto relè deve quindi: avviarsi al momento di inizio del funzionamento breve in parallelo; separare l’impianto di produzione dalla rete alla fine del tempo di ritardo.Qualora il generatore preveda la necessità di funzionamento in parallelo alla rete superiore a30 s ma inferiore a 30 minuti (ad esempio per prove periodiche di generatori di emergenza),deve essere prevista una protezione di interfaccia che agisca sull’interruttore del generatorecon le regolazioni indicate nella Tabella 7.Protezione Soglia di intervento Tempo di interventoMassima tensione (59) 1,15 Vn Senza ritardo intenzionaleMinima tensione (27) 0,7 Vn 0,4 sMassima frequenza (81 >) 50,3 Hz Senza ritardo intenzionaleMinima frequenza (81

NORMA TECNICA CEI 0-21:2011-12Per il criterio di protezione della rete in isola, in mancanza di altre prescrizioni, si consiglianole seguenti funzioni che devono azionare il dispositivo del generatore.Protezione Soglia di intervento Tempo di interventoMassima tensione (59) 1,1 Vn Senza ritardo intenzionale – 0,1 sMinima tensione (27) 0,8 Vn 5 sMassima frequenza (81 >) 52 Hz 1 sMinima frequenza (81

NORMA TECNICA CEI 0-21:2011-12Per evitare interruzioni del servizio durante il cambio di assetto della rete, previo accordo trail Distributore e l’Utente, è ammesso il parallelo transitorio fra l’alimentazione di riserva (ades. gruppi elettrogeni) e la rete, realizzabile unicamente con un sistema automatico cheverifichi che la durata del funzionamento in parallelo delle diverse alimentazioni avvenga allecondizioni previste in 8.4.2.Nel caso in cui l’Utente sia dotato di gruppi statici di continuità per servizi non interrompibili diun certo rilievo (trifase di potenza complessiva superiore a 10 kW), si deve evitare che taliapparecchiature possano, anche transitoriamente, mantenere la rete, in tensione. Laseparazione di tali apparecchiature dalla rete deve essere garantita da un dispositivo diinterfaccia capace di assicurare il sezionamento rispetto alla rete 42) .8.4.4 Funzionamento continuativo in parallelo alla rete del distributore8.4.4.1 Requisiti costruttivi dei generatori: immissione di corrente continuaGli impianti di produzione indirettamente connessi devono prevedere un sistema per limitare,a regime, l’immissione in rete di correnti con componenti continue superiori allo 0,5 % dellacorrente nominale e superare le prove indicate in Allegato B. Il rispetto del suddetto requisitopuò essere realizzato con: un trasformatore operante alla frequenza di rete, oppure una funzione di protezione sensibile alla componente continua della corrente immessa inrete.La funzione di protezione deve intervenire sul DDG separando l’inverter dalla rete: in 200 ms se la componente continua supera 1 A; in 1 s se la componente continua supera lo 0,5 % della corrente nominale dell’inverter.8.4.4.2 Requisiti costruttivi dei generatori/impianti: immissione di potenza reattivaIl funzionamento in parallelo alla rete BT del Distributore è consentito agli impianti diproduzione, trifase e/o monofase, realizzati con una o più delle seguenti tipologie:a) macchina rotante asincrona non autoeccitata fino a 6 kW, macchina rotante sincrona finoa 6 kW, inverter in impianti di potenza complessiva fino a 3 kW, purché in grado difunzionare con fattore di potenza istantaneo compreso tra cos = 0,98 in assorbimento direattivo e cos = 0,98 in erogazione di reattivo;b) macchina rotante sincrona di potenza superiore a 6 kW, purché in grado di funzionare confattore di potenza istantaneo regolabile compreso tra cos = 0,98 in assorbimento direattivo e cos = 0,9 in erogazione di reattivo.c) macchina rotante asincrona non autoeccitata di potenza superiore a 6 kW, purché ingrado di funzionare con fattore di potenza istantaneo regolabile compreso tra cos = 0,98in assorbimento di reattivo e cos = 0,98 in erogazione di reattivo;d) inverter in impianti di potenza complessiva superiore a 3 kW e fino a 6 kW, purché ingrado di funzionare con fattore di potenza istantaneo regolabile compreso tra cos = 0,95in assorbimento di reattivo e cos = 0,95 in erogazione di reattivo;e) inverter in impianto di potenza complessiva superiore a 6 kW, purché in grado difunzionare con fattore di potenza istantaneo regolabile compreso tra cos = 0,90 inassorbimento di reattivo e cos = 0,90 in erogazione di reattivo.42) Come noto, ai fini del sezionamento, non sono ammessi dispositivi di tipo statico. La necessità di un dispositivodi interfaccia si ha allorché l’UPS (e/o CPS) sia dotato di ramo di bypass, oppure abbia lo stadio di conversionec.a/c.c in grado di rialimentare la rete a monte con batteria(e).55

NORMA TECNICA CEI 0-21:2011-12I limiti di potenza di cui sopra sono da intendersi riferiti al complesso dei generatori presentinell’impianto 43) .Per gli inverter in impianti di cui alla lettera e), il suddetto requisito è esplicitato nella Figura13 in cui sono rappresentate una capability triangolare ed una capability rettangolare.Nei punti di funzionamento compresi entro la capability triangolare (zona tratteggiata in Figura13), si assume convenzionalmente che l’impianto eroghi/assorba potenza reattiva con loscopo di limitare le sovratensioni/sottotensioni causate dalla propria immissione di potenzaattiva.Nei punti di funzionamento compresi tra la capability triangolare e quella rettangolare (zona asfondo grigio in Figura 13), si assume convenzionalmente che l’impianto eroghi/assorbapotenza reattiva con lo scopo di fornire un servizio di rete.Per gli inverter in impianti di cui alla lettera d), la capability dell’inverter deve essere in gradodi scambiare potenza reattiva secondo quanto riportato in E.2.Le suddette tipologie possono essere integrate in un unico sistema di produzione (ad es.macchina rotante collegata direttamente o tramite inverter alla rete).La normale condizione di funzionamento delle macchine prevede la sola iniezione di potenzaattiva (cos = 1); il funzionamento ad un fattore di potenza diverso da 1 può essere richiestodal Distributore qualora esigenze di esercizio della rete di distribuzione lo richiedano.Il funzionamento a fattore di potenza diverso da 1 deve essere possibile, sia con logiche eleggi di controllo locali, sia con logiche e leggi di controllo che prevedano segnali di controlloda remoto (queste ultime solo per impianti di potenza complessiva superiore a 6 kW). Lelogiche di controllo locale e le logiche di controllo da remoto sono definite nell’Allegato E.Le funzioni del sistema di comunicazione/regolazione sono descritte nell’Allegato D.cos = 0,9(assorbimento/induttivo)P/Pn [%]100cos = 0,9(erogazione/capacitivo)Capability “rettangolare”Per ogni P = Pn, |Q| = 0,4843 PnCapability “triangolare”Per ogni P = Pn, |Q| = 0,4843 P‐ 48,43 0 + 48,43 Q/Pn [%](‐Q min ) (+Q max )Figura 13 - Curve di capability “triangolare” e “rettangolare”,valide per inverter in impianti di potenza complessiva superiore a 6 kW43) I limiti di potenza indicati possono essere ottenuti anche con dispositivi aggiuntivi esterni ai generatori. Lemodalità realizzative di tale soluzione sono da concordare con il Distributore.56

NORMA TECNICA CEI 0-21:2011-128.4.4.3 Condizioni per il funzionamento in parallelo con la rete di distribuzioneIl funzionamento di un impianto di produzione in parallelo alla rete del Distributore èsubordinato a precise condizioni, tra le quali in particolare quelle di seguito elencate:il funzionamento in parallelo non deve causare perturbazioni al servizio sulla rete delDistributore, al fine di preservare il livello di qualità del servizio indicato dalla NormaCEI EN 50160; il funzionamento in parallelo deve interrompersi senza ritardo intenzionale edautomaticamente agendo sul DDI tramite il SPI: in assenza di alimentazione della rete di distribuzione; in caso di guasto al sistema di protezione di interfaccia; qualora i valori di tensione e frequenza della rete non siano compresi entro i valori diregolazione riportati nella Tabella 8 di 8.6.2.1.Si sottolinea che in particolari situazioni di carico della rete del Distributore, l’intervento delSPI e la conseguente apertura del DDI potrebbero non avvenire in caso di mancanzadell'alimentazione di rete o di guasti sulla rete. Pertanto, l’Utente attivo deve mettere in attotutti gli accorgimenti necessari alla salvaguardia dei propri impianti, in funzione dellecaratteristiche degli stessi, che devono resistere alle sollecitazioni conseguenti ad eventualirichiusure degli organi di manovra del Distributore, tipicamente richiusure rapide tripolarieffettuate da interruttori sulla rete MT, e che possano trovare i generatori in discordanza difase con la tensione di rete.8.5 Servizi di reteAllo scopo di evitare degrado nella qualità del servizio prestata della rete di distribuzione (siain Bassa sia, indirettamente, in Media tensione), nonché di consentire il sicuro esercizio dellarete di trasmissione in presenza di ingenti quantità di generazione distribuita, gli Utenti Attivicon generatori destinati a funzionare permanentemente in parallelo con la rete sono tenuti alrispetto delle seguenti prescrizioni. Tali prescrizioni risultano anche finalizzate, in prospettiva,al rispetto del disposto del DM 5 maggio 2011 (art. 11 comma 3).8.5.1 Insensibilità agli abbassamenti di tensioneLe prescrizioni di cui al presente paragrafo sono finalizzate, in prospettiva, al rispetto deldisposto del DM 5 maggio 2011 (art. 11 comma 3 lettera a); esse si applicano esclusivamenteai generatori statici.Per evitare che si verifichi l’indebita separazione dalla rete in occasione di buchi di tensione,l’impianto di produzione con potenza complessiva superiore a 6 kW deve essere in grado disoddisfare opportuni requisiti funzionali, che in letteratura internazionale sono indicati conl’acronimo LVFRT (Low Voltage Fault Ride Through). I requisiti sono rappresentatigraficamente nella Figura 14.57

NORMA TECNICA CEI 0-21:2011-12Funzionamento normale.Ripristino P/Q entro 200 msdall'istante in cui ilgeneratore rientra inquesta banda di tensioneFigura 14 - Requisiti per LVFRTIn particolare devono essere soddisfatti i seguenti requisiti funzionali:nella zona tratteggiata il generatore non deve disconnettersi dalla rete. In questa zona èconsentito interrompere temporaneamente l’erogazione della potenza attiva e reattivaerogata prima dell’insorgenza del guasto;nella zona sottostante (grigio) il generatore può scollegarsi dalla rete; entro 200 ms dal ripristino di un livello di tensione di rete compreso entro + 10 % e – 15 %della tensione nominale, il generatore deve riprendere l’erogazione della potenza attiva ereattiva immessa in rete prima della insorgenza del guasto, con una tolleranza massimadel ± 10 % della potenza nominale del generatore (qualora la tensione si ripristini marimanga nella fascia tra 85 % e 90 %, è ammessa una riduzione della potenza erogata inbase ai limiti della corrente massima erogabile dal generatore).Le verifiche di rispondenza dei convertitori statici ai requisiti di immunità agli abbassamenti ditensione si effettuano secondo le modalità riportate nell’Allegato B, sezione B.1.NOTA La figura non comprende zone di funzionamento a tensione superiore al 110 % di Un: si ricorda tuttavia chei generatori, per rispettare le prescrizioni di cui al paragrafo 8.5.2, potrebbero dover operare transitoriamente contensione fino al 115 % di Un.8.5.2 Partecipazione al controllo della tensioneLe prescrizioni di cui al presente paragrafo sono finalizzate, in prospettiva, al rispetto deldisposto del DM 5 maggio 2011 (art. 11 comma 3 lettera d). Esse si applicano secondo lemodalità e restrizioni specificate di seguito ai generatori statici e ai generatori sincronidirettamente connessi, di potenza nominale superiore a 3 kW.La presenza dei generatori lungo le linee BT è potenzialmente in grado di innalzare latensione nel punto di connessione oltre i valori consentiti dalla Norma CEI EN 50160. TaleNorma prescrive che la media del valore efficace della tensione calcolata su 10 min nonpossa superare il 110 % di Un; al momento, non sono dati limiti su intervalli temporali piùristretti.58

NORMA TECNICA CEI 0-21:2011-12Al fine di rispettare i limiti suesposti anche in presenza di molteplici unità di generazione, ènecessario che:a) per valori di tensione superiori al 115 % di U n per più di 0,2 s, le unità di GD sianodistaccate dalla rete (compito assolto dalla regolazione 59.S2 del SPI);b) quando il valore medio della tensione misurato su una finestra temporale di 10 min inmodalità a media mobile supera il 110 % di Un, le unità di GD siano distaccate dalla reteentro 3 s (compito assolto dalla regolazione 59.S1 del SPI);c) oltre alle funzioni di distacco assolte dal SPI e previa richiesta del Distributore(formalizzata nel Regolamento di Esercizio), le unità GD per valori della tensione di reteprossimi al 110 % di U n dovranno contribuire alla limitazione della tensione misurata aimorsetti di uscita tramite assorbimento di potenza reattiva (comportamento induttivo),secondo le logiche di controllo locale contenute nell’Allegato E.Le sopraccitate prescrizioni sono riferite alla tensione come misurata ai morsetti di macchina;esse consentono di realizzare una logica locale di regolazione della tensione.In presenza di un opportuno sistema di comunicazione, le unità di GD utilizzate in impianti ditaglia complessiva superiore a 6 kW, potranno essere asservite a una regolazionecentralizzata. Esse dovranno operare secondo le logiche specificate nell’Allegato E e i segnaliesterni di regolazione e controllo remoto che verranno erogati a cura del Distributore secondoquanto stabilito nell’Allegato D. In questi casi le unità di GD dovranno esser in grado diassorbire potenza reattiva (comportamento induttivo) in prossimità del 110 % di U n e erogarepotenza reattiva (comportamento capacitivo) in prossimità del 90 % di U n .Le prescrizioni di cui al punto c), nel caso di generatori sincroni direttamente connessi,devono essere attuate qualora compatibili con i limiti di tensione ammessi dalle macchine.8.5.3 Limitazione della potenza attiva generataLe prescrizioni di cui al presente paragrafo sono anche finalizzate, in prospettiva, al rispettodel disposto del DM 5 maggio 2011 (art. 11 comma 3 lettera e). La limitazione di potenzaattiva iniettata in rete può essere attuata: in maniera automatica, per valori di tensione prossimi al 110 % di U n (8.5.3.1); in maniera automatica in caso di transitori di frequenza originatisi sulla rete ditrasmissione (8.5.3.2); su comando esterno proveniente dal Distributore (8.5.3.3).8.5.3.1 Limitazione della potenza attiva per valori di tensione prossimi al 110 % di UnCon riferimento al comma c) del paragrafo 8.5.2, è cioè al fine di evitare il distacco delgeneratore dalla rete, è possibile da parte del produttore prevedere la limitazione automaticadella potenza attiva iniettata in funzione della tensione, secondo la logica e le modalità diattivazione contenute nell’Allegato F.8.5.3.2 Limitazione della potenza attiva per transitori di frequenza originatisi sullarete di trasmissioneIn presenza di transitori di frequenza sulla rete di trasmissione, è necessario che le unità GDattuino una opportuna regolazione locale della potenza attiva, secondo quanto specificatonell’Allegato F. Le presenti prescrizioni si applicano ai generatori statici.8.5.3.3 Limitazione della potenza attiva su comando esterno proveniente dalDistributoreIn presenza di un opportuno sistema di comunicazione, le unità di GD di potenza nominaleinstallata superiore a 6 kW potranno essere asservite a una logica centralizzata delDistributore di riduzione della potenza attiva, e dovranno operare secondo i segnali specificatinell’Allegato F. I segnali, trasmessi alle unità GD dal Distributore, potranno essere legati arichieste da parte del TSO.59

