Commission Regulation (EU) 2016/1447 of 26 August 2016 establishing a network code on requirements for grid connection of high voltage direct current systems and direct current-connected power park modules (Text with EEA relevance)
(1) "HVDC system" means an electrical power system which transfers energy in the form of high-voltage direct current between two or more alternating current (AC) buses and comprises at least two HVDC converter stations with DC transmission lines or cables between the HVDC converter stations; (2) "DC-connected power park module" means a power park module that is connected via one or more HVDC interface points to one or more HVDC systems; (3) "embedded HVDC system" means an HVDC system connected within a control area that is not installed for the purpose of connecting a DC-connected power park module at the time of installation, nor installed for the purpose of connecting a demand facility; (4) "HVDC converter station" means part of an HVDC system which consists of one or more HVDC converter units installed in a single location together with buildings, reactors, filters, reactive power devices, control, monitoring, protective, measuring and auxiliary equipment; (5) "HVDC interface point" means a point at which HVDC equipment is connected to an AC network, at which technical specifications affecting the performance of the equipment can be prescribed; (6) "DC-connected power park module owner" means a natural or legal entity owning a DC-connected power park module; (7) "maximum HVDC active power transmission capacity" (P max ) means the maximum continuous active power which an HVDC system can exchange with the network at each connection point as specified in the connection agreement or as agreed between the relevant system operator and the HVDC system owner;(8) "minimum HVDC active power transmission capacity" (P min ) means the minimum continuous active power which an HVDC system can exchange with the network at each connection point as specified in the connection agreement or as agreed between the relevant system operator and the HVDC system owner;(9) "HVDC system maximum current" means the highest phase current, associated with an operating point inside the U-Q/P max -profile of the HVDC converter station at maximum HVDC active power transmission capacity;(10) "HVDC converter unit" means a unit comprising one or more converter bridges, together with one or more converter transformers, reactors, converter unit control equipment, essential protective and switching devices and auxiliaries, if any, used for the conversion.
(a) HVDC systems connecting synchronous areas or control areas, including back-to-back schemes; (b) HVDC systems connecting power park modules to a transmission network or a distribution network, pursuant to paragraph 2; (c) embedded HVDC systems within one control area and connected to the transmission network; and (d) embedded HVDC systems within one control area and connected to the distribution network when a cross-border impact is demonstrated by the relevant transmission system operator (TSO). The relevant TSO shall consider the long-term development of the network in this assessment.
(a) the HVDC system has at least one HVDC converter station owned by the relevant TSO; (b) the HVDC system is owned by an entity which exercises control over the relevant TSO; (c) the HVDC system is owned by an entity directly or indirectly controlled by an entity which also exercises control over the relevant TSO.
(a) HVDC systems whose connection point is below 110 kV unless a cross-border impact is demonstrated by the relevant TSO. The relevant TSO shall consider the long-term development of the network in this assessment; (b) HVDC systems or DC-connected power park modules connected to the transmission system and distribution systems or to parts of the transmission system, or distribution systems, of islands of Member States of which the systems are not operated synchronously with either the Continental Europe, Great Britain, Nordic, Ireland and Northern Ireland or Baltic synchronous area.
(a) the HVDC system or DC-connected power park module has been modified to such an extent that its connection agreement must be substantially revised in accordance with the following procedure: (i) the HVDC system or DC-connected power park module owners who intend to undertake the modernisation of a plant or replacement of equipment impacting the technical capabilities of the HVDC system or DC-connected power park module shall notify their plans to the relevant system operator in advance; (ii) if the relevant system operator considers that the extent of the modernisation or replacement of equipment is such that a new connection agreement is required, the system operator shall notify the relevant regulatory authority or, where applicable, the Member State; and (iii) the relevant regulatory authority or, where applicable, the Member State shall decide if the existing connection agreement needs to be revised or a new connection agreement is required and which requirements of this Regulation shall apply; or
(b) a regulatory authority or, where applicable, a Member State decides to make an existing HVDC system or existing DC-connected power park module subject to all or some of the requirements of this Regulation, following a proposal from the relevant TSO in accordance with paragraphs 3, 4 and 5.
