DRAFT PROPOSAL FOR NC RFG REQUIREMENTS OF GENERAL APPLICATION

Transcription

1 DRAFT PROPOSAL FOR NC RFG REQUIREMENTS OF GENERAL APPLICATION September 2017

2 Contents 1 Introduction Proposal for determination of significance [Art 5] Conditions for the choice of the maximum capacity thresholds PGM with 250kW PMACapacity < 1MW Other conditions Type A Frequency stability& Active Power management Frequency withstand capability [Art (a)] Rate Of Change Of Frequency (ROCOF) withstand capability [Art 13.1(b)] Limited Frequency Sensitive Mode Over frequency (LFSM-O) [Art (a)] Admissible maximum power reduction with falling frequency [Art. 13-4] Logical interface to cease active power injection [Art 13-6] Automatic reconnection [Art 13-7] Type B Frequency stability and active power management Remote control of active power [Art 14-2] Fault-ride through for symmetrical and asymmetrical faults [Art 14-3] Information exchange [Art 14-5 (d)] Structural data Scheduled data Real-time measurements Type B - SPGM Reactive power capabilities - SPGM [Art 17-2] Voltage Control SPGM type B[Art 17-2 (b)] Type B PPM Fault-ride through for symmetrical and asymmetrical faults - PPM [Art 20-3] Reactive capabilities - PPM [Art 20-2(a)] Fault Current & dynamic voltage support [Art 20-2 (b)] Post-fault active power recovery [Art 20-3] Type C Frequency stability& Active Power management Limited frequency sensitive mode under frequency (LFSM-U) [Art (c)] Frequency Sensitive Mode [Art d] Frequency restoration control [Art 15-2.e] Real-time monitoring of FSM [Art 15-2.g] Rates of change of active power output [Art 15-6.e] restoration [Art 15-5] Information exchange Voltage control mode (for SPGM and PPM) [Art 19-2(a) and Art 21.3(d)] Type C SPGM Reactive power capability SPGMs [Art 18-2] Voltage control requirements for SPGM type C Type C PPM Synthetic inertia for PPM [Art 21-2] Reactive capabilities - PPM [Art 21-3(a-c)] Voltage control - PPM [Art 21-3(d)] Type D Voltage Control Voltage withstand capability [Art 16-2] Information Exchange Type D -SPGM

3 6.3.1 Fault-ride through for symmetrical and asymmetrical faults SPGM [Art 16-3] Voltage stability SPGM (Art 19-2) Type D -PPM Fault-ride through for symmetrical and asymmetrical faults PPM [Art 22] Acronyms References Appendix - List of non-exhaustive articles for RfG

4 1 Introduction The aim of this document is to synthetize the technical proposal of the regarding the Belgian of the non-exhaustive requirements stated in the NC RfG [1]. This document will serve on its current state as a first draft version of the proposal for requirements of general application (hereafter named as general requirements (NC RfG), in accordance with Art. 7(4) of the NC RfG. Article 7(4) of the NC RfG states that relevant system operator or submits a proposal for general requirements, for approval by the competent entity, within two years of entry into force of the NC RfG, i.e. 17 May A similar requirement is included in the two other connection Network Codes, namely in Art. 6(4) of the NC DCC [2] and in Article 5(4) of the NC [3]. On 17 May 2018, Elia will submit the general requirements proposals on the NC RfG, NC DCC and NC to the competent authority together with the (track change) proposal of an amended Federal Grid Code [4] and a formal proposal on maximum capacity thresholds of type B, C and D powergenerating modules (PGM). Elia will organize beforehand a public consultation for all deliverables in March-April 2018, except for the public consultation on the maximum capacity thresholds B, C and D, that already took place from 19 May till 20 June This approach is in line with the vision of the Belgian Federal Administration (FOD/SPF Energy) [5]. The overview below has for aim to present the various non-exhaustive requirements. However this overview is under construction and is at this moment not yet complete. Only the most relevant, critical and cost-impacting specifications are currently detailed and represent the most recent position of Elia in the ongoing discussions with the stakeholders in each of the relevant topics. During the next months, this document will gradually be completed and presented to stakeholders, especially during the Federal Grid Code workshops until all non-exhaustive general requirements are included. As a result, this document should be considered at this stage as a working and not binding document, focusing on the technical general requirements. This document has not for aim to present legally enforcement ways of these requirements in the Belgian framework (e.g. via derogations, contracts, grid codes, etc.) nor to substitute any legal document or official proposal for modification of the current regulations. The document follows the same logic as in the NC RfG: the proposal is organized per technical topic and per PGM category, assuming the thresholds B, C and D as defined in Elia s (and Synergrid) proposal [6]. If not otherwise specified, each higher category has to fulfil the requirement of a lower one. As an example, the LFSM-O is specified for type A, but it is also valid for category B, C and/or D. The scope of this document contains especially, but is not limited to, the proposal of the non-exhaustive requirements in the NC RfG. To increase its readability, this document might also contain NC exhaustive requirements, proposal of non-exhaustive requirements of the other connection NC, or other specific /regional requirements. For which regards the complete list of non-exhaustive requirements to be proposed as general requirements, Elia is taking as reference the EN-e guidance document on Parameter of Nonexhaustive requirements [7]. This document does not only mention the parameters to be defined per topic, but also which article of each connection NC should be considered as non-exhaustive and who should be seen as relevant system operator to define an proposal. Both the and (C)DSOs can be considered as relevant system operator, depending on the requirement. In most cases, Elia is the relevant system operator, nevertheless the public DSOs are largely involved in developing the proposal or to define their own proposals for units connected to the DSO-grid. To facilitate the of these Network Code requirements, Elia and the public DSOs will align as much as possible, to avoid discrimination between a transmission-, or distribution-connected unit and to increase the simplicity in terms of technical requirements and legal readability. For aspects relevant for CDSOs, Elia has been interacting with CDSOs and Elia would welcome to continue this interaction during the further development of the general requirements. 3