NORMA TECNICA CEI 0-21:2011-12Il servizio di rete sarà oggetto di regolamentazione da parte dell’AEEG.8.6 Sistemi di protezione8.6.1 Sistema di protezione generaleIl sistema di protezione generale deve essere quello indicato per gli Utenti passivi.8.6.2 Sistema di protezione di interfacciaLe prescrizioni di cui al presente paragrafo sono finalizzate, in prospettiva, al rispetto deldisposto del DM 5 maggio 2011 (art. 11 comma 3 lettera b, lettera c e lettera f).Si premette che se il sistema di protezione di interfaccia è installato sul lato BT di un’utenzaconnessa alla rete MT, si applica la Norma CEI 0-16.Il sistema di protezione di interfaccia (SPI), agendo sul DDI, realizza le finalità di cui in8.2.2.1, prevedendo le seguenti funzioni:protezione di massima/minima frequenza;protezione di massima/minima tensione;capacità di ricevere segnali su protocollo serie CEI EN 61850 44) finalizzati a presenza rete dati (per abilitazione soglie di frequenza); comando di tele scatto.Il protocollo IEC 61850 deve essere certificato di livello A da ente esterno ISO 9000 oISO 17025.Per i sistemi trifase, le protezioni: di massima/minima tensione devono avere in ingresso grandezze proporzionali alle tretensioni BT concatenate; di massima/minima frequenza devono avere in ingresso grandezze proporzionali almenoad una tensione concatenata BT.Il SPI deve essere realizzato secondo le caratteristiche riportate in A1 e A2 e verificatosecondo le modalità previste in A3; l’attivazione di qualsiasi funzione di protezione devedeterminare l’apertura del dispositivo di interfaccia DDI.Le regolazioni delle protezioni avvengono sotto la responsabilità dell’Utente secondo leindicazioni della presente Norma.Tenendo conto dei valori di regolazione e dei tempi di intervento normalmente indicati, pertutti i tipi di guasto sulla rete del Distributore, si ha generalmente l’intervento del relè difrequenza, mentre i relè di tensione assolvono una funzione prevalentemente di rincalzo.Il sistema di protezione di interfaccia deve essere realizzato tramite: un dispositivo dedicato (relè di protezione) per impianti di produzione con potenzacomplessiva superiore a 6 kW; un dispositivo integrato nell’apparato di conversione statica oppure un dispositivodedicato (relè di protezione) per impianti di produzione con potenza fino a 6 kW.Le prescrizioni per le relative prove dell’SPI devono essere conformi a quanto riportato in A4.44) La definizione dei segnali su protocollo standard serie CEI EN 61850 è allo studio, e sarà oggettodell’Allegato D. Questi segnali, trasmessi dal Distributore ed uguali per tutti gli utenti attivi, potranno essereutilizzati direttamente dalla PI oppure “convertiti” in contatti puliti purché siano rispettati i tempi di interventoindicati nella presente norma.60

NORMA TECNICA CEI 0-21:2011-12Il sistema di protezione di interfaccia deve essere verificabile durante il suo funzionamento: secondo quanto indicato in A4, per il dispositivo dedicato (relè di protezione); secondo quanto indicato in A.4.4, per il dispositivo integrato (autotest).8.6.2.1 Regolazioni del sistema di protezione di interfacciaLe regolazioni del SPI sono riportate nella seguente Tabella 8.ProtezioneSoglia diinterventoTempo di intervento(tempo intercorrente tra l’istante di iniziodella condizione anomala rilevata dallaprotezione e l’emissione del comando discatto)Massima tensione (59.S1, misura a media mobilesu 10 min,in accordo a CEI EN 61000-4-30)1,10 Vn 3 sMassima tensione (59.S2) 1,15 Vn 0,2 sMinima tensione (27.S1)** 0,85 Vn 0,4 sMinima tensione (27.S2)*** 0,4 Vn 0,2 sMassima frequenza (81>.S1)* 50,5 Hz 0,1 sMinima frequenza (81.S2) 51,5 Hz 0,1 s ÷ 5 sMinima frequenza (81S1 e 81 45) .Le regolazioni possono essere riassunte mediante uno schema logico del funzionamento delSPI, illustrato nella Figura 15. Tale schema logico contiene anche l’indicazione dei segnali diteledistacco e di presenza rete comunicazione.Le eventuali protezioni (integrate oppure esterne) del generatore statico alla rete devonoessere coordinate con le protezioni di interfaccia e quindi devono consentire il funzionamentodel generatore nei campi di tensione e frequenza impostati nella protezione di interfaccia,come specificati nel regolamento di esercizio.45) Detta disabilitazione può avere un impatto sulla qualità del servizio fornita dalla rete del Distributore poichépuò comportare una minore probabilità di successo delle procedure di richiusura automatica nonché di selezioneautomatica del tronco guasto nei casi di significativa presenza di Utenti attivi connessi alla rete.61

NORMA TECNICA CEI 0-21:2011-12Per i generatori tradizionali, le eventuali protezioni del generatore che interferiscono con icampi di regolazione della protezione di interfaccia, devono essere riportate nel regolamentodi esercizio.Lo stato logico del “segnale locale” di cui in Figura 15 è definito, prima della connessione, nelregolamento di esercizio stabilito tra il Distributore e l’Utente attivo.Teledistacco1,10 Vn0 TT = 3 sMisura V0,40 Vn0 TT = 0,2 s1,15 Vn0,85 Vn0 TT = 0,4 sORScattoDDI81.S247,5 - 51,5 Hz81.S149,5 - 50,5 HzSegnalecomunicazioneANDComando SegnalelocaleFigura 15 - Schema logico funzionale del SPI8.6.2.2 Esclusione temporanea del SPISe il sistema di protezione di interfaccia è realizzata tramite dispositivo dedicato (relèesterno), il SPI può essere escluso temporaneamente solo in una delle seguenti condizioniparticolari di esercizio: l’impianto dell’Utente attivo è "in isola" e il dispositivo generale o qualsiasi altrodispositivo posto tra la rete di distribuzione e il dispositivo di interfaccia, che impedisce(con dispositivi di interblocco elettrici e/o meccanici) il parallelo dell’impianto diproduzione con la rete di distribuzione, siano bloccati in posizione di aperto; tutti i gruppi di generazione sono disattivati fuori servizio e scollegati.L'esclusione deve essere realizzata mediante un contatto chiuso con dispositivo delgeneratore aperto, posto in parallelo al contatto di scatto delle protezioni di interfaccia. Sesono presenti più generatori e un unico dispositivo di interfaccia, i contatti discordi dovrannoessere posti in serie tra loro affinché l'esclusione di detto dispositivo avvenga solo quandotutti i generatori sono disattivati. Nel caso siano presenti più interruttori di interfaccia,l’apertura dell’interruttore di ciascun generatore deve escludere il rispettivo SPI.Si noti che per quanto previsto al punto 8.4.2 (funzionamento di breve durata in parallelo), gliinterblocchi devono essere disattivati.62

NORMA TECNICA CEI 0-21:2011-12Allegato B(normativo)Prove sugli inverter per impianti indirettamente connessiB.1 Prove sull’inverterLe prove sull’inverter devono essere eseguite presso un laboratorio accreditato EA secondola Norma ISO 17025.Il dispositivo dovrà essere dotato di marcatura CE. Inoltre, lo stesso dovrà aver superato conesito positivo le seguenti prove (tra parentesi è indicata la norma CEI di riferimento per leprove):a) limiti di emissione armonica, per la classe A (CEI EN 61000-3-2 o CEI EN 61000-3-12);esse dovranno essere ripetute in 3 sessioni (al 33 %, 66 % e 100 % della potenzanominale);b) per dispositivi con correnti di fase superiori a 75 A è possibile effettuare le prove diemissione armonica, con gli stessi criteri previsti dalla CEI EN 61000-3-12;c) limiti delle fluttuazioni di tensione e flicker (CEI EN 61000-3-3 o CEI EN 61000-3-11);esse dovranno essere ripetute in 3 sessioni (al 33 %, 66 % e 100 % della potenzanominale);d) condizioni di connessione, riconnessione ed erogazione graduale della potenza (vedi8.4.1.3), come di seguito descritto in B.1.1;e) erogazione della potenza reattiva (vedi 8.4.4.2 e 8.5.2), come descritto in B.1.2;f) limitazione della potenza attiva (vedi 8.5.3), come descritto in B.1.3;g) verifica della componente c.c. della corrente di uscita (vedi 8.4.4.2), come descritto inB.1.4;h) verifica della insensibilità agli abbassamenti di tensione di cui in 8.5.1 (LVFRT), comedescritto in B.1.5;i) verifica dell’assenza di danneggiamenti in caso di richiusura automatica da parte delDistributore (vedi 8.4.4.3 e 8.6.2.1), come di seguito descritto in B.1.6.Le prove di cui ai punti a), b), c), g) dovranno essere eseguite sul dispositivo nelle condizionidi riferimento della Tabella 14 e Tabella 15. Le restanti prove potranno essere eseguite solonelle condizioni di cui alla Tabella 14.Gli inverter devono essere conformi alla Norma CEI EN 61000-6-3 (ambiente residenziale) inquanto direttamente connessi alla rete di bassa tensione del Distributore.Grandezza di influenzaValore di riferimentoTemperatura ambiente 20 °C 2 °CPressione atmosferica96 10 kPaUmidità relativa 65 %Posizione apparecchiaturaFrequenzaSecondo quanto dichiarato del costruttore50 HzForma d’onda della tensione di riferimento Conforme alla CEI EN 50160Tabella 14 – Condizioni di riferimento85

NORMA TECNICA CEI 0-21:2011-12Grandezza di influenzaValore di riferimentoTemperatura ambiente -10 °C e +55 °CPressione atmosferica96 10 kPaUmidità relativa 65 %Posizione apparecchiaturaFrequenzaSecondo quanto dichiarato dal costruttore50 HzForma d’onda della tensione di riferimento Conforme alla CEI EN 50160Tabella 15 – Condizioni di riferimentoQualora i requisiti di cui ai punti a), b), c), g) precedenti siano rispettati in un campo ditemperatura dichiarato dal Costruttore diverso da quello indicato in Tabella 15, il Costruttoredeve impedire il funzionamento del dispositivo al di fuori del campo di funzionamentodichiarato. Questa funzionalità deve essere verificata mediante apposita prova.B.1.1 Condizioni di connessione, riconnessione ed erogazione graduale dellapotenzaB.1.1.1 Verifica delle condizioni di connessione e riconnessioneAl fine di prevenire perturbazioni alla rete, il parallelo dei generatori di qualsiasi tipo deveavvenire SOLO quando frequenza e tensione rilevate ai morsetti di uscita 60) permangonoall’interno dei seguenti limiti per un tempo minimo di 300 s: tensione compresa tra l’85 % ed il 110 % di Un; frequenza compresa tra 49,95 Hz e50,05 Hz (regolazione di default, campo di regolazione nei limiti delle protezioni 81.S2, rispettivamente).Inoltre l’erogazione di potenza per impianti di produzione indirettamente connessi deveessere graduale, con un transitorio dalle condizioni iniziali di “vuoto” in corrispondenzadell’istante di parallelo, al valore di potenza disponibile con un gradiente positivo massimonon superiore al 20 % al minuto della potenza massima.La verifica della rispondenza a questi requisiti prevede di utilizzare il circuito di Figura 21.Rete in correntealternataSorgente incorrentecontinuaInverterAnalizzatorediReteNOTA Il circuito di prova illustrato è relativo a sistemi monofase; per sistemi trifase si dovrà prevedere un circuitoequivalente di tipo trifase.Figura 21 - Circuito di prova delle condizioni di connessionea) Si effettui l’accensione dell’inverter rispettivamente con tensione c.a. inferiore all’85 % esuperiore al 110 % del valore nominale U n (mentre la frequenza deve essere compresa tra49,95 Hz e 50,05 Hz), verificando che l’unità non abiliti il parallelo con la rete - assenza dierogazione della potenza letta dall’analizzatore di rete.60) Ovvero al punto di connessione dell’impianto per i sistemi dotati di SPI esterno.86

NORMA TECNICA CEI 0-21:2011-12b) Trascorsi almeno 300 s dall’istante di inizio della prova di cui al punto a), si verifichi ilpermanere dello stato di “aperto”, ovvero assenza di erogazione di potenza in uscita. Aquesto punto si può riportare la tensione U all’interno dei limiti - 85 % U n < U < 110% U n -e al contempo disabilitare l’inverter. In queste condizioni si proceda poi al riarmo,verificando che il parallelo con la rete e l’inizio della erogazione di potenza non avvengaprima che siano trascorsi almeno 180 s dall’istante di attivazione del convertitore.c) Si ripeta la prova con tensione U - 85 % U n < U < 110 % U n - e frequenza rispettivamenteinferiore a 49,95 Hz e superiore a 50,05 Hz, verificando che l’unità non abiliti il parallelocon la rete - assenza di erogazione della potenza letta dall’analizzatore di rete.d) Trascorsi almeno 300 s dall’istante di inizio della prova di cui al punto c), si verifichi ilpermanere dello stato di “aperto”, ovvero assenza di erogazione di potenza in uscita. Aquesto punto si può riportare la frequenza f all’interno dei limiti - 49,95 Hz < f < 50,05 Hz -e al contempo disabilitare l’inverter. In queste condizioni si proceda poi al riarmo,verificando che il parallelo con la rete e l’inizio della erogazione di potenza non avvengaprima che siano trascorsi almeno 180 s dall’istante di attivazione del convertitore.La prova può essere effettuata alternativamente con un simulatore di rete in grado dimodificare i parametri di frequenza e tensione disponibili ai morsetti di uscita dell’inverter,oppure direttamente sulla rete elettrica. In questo caso per effettuare la prima fase dellaprova a), c)), è consentito regolare i parametri di frequenza e tensione che controllano lecondizioni di parallelo in modo che siano al di fuori dei valori attuali della frequenza etensione di rete. Per verificare il tempo minimo di ritardo alla connessione si riporteranno poidurante la prova i valori rispettivamente dei limiti di U ammessa e di f a quelli di default (85 %U n < U < 110 % U n ; 47,5 Hz < f < 50,05 Hz). In ogni caso la sorgente di alimentazione c.c.deve essere impostata per erogare una potenza pari alla potenza nominale c.c. dell’inverter.B.1.1.2 Verifica della erogazione graduale della potenza attivaLa verifica della erogazione graduale con rampa di salita da “vuoto” al valore nominale inalmeno 300 s si effettua registrando durante le sequenze di test b) e d) con l’analizzatore direte i parametri di uscita all’inverter con una cadenza di un campione pari al valore medioogni 200 ms (5 campioni/s). I campioni registrati a partire dall’istante in cui l’inverter inizial’erogazione di potenza, riportati su un grafico, dovranno essere tutti al di sotto della curvalimite P < 0,333 % P n /s.B.1.2 Erogazione della potenza reattivaB.1.2.1 Verifica dei requisiti costruttivi: capability erogazione della potenza reattivaCome stabilito in 8.4.4.2 i convertitori statici utilizzati in impianti di potenza complessivasuperiore a 3 kW predisposti per applicazioni in regime di funzionamento continuativo inparallelo alla rete del Distributore, devono poter funzionare con fattore di potenza diverso da1. Lo scambio di potenza reattiva con la rete può avvenire su richiesta del Distributore neiseguenti casi:qualora ci siano esigenze di gestione della rete, in particolare al fine di contribuire allalimitazione della tensione ai morsetti di uscita o sulla linea BT su cui sono eventualmentecollegate anche altre sorgenti di GD; con lo scopo di fornire un servizio di rete; requisito applicabile solo per impianti di potenzacomplessiva superiore a 6 kW ed alle condizioni che saranno oggetto di regolamentazioneda parte dell’AEEG.Le prove di cui al presente paragrafo hanno lo scopo di verificare la “capability” di erogazionedella potenza reattiva dei convertitori statici al variare della potenza attiva, affinché siagarantito il rispetto dei requisiti costruttivi minimi stabiliti in 8.4.4.2, almeno pari a:a) per tutti gli inverter in impianti di potenza complessiva superiore a 3 kW e fino a 6 kW, un fattore di potenza istantaneo compreso tra cos = 0,95 in assorbimento di reattivo(comportamento induttivo) e cos = 0,95 in erogazione di reattivo (comportamentocapacitivo);87