(a) it is already connected to the network on the date of entry into force of this Regulation; or (b) the HVDC system owner or DC-connected power park module owner has concluded a final and binding contract for the purchase of the main generating plant or HVDC equipment by two years after the entry into force of the Regulation. The HVDC system owner or DC-connected power park module owner must notify the relevant system operator and relevant TSO of conclusion of the contract within 30 months after the entry into force of the Regulation. The notification submitted by the HVDC system owner or DC-connected power park module owner to the relevant system operator and to the relevant TSO shall at least indicate the contract title, its date of signature and date of entry into force and the specifications of the main generating plant or HVDC equipment to be constructed, assembled or purchased. A Member State may provide that in specified circumstances the regulatory authority may determine whether the HVDC system or DC-connected power park module is to be considered an existing or new HVDC system or DC-connected power park module.
(a) the costs, in regard to existing HVDC systems and DC-connected power park modules, of requiring compliance with this Regulation; (b) the socioeconomic benefit resulting from applying the requirements set out in this Regulation; and (c) the potential of alternative measures to achieve the required performance.
(a) carry out a preliminary qualitative comparison of costs and benefits; (b) obtain approval from the relevant regulatory authority or, where applicable, the Member State.
(a) apply the principles of proportionality and non-discrimination; (b) ensure transparency; (c) apply the principle of optimisation between the highest overall efficiency and lowest total costs for all parties involved; (d) respect the responsibility assigned to the relevant TSO in order to ensure system security, including as required by national legislation; (e) consult with relevant DSOs and take account of potential impacts on their system; (f) take into consideration agreed European standards and technical specifications.
(a) an HVDC system shall be capable of adjusting the transmitted active power up to its maximum HVDC active power transmission capacity in each direction following an instruction from the relevant TSO. The relevant TSO: (i) may specify a maximum and minimum power step size for adjusting the transmitted active power; (ii) may specify a minimum HVDC active power transmission capacity for each direction, below which active power transmission capability is not requested; and (iii) shall specify the maximum delay within which the HVDC system shall be capable of adjusting the transmitted active power upon receipt of request from the relevant TSO.
(b) the relevant TSO shall specify how an HVDC system shall be capable of modifying the transmitted active power infeed in case of disturbances into one or more of the AC networks to which it is connected. If the initial delay prior to the start of the change is greater than 10 milliseconds from receiving the triggering signal sent by the relevant TSO, it shall be reasonably justified by the HVDC system owner to the relevant TSO. (c) the relevant TSO may specify that an HVDC system be capable of fast active power reversal. The power reversal shall be possible from the maximum active power transmission capacity in one direction to the maximum active power transmission capacity in the other direction as fast as technically feasible and reasonably justified by the HVDC system owner to the relevant TSOs if greater than 2 seconds. (d) for HVDC systems linking various control areas or synchronous areas, the HVDC system shall be equipped with control functions enabling the relevant TSOs to modify the transmitted active power for the purpose of cross-border balancing.
(a) how and when a voltage deviation is to be determined as well as the end of the voltage deviation; (b) the characteristics of the fast fault current; (c) the timing and accuracy of the fast fault current, which may include several stages.
(a) the U-Q/P max -profile shall not exceed the U-Q/Pmax -profile envelope represented by the inner envelope in the figure set out in Annex IV, and does not need to be rectangular;(b) the dimensions of the U-Q/P max -profile envelope shall respect the values established for each synchronous area in the table set out in Annex IV; and(c) the position of the U-Q/P max -profile envelope shall lie within the limits of the fixed outer envelope in the figure set out in Annex IV.
(a) voltage control mode; (b) reactive power control mode; (c) power factor control mode.
(a) a setpoint voltage at the connection point shall be specified to cover a specific operation range, either continuously or in steps, by the relevant system operator, in coordination with the relevant TSO; (b) the voltage control may be operated with or without a deadband around the setpoint selectable in a range from zero to +/– 5 % of reference 1 pu network voltage. The deadband shall be adjustable in steps as specified by the relevant system operator in coordination with the relevant TSO; (c) following a step change in voltage, the HVDC converter station shall be capable of: (i) achieving 90 % of the change in reactive power output within a time t1 specified by the relevant system operator in coordination with the relevant TSO. The time t1 shall be in the range of 0,1-10 seconds; and (ii) settling at the value specified by the operating slope within a time t2 specified by the relevant system operator in coordination with the relevant TSO. The time t2 shall be in the range of 1-60 seconds, with a specified steady-state tolerance given in % of the maximum reactive power.