5 2 Proposal for determination of significance [Art 5] The current proposal for determination of significance has been shared with the stakeholders through the Public consultation relating to the proposal for maximum capacity thresholds for types B, C and D power-generating modules running from 19/05/2017 to 20/06/2017 and is available online. A synthesis of the proposed determination of significance is presented here below. In line with the NC RfG art. 5, Elia is proposing the following choice of maximum capacity thresholds for the determination of type: Type A o 0.8kW P Capacity MA < 0.25 MW and V cp < 110kV Type B o 0.25 MW P Capacity MA < 25MW and V cp < 110kV Type C o 25MW P Capacity MA < 75MW and V cp < 110kV Type D o o 75MW P Capacity MA or 0.8kW P Capacity MA and V cp 110kV Where P Capacity MA is the maximum (installed) capacity of the power-generating modules and V cp is the voltage level at the connection point. The parameters for the determination of significance are graphically illustrated in Figure 1 below. 110 kv Type A Type B Type C Type D MW Figure 1 : Graphical representation of the proposed maximum capacity thresholds. However, Elia is proposing to adapt the requirements for power-generating modules (PGM) with a maximum installed capacity lower than 25MW and with a voltage at the connection point higher or equal to 110kV to reflect the specification of the PGM of the same size with a voltage at the connection point lower or equal to 110kV. The justification to this choice is presented in Section The requirements will be adapted via derogation. More specifically the following requirements are proposed: 4

6 Type D PGM having a 0.8kW P Capacity MA < 0.25 MW will follow the same requirements as type A PGM Type D PGM having a 0.25 MW P Capacity MA < 25MW will follow the same requirements as type B PGM. A graphical representation of the expected resulting requirements is presented in Figure 2 below. 110 kv Type D (requir. = A) Type D (requir.= B) Type A Type B Type C Type D MW Figure 2 : Graphical representation of the requirements to be followed by PGM depending on the proposed maximum capacity thresholds considering the results of the intended derogation process. It must be noted that the Modules (PPM), for which the connection point is located offshore should follow the same prescriptions as type D PPM units. A proposal by the relevant to change the thresholds could be made not sooner than three years after the previous proposal [Art 5.3].The proposed thresholds are the result of several rounds of workshops and discussions with the stakeholders and are proposed under the conditions explained in this section. 2.1 Conditions for the choice of the maximum capacity thresholds PGM with 250kW P Capacity MA < 1MW For PGM with 250kW P Capacity MA < 1MW, there is a considerable uncertainty on the expected growth rate on the medium and long term horizon. These PGMs are considered of type B in the proposal but will not be required to respect the full set of requirement for this type. Therefore, the proposal made below for derogations for this group of PGMs should be considered in the context of further evolutions of the generation mix and system needs. If the context changes and the evolutions go in directions that system needs would no longer be adequately covered, more stringent requirements could be required or derogations be repealed (or not prolonged) or even the maximum capacity thresholds be revised. Only if such a flexible approach is considered acceptable, Elia and the DSOs can agree to seek derogations for some specific requirements and can consider not using, in the future, the option to retroactively request new investments on existing installations to meet the system needs. More specifically it is proposed that for the following requirements a request for derogation is submitted by the relevant system operator or the relevant (in line with NC RfG art. 63). The initial duration of the derogation is intended to be fixed to five years. After this period a reassessment of the need for the derogation will be performed. Robustness o o o 14(3)a&b - Fault Ride Through (FRT). 17(3) - Providing post-fault active power recovery (SPGM) 20(2)b&c. - Providing fast fault current (PPM) 5

7 o 20(3)a&b. - Providing post-fault active power recovery (PPM) Elia expects support from all the stakeholders for defining and defending the process of derogation Other conditions For type C Synchronous Power Generating Modules (SPGM), stricter requirements than foreseen by the NC RfG for which regards voltage regulations will be necessary. Elia will request Automatic Voltage Regulation (AVR), Over Excitation Limiter (OEL), Under Excitation Limiter (UEL) and Power Stabilizer (PSS) functions. The activation and tuning of the PSS function will be required depending on the connection point, size and the characteristic of the SPGM. This approach is in line with the Implementation Guidance Document, proposed and submitted by EN-e, for of the network codes on grid connection (IGD) on Parameters of Nonexhaustive requirements which recommends site specific of the requirement 19(2)b.(v) Closed Distribution s (CDS) requirements will be aligned, to the greatest possible extent, to the ones of Demand Facilities and DSO. 6