NORMA TECNICA CEI 0-21:2011-12b) per tutti gli inverter in impianti di potenza complessiva superiore a 6 kW, un fattore di potenza istantaneo compreso tra cos = 0,90 in assorbimento di reattivo(comportamento induttivo) e cos = 0,90 in erogazione di reattivo (comportamentocapacitivo), secondo la curva di capability “triangolare” riportata in Figura 22. In talcaso lo scambio di reattivo è finalizzato alla limitazione della sovratensione osottotensione di rete causata dalla propria immissione di potenza attiva; assorbimento o erogazione di una potenza reattiva fino al 48,43 % della potenza attivanominale, per qualsiasi valore istantaneo della potenza attiva erogata, secondo lacurva di capability “rettangolare” riportata in Figura 22, finalizzata alla fornitura di unservizio di rete richiesto dal Distributore, alle condizioni oggetto di regolamentazioneda parte dell’AEEG.Ai fini della presente prova (requisiti minimi), il costruttore dovrà indicare ed impostare laregolazione di potenza reattiva massima disponibile al variare della potenza attiva erogata,con il fine di rendere possibile una caratterizzazione delle massime capability del sistema diconversione (potendo macchine di taglia inferiore essere utilizzate anche su impianti conpotenza complessiva superiore a 6 kW).Figura 22 - Curve di capability “triangolare” e “rettangolare”, per inverter in impianti dipotenza complessiva superiore a 6 kWB.1.2.2 Modalità di esecuzione e registrazione della prova.Con riferimento al circuito di prova di Figura 21, sono date le prescrizioni seguenti. Il convertitore deve essere impostato affinché possa rispettivamente assorbire(comportamento induttivo) ed erogare (comportamento capacitivo) la massima potenzareattiva disponibile a ciascun livello della potenza attiva erogata in base alla propriacapability.Si regoli a questo punto la sorgente c.c. in modo tale che il convertitore possa erogare insequenza una potenza attiva compresa nei 10 intervalli [0-10] %; [10-20] %; ...; [90-100]% della potenza nominale (valori medi ad 1 min calcolati sulla base dei valori misurati allafrequenza fondamentale su finestra di 200 ms).88

NORMA TECNICA CEI 0-21:2011-12Per ognuno dei 10 livelli di potenza attiva si dovranno registrare almeno 3 valori dellapotenza reattiva induttiva e 3 per quella capacitiva, come valori medi ad 1 min calcolatisulla base delle misure alla frequenza fondamentale su finestra di 200 ms. In aggiunta alle misure ai valori limite di impostazione della potenza reattiva, si dovrannoregistrare i valori misurati impostando la potenza reattiva erogata a 0 (cos = 1).La capability massima in assorbimento (Qmin) ed erogazione (Qmax) di potenza reattivarisultante dalla sequenza di misure di cui sopra e quella per Q = 0 deve essere documentatain forma tabulare riportando, per ogni livello di potenza attiva erogata compreso tra 0 % e 100 %della potenza nominale, il corrispondente livello della potenza reattiva assorbita (e erogata),espresso sia in valore assoluto che in termini di cos. La prova si intende superata con esitopositivo secondo le condizioni espresse in B.1.2.2.1 o B.1.2.2.2.B.1.2.2.1 Inverter in impianti di potenza complessiva superiore a 3 kW e fino a 6 kWIl valore del fattore di potenza istantaneo risultante in ciascuno dei 10 punti di misura è pari oinferiore a 0,95 sia in modalità di assorbimento (comportamento induttivo) che di erogazione(comportamento capacitivo) della potenza reattiva.B.1.2.2.2 Inverter in impianti di potenza complessiva superiore a 6 kWIl valore della potenza reattiva assorbita (comportamento induttivo) ed erogata(comportamento capacitivo) risultante in ciascuno dei 10 punti di misura è almeno pari invalore assoluto al 48,43 % della potenza attiva nominale del convertitore.Power-Bin Potenza attiva [W] Potenza reattiva [VAr] Power Factor (cos) Potenza DC [W]0 % - 10 %10 % - 20 %20 % - 30 %30 % - 40 %40 % - 50 %50 % - 60 %60 % - 70 %70 % - 80 %80 % - 90 %90 % - 100 % (*)Tabella 16 – Assorbimento di potenza reattiva induttivaPower-Bin Potenza attiva [W] Potenza reattiva [VAr] Power Factor (cos) Potenza DC [W]0 % - 10 %10 % - 20 %20 % - 30 %30 % - 40 %40 % - 50 %50 % - 60 %60 % - 70 %70 % - 80 %80 % - 90 %90 % - 100 % (*)Tabella 17 – Erogazione di potenza reattiva capacitiva89

NORMA TECNICA CEI 0-21:2011-12Power-Bin Potenza attiva [W] Potenza reattiva [VAr] Power Factor (cos) Potenza DC [W]0 % - 10 %10 % - 20 %20 % - 30 %30 % - 40 %40 % - 50 %50 % - 60 %60 % - 70 %70 % - 80 %80 % - 90 %90 % - 100 % (*)Tabella 18 – Erogazione di potenza reattiva con set point Q = 0(*) Verificare che il requisito minimo di cos sia sostenuto stabilmente ad equilibrio termico raggiunto.Il Test Report dovrà riportare i risultati delle misure della potenza reattiva massima assorbita(Qmin) ed erogata (Qmax) dal convertitore anche in forma di grafico P(Q) in funzione dellapotenza attiva immessa in rete. Si vedano gli esempi riportati in Figura 23 (inverter in impiantifino a 6 kW) e Figura 24 (inverter per impianti di taglia superiore a 6 kW).Potenza attiva in funzione della potenza attiva nominale P/Pn [%]100908070605040‐60 ‐40 ‐20 0 20 40 60Potenza reattiva in funzione della potenza attiva nominale Q/Pn [%]Figura 23 - Esempio di Grafico P(Q). Massima potenza reattiva induttiva e capacitivaerogata in funzione della potenza attiva (qui è rappresentato il caso di un inverter dipotenza superiore a 6kW, che deve poter assorbire o erogare a qualsiasi livello dipotenza attiva una potenza reattiva pari almeno al 48,43 % della potenza attivanominale, Qmin/P n = 48,43 % P n )90

NORMA TECNICA CEI 0-21:2011-12B.1.2.3 Erogazione di potenza reattiva secondo un livello assegnatoLe unità di GD devono partecipare al controllo della tensione di rete. Per inverter utilizzati inimpianti di potenza complessiva superiore a 6 kW è prevista la possibilità di attuare unastrategia centralizzata di controllo tramite segnale di regolazione da remoto, erogato dalDistributore.Le prove oggetto di questo paragrafo sono obbligatorie solo per inverter utilizzati in impianti dipotenza superiore a 6 kW, ma su richiesta del costruttore possono essere effettuate edocumentate anche per convertitori di taglia inferiore.Scopo della prova è verificare la capacità del sistema di controllo del convertitore di eseguireil comando di regolazione del livello di potenza reattiva tra i limiti massimi di capability(capability “rettangolare”, secondo la definizione data in 8.4.4.2 e riportata in Figura 22) sia inassorbimento che in erogazione della potenza reattiva e di verificare l’accuratezza dellaregolazione.In assenza di un protocollo definito per lo scambio dei comandi di regolazione, è facoltà delcostruttore di stabilire le modalità con cui eseguire i comandi di impostazione del punto dilavoro della potenza reattiva, sia per quanto riguarda il segnale fisico (analogico, suprotocollo seriale, ecc.) che per il parametro di regolazione adottato (impostazione secondoun valore assoluto di potenza reattiva Q, oppure come valore del cos).B.1.2.3.1 Modalità di esecuzione della prova e registrazione dei risultati (ipotesi diregolazione tramite Q)Impostare la sorgente c.c. affinché l’inverter eroghi circa il 50 % della potenza attivanominale Pn.Utilizzando le modalità ed il parametro di controllo stabilito dal costruttore, variare lapotenza reattiva erogata dal convertitore passando dal valore massimo induttivo (almenopari a Qmin ≤ - 0,4843 P n ) direttamente a zero (Q = 0), per poi passare da zero al valoremassimo capacitivo (pari a Qmax ≥ + 0,4843 P n ). Mantenere ciascuno dei 3 set-point limite per un tempo di 180 s. Calcolare i valori medi ad 1 minuto della potenza reattiva sulla base dei valori misurati suuna finestra di 200 ms alla frequenza fondamentale. Il calcolo del valore su media di 1minuto deve partire dai campioni rilevati dopo 30 s dall’istante in cui si è inviato ilcomando del nuovo set-point di regolazione della potenza reattiva, questo per assicurareche il sistema abbia raggiunto lo stato stazionario.La prova si intende superata con successo se lo scostamento massimo tra il livello assegnatoed il valore attuale misurato per la potenza reattiva è pari a: ∆Q ≤ ± 2,5 % della potenza attiva nominale del convertitore (impostazione diretta dellivello di potenza reattiva) ∆cos ≤ ± 0,01 (impostazione tramite fattore di potenza)La prova dovrà essere documentata sia in forma tabellare che grafica, come riportato negliesempi di Tabella 19 e di Figura 33.Tabella 19 – Misura dell’accuratezza della regolazione della potenza reattiva in basead un comando esternoSet point Potenza reattivaQ/P n [%]-Q min - 48,430 0Potenza reattiva misurataQ/P n [%]Deviazione rispetto a setpoint∆Q/P n [%]+Q max + 48,4391

NORMA TECNICA CEI 0-21:2011-1250Potenza reattiva in funzione della potenza attiva nominaleQ/Pn [%]403020100‐10‐20‐30‐40‐50Set‐point potenza reattivaPotenza reattiva erogata dall’inverter(media 0,2s)Valori potenza reattiva media a 1min50 100 150 200 250 300 350Tempo [s]Figura 25 - Misura della potenza reattiva erogata in base ad un comando esterno,verifica di accuratezzaB.1.2.4 Tempo di risposta ad una variazione a gradino del livello assegnatoAd integrazione dei requisiti oggetto delle prove di cui al paragrafo B.1.2.3, relativi al controllodella tensione di rete tramite erogazione di potenza reattiva, è necessario non solo verificarel’accuratezza del sistema di controllo dei convertitori, ma anche il tempo di risposta deglistessi quando sia applicata una variazione a gradino del livello di potenza reattiva richiestadal comando esterno.Come per i requisiti di cui al paragrafo precedente, anche in questo caso le prove sonorichieste agli inverter utilizzati in impianti di potenza complessiva superiore a 6 kW, chedovranno poter attuare anche una strategia centralizzata di controllo tramite segnale diregolazione da remoto, emesso dal Distributore. Rimane comunque facoltà del costruttore dieffettuare volontariamente le prove anche per inverter di taglia inferiore.Lo scopo della prova è di misurare il tempo di risposta dell’inverter ad un gradino applicato alcomando di erogazione della potenza reattiva, passando da un livello ad un altro livello con lemodalità descritte di seguito ed illustrate in Figura 26. Dai risultati delle prove di capability di cui al paragrafo B.1.2.1, si rilevino i valori + Qmaxe – Qmin della potenza reattiva capacitiva e induttiva massima erogabile dal convertitorerispettivamente al 50 % ed al 100 % della potenza attiva nominale. Si riportino in un grafico analogo a quello esemplare di Figura 26 i valori misurati comemedie a 0,2 s della potenza reattiva durante l’esecuzione di comandi di regolazione dellapotenza reattiva con variazioni a gradino, quando l’inverter eroga rispettivamente unapotenza attiva pari al 50 % (Prova 1) ed il 100 % della potenza attiva nominale P n (Prova 2).92

NORMA TECNICA CEI 0-21:2011-12+QmaxSet‐point potenza reattiva0Prova 1: P = 50 % PnProva 2: P = Pn1Tr23Set‐pointPotenza reattiva erogatadall’in verter (media 0,2s)Tr = tempo di diassestamentoQ entro ± ±5 5 % Pn del delvalore assegnato‐QminTolleranza Toll. ± 5 % del ±5 % val. Pn assegn.0 2 4 6 8Tempo [min]Figura 26 - Misura del tempo di risposta a variazioni a gradino del set-point assegnatoper la potenza reattivaSi rilevi il tempo di risposta (Tr = tempo di assestamento nel grafico di Figura 26), cheequivale all’intervallo di tempo che intercorre dall’istante di applicazione del nuovo setpointall’istante in cui la potenza reattiva raggiunge un valore all’interno di un intervallocompreso entro una banda di ± 5 %del nuovo valore assegnato. Come riportato in Figura 26 il tempo di risposta deve essere rilevato in corrispondenza diuna variazione del set-point da zero a – Qmin (passo 1), da –Qmin a + Qmax (passo 2) eda + Qmax a zero (passo 3).I valori del tempo di risposta dovranno essere documentati nel test report, che dovrà ancheindicare i valori di + Qmax, - Qmin, della tensione c.a. di prova ed il metodo utilizzato perinviare il comando di controllo del set-point della potenza reattiva.La prova è superata se il tempo di risposta massimo rilevato è inferiore a 10 secondi in tuttele condizioni di misura.B.1.2.5 Erogazione automatica di potenza reattiva secondo una curva caratteristicacos = f(P)Tutti i convertitori statici in impianti di potenza complessiva superiore a 3 kW devono poterassorbire potenza reattiva in modo automatico ed autonomo (logica di controllo locale)secondo una curva caratteristica del fattore di potenza/della potenza attiva = f(P).La prova ha come scopo di verificare che il convertitore segua la modalità di erogazioneautomatica della potenza reattiva secondo la curva caratteristica standard cos = f(P)riportata in E.2, secondo il metodo a).La curva standard è definita univocamente dall’interpolazione lineare dei tre punticaratteristici:A: P = 0,2 P n ; cos = 1B: P = 0,5 P n ; cos = 1C: P = P n ; cos = cos_max93

NORMA TECNICA CEI 0-21:2011-12ove cos_max è pari rispettivamente a 0,95 (induttivo) per macchine fino a 6 kW e 0,90(induttivo) per convertitori di taglia superiore a 6 kW.La regolazione secondo la curva caratteristica viene abilitata quando la tensione rilevata aimorsetti di uscita supera il valore “critico” di lock-in (per es. impostato a V = 1,05 V n , si vedasempre il paragrafo E.2).Il valore di tensione di lock-in che abilita la modalità di erogazione automatica della potenzareattiva e che durante le prove deve essere impostato a 1,05 V n (impostazione di “default”anche per la produzione di serie), deve essere regolabile tra V n e 1,1 V n con intervalli di0,01 V n .È a cura del Distributore specificare nel regolamento di esercizio il valore richiesto per latensione di lock-in.cos0,9 (0,95*)Curva caratteristica standard1Induttivo Capacitivo0,2A0,3 0,4 0,5B0,6 0,7 0,8 0.9 1max deviazione Δcos = ± 0,01P/PnNessuna regolazione(cos = ± 0,98)0,9 (0,95*)C(*) cos_max dipende dalla potenza complessiva installata(0,95 fino a 66kW; kW, 0,90 oltre 6kW) 6 Figura 27 - Curva caratteristica standard cos = f(P)Si ricorda che il tempo di assestamento massimo al nuovo valore di potenza reattiva sullacurva caratteristica deve essere regolato automaticamente dall’inverter entro 10 s (si vedanoa questo proposito le prove sul tempo di risposta di cui in B.1.2.4).La modalità di regolazione automatica viene disabilitata quando:la potenza attiva P erogata rientra sotto il 50 % di P n (punto B), definito come lock-out inpotenza, indipendente dalla tensione ai morsetti, oppure:la tensione letta ai morsetti di uscita del convertitore scende al di sotto del limite di lockout,da impostare ad un valore di default pari a V n , ma che deve essere regolabilenell’intervallo compreso tra 0,9 V n e V n con intervalli di 0,01 V n .94