(d) voltage control mode shall include the capability to change reactive power output based on a combination of a modified setpoint voltage and an additional instructed reactive power component. The slope shall be specified by a range and step specified by the relevant system operator in coordination with the relevant TSO.
(a) pre-fault minimum short circuit capacity at each connection point expressed in MVA; (b) pre-fault operating point of the HVDC converter station expressed as active power output and reactive power output at the connection point and voltage at the connection point; and (c) post-fault minimum short circuit capacity at each connection point expressed in MVA.
(a) network system and HVDC system protection; (b) active power control for emergency assistance; (c) synthetic inertia, if applicable; (d) automatic remedial actions as specified in Article 13(3); (e) LFSM; (f) FSM and frequency control; and (g) power gradient constraint.
(a) a DC-connected power park module shall be capable of receiving a fast signal from a connection point in the synchronous area to which frequency response is being provided, and be able to process this signal within 0,1 second from sending to completion of processing the signal for activation of the response. Frequency shall be measured at the connection point in the synchronous area to which frequency response is being provided; (b) DC-connected power park modules connected via HVDC systems which connect with more than one control area shall be capable of delivering coordinated frequency control as specified by the relevant TSO.
(a) a DC-connected power park module shall be capable of staying connected to the remote-end HVDC converter station network and operating within the frequency ranges and time periods specified in Annex VI for the 50 Hz nominal system. Where a nominal frequency other than 50 Hz, or a frequency variable by design is used, subject to agreement with the relevant TSO, the applicable frequency ranges and time periods shall be specified by the relevant TSO taking into account specificities of the system and the requirements set out in Annex VI; (b) wider frequency ranges or longer minimum times for operation can be agreed between the relevant TSO and the DC-connected power park module owner to ensure the best use of the technical capabilities of a DC-connected power park module if needed to preserve or to restore system security. If wider frequency ranges or longer minimum times for operation are economically and technically feasible, the DC-connected power park module owner shall not unreasonably withhold consent; (c) while respecting the provisions of point (a) of paragraph 2, a DC-connected power park module shall be capable of automatic disconnection at specified frequencies, if specified by the relevant TSO. Terms and settings for automatic disconnection shall be agreed between the relevant TSO and the DC-connected power park module owner.
(a) a DC-connected power park module shall be capable of staying connected to the remote-end HVDC converter station network and operating within the voltage ranges (per unit), for the time periods specified in Tables 9 and 10, Annex VII. The applicable voltage range and time periods specified are selected based on the reference 1 pu voltage; (b) wider voltage ranges or longer minimum times for operation can be agreed between the relevant system operator, the relevant TSO and the DC-connected power park module owner to ensure the best use of the technical capabilities of a DC-connected power park module if needed to preserve or to restore system security. If wider voltage ranges or longer minimum times for operation are economically and technically feasible, the DC-connected power park module owner shall not unreasonably withhold consent; (c) for DC-connected power park modules which have an HVDC interface point to the remote-end HVDC converter station network, the relevant system operator, in coordination with the relevant TSO may specify voltages at the HVDC interface point at which a DC-connected power park module shall be capable of automatic disconnection. The terms and settings for automatic disconnection shall be agreed between the relevant system operator, the relevant TSO and the DC-connected power park module owner; (d) for HVDC interface points at AC voltages that are not included in the scope of Annex VII, the relevant system operator, in coordination with the relevant TSO shall specify applicable requirements at the connection point; (e) where frequencies other than nominal 50 Hz are used, subject to relevant TSO agreement, the voltage ranges and time periods specified by the relevant system operator, in coordination with the relevant TSO, shall be proportional to those in Tables 9 and 10, Annex VII.
(a) if the DC-connected power park module owner can obtain a bilateral agreement with the owners of the HVDC systems connecting the DC-connected power park module to a single connection point on a AC network, it shall fulfil all of the following requirements: (i) it shall have the ability with additional plant or equipment and/or software, to meet the reactive power capabilities prescribed by the relevant system operator, in coordination with the relevant TSO, according to point (b), and it shall either: have the reactive power capabilities for some or all of its equipment in accordance with point (b) already installed as part of the connection of the DC-connected power park module to the AC network at the time of initial connection and commissioning; or demonstrate to, and then reach agreement with, the relevant system operator and the relevant TSO on how the reactive power capability will be provided when the DC-connected power park module is connected to more than a single connection point in the AC network, or the AC network at the remote-end HVDC converter station network has either another DC-connected power park module or HVDC system with a different owner connected to it. This agreement shall include a contract by the DC-connected power park module owner (or any subsequent owner), that it will finance and install reactive power capabilities required by this Article for its power park modules at a point in time specified by the relevant system operator, in coordination with the relevant TSO. The relevant system operator, in coordination with the relevant TSO shall inform the DC-connected power park module owner of the proposed completion date of any committed development which will require the DC-connected power park module owner to install the full reactive power capability.