8 3 Type A 3.1 Frequency stability& Active Power management In general all frequency related parameters are being coordinated between s in the CE synchronous area to guaranty fair contribution among all control areas power generation units and overall resilience and stability of the system. A final guidance of requirements will be published by the CNC group of EN-e for each synchronous area. Further studies to assess the adequacy of the coordinated requirements might be executed by EN/e SPD inter- groups Frequency withstand capability [Art (a)] Definition of the non-exhaustive requirements related to frequency withstand capability coordinated between s in the CE synchronous area Rate Of Change Of Frequency (ROCOF) withstand capability [Art 13.1(b)] Definition of the non-exhaustive requirements related to RoCoF withstand capability is coordinated between s in the CE synchronous area Limited Frequency Sensitive Mode Over frequency (LFSM-O) [Art (a)] Definition of the non-exhaustive requirements related to LFSM-O function is coordinated between s in the CE synchronous area Admissible maximum power reduction with falling frequency [Art. 13-4] Definition of the non-exhaustive requirements related to admissible maximum power reduction with falling frequency is coordinated between s in the CE synchronous area Logical interface to cease active power injection [Art 13-6] This specification is site specific and is to be agreed with the relevant system operator (CDSOs, DSOs or Elia) on a case by case level Automatic reconnection [Art 13-7] This is a site specific requirement. Definition of the non-exhaustive requirements related to automatic reconnection and gradient of active power increase is coordinated between s in the CE synchronous area. 7

9 Voltage [pu] 4 Type B In addition to the specifications for type A, the following is requested. 4.1 Frequency stability and active power management Remote control of active power [Art 14-2] The requirement for the control of active power is defined as site specific. It has to be agreed with the relevant system operator on a case to case basis. 4.2 Fault-ride through for symmetrical and asymmetrical faults [Art 14-3] This requirement should be met at the point of common coupling (POCC) This requirement should not be applicable to units of type B with a maximum installed capacity lower than 1MW 1. The SPGM should be able to support the network during fast transient voltages and network shortcircuits for which the profile of the voltage versus time is referred as Fault-Ride-Through (FRT). SPGM shall fulfil the requirements in the figure below, where the SPGM shall remain connected to the grid as long as the voltage of the phase having the lower voltage is above the profile. It is recommended however to remain connected as long as the technical capability of the PGM would allow. The same profile applies for asymmetrical faults. Proposal LVRT vs NC PGM Type B&C 1 0,9 0,8 0,7 0,6 0,5 0,4 0,3 0,2 0,1 0-0,5 0,5 1,5 2,5 Time [s] Current LVRT NC less stringent NC most stringent Proposal Figure 3: LVRT requirement for PGM type B and C 4.3 Information exchange [Art 14-5 (d)] The discussion on the precise list of data/measures to exchange in real-time is still ongoing. According to the feedback received from stakeholders on this topic some requirements may be difficult to meet for several installations. Elia has taken note of this feedback and take it into consideration when making the final proposal for the General s. 1 To enforce this, a request for derogation will be submitted by the relevant system operator or the relevant (in line with NC RfG art. 63). The initial duration of the derogation is intended to be fixed to five years. After this period a reassessment of the need for the derogation will be performed. 8

10 4.3.1 Structural data See Excel file communicated during Experts group. 9

11 4.3.2 Scheduled data Type B connected to (legal obligation general application) - active power output and active power reserves amount and availability, on a dayahead and intra-day basis; - without any intentional delay, any scheduled unavailability or active power capability restriction; - any forecasted restriction in the reactive power control capability; and Type B connected to DSO (only when specific contract is signed (i.e. CIPU) size specific) - its scheduled unavailability, active power restriction and its forecasted scheduled active power output at the connection point; - any forecasted restriction in the reactive power control capability; and Real-time measurements Type B connected to - position of the circuit breakers at the connection point or another point of interaction agreed with the ; - active and reactive power at the connection point or another point of interaction agreed with the ; and - in the case of power generating facility with consumption other than auxiliary consumption net active and reactive power. Type B connected to DSO - active and reactive power flows at the connection point. 4.4 Type B - SPGM Reactive power capabilities - SPGM [Art 17-2] This requirement should be met at the point of common coupling (POCC). For SPGMs of type B, the requirement at the connection point for the reactive power provision capability is determined by the Q-P profile represented in Figure 4 where the limitations are based on nominal current at high active power output and by a reactive power (Q) limited to -25% and +48% of PD, where PD is the maximum active power that can be produced in case of the maximum requested reactive power output (hence equal to 0.9*Snom). This figure should be respected at nominal voltage. Note that the available capability of the SPGM (which could be wider than the minimum requirement) should be communicated, demonstrated and considered as the Q-P profile of the SPGM. P Required P D S nom -25% P D 48% P D Q Figure 4: Capability curve for SPGM type B 10

12 Voltage [pu] Voltage Control SPGM type B[Art 17-2 (b)] With regard to the voltage control system, a synchronous power-generating module of type B shall be equipped with a permanent automatic excitation control system that can provide constant alternator terminal voltage at a remotely selectable setpoint without instability over the entire operating range of the synchronous power-generating module. This means that this synchronous power-generating module shall be capable to control voltage with 2 control modi: Qfix: maintain a constant reactive power within the P/Q capabilities of Figure 4 Q(U): maintain a constant alternator voltage within the P/Q capabilities of Figure Type B PPM Fault-ride through for symmetrical and asymmetrical faults - PPM [Art 20-3] This requirement should be met at the point of common coupling (POCC). This requirement should not be applicable to units of type B with a maximum installed capacity lower than 1MW 2. The PPM should be able to support the network during fast transient voltages and network shortcircuits for which the profile of the voltage versus time is referred as Fault-Ride-Through (FRT). PPM shall fulfil the requirements in Figure 5: LVRT requirement for PPM type B and C (the evolution of the minimum voltage at the Connection Point), where the PPM shall remain connected to the grid as long as the voltage of the phase having the lower voltage is above the profile of Figure 5. It is recommended however to remain connected as long as the technical capability of the PPM would allow. The same profile applies for asymmetrical faults. Proposal LVRT vs NC PPM Type B&C 1 0,9 0,8 0,7 0,6 Current LVRT 0,5 NC less stringent 0,4 0,3 NC most stringent 0,2 Proposal 0,1 0-0,5 0,5 1,5 2,5 Time [s] Figure 5: LVRT requirement for PPM type B and C 2 To enforce this, a request for derogation will be submitted by the relevant system operator or the relevant (in line with NC RfG art. 63). The initial duration of the derogation is intended to be fixed to five years. After this period a reassessment of the need for the derogation will be performed. 11