NORMA TECNICA CEI 0-21:2011-12B.1.2.5.1 Verifica di rispondenza alle modalità di applicazione della curva standarddi erogazioneIn base a quanto stabilito in E.2, con riferimento alla Figura 27, per la verifica di rispondenzaalle modalità di applicazione della curva standard di erogazione si proceda come di seguito.A. Si colleghi il convertitore come indicato nel circuito di prova di Figura 21 (collegamentodiretto alla rete c.a., purché regolabile da 0,9 V n fino a 1,1 V n , oppure tramite unsimulatore di rete).B. Si abiliti la funzione di regolazione secondo la curva “standard” agendo sulconvertitore in base alle indicazioni fornite dal costruttore.C. Si imposti la sorgente c.c. in modo che la potenza attiva erogata dal convertitore siapari al 20 % della potenza nominale P = 0,2 P n (punto A), con tensione ai morsetti diuscita pari a Vn o comunque non superiore a 1,04 V n (nell’ipotesi che il parametro dilock-in sia impostato a 1,05 V n , ovvero nel punto medio del campo di regolazionestabilito in E.2).D. Si misuri la potenza attiva, la potenza reattiva ed il fattore di potenza cos comemedie a 0,2 s, riportando questi valori in una tabella (vedi Tabella 18) e in un graficoanalogo a quello di Figura 27.E. Si ripeta la misura di cui al punto d) precedente aumentando la potenza attiva erogataa scaglioni del 10 % della potenza nominale, dal 20 % P n fino al 60 % P n . Si verifichi alcontempo che durante queste prove la tensione c.a. ai morsetti di uscita non superi ilvalore limite V = 1,04 V n .F. Si trascrivano nella Tabella 18 i valori della potenza attiva, potenza reattiva e del cosrilevati durante le misure effettuate ai 5 livelli di potenza attiva erogata dal 20 % al60 % della potenza nominale. In queste condizioni, essendo la tensione c.a. aimorsetti di uscita inferiore a 1,05 V n , l’inverter NON deve abilitare l’erogazione dellapotenza reattiva.G. A questo punto, con potenza c.a. erogata sempre pari all’ultimo livello raggiunto inprecedenza (P = 0,6 P n ), si aumenti la tensione di rete (o del simulatore), affinchéquesta sia leggermente superiore (2 V) al limite “critico” V = 1,05 V n .H. Si ripeta la misura di cui al punto d) precedente aumentando la potenza attiva erogataa scaglioni del 10 % della potenza nominale, dal 60 % P n fino al 100 % P n (semprecon tensione c.a. letta ai morsetti di uscita superiore a V = 1,05 V n ).I. Si trascrivano nella tabella i valori della potenza attiva, potenza reattiva e del cosrilevati durante le misure effettuate ai 5 livelli di potenza attiva erogata dal 60 % al100 % della potenza nominale. In queste condizioni, essendo la tensione c.a. aimorsetti di uscita superiore a 1,05 V n , l’inverter deve attivare l’erogazione dellapotenza reattiva seguendo la curva caratteristica standard.J. Con inverter in piena erogazione di potenza attiva, tensione c.a. di uscita superiore al105 % V n e quindi potenza reattiva erogata pari al limite massimo (cos = 0,95 ovvero0,90 per potenze superiori a 6kW in assorbimento di reattivo), si riduca la tensionec.a. portandola al valore nominale, verificando che la potenza reattiva rimangaagganciata al valore limite massimo. Questo serve a verificare che, una volta superatoil valore di tensione “critico” di Lock-In, l’inverter permane in modalità di erogazionedella potenza reattiva secondo la curva caratteristica standard, mantenendo questocomportamento per tutti i valori di tensione di uscita superiori alla soglia di Lock-Out(soglia di default impostata a V n ).95

NORMA TECNICA CEI 0-21:2011-12Per ciascun punto di lavoro, lo scostamento massimo del cos rispetto al valore previsto inbase alla curva caratteristica standard deve essere inferiore a ∆cos_max ≤ ± 0,01.P/P n [%] P [W] Q [VAr]cosmisuratocosatteso∆ cos20 %30 %40 %50 %60 %70 %80 %90 %100 %Tabella 20 – verifiche di erogazione della potenza reattiva secondo la curvacaratteristica standard cos=f(P)NOTA Il Distributore può prescrivere curve caratteristiche diverse da quella standard in base alla tipologia di rete,al carico e alla potenza immessa. Tuttavia la curva caratteristica cos = f(P) è, di norma, univocamente definitacome spezzata poligonale passante per i tre punti A, B e C di cui alla Figura 27.Per questo motivo il costruttore, oltre a pre-impostare di fabbrica il sistema di controllo in base alla curva“standard” oggetto di verifica tramite prove di tipo oggetto del presente paragrafo, dovrà parametrizzare la curva diregolazione in modo da renderla regolabile variando i soli 3 punti A, B e C.Di conseguenza il metodo di regolazione cosiddetto a “cos fisso” di cui in E.2.1 (curva di tipo b)), non necessita diverifica, in quanto derivabile dalla curva caratteristica cos = f(P) impostando i parametri di regolazione comesegue:A = B: P = 0,05; cos = 1C: P = Pn; cos = cos_maxB.1.2.6 Erogazione automatica di potenza reattiva secondo una curva caratteristicaQ=f(V)Secondo quanto stabilito in 8.4.4.2, tutti i convertitori statici in impianti di potenzacomplessiva superiore a 6 kW devono poter assorbire o erogare potenza reattiva in modoautomatico ed autonomo (logica di controllo locale) secondo la curva caratteristica Q = f(V)riportata a titolo esemplificativo in E.2 (Figura 28).La prova ha come scopo di verificare che il convertitore segua la modalità di erogazioneautomatica della potenza reattiva secondo la curva caratteristica standard Q = f(V) riportata inE.2, secondo il metodo c).Essendo il funzionamento secondo questo criterio di regolazione assimilato ad un servizio direte erogato dall’Utente Attivo su richiesta del Distributore, vale quanto di seguito specificato.L’attivazione è subordinata alla disponibilità di una opportuna regolamentazione stabilita daAEEG (modalità di attivazione e di esercizio; condizioni economiche).L’attivazione dovrà avvenire dietro richiesta del Distributore, in occasione della emissione delRegolamento di Esercizio. Il Distributore dovrà altresì specificare i valori dei parametri checaratterizzano univocamente la curva, ovvero: V1i, V2i, V1s e V1s, nonché il valore di lock-indi potenza attiva (valore di default P = 0,2 P n ).96

NORMA TECNICA CEI 0-21:2011-12I parametri V1i, V2i, V1s e V1s devono poter essere impostati nel campo 0,9÷1,1 Vn conpasso 0,01 Vn. Al fine di facilitare l’esecuzione delle prove di tipo, è stato stabilitoconvenzionalmente di impostare i parametri caratterizzanti come segue:V1s =1,08 V n ; V2s = 1,1 V nV1i =0.92 V n ; V2i = 0.9 V nnonché il valore di lock-in di potenza attiva (valore di default = 0,2 P n ).B.1.2.6.1 Verifica di rispondenza alle modalità di applicazione della curvacaratteristica Q=f(V)In base a quanto stabilito in E.2, con riferimento alla Figura 28, per la verifica di rispondenzaalle modalità di applicazione della curva caratteristica Q=f(V) si procede come di seguito.A. Si colleghi il convertitore come indicato nel circuito di prova di Figura 20 tramite unsimulatore di rete;B. Si abiliti la funzione di regolazione secondo la curva “standard” di cui alla Figura 28,agendo sul convertitore in base alle indicazioni fornite dal costruttore.C. Si imposti il simulatore in modo che la tensione letta ai morsetti di uscita delconvertitore sia pari a 1,07 V n e la sorgente c.c. in modo che la potenza attiva erogatain uscita sia inferiore a 0,2 P n (quindi inferiore al valore di Lock-In che abilita laregolazione secondo la curva Q(V)).D. Si misuri la potenza attiva e la potenza reattiva come medie a 0,2 sec, riportandoquesti valori in una tabella (vedi Tabella 20) e in un grafico analogo a quello diFigura 28 per la potenza reattiva.E. Si ripeta la misura di cui al punto d) precedente aumentando la tensione di uscita(simulatore) a step di 1 V, dal valore iniziale pari a 1,07 V n fino a 1,09 V n . In questecondizioni, essendo la potenza attiva erogata inferiore a 0,2 P n l’inverter NON deveabilitare l’erogazione della potenza reattiva.F. A questo punto, con tensione c.a. sempre pari a 1,09 V n , si aumenti la potenza attivaerogata agendo sulla sorgente c.c., affinché questa sia superiore (+10%) del limite diLock-In, quindi portandola al valore di 0,3 P n .G. Si verifichi che, trascorsi non oltre 10 s dall’istante in cui la potenza attiva erogata hasuperato il limite di Lock-In, il generatore abiliti l’erogazione della potenza reattiva. Siriporti il valore della potenza attiva e di quella reattiva erogata nella Tabella 20 e nelgrafico, analogo a quello di Figura 28, che mette a confronto la curva attesa con quellarilevata sperimentalmente. In base alle impostazioni di default della curva standard, illivello atteso di potenza reattiva deve essere pari a -0,5 Qmin (a meno di unatolleranza pari a ∆Q ≤ ± 2,5 % P n )H. Si ripeta la misura di cui al punto d) precedente aumentando la potenza attiva erogataa scaglioni del 10 % della potenza nominale dal 30 % P n fino al 100 % P n (sempre contensione c.a. letta ai morsetti di uscita tenuta al valore di V = 1,09 V n ).I. Si trascrivano nella tabella i valori della potenza attiva, potenza reattiva e tensionec.a. rilevati durante le misure effettuate agli 8 livelli di potenza attiva erogata dal 30 %al 100 % della potenza nominale. In queste condizioni, essendo la tensione c.a. aimorsetti di uscita pari 1,09 V n , l’inverter deve continuare ad erogare un livello dipotenza reattiva pari a -0,5 Qmin , seguendo la curva caratteristica standard.97

NORMA TECNICA CEI 0-21:2011-12J. A questo punto è possibile aumentare la tensione ai morsetti di uscita fino a 1,1 V n perregistrare i valori corrispondenti della potenza attiva, che deve essere pari a P n (ultimopunto registrato al passo precedente) e della potenza reattiva, che deve raggiungerestabilmente il limite minimo della capability pari a –Qmin.K. Con inverter in piena erogazione di potenza attiva, tensione c.a. di uscita pari al110 % V n e quindi potenza reattiva erogata pari al limite massimo (-Qmin, inassorbimento di reattivo), si riduca la potenza attiva portandola prima al 10 % P n epoi, trascorsi almeno 30 sec, al di sotto del 5 % P n . Durante la sequenza si dovràverificare che la potenza reattiva rimanga al valore massimo/induttivo (-Qmin)incorrispondenza del primo gradino di potenza attiva 100 %--> 10 %, per scendere avalori prossimi a zero SOLO dopo aver effettuato il secondo scalino dal 10 % P n ≤ 5% P n . Questo serve a verificare che, una volta superato il valore di potenza attiva diLock-In, l’inverter permane in modalità di erogazione della potenza reattiva secondo lacurva caratteristica standard, mantenendo questo comportamento per tutti i valori dipotenza attiva erogata in uscita superiori alla soglia di Lock-Out (soglia di defaultimpostata a 5 % P n ).Per ciascun punto di lavoro, lo scostamento massimo della potenza reattiva rispetto al valoreprevisto in base alle curve caratteristiche standard deve essere inferiore a ∆Q ≤ ± 2,5 % P n .VV max = 1,1 V nVV 1= 1,08 V nV 2sV 1sV 2sV 1s-Q maxQQmax-Q maxVV 1inQ rQ maxQV 1iV 2iV 2iFigura aV 2 = 0,92 V nV min= 0,9 V nQ rFigura bFigura 28 - Curve caratteristiche standard Q = f(V)98

NORMA TECNICA CEI 0-21:2011-12P/P n [%]Set-pointVac [V]Set-pointP/P n [%]misurataVac [V]MisurataQ [VAr]misurataQ [Var]atteso∆ Q(≤ ± 2,5 %P n )< 20 % 1,07 V n ≈0 (< ± 2,5 % P n )< 20 % 1,09 V n ≈0 (< ± 2,5 % P n )

NORMA TECNICA CEI 0-21:2011-12B.1.3.1.1 Esecuzione delle prove Collegare l’oggetto in prova secondo le istruzioni fornite dal Costruttore.Fissare tutti i parametri della rete simulata ai rispettivi valori di normale esercizio.Portare tutti i parametri dell’oggetto in prova ai rispettivi valori di normale esercizio,tali che la potenza in c.a. in uscita all’inverter sia uguale alla potenza in c.a. massimaerogabile per la sequenza A, ovvero al 50 % nel caso della sequenza B.Eseguire le misure su 7 punti (il valore di frequenza dovrà avere una incertezza dimassimo ± 10 mHz) temporalmente conseguenti l’uno all’altro:1) f = 47,51 Hz (t 1 per la sequenza A, t’ 1 per la sequenza B)2) f =50 Hz + 0,2 Hz (t 2 per la sequenza A, t’ 2 per la sequenza B)3) f = 50 Hz + 0,40 Hz (t 3 per la sequenza A, t’ 3 per la sequenza B)4) f = 50 Hz + 0,60 Hz (t 4 per la sequenza A, t’ 4 per la sequenza B)5) f = 50 Hz + 1,49 Hz (t 5 per la sequenza A, t’ 5 per la sequenza B)6) f = 50 Hz + 0,10 Hz (t 6 per la sequenza A, t’ 6 per la sequenza B)A questo punto eseguire il passo 7. riportando la frequenza al valore nominale per laverifica delle condizioni di ripristino graduale della erogazione massima (sequenza A),ovvero al 50 % della potenza massima (sequenza B):7) f = 50 Hz (t 7 per la sequenza A, t’ 7 per la sequenza B).B.1.3.1.2 Esiti delle proveI risultati devono essere riportati in una tabella e in base ad essi si deve estrapolarel’andamento su un grafico (con due curve rappresentanti rispettivamente la Sequenza A e laSequenza B, come riportato a titolo esemplificativo in figura 29). Sul grafico devono ancheessere rappresentati gli andamenti attesi per la Sequenza A e la Sequenza B.La prova si considererà superata se per le sequenze A e B sono soddisfatte entrambe lecondizioni di seguito riportate:per ciascuno dei 6 punti da t1 (t’1) a t6 (t’6) lo scostamento tra il valore atteso di potenzaattiva e quello misurato rientra all’interno di una tolleranza pari a ± 2,5% P n , dove P n è lapotenza nominale dell’inverter;al ritorno della frequenza di rete al valore nominale (passo 7 delle sequenze riportate inB.1.3.1.1), l’inverter dovrà mantenere il livello minimo di potenza raggiunto nella faseprecedente di aumento della frequenza per un tempo minimo di attesa pari a 5 minuti,terminato il quale dovrà ripristinare l’erogazione in maniera graduale con un gradientepositivo massimo non superiore al 20 % al minuto della potenza erogata primadell’aumento di frequenza (valore memorizzato).100

NORMA TECNICA CEI 0-21:2011-12Pi/Pn [%]Sequenza A100%50%t 1 t 2t 3t’1t’ 2t’3t4Sequenza Bt’ 40%t6 = t’6t5 = t’5t7 = t’747,5 50 50,1 50,2 50,3 50,4 50,6 51,5fFigura 29 - Curve di limitazione della potenza attiva rispetto alla frequenzaB.1.3.2 Limitazione della potenza attiva su comando esterno proveniente dalDistributoreLa capacità di ridurre la potenza attiva generata a seguito di segnale da remoto deve esseretestata concordando con il costruttore dell’inverter la modalità di ricezione e trattamento delsegnale.Sarà impiegata la procedura qui di seguito riportata. Si partirà impostando l’inverter in modo da produrre il 100 % della potenza nominale. Dopo 1 minuto di funzionamento si richiederà di ridurre la potenza al 90 %. Si darà 1 minuto di tempo all’inverter per eseguire il comando, dopodiché si misura ilvalore di potenza attiva (media su 1 minuto). Lo scostamento rispetto al set point nelminuto di misurazione dovrà essere di ± 2,5 % P n , perché la prova possa ritenersisuperata. Successivamente, si proseguirà richiedendo di ridurre la potenza di un ulteriore 10 %,rimanendo a quel valore per altri 2 minuti, e così fino a raggiungere il valore di 0 % P n .Nella misurazione relativa al set-point 10 % P n si verificherà in base alle prescrizioninormative in Allegato F, e quindi la potenza misurata dovrà rientrare nell’intervallo tra 12,5 %P n e 0, perché la prova possa ritenersi superata.I risultati della prova dovranno essere riportati su una tabella simile alla seguente:101

NORMA TECNICA CEI 0-21:2011-12Set point P [P/P n ] Set point P [W] P misurata [W] Precisione100 %90 %80 %70 %60 %50 %40 %30 %20 %10 %0 %Tabella 22 – Verifiche di limitazione della potenza attiva su comando esternoInoltre, si dovrà riportate i risultati su un grafico contenente l’andamento del set-point,l’andamento dei valori delle potenze medie misurate, le tolleranze sui valori delle potenzemedie misurate rispetto ai set-point.Nel grafico esemplificativo seguente si può trovare in nero l’andamento dei set-point e inrosso i valori medi della potenza per ciascuna misura, che devono tutti rientrare entro le areegrigie di tolleranza perché il test possa considerarsi superato.102