13 4.5.2 Reactive capabilities - PPM [Art 20-2(a)] This requirement should be met at the point of common coupling (POCC). For PPMs of type B, the requirement at the connection point for the reactive power provision capability is determined by the Q-P profile represented in Figure 6 where the limitations are based on nominal current at high active power output and by a power factor (cos(phi)) defined by the 2 points at Q= -30% and +33% of PD, where PD is the maximum active power that can be produced in case of the maximum requested reactive power output (hence equal to 0.95*Snom). This figure should be respected at nominal voltage. Note that, the available capability of the PPM (which could be wider than the minimum requirement) should be communicated, demonstrated and considered as the Q-P profile of the PPM. P Required P D S nom -30% P D 33% P D Q Figure 6: Capability curve for PPM type B In case the PPM has already the capability of voltage regulation, one should not refuse the relevant system operator to make use of it. In this case, the settings of the controllers should be agreed with the relevant system operator Fault Current & dynamic voltage support [Art 20-2 (b)] This requirement should not be applicable to units of type B with a maximum installed capacity lower than 1MW 3. The PPM shall be able to inject/absorb additional reactive current compared to the pre-fault state during low and high voltage conditions up to the maximum of its capability. The additional injected/absorbed reactive current shall be function of the positive sequence voltage at the Connection Point. The requested additional reactive current behavior injection is illustrated in Figure 7 For voltages within the deadband [ V act, V + act ] the PPM should follow the normal voltage control mode. The injection or absorption of additional reactive current shall be delivered by the PPM with a minimal delay from the detection of the over/undervoltage, t Iq act.the functionality should remain active for a minimum time of t Iq on and can be deactivated if the voltage returns and remains within [ V act, V + act ] for a time longer than t Iq off. The parameters of this functionality lying within the normal operational range of the installation as well as the delays of activation, deadband and duration of the activation are to be agreed on a case by case way by the relevant system operator in with the relevant. 3 To enforce this, a request for derogation will be submitted by the relevant system operator or the relevant (in line with NC RfG art. 63). The initial duration of the derogation is intended to be fixed to five years. After this period a reassessment of the need for the derogation will be performed. 12

14 I I I q pre fault q q pre fault Iq MA I q V ACT V MA MA V ACT V V V V V pre fault pre fault min I q Figure 7: Injection of additional reactive current Post-fault active power recovery [Art 20-3] This requirement should not be applicable to units of type B with a maximum installed capacity lower than 1MW 4. The parameters of this functionality and its activation should be agreed with the relevant. 4 To enforce this, a request for derogation will be submitted by the relevant system operator or the relevant (in line with NC RfG art. 63). The initial duration of the derogation is intended to be fixed to five years. After this period a reassessment of the need for the derogation will be performed. 13

15 5 Type C In addition to the specifications for type B, the following is requested. 5.1 Frequency stability& Active Power management Limited frequency sensitive mode under frequency (LFSM-U) [Art (c)] Definition of the non-exhaustive requirements related to LFSM-U withstand capability is coordinated between s in the CE synchronous area Frequency Sensitive Mode [Art d] Definition of the non-exhaustive requirements related to FSM capability is coordinated between s in the CE synchronous area Frequency restoration control [Art 15-2.e] Specifications aligned with synchronous area s in compliance with the operation guidelines (Articles 154, 158, 161, 165) [9] and currently applicable requirement of Elia Real-time monitoring of FSM [Art 15-2.g] Defined coherently as per the Operation Guidelines (Article 47) [9] and currently applicable requirement of Elia Rates of change of active power output [Art 15-6.e] Minimum and maximum active power ramping limits (upward and downward) are to be defined site specifically taking into consideration the prime mover technology in compliance the system operation guidelines [9]. 5.2 restoration [Art 15-5] Different from the current Federal Grid code [4], the NC asks for more strict behaviour for system restoration. More specifically with regard to quick re-synchronisation capability: In case of disconnection of the power-generating module from the network, the powergenerating module shall be capable of quick re-synchronisation in line with the protection strategy agreed between the relevant system operator in with the relevant and the power-generating facility; a power-generating module with a minimum resynchronisation time greater than 15 minutes after its disconnection from any external power supply must be ed to trip to houseload from any operating point in its P-Q-capability diagram. In this case, the identification of houseload operation must not be based solely on the system operator's switchgear position signals; power-generating modules shall be capable of continuing operation following tripping to houseload, irrespective of any auxiliary connection to the external network. The minimum operation time shall be specified by the relevant system operator in with the relevant, taking into consideration the specific characteristics of prime mover technology. 5.3 Information exchange See Excel file communicated during Experts group. Current practice is already almost 100% in line with Network Codes. 5.4 Voltage control mode (for SPGM and PPM) [Art 19-2(a) and Art 21.3(d)] 14

16 This requirement should be met at the point of common coupling (POCC). These specifications are given in accord with the FGC Article 69. The PMG of type C and D are considered regulating units. They must be able to adapt their reactive power injected at the Connection Point: Automatically in case of slow or fast variations of the grid voltage. This has to happen according to a reactive droop (FGC Article 73); Through change of the controller setpoint on request of the Operator. This request is quantified in MVAr measured at the Connection Point. The change of setpoint shall be initiated immediately after reception of the request; Reactive power exchange with the Network to control the voltage covering at least the 0.90 to 1.10 pu voltage range should be in steps not greater than 0.01 pu; The Reactive Power output shall be zero when the grid Voltage value at the Connection Point equals the Voltage Setpoint. Upcc (p.u.) 1pu Reactive droop Qmin 0 Qmax Figure 8 Principle of the voltage and reactive power control Automatic voltage control has to fulfil a reactive droop requirement (Figure 8). On request of the Operator, the setpoint of the controller can be modified in real-time, and the operating point is to be shifted to a parallel line (dashed) with the same slope (illustrated in Figure 8). The control loop gain will be agreed between the Operator and the PGM operator (before first energization) so that α_eq lies between 18 and 25, as expressed in the following: Qnet 0,45 Pnom _ eq Unet Unorm, exp Where U net is the voltage measured at the Connection Point U norm,exp is the normal exploitation voltage at the Connection Point Q net is the injected reactive power measured at the Connection Point 5.5 Type C SPGM Reactive power capability SPGMs [Art 18-2] This requirement should be met at the point of common coupling (POCC). All SPGMs of type C (but also type D) should be compliant with the requested reactive power capabilities shown in the U-Q/Pmax diagram, shown in Figure 9. For every connection demand, it should be proven that the SPGM is able to operate within the range shown in the figure. The value of 1.118pu should be considered as 1.05pu in case of connection to voltage level above 300kV. 15

17 Figure 9: Capability curve for SPGM type C and D Voltage control requirements for SPGM type C In line with the current federal grid code (art 75) [4] for which regards the functionalities and parameter settings of the automatic voltage regulator with regard to steady-state voltage and transient voltage control and the specifications and performance of the excitation control system. The latter shall include: - bandwidth limitation of the output signal to ensure that the highest frequency of response cannot excite torsional oscillations on other power-generating modules connected to the network; - an underexcitation limiter to prevent the AVR from reducing the alternator excitation to a level which would endanger synchronous stability;an overexcitation limiter to ensure that the alternator excitation is not limited to less than the maximum value that can be achieved whilst ensuring that the synchronous power-generating module is operating within its limits; - a stator current limiter; - a Power Stabilizer (PSS) function to attenuate power oscillations, requested by the relevant (site specific, i.e. the activation and tuning of the PSS function will be agreed depending on the connection point, size and the characteristic of the SPGM.) 5.6 Type C PPM Synthetic inertia for PPM [Art 21-2] Synthetic inertia functionality is not required for the current Grid Code due low maturity of the available technology and limitations in term of minimum time response which could result in adverse effects Reactive capabilities - PPM [Art 21-3(a-c)] This requirement should be met at the point of common coupling (POCC). A type C PPM shall be capable to deliver reactive power within the Q-P profile described in Figure 10. This profile has an obligated span of 0.6p.u. with regards to Q/Pnom, but can move within an area of [- 0.3p.u., +0.35p.u.] when accepted by the relevant, based on the connection point, size and the characteristic of the PPM.) For every connection demand, it should be proven that the PPM is able to operate at least within this figure. 16

18 Figure 10: Reactive power capability for a Type C and D PPM Voltage control - PPM [Art 21-3(d)] This requirement should be met at the point of common coupling (POCC). The PPM shall be capable of providing reactive power automatically by either voltage control mode, reactive power control mode or power factor control mode. 17

19 6 Type D In addition to the specifications for type C, the following is requested. 6.1 Voltage Control Voltage withstand capability [Art 16-2] This requirement should be met at the point of common coupling (POCC). The following voltage withstand capability are proposed in line with the RfG. Voltage ranges below 300kV Voltage ranges above 300kV Voltage Range Time period for operation 0.85 pu 0.90 pu 60 minutes 0.90 pu pu Unlimited pu 1.15 pu 20 minutes 0.85 pu 0.90 pu 60 minutes 0.90 pu 1.05 pu Unlimited 1.05 pu 1.10 pu 20 minutes The following base values are to be considered: 400kV 220kV 150kV 110kV 70kV 36kV 6.2 Information Exchange See Excel file communicated during Experts group. No specific question anymore from stakeholders. 6.3 Type D -SPGM Fault-ride through for symmetrical and asymmetrical faults SPGM [Art 16-3] This requirement should be met at the point of common coupling (POCC). The SPGM should be able to support the network during fast transient voltages and network shortcircuits for which the profile of the voltage versus time is referred as Fault-Ride-Through (FRT). SPGM shall fulfil the requirements in the Figure below (the evolution of the minimum voltage at the Connection Point), where the SPGM shall remain connected to the grid as long as the voltage of the phase having the lower voltage is above the profile of Figure 11. It is recommended however to remain connected as long as the technical capability of the SPGM would allow. 18