NORMA TECNICA CEI 0-21:2011-12Figura 30 – Esempio di limitazione della potenza attiva in risposta a comando esternoB.1.4 Emissione di componente continua nella corrente di uscitaB.1.4.1 Verifica della emissione di componente continuaLa prova deve essere eseguita come segue:1) La tensione di rete (o simulatore) deve essere inizialmente posta a un valore pari allatensione nominale ± 1 %, (frequenza pari a 50 ± 0,2 Hz). La distorsione totale di tensione(THD) deve essere inferiore al 2,5 % (ad inverter spento). Nel caso di utilizzo di unsimulatore, questo deve produrre una tensione sinusoidale con offset (componentecontinua) trascurabile (< 0,1 %).2) La sorgente c.c. di ingresso deve essere regolata in modo che la tensione sia pari aquella nominale in MPPT dichiarata dal costruttore (o valore medio tra i valori MPPTminimo e massimo, qualora il valore nominale non venga dichiarato) e la Potenza c.a. diuscita all’inverter, misurata in volt-ampere, risulti pari a (33 ± 5 %) del valore nominaledichiarato dal costruttore.3) Si lasci il sistema operare nelle condizioni impostate al punto precedente per almeno 5minuti o il tempo necessario affinché si stabilizzi la temperatura interna al convertitore.103

NORMA TECNICA CEI 0-21:2011-124) A questo punto si misuri la componente continua della corrente immessa in rete(frequenza < 1 Hz) su ciascuna delle fasi di uscita. La misura deve essere effettuatamediando la grandezza misurata su una finestra temporale di massimo 1 sec,registrandone l’andamento per un periodo minimo di 5 minuti e acquisendo un numerominimo di campioni pari al reciproco della finestra temporale su cui è stata mediata lagrandezza (nel caso 1 sec, almeno 300 campioni). Con le stesse modalità si dovrannomisurare e registrare la corrente rms e la tensione rms di uscita dell’inverter.5) Ripetere i passi 2), 3) e 4) con il convertitore operante rispettivamente al (66 ± 5) %, e(100 ± 5) % della potenza nominale, misurata in volt-ampere.Per ciascun livello di potenza:a) Si effettui il calcolo del valore medio della corrente rms e della tensione rms su ciascunafase. Per ciascuna grandezza la media deve essere calcolata considerando tutti icampioni rilevati durante il periodo di misura.b) Si verifichi che il valore medio della corrente rms su ciascuna fase calcolato al punto a)sia entro il 5 % del valore impostato (rispettivamente al 33 %, 66 % e 100 % del valorenominale).c) Si verifichi che il valore medio della tensione rms su ciascuna fase calcolato al punto a)sia entro il 5 % del valore nominale.d) Si calcoli il valore medio della componente continua della corrente su ciascuna fase. Lamedia dovrà essere calcolata considerando il modulo (senza segno) del valore di ciascuncampione registrato durante ciascun periodo di osservazione di 5 minuti (sui 3 livelli dipotenza).e) Per ciascuna fase, si divida il valore medio della componente continua calcolata al puntod) per il valore nominale della corrente di uscita del convertitore e si moltiplichi questorapporto per 100. I valori così calcolati rappresentano la percentuale di corrente continuaimmessa in rete per ciascuna fase, rispetto alla corrente nominale del convertitore.104

NORMA TECNICA CEI 0-21:2011-12La componente continua misurata secondo questa procedura deve rientrare nei limitispecificati. A titolo indicativo la Tabella 23 riporta un esempio di rappresentazionedell’esito delle prove.Livello di Potenza (% VA nominali) (33 ± 5) % (66 ± 5) % (100 ± 5) %WattVrmsArmsPFCosφc.c. (mA)c.c. (% In)Tabella 23 - Test Report - Misura della componente continua (c.c.) immessa in reteRete in correntealternataSorgentein correntecontinuaInverterAnalizzatoredi reteNOTA Questo circuito di prova si applica ai sistemi monofase. Per sistemi trifase si dovrà prevedere un circuitoequivalente di tipo trifase.Figura 31 - Circuito di prova per la misura della componente continuaB.1.4.2 Verifica delle protezioni contro l’immissione di componente continuaLa prova deve essere eseguita come segue:1) L’inverter viene collegato ad un circuito di prova simile a quanto riportato in Figura 31.2) La tensione di rete (o simulatore) deve essere mantenuta entro un valore pari allatensione nominale ± 1 %, (frequenza pari a 50 ± 0,2 Hz). La distorsione totale di tensione(THD) deve essere inferiore al 2,5 % (ad inverter spento). Nel caso di utilizzo di unsimulatore, questo deve produrre una tensione sinusoidale con offset (componentecontinua) trascurabile (< 0,1 %).3) La sorgente c.c. di ingresso deve essere regolata in modo che la tensione sia pari aquella nominale in MPPT dichiarata dal costruttore (o valore medio tra i valori MPPTminimo e massimo, qualora il valore nominale non venga dichiarato) e la Potenza c.a. diuscita all’inverter, misurata in volt-ampere, risulti pari a (33 ± 5) % del valore nominaledichiarato dal costruttore.4) La verifica dello spegnimento del convertitore, per superamento della prima soglia diprotezione Idc > (> 0,5% I n ), si effettua alternativamente come descritto ai punti a) e b):a) Attraverso una simulazione della deriva del controllo di simmetria del convertitore, conmodalità da concordare col costruttore e tale da indurre un offset sulla Idc superioreallo0,5 % della corrente nominale. Lo spegnimento deve avvenire entro 1 secondodall’istante di applicazione dell’offset.b) Nel dispositivo di misurazione della componente continua (p.es. trasformatore dicorrente, o resistenza) viene impressa una corrente continua superiore allo 0,5 %della corrente nominale. Lo spegnimento deve avvenire entro 1 secondo dall’istante diapplicazione della corrente di sbilanciamento.105

NORMA TECNICA CEI 0-21:2011-125) La verifica dello spegnimento del convertitore, per superamento della seconda soglia diprotezione Idc >> (>1 A), si effettua alternativamente come descritto ai punti c) nel caso laprotezione sia integrata nel sistema di controllo del convertitore, oppure d) per sistemi diprotezione esterni:c) Attraverso una simulazione del guasto, mediante misurazione, con modalità daconcordare col costruttore, bisogna accertare se un funzionamento dell’impiantoanomalo con la componente continua della corrente immessa in rete superiore ad 1 A,porti allo spegnimento entro 0,2 secondi dall’istante di innesco della condizione diguasto simulato.d) Nel dispositivo di misurazione della componente continua (p.es. trasformatore dicorrente, o resistenza) viene impressa una corrente continua superiore a 1 A. Lospegnimento deve avvenire entro 0,2 secondi dall’istante di applicazione dellacorrente di guasto.6) Ripetere i passi 2), 3) e 4) con il convertitore operante rispettivamente al (66 ± 5) %, e(100 ± 5) % della potenza nominale, misurata in VA.NOTA per la misurazione dei tempi di intervento e la verifica dei livelli di corrente continua di guasto (> 1 A c.c.) oderiva (> 0,5 % I n ) simulati come specificato ai paragrafi A.5.4 e A.5.5 è possibile utilizzare un analizzatore di retecon oscilloscopio integrato, oppure un oscilloscopio corredato di sonde di corrente adatte alla misurazione dicomponenti continue.B.1.5 Verifica della insensibilità agli abbassamenti di tensione (LVFRT capability)Queste prove hanno come scopo di verificare che il convertitore, qualora utilizzato in impiantidi potenza complessiva superiore a 6 kW, sia insensibile agli abbassamenti di tensionesecondo il profilo tempo-ampiezza indicato nella Figura 14.In particolare le prove dovranno verificare che siano soddisfatti i seguenti requisiti funzionali: nella zona tratteggiata il generatore non deve disconnettersi dalla rete. In questa zona èconsentito interrompere temporaneamente l’erogazione della potenza attiva e reattivaerogata prima della insorgenza del guasto. nella zona sottostante (grigio) il generatore può scollegarsi dalla rete. entro 200 ms dal ripristino di un livello di tensione di rete compreso tra + 10 % e – 15 %della tensione nominale, il generatore deve riprendere l’erogazione della potenza attiva ereattiva immessa in rete prima della insorgenza del guasto con una tolleranza massimadel ± 10 % della potenza nominale. Nella fascia tra 85 % e 90 % della tensione nominaleè ammessa una riduzione della potenza erogata in base ai limiti della corrente massima diuscita dal generatore.Le verifiche di rispondenza ai requisiti di immunità agli abbassamenti di tensione si effettuanosecondo le sequenze di test riportate in Tabella 24, da eseguire con il generatore funzionanterispettivamente:a) tra il 10 % ed il 30 % della potenza nominale eb) al di sopra del 90 % della potenza nominale.Per ognuna delle sequenze a) e b) si lasci il sistema operare nelle condizioni impostate peralmeno 5 minuti o il tempo necessario affinché si stabilizzi la temperatura interna alconvertitore.La protezione di interfaccia dovrà essere disabilitata oppure regolata al fine di evitare scattiintempestivi durante l’esecuzione della prova.Il sistema di simulazione del guasto deve produrre gli abbassamenti di tensione con profiloriportato in Tabella 24 e secondo la Figura 14 in condizioni di funzionamento a vuoto e quandocollegato al generatore in prova. Il risultato di ciascuna sequenza dovrà essere documentatocome segue:106

NORMA TECNICA CEI 0-21:2011-12Andamento temporale di potenza attiva P, potenza reattiva Q e tensioni di fase ai morsettidi uscita Vr, s, t, come valori rms a media mobile di un ciclo di rete e con aggiornamentoogni mezzo ciclo (10 ms), su una finestra temporale che decorre da 100 ms primadell’inizio della prova e termina almeno dopo 400 ms dalla fine del transitorio di tensione(onde poter verificare il ripristino della potenza attiva e reattiva). Il transitorio di tensionefinisce quando la tensione rientra oltre il 85 % del valore di tensione nominale.Nello stesso periodo di osservazione si dovranno riportare gli oscillogrammi delle tensionie delle correnti di fase (eventualmente con dettaglio ingrandito dell’andamento durante ifronti di salita e discesa di tensione)Elenco proveAmpiezza residua della tensionefase-fase V/V nomDurata [ms] Forma(*)1 – guasto simmetrico trifase 0,05 ± 0,05 (V 1 /V nom ) 200 ± 202 – guasto simmetrico trifase 0,45 ± 0,05 (V 2 /V nom ) 400 ± 203 – guasto asimmetrico bifase 0,05 ± 0,05 (V 3 /V nom ) 200 ± 204 – guasto asimmetrico bifase 0,45 ± 0,05 (V 4 /V nom ) 400 ± 205 – guasto asimmetrico bifase in BT 0,05 ± 0,05 (V 5 /V nom ) 200 ± 206 – guasto asimmetrico bifase in BT 0,45 ± 0,05 (V 6 /V nom ) 400 ± 20* A prescindere dal metodo utilizzato per simulare i transitori (simulatore o rete di impedenze), i fronti di discesa e disalita della tensione devono avere durata inferiore a 10msTabella 24 - Sequenze di test per verifica immunità agli abbassamenti temporanei ditensione. Le ampiezze, la durata e la forma si riferiscono alle condizioni di test a vuoto.S RS 1Z1˜=Rete in c.a.(Z R )Z 2Generatore(P N )S 2Figura 32 - Esempio di circuito di prova per simulare gli abbassamenti temporanei ditensioneLe prove possono essere effettuate utilizzando ad esempio il circuito di prova riportato inFigura 32. Gli abbassamenti di tensione sono riprodotti da un circuito che simula uncortocircuito collegando le 3 oppure le 2 fasi a terra tramite una impedenza (Z 2 ), oppurecollegando le 3 o 2 fasi insieme tramite la stessa impedenza. Gli interruttori S 1 ed S 2 servonoa definire i profili temporali delle singole sequenze di prova.107

NORMA TECNICA CEI 0-21:2011-12Per il dimensionamento del circuito di prova valgono le seguenti considerazioni: L’impedenza Z 1 serve a limitare l’effetto del cortocircuito sulla rete elettrica che alimenta ilcircuito di prova (limitazione della corrente di cortocircuito). Il dimensionamento di Z 1 deveessere tale da consentire di avere una corrente massima di cortocircuito pari a 800 A perfase (in particolare nel caso peggiore, e cioè con tensione residua 5 % V n ). Un interruttore di bypass S 1 viene solitamente impiegato per evitare il surriscaldamentodella impedenza serie Z 1 prima e dopo l’esecuzione di ciascuna sequenza. La caduta di tensione viene creata collegando a terra o verso un’altra fase l’impedenza Z 2tramite l’interruttore S 2 . Il valore di Z 2 deve essere calcolato per produrre una tensione aisuoi capi pari ai valori di tensione residua specificati in Tabella 24 (condizioni a vuoto). Come rete c.a. si intende rete trifase in bassa tensione. Non è consentito ai laboratori diprova allacciarsi direttamente a una linea pubblica BT. Sarà quindi necessario che illaboratorio di prova disponga di allaccio MT e successivo trasformatore. La chiusura e apertura dell’interruttore S 2 determina la durata degli eventi diabbassamento della tensione, pertanto il suo controllo deve essere accurato sia nellesimulazioni di guasti bifase che in quelli trifase. L’interruttore può essere ad esempio uncontattore di calibro adeguato. In assenza di generatore, il circuito di prova deve garantire un inviluppo della tensionedurante la simulazione conforme al grafico di Figura 23. La durata del transitorio diabbassamento della tensione deve essere misurato dall’istante di chiusura a quello diriapertura dell’interruttore S2. Le tolleranze tratteggiate in Figura 23 tengono conto degliscostamenti e ritardi nei tempi di chiusura e apertura del dispositivo e della pendenza didiscesa e salita della tensione. Eventuali scostamenti rispetto al grafico riportato sottovanno adeguatamente documentati e giustificati nel rapporto di prova.Figura 33 - Tolleranze di ampiezza e tempo per le sequenze di prova di abbassamentodella tensione di rete (VRT Test) (Fonte: norma IEC 61400-21)Sono ammessi circuiti di prova alternativi e in particolare i simulatori di rete (Figura 34).Qualora si utilizzi un simulatore di rete, quest’ultimo deve:1) garantire la possibilità di un controllo indipendente in ampiezza e angolo di fase delle tretensioni2) essere fornito delle impedenze Z 1 , Z 2 e Z 3 , Z N regolabili in modo da riprodurre i parametritipici della rete.108

NORMA TECNICA CEI 0-21:2011-12Figura 34 - Utilizzo di simulatore di reteCon riferimento all’elenco delle prove riportate in Tabella 24, gli abbassamenti di tensione chesono oggetto di queste prove sono causati da guasti prodotti sulla linea di distribuzione inbassa, media o alta tensione. Le tipologie di guasto considerate sono tre:1) guasto simmetrico trifase (Tabella 24, Prove N. 1 e N.2)2) guasto asimmetrico bifase (Tabella 24, Prove N. 3 e N.4)Guasto in MT, che provoca in BT una variazione oltre che di ampiezza anche della relazionedi fase delle tensioni (il caso considerato prevede la presenza di un trasformatore Dy incabina secondaria).Durante il guasto asimmetrico bifase, l’ampiezza residua delle 3 tensioni e gli sfasamenti trale fasi dovranno essere conformi ai valori riportati nella Tabella seguente109

NORMA TECNICA CEI 0-21:2011-12Prova N.V/V nomTensioni fase-terraAngoli di faseu 1 /u 1,nom u 2 /u 2,nom u 3 /u 3,nom φ u1 φ u2 φ u33 0,05 ± 0,05 0,87 ± 0,05 0,87 ± 0,05 0,05 ± 0,05 27° -147° 113°4 0,45 ± 0,05 0,90 ± 0,05 0,90 ± 0,05 0,45 ± 0,05 15° - 135° 115°cond. norm. 1 1 1 1 0° -120° 120°3) guasto asimmetrico bifase in BT (Tabella 24, Prove N. 5 e N.6)Queste alterazioni si propagano sulle linee di distribuzione in bassa tensione con valori diampiezza delle singole tensioni ed angolo di fase che sono dipendenti dalle caratteristiche deitrasformatori presenti nella cabina di distribuzione, in particolare gruppo vettoriale edimpedenza.Pertanto, al fine di simulare correttamente gli effetti prodotti dall’insorgenza dei guasti bifasesul lato bassa tensione della linea, occorre riprodurre tramite il simulatore le condizioni che siproducono sulle linee BT quando il guasto viene indotto sulla tratta MT della linea didistribuzione, incluse le alterazioni della relazione di fase in presenza di guasti asimmetricibifase.B.1.6 Verifica della insensibilità alle richiusure automatiche in discordanza di faseQuesto tipo di test può essere eseguito secondo due modalità:1. con l’inverter connesso ad una rete simulata (B.1.6.1)2. con l’inverter connesso alla rete di distribuzione (B.1.6.2 e in alternativa B.1.6.3).Il generatore non deve danneggiarsi a seguito delle prove. Sono ammessi lo spegnimento e loscatto di eventuali protezioni.110

NORMA TECNICA CEI 0-21:2011-12B.1.6.1Test su rete simulata:Rete in c.a.(Z R )Simulatore di reteTensione di retesimulata(V R )Generatore(P N )Figura 35 - Circuito per la verifica della insensibilità alla richiusura automatica indiscordanza di fase tramite simulatore di reteCon riferimento allo schema riportato in Figura 35 – utilizzo di rete simulata: Il simulatore di rete dovrà essere in grado di produrre salti di fase della tensione aimorsetti di uscita dell’inverter rispettivamente di 90° e di 180°. Generatore: inverter in funzionamento alla potenza nominale con fattore di potenzaunitario (cos = 1) VR: tensione di rete simulataIl generatore va portato in funzionamento alla potenza nominale. Si lasci il sistema operarenelle condizioni impostate per almeno 5 minuti o il tempo necessario affinché si stabilizzi latemperatura interna al convertitore.Al termine per periodo di stabilizzazione si dovranno effettuare in sequenza 2 prove,inducendo un transitorio che produca repentinamente un angolo di sfasamento sulla tensionedi rete simulata VR pari a 180 ° ed a 90°.Nel test report vanno indicati per ciascuna delle due sequenze di test: l’angolo fra la tensione prima e dopo il salto di fase, con uno strumento avente errore di 1°; la corrente del generatore su una finestra temporale che decorre da 20 ms prima adalmeno 200 ms dopo il salto di fase della tensione di rete simulata.111

NORMA TECNICA CEI 0-21:2011-12B.1.6.2Test su rete di distribuzione tramite trasformatore di accoppiamento:Interruttore ocontattorecomandatointerbloccatoCBGeneratore (P N )Rete in c.a.(Z R )Tensione di reteVRTensione di rete90° e 180°VR'Tensione digeneratoreVGFigura 36 - Circuito per la verifica della insensibilità alla richiusura automatica indiscordanza di fase tramite trasformatore di accoppiamentoCon riferimento allo schema riportato in Figura 35 - circuito per la verifica della insensibilitàalla richiusura automatica in discordanza di fase tramite simulatore di rete – utilizzo di untrasformatore di accoppiamento: TR: trasformatore con colonne aperte, da configurare YYn o DYn in funzione della provada effettuare Generatore: inverter in funzionamento alla potenza nominale con fattore di potenzaunitario (cos = 1) Rc: carico resistivo zavorra, di potenza pari alla potenza nominale dell’inverter VR: tensione della rete di distribuzione VR’: tensione sfasata rispetto alla rete di distribuzione di 90° e 180° in funzione dellaprova da effettuare VG: tensione applicata al generatore.Il contattore CB è chiuso, il contattore CB’ è aperto.Il generatore va portato in funzionamento alla potenza nominale. Si lasci il sistema operarenelle condizioni impostate per almeno 5 minuti o il tempo necessario affinché si stabilizzi latemperatura interna al convertitore.Si verifichi che, per almeno 1 minuto, la corrente attraverso l’interruttore CB sia inferiore al2 %. Il valore misurato va riportato nel test report.Quindi aprire il contattore CB e chiudere il contattore CB’, in modo coordinato e istantaneo (ameno della differenza sui tempi di apertura e chiusura). La resistenza di zavorra attenua itransitori elettrici sull’uscita dell’inverter ed impedisce che l’inverter si scolleghi dalla rete.112

NORMA TECNICA CEI 0-21:2011-12Lo spegnimento del generatore o l’intervento delle protezioni possono avvenire solo a valledella completa chiusura del contattore CB’.Vanno effettuate 2 prove, con angolo di sfasamento alla chiusura rispettivamente pari a 180°ed a 90°. A tal fine il gruppo vettoriale del trasformatore TR va riconfigurato in modoopportuno.Nel test report vanno indicati: l’angolo fra le 2 tensioni misurate con uno strumento avente errore di 1°; la corrente del generatore a seguito della chiusura, rilevata su una finestra temporale chedecorre da 20 ms prima ad almeno 200 ms dopo il salto di fase della tensione di rete.B.1.6.3 Test su rete di distribuzione, simulazione della deriva di frequenzaCon riferimento allo schema riportato in Figura 37: CB: interruttore comandato o contattore. Il potere di chiusura, per entrambi, deve essereadeguato. Il tempo di chiusura deve essere noto e stabile Generatore: inverter in funzionamento alla potenza nominale con fattore di potenzaunitario (cos = 1) Rc: carico resistivo zavorra, di potenza pari alla potenza nominale dell’inverter Zc: carico reattivo di deriva. Zc sarà dimensionato per assorbire una corrente reattiva diordine pari all’1 % di quella nominale dell’inverter. Il valore effettivo, la natura capacitiva oinduttiva sarà comunque concordato con il costruttore dell’inverter e riportato nel testreport.VR: tensione della rete di distribuzioneVG: tensione del generatore in isola sul carico zavorra.Rete c.a.Figura 37 - Circuito per la verifica della insensibilità alla richiusura automatica indiscordanza di fase. Collegamento diretto alla rete di distribuzione e simulazione delladeriva di frequenzaIl generatore va portato in funzionamento alla potenza nominale. Si lasci il sistema operarenelle condizioni impostate per almeno 5 minuti o il tempo necessario affinché si stabilizzi latemperatura interna al convertitore.113

NORMA TECNICA CEI 0-21:2011-12Poiché il funzionamento in isola degli inverter per connessione alla rete non è previsto, perl’esecuzione di questa prova potrebbe essere necessario alterare alcuni parametri di controlloe regolazione.L’algoritmo MPPT va disabilitato.Per i generatori statici, qualsiasi protezione interna contro la perdita di rete diversa da quelledescritte nella presente norma, per esepio basata sulla misura dell’impedenza, salto di fase,ecc., va esclusa, come pure le protezioni e i controlli in frequenza che possano distaccare ilgeneratore.Si verifichi che, per almeno 1 minuto, la corrente attraverso l’interruttore CB sia inferiore al 2%. Il valore misurato va riportato nel test report.A questo punto la frequenza dell’inverter deriva con dinamica dipendente dai parametri edalla tecnologia dell’inverter sottoposto al test. Il carico Zc contribuisce a rendere il sistemainstabile e potrebbe risultare non indispensabile per l’esecuzione della prova.Il setup deve garantire che la deriva di frequenza sia sufficientemente lenta da permetterel’osservazione della differenza di fase tra rete e uscita dell’inverter attraverso un oscilloscopiocon misura a canali isolati.Vanno effettuate 2 prove, con angolo di sfasamento alla chiusura rispettivamente pari a 180°ed a 90°.Il generatore non deve danneggiarsi a seguito delle prove. Sono ammessi lo spegnimento e loscatto di eventuali protezioni.Nel test report vanno indicati: l’angolo fra le 2 tensioni misurate con uno strumento avente errore di 1°; la corrente del generatore a seguito della chiusura, rilevata su una finestra temporale chedecorre da 20 ms prima ad almeno 200 ms dopo il salto di fase della tensione di rete.114

phiphi absphi prodU miniU maxiULes dispositions constructives que doit respecter l’installation sont détaillées ci-dessous.Phi représente le déphasage entre l’intensité et la tension au point de livraison :- Phi abs correspond à la valeur minimale requise, en absorption de puissance réactive. Cette valeurdoit être réglable entre 0° et 18° ;- Phi prod correspond à la valeur minimale requise, en fourniture de puissance réactive. cette valeurdoit être réglable entre 0° et 26° ;U représente la tension au point de livraison et Un la tension en cas fonctionnement normal :- U mini doit être réglable de Un × 95 % à Un × 102,5 % ;- U maxi doit être réglable de Un × 97,5 % à Un × 105 % ;- Umaxi –Umini = Un × 2,5 %.d. MesuresL’énergie injectée sera mesurée par des dispositifs de comptage classiques. Ces dispositifs de comptageenregistreront également les puissances moyennes par périodes de 10 minutes (« puissance moyenne10 min »).Les mesures de puissance instantanée serviront de base pour déterminer les écarts éventuels par rapportaux prévisions contractuelles à J-1.Les valeurs des puissances active et réactive injectées au point de livraison feront l’objet de télémesurespar le gestionnaire du système électrique concerné. La période de rafraîchissement de ces télémesures nepourra être supérieure à 10 secondes.S’il le juge utile, le producteur pourra prévoir des télésignalisations à destination du gestionnaire dusystème électrique concerné, afin d’informer ce dernier de situations particulières de l’installationéolienne, comme par exemple l’état de charge du système de stockage d’énergie.29/43

Définitions relatives à l’annexe 3Puissance maximale (P_max) :Elle est exprimée en kW et uniquement définie pour les installations de production. Cette puissance a étéintroduite pour les études de raccordement par l’article premier de l’arrêté du 23 avril 2008 relatif auxprescriptions techniques de conception et de fonctionnement pour le raccordement à un réseau public dedistribution d’électricité en basse tension ou en moyenne tension d’une installation de productiond’énergie électrique : « Pour l’application des dispositions du présent arrêté, P_max désigne la puissanceinstallée définie à l’article 1er du décret du 7 septembre 2000 susvisé. Par convention, la puissanceP_max est la puissance active pour les installations de production raccordées en HTA et la puissanceapparente pour les installations de production raccordées en BT ».La puissance déclarée par le demandeur sur la fiche de collecte doit être identique avec celle déclarée autitre de l’instruction de la déclaration ou de l’autorisation d’exploiter telle que définie à l’article premierdu décret 2000-877 du 7 septembre 2000 relatif à l’autorisation d’exploiter les installations de productiond’électricité : « Pour l’application du présent décret, la puissance installée d’une installation deproduction est définie comme la somme des puissances unitaires maximales des machines électrogènessusceptibles de fonctionner simultanément dans un même établissement, identifié par son numérod’identité au répertoire national des entreprises et des établissements, tel que défini par décret du 14 mars1973 susvisé ».Comme le précise cet article, cette puissance est déterminée à partir des puissances des composantes del’installation de production et par conséquent ne prend pas en compte d’éventuelles consommations dusite.Puissance de raccordement (P_racc) :Elle désigne la capacité physique de transit du raccordement. Sauf stipulation contraire figurant auxconditions particulières de la convention de raccordement, pour chaque poste de livraison, le point deraccordement du poste de livraison au réseau public de distribution HTA est situé, sur chaque canalisationde raccordement, à la limite de concession définie à l’article 3.1 de la convention de raccordement.30/43

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 1 di 13REGOLAZIONE TECNICA DEI REQUISITI DI SISTEMA DELLAGENERAZIONE DISTRIBUITAStoria delle revisioni01 13/03/2012 Prima emissione

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 2 di 13INDICE1. SCOPO........................................................................................................................... 32. CAMPO DI APPLICAZIONE ............................................................................................. 33. RIFERIMENTI ................................................................................................................. 44. DEFINIZIONI ................................................................................................................... 45. CAMPO DI FUNZIONAMENTO DEGLI IMPIANTI DI PRODUZIONE .................................... 56. TRASMISSIONE DEI DATI NECESSARI AI FINI DEL CONTROLLO DEL SEN .................... 67. REGOLAZIONI ................................................................................................................ 67.1. COMPORTAMENTO DEGLI IMPIANTI DI PRODUZIONE NEI TRANSITORI DIFREQUENZA .......................................................................................................... 67.1.1. RICONNESSIONE E REGOLAZIONE DELLA POTENZA ATTIVA IN FUNZIONEDELLA FREQUENZA ................................................................................. 67.1.2. AVVIAMENTO E AUMENTO GRADUALE DELLA POTENZA IMMESSA INRETE ....................................................................................................... 77.2. COMPORTAMENTO DEGLI IMPIANTI DI PRODUZIONE NEI TRANSITORI DITENSIONE ............................................................................................................. 77.2.1. INSENSIBILITA’ AGLI ABBASSAMENTI DI TENSIONE ................................... 88. COMPATIBILITA’ DELLE PROTEZIONI DEGLI IMPIANTI DI PRODUZIONE CON LEESIGENZE DI SISTEMA .................................................................................................. 88.1. IMPIANTI DI PRODUZIONE CONNESSI ALLA RETE MT ................................ 98.1.1. Regolazioni dei relè da adottare in via transitoria .......................................... 118.2. IMPIANTI DI PRODUZIONE CONNESSI ALLA RETE BT ............................... 129. APPENDICE 1 - Ulteriori accorgimenti riportati a titolo informativo ..................................... 13

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 3 di 131. SCOPOLa presente Guida regola i requisiti tecnici a cui gli impianti di produzione di energia elettricaconnessi alle reti di distribuzione MT e BT (nel seguito: GD) devono rispondere ai fini dellasicurezza del sistema elettrico nazionale interconnesso. In particolare, il presente documento ha loscopo di prescrivere i requisiti minimi relativamente a:Campi di funzionamento in tensione e frequenzaControlloEsigenze di sistema per le protezioniRegolazioniLa presente Guida non riguarda la protezione contro l’elettrocuzione o danni ambientali chehanno precedenza sulla presente.2. CAMPO DI APPLICAZIONELe prescrizioni del presente allegato si applicano, secondo le modalità e i termini di cui alladelibera dell’Autorità per l’energia elettrica e il gas 84/2012/r/eel, in particolare a:a) Impianti tradizionali, vale a dire impianti rotanti sincroni o asincroni connessi alla retesenza interposizione di sistemi di raddrizzamento/inversione;b) Impianti di tutte le altre tipologie connessi alla rete mediante interposizione di sistemi diraddrizzamento/inversione (inverter lato rete);1c) Le eventuali parti d’impianto nella titolarità delle imprese distributrici strumentali allaprotezione e controllo degli impianti PV.Gli obblighi informativi previsti dal capitolo 6 si applicano a tutte le cabine primarie di distribuzione,cui afferisca produzione.Le Imprese di Distribuzione sono tenute al rispetto dei requisiti descritti, alla vigilanzasull’applicazione degli stessi da parte di utenti connessi alle reti di distribuzione con potenzecomplessive per utente non inferiori a 1 kW; le predette Imprese, inoltre, sono tenute a nonadottare pratiche d’esercizio in contrasto con gli stessi.L’osservanza delle prescrizioni previste nel presente documento deve costituire condizioneessenziale per la connessione degli impianti alla rete.1 Gli impianti di cui in a) e b) sono attualmente indicati nella normativa tecnica corrente rispettivamente con ilnome di generatori direttamente connessi e indirettamente connessi.

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 5 di 13Utente attivo:Richiusura RapidaAutomaticaUtente che utilizza qualsiasi macchinario (rotante o statico) che convertaogni forma di energia utile in energia elettrica in corrente alternataprevisto per funzionare in parallelo (anche transitorio) con la rete.Richiusura degli interruttori di linea aperti per intervento delle protezioni.(RRA)5. CAMPO DI FUNZIONAMENTO DEGLI IMPIANTI DI PRODUZIONETutti gli impianti di produzione ed i relativi macchinari ed apparecchiature devono essere progettati,costruiti ed eserciti per restare in parallelo anche in condizioni di emergenza e di ripristino di rete.In particolare gli impianti, in ogni condizione di carico, devono essere in grado di rimanerepermanentemente connessi alla rete MT e BT per valori di tensione nel punto di consegna,compresi nel seguente intervallo:85% Vn ≤ V ≤ 110% VnRiguardo all’esercizio in parallelo con la rete MT/BT in funzione della frequenza, l’impianto diproduzione deve essere in grado di rimanere connesso alla rete per un tempo indefinito 2 , per valoridi frequenza compresi nel seguente intervallo:47,5 Hz ≤ f ≤ 51,5 HzL’Utente Attivo deve garantire che tali intervalli di funzionamento siano rispettati sia dalle protezionidi interfaccia che dalle protezioni e regolazioni dell’impianto di produzione. L’Impresa diDistribuzione vigila sul rispetto di tali requisiti.Per soddisfare contemporaneamente le esigenze generali del Sistema Elettrico Nazionale, leesigenze delle Imprese di Distribuzione, nonché le esigenze degli utenti attivi (salvaguardia delmacchinario di generazione)- e dei clienti finali (qualità del servizio) è necessario adottare logichedi funzionamento in grado di selezionare soglie e tempi di intervento dei relè di frequenza sullabase di due diversi tipi di evento:• guasto locale• perturbazione di sistema con variazione transitoria della frequenza.Nel capitolo 8 viene descritta, sia per il livello MT che per quello BT, una soluzione funzionale dellelogiche di intervento delle protezioni di minima e massima frequenza degli impianti di produzione,coerente con la prescrizione.2La specificazione ammette solo modeste eccezioni relative ai generatori direttamente connessi alle reti BT nellecondizioni precisate al paragrafo 8.2.