20 Voltage [pu] Proposal FRT vs NC SPGM Type D 1,1 1 0,9 0,8 0,7 0,6 0,5 0,4 0,3 0,2 0,1 0-0,5 0,5 1,5 2,5 Time [s] Current FRT Current LVRT NC most stringent NC less stringent Proposal Figure 11: LVRT requirement for SPGM type D Voltage stability SPGM (Art 19-2) In line with the current federal grid code (art 75) [4] for which regards the functionalities and parameter settings of the automatic voltage regulator with regards to steady-state voltage and transient voltage control and the specifications and performance of the excitation control system. The latter shall include: i. bandwidth limitation of the output signal to ensure that the highest frequency of response cannot excite torsional oscillations on other power-generating modules connected to the network; ii. an underexcitation limiter to prevent the AVR from reducing the alternator excitation to a level which would endanger synchronous stability; iii. an overexcitation limiter to ensure that the alternator excitation is not limited to less than the maximum value that can be achieved whilst ensuring that the synchronous powergenerating module is operating within its limits; iv. a stator current limiter; and v. a PSS function to attenuate power oscillations, requested by the relevant (site specific, i.e. The activation and tuning of the PSS function will be required depending on the connection point, size and the characteristic of the SPGM) 6.4 Type D -PPM Fault-ride through for symmetrical and asymmetrical faults PPM [Art 22] This requirement should be met at the point of common coupling (POCC). The PPM should be able to support the network during fast transient voltages and network shortcircuits for which the profile of the voltage versus time is referred as Fault-Ride-Through (FRT). PPM shall fulfil the requirements in Figure 12, where the PPM shall remain connected to the grid as long as the voltage of the phase having the lower voltage is above the profile of Figure 6. It is recommended however to remain connected as long as the technical capability of the PPM would allow. The same profile applies for asymmetrical faults. 19

21 Voltage [pu] Proposal FRT vs NC PPM Type D 1 0,9 0,8 0,7 0,6 0,5 0,4 0,3 0,2 0,1 0-0,5 0,5 1,5 2,5 Time [s] Current FRT Current LVRT NC most stringent NC less stringent Proposal Figure 12: LVRT requirement for PPM type D. 20

22 7 Acronyms SGU PGM LFSM LVRT PPM Significant Grid User Power Generating Module Limited Frequency Sensitive Mode Low Voltage Ride Through Module SPGM Synchronous Power-Generating Modules RfG NCC 8 References for Grid connection of generators Elia National Control Center [1] Network Code s for Generators or NC RfG : Commission Regulation (EU) 2016/631 of 14 April 2016 establishing a network code on requirements for grid connection of generators, [2] Network Code on Demand Connection or NC DCC : Commission Regulation (EU) 2016/1388 of 17 August 2016 establishing a Network Code on Demand Connection, [3] Network Code on High Voltage Direct Current or NC : Commission Regulation (EU) 2016/1447 of 26 August 2016 establishing a network code on requirements for grid connection of high voltage direct curret systems and direct current-connected power park modules, [4] Federal Technical Reglement- 19 DECEMBER Koninklijk besluit houdende een technisch reglement voor het beheer van het transmissienet van elektriciteit en de toegang ertoe, Arrêté royal établissant un règlement technique pour la gestion du réseau de transport de l électricté et l accès à celui-ci, 2/grid-codes/Technisch%20reglement%20Federaal% pdf [5] Presentation FOD/SPF Energy in WG Belgian Grid (in Dutch): -for_federalgridcode.pdf Minutes of Meeting WG Belgian Grid 7 th March 2017 (in French): INAL_WRITTEN-APPROVED.pdf [6] Public consultation document related to the maximum capacity thresholds of Type B, C and D PGM: group/public%20consultations/2017/ _public-consultation-maimum- CAPACITY-THRESHOLDS_ENG.pdf [7] EN-E Guidance document for for network codes on grid connection : Parameters of Non-exhaustive requirements, 16 November 2016: _IGD_General%20guidance%20on%20parameters_for%20publication.pdf [8] Frequency Stability Evaluation Criteria for the Synchronous Zone of Continental Europe, SPD WG, March 2016 [9] Operation Guidelines : Commission Regulation (EU) 2017/1485 of 2 August 2017 establishing a guideline on electricity transmission system operation, 21

23 9 Appendix - List of non-exhaustive articles for RfG This list is extracted from EN-E Guidance document for for network codes on grid connection : Parameters of Nonexhaustive requirements [7] 22

24 FREQUENCY ISSUES Parameters of Non-exhaustive requirements Table 1 RfG Non-Exhaustive s Type Non-Exhaustive Non- Mandatory Article Applicability Parameters to be defined Timing of proposal Proposer FREQUENCY RANGES RATE OF CHANGE OF FREQUENCY (ROCOF) WITHSTAND CAPABILITY 13.1.a.(i) A, B, C, D 13.1.a.(ii) A, B, C, D 13.1.(b) A, B, C, D Time period for operation in the frequency ranges Continental Europe Hz and Hz Nordic: Hz GB: Hz Ireland: Hz Baltic: Hz and Hz and 51-51,5 Hz Agreement on wider frequency ranges, longer minimum times for operation or specific requirements for combined frequency and voltage deviations - Maximum ROCOF for which the Power Generating Module (PGM) shall stay connected specify ROCOF of the loss of main protection plant Range CNC agreement between the RSO (DSO or ), in with the, and the Power Generating Facility Owner (PGFO) with the LIMITED FREQUENCY SENSITIVE MODE (LFSM)-O ADMISSIBLE ACTIVE POWER REDUCTION FROM MAIMUM OUTPUT WITH FALLING FREQUENCY 13.2.(a) A, B, C, D 13.2(b) A 13.2(f) A, B, C, D 13.4 A, B, C, D 13.5 A, B, C, D Frequency threshold and droop settings Use of automatic disconnection and reconnection Expected behaviour of the PGM once the minimum regulating level is reached Admissible active power reduction from maximum output with falling frequency definition of the ambient conditions applicable when defining the admissible active power reduction and take Value before plant commissioning and to be reselected as appropriate using the capabilities defined at CNC Value and criteria - CNC CNC CNC and reviewed in due time for plant CNC and reviewed in due time for EN-E AISBL Avenue de Cortenbergh Brussels Belgium Tel Fax info@entsoe.eu www. entsoe.eu

25 Parameters of Non-exhaustive requirements Type Non-Exhaustive Non- Mandatory LOGIC INTERFACE 13.6 A, B, C, D AUTOMATIC CONNECTION TO THE NETWORK Article Applicability Parameters to be defined 13.7 A, B, C, D LOGIC INTERFACE 14.2.b B, C, D FREQUENCY STABILITY 15.2.(a) C, D account of the technical capabilities of power-generating modules s for the additional equipment necessary to allow active power output to be remotely operable Conditions for automatic connection to the network, including: - frequency ranges and corresponding delay time - Maximum admissible gradient of increase in active power output s for the equipment necessary to make the logic interface (to cease active power output) remotely operable Time period for reaching x% of the target output Timing of proposal plant plant CNC plant CNC Range CNC Proposer RSO RSO LFSM-U 15.2.c C, D Definition of the frequency threshold and droop C, D Definition of Pref Adjustable Setting In due time for plant and to be reselected as appropriate using the capabilities defined at CNC CNC Range CNC FREQUENCY SENSITIVE MODE 15.2.d.(i) 15.2.d.(iii ) C, D C, D 15.2.d.(iv) C, D Parameters of the Frequency Sensitive Mode (FSM): - Active power range related to maximum capacity - Frequency response insensitivity - Frequency response dead band - Droop Maximum admissible full activation time Maximum admissible initial delay for power generating modules without inertia Adjustable Setting In due time for plant and to be reselected as appropriate using the capabilities defined at CNC CNC CNC EN-E AISBL Avenue de Cortenbergh Brussels Belgium Tel Fax info@entsoe.eu www. entsoe.eu

26 VOLTAGE ISSUES Parameters of Non-exhaustive requirements Type Non-Exhaustive FREQUENCY RESTORATION CONTROL REAL-TIME MONITORING OF FSM RATES OF CHANGE OF ACTIVE POWER OUTPUT SYNTHETIC INERTIA CAPABILITY FOR POWER PARK MODULE (PPM) Non- Mandatory Article Applicability Parameters to be defined 15.2.d.(v) 15.2.e 15.2.g 15.6.e C, D C, D C, D C, D 21.2 PPM: C, D time period for the provision of full active power frequency response Specifications of the Frequency Restoration Control List of the necessary data which will be sent in real time definition of additional signals Definition of the minimum and maximum limits on rates of change of active power output (ramping limits) in both an up and down direction, taking into consideration the specific characteristics of the prime mover technology Definition of the operating principle of control systems to provide synthetic inertia and the related performance parameters Timing of proposal CNC CNC plant plant CNC and reviewed in due time for plant CNC Proposer RSO (DSO or ) or RSO (DSO or ) or with the FAULT RIDE THROUGH CAPABILITY ACTIVE POWER CONTROLLABILTY AND CONTROL RANGE 14.3.a B, C, D Voltage-against-time profile 14.3.a B, C, D pre-fault and post-fault conditions 14.3.b B, C, D Voltage-against-time profile for asymmetric faults 16.3.a.(i) D voltage-against-time profile 16.3.a.(ii) 16.3.c 15.2.a D D C, D pre-fault and post-fault conditions Voltage-against-time profile for asymmetric faults Time period to reach the adjusted active power set point Tolerance applying to the new set point and the time to reach it. CNC CNC CNC CNC CNC CNC CNC RSO (DSO or ) or AUTOMATIC DISCONNECTION DUE TO VOLTAGE LEVEL VOLTAGE RANGES 15.3 C, D 16.2.a.(i) D Voltage criteria and technical parameters at the connection point for automatic disconnection For Continental Europe time period for operation in the voltage range 1,118 pu-1,15 pu for PGM connected between 110kV and 300 kv RSO (DSO or ), in with the 16.2.a.(ii) D Determination of shorter time periods in the event of simultaneous overvoltage and under frequency or simultaneous under voltage and over frequency CNC relevant EN-E AISBL Avenue de Cortenbergh Brussels Belgium Tel Fax info@entsoe.eu www. entsoe.eu

27 Parameters of Non-exhaustive requirements Type Non-Exhaustive Non- Mandatory Article Applicability Parameters to be defined 16.2.a.(iii) D For Spain time period for operation in the voltage range 1,05 pu-1,0875 pu for PGMs connected between 300kV and 400 kv may be specified as unlimited Timing of proposal Proposer 16.2.a.(v) D For Baltic voltage ranges and time period for operation may be specified in line with continental Europe for facilities connected for 400 kv 16.2.b D Wider voltage ranges or longer minimum time periods for operation may be agreed. agreement between the RSO and the PGFO, in with the REACTIVE POWER CAPABILITY FOR SYNCHRONOUS PGM SUPPLEMENTARY REACTIVE POWER FOR SYNCHRONOUS PGM REACTIVE POWER CAPABILITY AT MAIMUM CAPACITY FOR SYNCHRONOUS PGM VOLTAGE STABILITY FOR SYNCHRONOUS PGM REACTIVE POWER CAPABILITY FOR PPM 17.2.a 18.2.a 18.2.b.(i) 18.2.b.(iv) 19.2.b.(v) 20.2.a Synchronous B, C, D Synchronous C, D Synchronous C, D Synchronous C, D Synchronous D PPM: B, C, D Capability to supply or absorb reactive power Definition of supplementary reactive power to compensate for the reactive power demand of the high-voltage line or cable when the connection point is not located at the HV side of the step-up transformer Definition of a U-Q/Pmax-profile at maximum capacity appropriate timescale to reach the target value Power threshold above which a PSS function is to be specified Capability to supply or absorb reactive power Range -CNC Range - CNC Range of capability - CNC Value -CNC Value -CNC Range of capability - CNC RSO RSO with the RSO RSO EN-E AISBL Avenue de Cortenbergh Brussels Belgium Tel Fax info@entsoe.eu www. entsoe.eu