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 6 di 136. TRASMISSIONE DEI DATI NECESSARI AI FINI DEL CONTROLLO DEL SENAi fini del controllo del SEN, che presuppone la fedele conoscenza della GD in MT e BT sia in fasepredittiva che in tempo reale, risultano necessari al Gestore, per ogni cabina primaria, sia datiprevisionali sia telemisure in tempo reale della potenza attiva e reattiva, differenziata peraggregato:caricogenerazione differenziata per fontetotale di cabinaLe predette informazioni dovranno essere rese disponibili dall’Impresa di Distribuzione al Gestore.Le telemisure saranno rese disponibili ai sistemi SCADA del Gestore con le caratteristiche definitedallo stesso.7. REGOLAZIONIIn caso di perturbazioni che siano causa di transitori di frequenza e/o di tensione, gli impiantidevono continuare a garantire il proprio sostegno al SEN nell’ambito dell’intervallo difunzionamento richiesto al paragrafo 5.7.1. COMPORTAMENTO DEGLI IMPIANTI DI PRODUZIONE NEI TRANSITORI DIFREQUENZAPer il controllo dei transitori in frequenza, si richiede agli impianti di produzione statici connessi allereti MT e BT:• la capacità di ridurre la potenza immessa in rete in risposta ad una variazione della frequenzadel sistema al di sopra di una soglia predefinita (regolazione della potenza in funzione dellasovrafrequenza);• l’inserimento graduale della potenza immessa in rete in modo da minimizzare gli effetti sulsistema in caso di ripresa del servizio.• l’avviamento con l’aumento graduale della potenza immessa in rete.7.1.1. RICONNESSIONE E REGOLAZIONE DELLA POTENZA ATTIVA IN FUNZIONEDELLA FREQUENZADurante un transitorio di frequenza, detti impianti di produzione devono essere in grado di:a) non variare la potenza immessa in rete nei limiti previsti, per frequenze comprese tra 47,5 Hze 50,3 Hz, salvo che per motivi legati alla disponibilità della fonte primaria;b) ridurre la potenza immessa in rete in funzione dell’entità dello scarto di frequenza positivorispetto a 50 Hz per frequenze comprese tra 50,3 Hz e 51,5 Hz, secondo uno statismocompreso tra il 2% e il 5%; di norma verrà impostato un valore pari al 2,4%;c) non riconnettersi alla rete e non aumentare il livello di produzione minimo raggiunto in casodi ridiscesa della frequenza dopo un aumento della stessa oltre il valore di 50,3 Hz (a menoche la frequenza non si attesti per almeno 5 minuti primi ad un valore compreso tra 49.95 Hze 50,05 Hz per il continente, e 49.9 e 50,1 per Sicilia e Sardegna), salvo diversa indicazioneda parte del Gestore.

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 7 di 13figura 1 – Regolazione della potenza attiva immessa in rete in funzione della frequenza7.1.2. AVVIAMENTO E AUMENTO GRADUALE DELLA POTENZA IMMESSA IN RETEL’avviamento di detti impianti deve essere condizionato ad una frequenza di rete stabilizzata equindi non inferiore a 49,9 (49.95) Hz e non superiore a 50,1 (50.05) Hz per le isole (per ilContinente) .Nel caso in cui la riconnessione avvenga automaticamente, il sistema di controllo dell’impiantodovrà consentire la taratura di rientro in un intervallo compreso tra 49 Hz e 51 Hz a step di 0.05Hz; dovrà inoltre essere selezionabile il tempo minimo di permanenza in tale intervalloselezionabile tra 0 e 900 secondi a step di 5 secondi.In tali condizioni la riconnessione deve avvenire aumentando gradualmente la potenza immessarispettando un gradiente positivo massimo non superiore al 20% al minuto della potenza erogabile.Il Gestore è disponibile ad accettare soluzioni equivalenti, proposte dalle Imprese di distribuzionepurché tali da assicurare le stesse prestazioni di cui ai punti precedenti a livello di aggregato.7.2. COMPORTAMENTO DEGLI IMPIANTI DI PRODUZIONE NEI TRANSITORI DI TENSIONEA salvaguardia del sistema elettrico nazionale per evitare perdite incontrollate di generazionedistribuita in concomitanza con guasti sulla rete AAT e AT, che causano abbassamenti di tensionesu aree, vengono prescritti due requisiti:• limiti di funzionamento coerenti con quanto indicato nel paragrafo 5.• capacità dell’impianto di produzione di rimanere connesso alla rete, secondo una curva“tensione – durata” predefinita (Low Voltage Fault Ride Through capability, LFVRT).

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 8 di 137.2.1. INSENSIBILITA’ AGLI ABBASSAMENTI DI TENSIONEGli impianti di produzione statici connessi alle reti MT e BT di potenza nominale ≥ 6 kVA devonoessere in grado di non disconnettersi istantaneamente durante l’abbassamento di tensioneconseguente a un qualsiasi tipo di cortocircuito esterno, monofase o polifase (con e senza terra).In particolare deve essere garantita la connessione alla rete nella zona al di sopra e lungo i puntidella caratteristica (V - t) indicata, dove la tensione V è la tensione ai morsetti dell’impianto diproduzione. I valori indicati sono in percentuale della tensione nominale.Nell’intervallo di durata dell’abbassamento di tensione l’impianto dovrà rimanere connesso allarete, anche se non garantirà il valore di potenza immessa nell’istante immediatamente precedenteal guasto. Al ristabilirsi delle normali condizioni di funzionamento 3 la potenza immessa in retedovrà tornare ad un valore prossimo a quello precedente il guasto, in un tempo non superiore a200 ms.figura 2 – LVRFT (tratta da norma CEI 0-21)8. COMPATIBILITA’ DELLE PROTEZIONI DEGLI IMPIANTI DI PRODUZIONE CON LEESIGENZE DI SISTEMALe protezioni di interfaccia possono interferire negativamente con il bilanciamento del sistemaelettrico nazionale. Per minimizzare tali effetti le predette protezioni devono essere in grado digarantire:il distacco selettivo della GD soltanto per guasti sulle reti MT e/o BT;il mantenimento in servizio della GD per perturbazioni di sistema con variazione transitoriadella frequenza.3 Le normali condizioni sono quelle precedenti l’evento

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 9 di 13Tali protezioni sono gestite dagli Utenti Attivi sotto la vigilanza ed il coordinamento dell’Impresa diDistribuzione. Esse devono operare in accordo con i criteri di selettività descritti nel seguito deldocumento, in modo da :• evitare danni ai generatori tradizionali dovuti a momenti torsionali provocati dalle richiusureimplementate su tale rete in caso di guasti sui collegamenti (per i soli impianti diproduzione tradizionali);• limitare la probabilità di creazione di isole di carico in caso di apertura del tronco in MT;• limitare i disturbi in tensione ad altri utenti in caso di funzionamento in isola.8.1. IMPIANTI DI PRODUZIONE CONNESSI ALLA RETE MTPer gli impianti di produzione connessi alle reti MT, in presenza di segnali logici inviati dall’Impresadi Distribuzione, è sufficiente implementare una regolazione opportuna delle quattro soglie giàattualmente previste nelle Regole Tecniche di Connessione [6].Per quanto riguarda le due soglie di massima frequenza, esse dovranno essere regolate come diseguito:- una soglia restrittiva a 50,3 Hz (con tempo 0,1 s)- una soglia permissiva a 51,5 Hz (con tempo 1,0 s)Per quanto riguarda le due soglie di minima frequenza, esse dovranno essere regolate come diseguito:- una soglia restrittiva a 49,7 Hz (con tempo 0,1 s)- una soglia permissiva a 47,5 Hz (con tempo 4,0 s).Le predette caratteristiche (presenza di due separate regolazioni selezionate da remoto)consentono che la protezione d’interfaccia dell’impianto di produzione operi in maniera opportunacontemperando le esigenze locali con quelle di sistema.Infatti, una perturbazione di sistema (transitorio in sottofrequenza o sovra frequenza che interessauna vasta rete funzionante in regime separato con carico o produzione eccedente) è un fenomenonormalmente caratterizzato da una variazione relativamente lenta del parametro frequenza e da unandamento delle tensioni di tipo simmetrico. Se il fenomeno si presenta con queste caratteristichela finestra restrittiva di frequenza (49,7 – 50,3 Hz) dovrà rimanere inattiva ed il distacco degliimpianti dovrà essere affidato esclusivamente alla finestra di frequenza larga (47,5 – 51,5 Hz).Viceversa, in caso di fenomeni locali (guasto, apertura dell’interruttore di CP o di un IMS lungolinea), l’Impresa di Distribuzione è in grado di comandare l’attivazione delle soglie restrittive,favorendo la disconnessione degli impianti di produzione connessi.In assenza di disponibilità dei segnali di commutazione da remoto, è necessario che gli Utenti Attivisi dotino di un sistema di protezione, sempre basato su informazioni locali, in grado di discriminaretra eventi di sistema ed eventi localizzati nella della rete di distribuzione.Infatti, in caso di guasto locale (cortocircuito tra le fasi o guasto a terra nella rete MT dell’Impresadi Distribuzione), è possibile abilitare l’intervento della finestra di frequenza restrittiva (49,7 – 50,3Hz) correlandone l’attivazione con una delle seguenti funzioni di protezione:o massima tensione omopolare (59N) per il rilevamento dei guasti monofasi e polifasi con terra;

Guida TecnicaCodificaRevisioneAllegato A. 70PaginaN° 01 10 di 13oomassima tensione di sequenza inversa (59INV) per il rilevamento dei guasti bifase isolati daterra;minima tensione di sequenza diretta (27DIR) per il rilevamento dei guasti trifase (e bifase)isolati da terra.La logica di questo sistema di protezione con relè di frequenza a sblocco voltmetrico (il codicenumerico assegnato a questa protezione è 81V) è esposta in Figura 3. In base ad essa il sistemadi protezione installato nell’impianto di produzione è in grado di riconoscere variazioni di frequenzaconseguenti all’apertura dell’interruttore in Cabina Primaria oppure all’apertura di IMS lungo lineain presenza di un guasto nella linea di connessione e di separarsi da essa in tempo breve, primadella eventuale manovra di richiusura automatica rapida, in modo da evitare un parallelo con larete con sfasamenti angolari troppo ampi. Eventuali relè di massima e minima frequenza diversi daquelli propri del sistema di protezione di interfaccia (tipicamente quelli integrati nell’inverter),dovranno essere regolati in modo coerente con quanto sopra stabilito con finestre di intervento piùampie di quelle di tipo permissivo della protezione di interfaccia o, a limite, uguali ad esse.ff < 47,5 Hzf > 51,5 HzScatto ritardato 4,0 sScatto ritardato 1 ,0 sf < 49,7 Hzf > 50,3 HzorVV0> Soglia&Scatto ritardato 0,1 sVi > SogliaorVd< SogliaFigura 3: Logica di funzionamento per attivazione soglie dei relè di frequenza a sblocco voltmetricoLe soluzioni tecniche per la discriminazione degli eventi locali rispetto agli eventi di sistema basatesul rilievo di informazioni legate alla tensione, e quelle prospettate nella norma CEI 0-16, cheutilizzano informazioni provenienti da remoto possono essere utilmente combinate per aumentarel’affidabilità del sistema di protezione come illustrato in figura 4. In esso i segnali da remoto sonofinalizzati:a) all'abilitazione delle soglie di frequenza in parallelo all’azione esercitata dai relè ditensione [Vo>], [Vi>] e [Vd>] ;b) allo scatto diretto dell’interruttore di interfaccia (sistema di telescatto agente sul SPI).

Technical GuidelineGenerating Plants Connected to theMedium-Voltage NetworkGuideline for generating plants’ connection to and paralleloperation with the medium-voltage networkJune 2008 issue

Technical Guideline „Generating plants connected to the medium-voltage network”IntroductionThe present guideline summarizes the essential aspects which have to be taken into considerationfor the connection of generating plants to the network operator’s medium-voltagenetwork. Thus, they shall serve as a basis to the network operator and to the installer in theplanning and decision-making process and provide important information on the plant operationto the observer.This guideline complements that for low voltage and high and extra-high voltage whichtakes the particular characteristics of the different voltage levels individually into consideration.The distinction of the guidelines into voltage levels has turned out to be reasonable asthe specific requirements are too disparate to be combined within one guideline.The present guideline constitutes the third revised version of the VDEW guideline on „Generatingplants connected to the medium-voltage network“ („Eigenerzeugungsanlagen amMittelspannungsnetz“) and transposes the latter into a BDEW guideline. For the revision,account has been taken of the findings obtained from the elaboration of the guidelines onthe connection of renewables-based plants to the high and extra-high voltage network, andthe outline has been reorganized. Furthermore, the requirements under the Renewable EnergySources Act (Erneuerbare-Energien-Gesetz – EEG) have been adequately taken intoconsideration.Like at the high and extra-high voltage level, generating plants supplying medium-voltagenetworks will have to make a contribution to network support in the future. Therefore, inthe event of failures they must not immediately be disconnected from the network as in thepast and have also to make a contribution to voltage stability in the medium-voltage networkduring normal network operation. This has a direct impact on the plants’ design. Thepresent guideline summarizes the essential aspects which have to be taken into considerationfor the connection to the medium-voltage network so as to maintain the security andreliability of network operation in accordance with the provisions of the Energy Industry Actin the light of a growing share of dispersed generating plants, and to enable the limit valuesof voltage quality determined in DIN EN 50160 to be observed.Naturally, this guideline can only refer to the plants’ usual conceptual design. For specialconstruction lines, this guideline shall be applied analogously and by taking the given networkstructure into consideration.