28 Parameters of Non-exhaustive requirements Type Non-Exhaustive FAST FAULT CURRENT INJECTION FOR PPM SUPPLEMENTARY REACTIVE POWER FOR PPM REACTIVE POWER CAPABILITY AT MAIMUM CAPACITY FOR PPM REACTIVE POWER CAPABILITY BELOW MAIMUM CAPACITY FOR PPM REACTIVE POWER CONTROL MODES FOR PPM PRIORITY TO ACTIVE OR REACTIVE POWER CONTRIBUTION FOR PPM Non- Mandatory Article Applicability Parameters to be defined 20.2.b 20.2.c PPM: B, C, D PPM: B, C, D 21.3.a PPM: C, D 21.3.b 21.3.c.(i) 21.3.c.(ii) 21.3.c.(iv) 21.3.d.(iv) 21.3.d.(vi) 21.3.d.(vii ) 21.3.e PPM: C, D PPM: C, D PPM: C, D PPM: C, D PPM: C, D PPM: C, D PPM: C, D Specifications of: - how and when a voltage deviation is to be determined as well as the end of the voltage deviation - Fast fault current characteristics - Timing and accuracy of the fast fault current, which may include several stages during a fault and after its clearance Specifications for asymmetrical current injection, in case of asymmetric faults (1-phase or 2- phase) Definition of supplementary reactive power for a PPM whose connection point is not located at the high-voltage terminals of its step-up transformer nor at the terminals of the high-voltage line or cable to the connection point at the PPM, if no step-up transformer exists Definition of a U-Q/Pmax-profile at maximum capacity definition of a P-Q/Pmax-profile below maximum capacity appropriate timescale to reach the target values In voltage control mode: t1 = time within which 90% of the change in reactive power is reached t2 = time within which 100% of the change in reactive power is reached In power factor control mode: - Target power factor - Time period to reach the set point - Tolerance Specifications of which of the above three reactive power control mode options and associated set points is to apply, and what further equipment is needed to make the adjustment of the relevant set point operable remotely; Specification of whether active power contribution or reactive power contribution has priority during faults for which fault-ridethrough capability is required. Timing of proposal Values -CNC Value -CNC Range -CNC Range of capability - CNC Range of capability- CNC Values - CNC Ranges - CNC in due time for plant CNC Proposer with the with the RSO with the with the RSO RSO RSO RSO, in with the and the PGFO relevant EN-E AISBL Avenue de Cortenbergh Brussels Belgium Tel Fax info@entsoe.eu www. entsoe.eu

29 SYSTEM RESTORATION Parameters of Non-exhaustive requirements Type Non-Exhaustive VOLTAGE RANGES FOR OFFSHORE PPM Non- Mandatory Article Applicability Parameters to be defined 25.1 Offshore For Continental Europe time period for operation in the voltage range 1,118 pu-1,15 pu for PGM connected between 110kV and 300 kv Timing of proposal Proposer VOLTAGE CONTROL SYSTEM FOR SYNCHRONOUS PGM 19.2.a Synchronous D - Parameters and settings of the components of the voltage control system - Specifications of the AVR Ranges - in due agreement between the PGFO and the RSO, in with the 25.1 Offshore For Continental Europe time period for operation in the voltage range 1,118 pu-1,15 pu, 1,05pu- 1,10pu for PGM For Nordic time period for operation in the voltage range 1,05pu-1,10pu for PGM VOLTAGE RANGES 16.2.a.(iii) Offshore For Spain time period for operation in the voltage range 1,05 pu-1,0875 pu for PGMs connected between 300kV and 400 kv may be specified as unlimited 16.2.a.(v) Offshore For Baltic voltage ranges and time period for operation may be specified in line with continental Europe for facilities connected for 400 kv REACTIVE POWER CAPABILITY AT MAIMUM CAPACITY FOR OFFSHORE PPM CAPABILITY OF RECONNECTION AFTER AN INCIDENTAL DISCONNECTION CAUSED BY A NETWORK DISTURBANCE BLACK START CAPABILITY 25.5 Offshore 14.4.a B, C, D 14.4.b B, C, D 15.5.a.(ii) C, D 15.5.a.(iii) C, D Definition of the U-Q/Pmaxprofile at Pmax Conditions for reconnection to the network after an incidental disconnection caused by network disturbance Conditions for automatic reconnection Technical specifications for a quotation for Black Start Capability Timeframe within which the PGM is capable of starting from shutdown without any external electrical energy supply Range of capability- CNC CNC CNC Principle - CNC in due time for plant RSO (DSO or ) in with the EN-E AISBL Avenue de Cortenbergh Brussels Belgium Tel Fax info@entsoe.eu www. entsoe.eu