Technical Guideline „Generating plants connected to the medium-voltage network“As a matter of principle, the audio-frequency level caused by the operation of generatingplants must not be reduced by more than 5 % at any point of the medium-voltage networkas compared to the operation without generating plants; consumption and generation installationsshall be taken into consideration according to their audio-frequency impedance.With this reduction of the audio-frequency level by generating plants, it is necessary to takeaccount of the fact that generating plants supplying the network through static inverterswithout filter circuits do normally not cause a substantial reduction of the ripple-controllevel. Where filter circuits or compensating capacitors exist, it is necessary to examinewhether the short-circuit reactance of the customer transformer may give rise to a seriesresonance.Apart from the limitation of the level reduction, it is not allowed to generate inadmissible interferencevoltages. The following rules shall apply in particular:• The interference voltage caused by a generating plant whose frequency correspondsto the locally applied ripple-control frequency or is very close to it, must not exceedthe value of 0.1 % U c.• The interference voltage caused by a generating plant whose frequency lies at theambient frequencies of +/- 100 Hz to the locally applied ripple-control frequency or inits immediate proximity, must not exceed a value of 0.3 % U c.These limit values as well as further details are given in the guidelines on audio-frequencycentralized ripple control („Tonfrequenz-Rundsteuerung“) 6 .Should a generating plant inadmissibly impair the operation of the centralized ripple-controlfacilities, the operator of the generating plant shall take appropriate remedial measureseven if the impairment is noticed at a later date.2.5 Behaviour of generating plants connected to the network2.5.1 Principles of network supportDuring network feed-in, generating plants must be capable of participating in voltage control.A distinction is made between steady-state voltage control and dynamic network support.© BDEW, June 2008 page 20/130

Technical Guideline „Generating plants connected to the medium-voltage network“2.5.1.1 Steady-state voltage controlSteady-state voltage control means voltage control within the medium-voltage network undernormal operating conditions, where slow voltage changes in the distribution network arekept within acceptable limits.If required by the network operator and to meet network requirements, generating plantsmust participate in steady-state voltage control within the medium-voltage network.2.5.1.2 Dynamic network supportDynamic network support means voltage control in the event of voltage drops within thehigh and extra-high voltage network with a view to avoiding unintentional disconnections oflarge feed-in power, and thus network collapse.In the light of the strong increase in the number of generating plants to be connected to themedium-voltage network, the integration of these plants into the dynamic network supportscheme is becoming ever more important. Consequently, these generating plants must generallyparticipate in dynamic network support even if this is not required by the network operatorat the time of the plant’s connection to the network. That means that generatingplants must be able in technical terms• not to disconnect from the network in the event of network faults,• to support the network voltage during a network fault by feeding a reactive currentinto the network,• not to extract from the medium-voltage network after fault clearance more inductivereactive power than prior to the occurrence of the fault.These requirements apply to all types of short circuits (i.e. to single-phase, two-phase andthree-phase short circuits).Just like in the Transmission Code 2007 7 , a distinction is made in these guidelines betweentype-1 and type-2 generating plants with regard to their behaviour in the event of networkdisturbances. A type-1 generating unit exists if a synchronous generator is directly (onlythrough the generator transformer) connected to the network. All other plants are type-2generating units.6„Tonfrequenz-Rundsteuerung, Empfehlung zur Vermeidung unzulässiger Rückwirkungen“,3rd edition 1997, published by VDEW7 TransmissionCode 2007 „Network and System Rules of the German Transmission SystemOperators“, August 2007, published by VDN© BDEW, June 2008 page 21/130

Technical Guideline „Generating plants connected to the medium-voltage network“Concerning type-1 plants, the Transmission Code 2007 is put more precisely in the followingrespect:• If the voltage drops at values above the red border line in figure 2.5.1.2-1, generatingplans must not be disconnected from the network.Grenzkurve SpannungsverlaufU/U cunterer Wert desSpannungsbandes100%70%45%15%0 150 700 1.5003.000Zeit in msZeitpunkt eines StörungseintrittsFigure 2.5.1.2-1:Borderline of the voltage profile at the network connectionpoint of a type-1 generating plantThe following conditions shall apply to type-2 generating plants, taking the TransmissionCode 2007, Section 3.3.13.5, into account:• Generating units must not disconnect from the network in the event of voltage dropsto 0 % U c of a duration of ≤ 150 ms.• Below the blue line shown in Figure 2.5.1.2-2, there are no requirements saying thatgenerating plants have to remain connected to the network.© BDEW, June 2008 page 22/130

Technical Guideline „Generating plants connected to the medium-voltage network“Grenzkurven SpannungsverlaufGrenzlinie 1U/U cGrenzlinie 2unterer Wert desSpannungsbandes= 90% von U c100%70%45%Unterhalb der blauenKennlinie bestehen keineAnforderungen hinsichtlichdes Verbleibens am Netz.30%15%0 150 700 1.5003.000Zeit in msZeitpunkt eines StörungseintrittsFigure 2.5.1.2-2 Borderlines of the voltage profile of a type-2 generating plant atthe network connection pointNote:U means the lowest value of the three line-to-line voltagesVoltage drops with values above the borderline 1 must not lead to instability or to the disconnectionof the generating plant from the network (TC2007; 3.3.13.5, section 13; extendedto asymmetrical voltage drops).If the voltage drops at values above the borderline 2 and below the borderline 1, generatingunits shall pass through the fault without disconnecting from the network. Feed-in of ashort-circuit current during that time is to be agreed with the network operator. In consultationwith the network operator, it is permissible to shift the borderline 2 if the generatingplant’s connection concept requires to do so. Also in consultation with the network operator,a short-time disconnection from the network is permissible if the generating plant can beresynchronized 2 seconds, at the latest, after the beginning of the short-time disconnection.After resynchronization, the active power must be increased with a gradient of at least10% of the nominal capacity per second (TC2007; 3.3.13.5, section 14).Below the borderline 2, a short-time disconnection of the generating plant may be carriedout in any case. Prolonged resynchronization times and lower gradients of the active power© BDEW, June 2008 page 23/130

Technical Guideline „Generating plants connected to the medium-voltage network“increase after resynchronization as compared to those admissible above the borderline 2 arepermitted if they are agreed with the network operator (TC2007, 3.3.13.5, section 15).The behaviour of type-2 generating plants in the case of automatic re-closure is describedmore precisely in Annex B.3.Depending on the concrete technical network conditions, the actual duration of the generatingfacility’s connection to the medium-voltage network can be reduced by requirements ofthe network operator in terms of protection equipment.For all generating plants, the rule shall apply that a current according to the TransmissionCode 2007 is to be supplied to the network for the duration of a symmetrical fault. Concerningunsymmetrical faults, it is not permissible that during the duration of the fault reactivecurrents be fed into the network which give rise to voltages higher than 1,1 U c in non-faultyphases at the network connection point.As a matter of principle, the requirements in terms of dynamic network support apply to allfacilities irrespective of their type and connection variant. They shall be implementedthrough setting of the generating plants’ or units’ control equipment.The network operator shall determine the extent to which generating plants must participatein dynamic network support. A distinction is made between connections• directly via a separate circuit breaker bay to the bus-bar of a transforming station and• in the system operator’s medium-voltage network.A general basic requirement is however that all generating plants remain connected to thenetwork in the case of voltage drops above the borderline in figure 2.5.1.2-1 or the borderlinein figure 2.5.1.2-1. Consequently, the network operator only determines whether or towhich extent a reactive current is to be supplied to the network by the generating facility inthe event of voltage drops.Customer plants with generating plants turning into isolated operation in the event of disturbancesin the higher-voltage network to cover the customer’s own energy demand mustparticipate in network support until they are disconnected from the system operator’s medium-voltagenetwork. Isolated operation scheduled by the customer has to be agreed bycontract with the network operator.© BDEW, June 2008 page 24/130

Technical Guideline „Generating plants connected to the medium-voltage network“2.5.2 Maximum admissible short-circuit currentDue to the operation of a generating plant, the network’s short-circuit current is increasedby the generating plant’s short-circuit current, particularly in the vicinity of the networkconnection point. Therefore, information about the anticipated short-circuit currents of thegenerating plant at the network connection point has to be provided together with the applicationfor connection to the network.To determine a generating plant’s short-circuit current contribution, the following rough valuescan be assumed:• for synchronous generators: eight times the rated current• for asynchronous generators and double-fed asynchronous generators: six times therated current• for generators with inverters: one time the rated current.To ensure correct calculations, the impedances between the generator and the network connectionpoint (customer transformer, lines, etc.) need to be taken into consideration.If the generating plant gives rise to a short-circuit current increase in the medium-voltagenetwork above the rated value, the network operator and the connection owner shall agreeupon appropriate measures, such as limitation of the short-circuit current from the generatingfacility (e.g. by using I s –limiters).2.5.3 Active power outputIt must be possible to operate the generating facility at reduced power output. In the caseslisted below, the network operator is entitled to require a temporary limitation of the powerfeed-in or disconnect the facility:• potential danger to secure system operation,• congestion or risk of overload on the network operator’s network,• risk of islanding,• risk to the steady-state or dynamic network stability,• rise in frequency endangering the system stability,• repairs or implementation of construction measures,© BDEW, June 2008 page 25/130

Technical Guideline „Generating plants connected to the medium-voltage network“• within the scope of generation management/ feed-in management/ network securitymanagement (see „Grundzüge zum Erzeugungsmanagement“ 8 ).The generating plants must be capable of reducing their active power at steps of maximally10 % of the agreed active connection power. This power reduction must be possible in anyoperating condition and from any operating point to a target value given by the networkoperator. This target value is normally preset without steps or in steps, and corresponds toa percentage value related to the agreed active connection power P AV . To date, target valuesof 100 % / 60 % / 30 % / 0 % have proven to be effective. The network operator shallnot interfere in the control of the generating plants. He shall only be responsible for signalling.The reduction of the power feed-in is carried out at the plant operator’s own responsibility.The reduction of the power output to the respective target value must be realized withoutdelay, but within one minute, at the most. A reduction to the target value 10 % must bepossible without automatic disconnection from the network; below 10 % of the agreed activeconnection power P AV , the generating facility may disconnect from the network.All generating units must reduce, while in operation, at a frequency of more than 50.2 Hzthe instantaneous active power (at the time of request; value freeze) with a gradient of40 % of the generator’s instantaneously available capacity per Hertz (see figure 2.5.3-1„Active power reduction in the case of over-frequency“, taken from the Transmission Code2007, Section 3.3.13.3, figure 1 ibid.).The active power may be increased again only if the frequency returns to a value of f ≤50.05 Hz, as long as the actual frequency does not exceed 50.2 Hz. The neutral zone mustbe below 10 mHz.8„Grundzüge zum Erzeugungsmanagement zur Umsetzung des §4 Abs. 3 EEG (status:27/02/2006)“, published by VDN© BDEW, June 2008 page 26/130

Technical Guideline „Generating plants connected to the medium-voltage network“f Netz50,2 HzfNetzΔP=40% PM pro HzΔPΔ PΔP=20PM50,2Hz−f50HzNetzbei 50,2 Hz ≤ f Netz ≤ 51.5 HzP MΔPMomentane verfügbare LeistungLeistungsreduktionf NetzNetzfrequenzIm Bereich 47.5 Hz ≤ f Netz ≤ 50.2 Hz keine EinschränkungBei f Netz ≤ 47.5 Hz und f Netz ≥ 51.5 Hz Trennung vom NetzBild 1Wirkleistungsreduktion bei ÜberfrequenzFigure 2.5.3-1: Active power reduction in the case of over-frequency (fromTransmission Code 2007)2.5.4 Reactive powerWith active power output, it must be possible to operate the generating plant in any operatingpoint with at least a reactive power output corresponding to a active factor at the networkconnection point ofcos ϕ = 0.95 underexcited to 0.95 overexcitedValues deviating from the above must be agreed upon by contract. In the consumer referencearrow system (see Annex B.4), that means operation in quadrant II (under-excited) orIII (overexcited).With active power output, either a fixed target value for reactive power provision or a targetvalue variably adjustable by remote control (or other control technologies) will be specifiedby the network operator in the transfer station. The setting value is eithera) a fixed active factor cos ϕ orb) a active factor cos ϕ (P) orc) a fixed reactive power in MVar ord) a reactive power/voltage characteristic Q(U).© BDEW, June 2008 page 27/130

Technical Guideline „Generating plants connected to the medium-voltage network“The reactive power of the generating plant must be adjustable. It must be possible to passthrough the agreed reactive power range within a few minutes and as often as required. If acharacteristic is specified by the network operator, any reactive power value resulting fromthe characteristic must automatically adapt as follows:• within 10 seconds for the cos ϕ (P)-characteristic and• adjustable between 10 seconds and 1 minute for the Q(U)-characteristic (specified bythe network operator).Figure 2.5.4-1 shows an example of a cos ϕ (P)-characteristic.cos ϕ0.95overexcited1underexci-1P/P n0.95Figure 2.5.4-1: Example of a ϕ (P)-characteristicWith a view to avoiding voltage jumps in the event of fluctuations in active power feed-in, itis advisable to choose a characteristic with continuous profile and limited gradient.Both the chosen approach and the target values shall be determined individually for everygenerating facility by the network operator. The specification can be based on• the agreement of a value or, where applicable, of a schedule• online presetting of target valuesIn the case of online presetting of target values, the new specifications for the working pointof reactive power exchange shall be implemented at the network connection point after oneminute, at the latest.© BDEW, June 2008 page 28/130

Technical Guideline „Generating plants connected to the medium-voltage network“gure 3.2.3.4-2). If the generating plant must participate in dynamic network support by injectionof a reactive current, the relevant protection devices and transformers need to beupgraded by the connection owner and the settings of the generating units’ protection devicesmust be adjusted according to Section 3.2.3.3 (see 3.2.3.4-2).3.2.3.6 Short-circuit protectionThe connection of generating plants to the medium-voltage network is implemented eitherby means of circuit breakers or through an on-load-switch-fuse combination, depending onnetwork conditions and the number and size of generating units.Generating plants connected through a circuit breaker shall be equipped at least with overcurrenttime protection as short-circuit protection. Short-circuit protection of generatingplants connected by means of a combined on-load-switch-fuse is ensured by the fuse.The installation of a distance relay and the relevant voltage transformers is to be taken intoconsideration in the conceptual design, and has to be realized at the network operator’s request.The “retrofitting” option is shown in Figure 3.2.3.4-2 by a broken line.The distance protection device must then act upon the circuit breaker at the transfer pointor, in the case of an on-load-switch-fuse combination, upon the generator-side circuitbreaker.3.2.3.7 Protective disconnection devicesAt the transfer station, the installation of protective disconnection devices is to be takeninto consideration in the conceptual design according to Section 3.2.3.3, and has to be realizedat the network operator’s request. If connected through a circuit breaker, the protectivedisconnection device acts upon the latter or upon the coupling switch, if it is connectedby means of an on-load-switch-fuse combination, the protective device acts upon the generator-sidecircuit breaker or on the coupling switch (see Annex C, Examples of connections).The same protection equipment as for the generating plant’s connection to the bus-bar of atransformer station (cf. Table 3.2.3.3-2) is required at the generating units; only the settingsof the voltage protection devices are dissimilar.The network operator may require super-ordinate protective disconnection equipment forgenerating plants which have a widespread medium-voltage network available and are connectedwith the network operator’s network through a transfer station. The function of thisprotective equipment is to disconnect the entire generating plant from the network if thenetwork voltage or network frequency limits are violated. A circuit breaker has to be generallyprovided for disconnection from the network in this case.© BDEW, June 2008 page 41/130

Technical Guideline „Generating plants connected to the medium-voltage network“Protective disconnection devices of generating units shall be connected at the high or lowvoltageside of the generator transformer. The following settings are recommended as basicparameters:FunctionSetting range ofthe protectionrelayRecommended protectionrelay settingsRise-in-voltage protection U>> 1.00 – 1.30 U n 1.15 U NS *) ≤ 100 ms *)Under-voltage protection U< 0.10 – 1.00 U n 0.80 U NS **) 1 s **)Under-voltage protection U 50.0 – 52.0 Hz 51.5 Hz ≤ 100 msUnder-frequency protection f< 47.5 – 50 Hz 47.5 Hz ≤ 100 msTable 3.2.3.4-1Recommended settings of the protective equipment at the generatingunit for connection of the generating plant to the medium-voltagenetwork.U n is the secondary rated transformer voltage and thus the reference voltage of the protection equipment.U NS is the voltage on the low-voltage side of the generating unit’s generator transformer (U NS = U c / üwith ü = transformation ratio of the generator transformer). Consideration is to be given to the factthat disconnection times are obtained from the sum of setting times and inherent response times ofthe switching device and the protection equipment.*) and **) see remarks on Figure 3.2.3.4-1.The graphic below shows the protection scheme within the transfer station and in the generatingunits if the generating plants are connected to the medium-voltage network.© BDEW, June 2008 page 42/130

Technical Guideline „Generating plants connected to the medium-voltage network“protection equipment installed on the high-voltage side of the network transformer acts on correspondingcircuit breaker of the connected generating plant. Furthermore, inter-tripping of the protectionequipment of the medium-voltage outgoing feeder is required to the relevant circuit breaker ofthe connected generating plant.3.2.4 Test terminalFor the implementation of functional tests on protection equipment, a terminal block withsectionalizer and test sockets has to be provided as interface and mounted at an easily accessibleplace. Its basic structure is shown in Figure 3.2.4-1.The measurement inputs of the protection equipment, the auxiliary supplies and the trippingdevices for coupling switches shall be led via this terminal block. This shall apply aswell if functions of protective disconnection are integrated as a whole or separately intoother appliances (e.g. programmable control). In this case, the appliances shall be mountedor programmed so as to enable the release or the inspection of the protective functions irrespectiveof the generating plant’s operating condition.The type and structure of the test terminal need to be agreed with the network operator.Instead of the test terminal, the network operator may also require that a test socket beused.Figure 3.2.4-1: Basic structure of the test terminal board© BDEW, June 2008 page 45/130