(ii) the relevant system operator, in coordination with the relevant TSO shall account for the development time schedule of retrofitting the reactive power capability to the DC-connected power park module in specifying the point in time by which this reactive power capability retrofitting is to take place. The development time schedule shall be provided by the DC-connected power park module owner at the time of connection to the AC network.
(b) DC-connected power park modules shall fulfil the following requirements relating to voltage stability either at the time of connection or subsequently, according to the agreement as referred to in point (a): (i) with regard to reactive power capability at maximum HVDC active power transmission capacity, DC-connected power park modules shall meet the reactive power provision capability requirements specified by the relevant system operator, in coordination with the relevant TSO, in the context of varying voltage. The relevant system operator shall specify a U-Q/P max -profile that may take any shape with ranges in accordance with Table 11, Annex VII, within which the DC-connected power park module shall be capable of providing reactive power at its maximum HVDC active power transmission capacity. The relevant system operator, in coordination with the relevant TSO, shall consider the long term development of the network when determining these ranges, as well as the potential costs for power park modules of delivering the capability of providing reactive power production at high voltages and reactive power consumption at low voltages.If the Ten-Year Network Development Plan developed in accordance with Article 8 of Regulation (EC) No 714/2009 or a national plan developed and approved in accordance with Article 22 of Directive 2009/72/EC specifies that a DC-connected power park module will become AC-connected to the synchronous area, the relevant TSO may specify that either: the DC-connected power park module shall have the capabilities prescribed in Article 25(4) of Regulation (EU) 2016/631 for that synchronous area installed at the time of initial connection and commissioning of the DC-connected power park module to the AC-network; or the DC-connected power park module owner shall demonstrate to, and then reach agreement with, the relevant system operator and the relevant TSO on how the reactive power capability prescribed in Article 25(4) of Regulation (EU) 2016/631 for that synchronous area will be provided in the event that the DC-connected power park module becomes AC-connected to the synchronous area.
(ii) With regard to reactive power capability, the relevant system operator may specify supplementary reactive power to be provided if the connection point of a DC-connected power park module is neither located at the high-voltage terminals of the step-up transformer to the voltage level of the connection point nor at the alternator terminals, if no step-up transformer exists. This supplementary reactive power shall compensate the reactive power exchange of the high-voltage line or cable between the high-voltage terminals of the step-up transformer of the DC-connected power park module or its alternator terminals, if no step-up transformer exists, and the connection point and shall be provided by the responsible owner of that line or cable.
(a) each relevant system operator shall specify and make publicly available the method and the pre-fault and post-fault conditions for the calculation of minimum and maximum short circuit power at the HVDC interface point; (b) the DC-connected power park module shall be capable of stable operation within the minimum to maximum range of short circuit power and network characteristics of the HVDC interface point specified by the relevant system operator, in coordination with the relevant TSO; (c) each relevant system operator and HVDC system owner shall provide the DC-connected power park module owner with network equivalents representing the system, enabling the DC-connected power park module owners to design their system with regard to harmonics;
(a) a remote-end HVDC converter station shall be capable of staying connected to the remote-end HVDC converter station network and operating within the voltage ranges (per unit) and time periods specified in Tables 12 and 13, Annex VIII. The applicable voltage range and time periods specified are selected based on the reference 1 pu voltage; (b) wider voltage ranges or longer minimum times for operation may be agreed between the relevant system operator, in coordination with the relevant TSO, and the DC-connected power park module owner in accordance with Article 40; (c) for HVDC interface points at AC voltages that are not included in the scope of Table 12 and Table 13, Annex VIII, the relevant system operator, in coordination with the relevant TSO shall specify applicable requirements at the connection points; (d) where frequencies other than nominal 50 Hz are used, subject to agreement by the relevant TSO, the voltage ranges and time periods specified by the relevant system operator, in coordination with the relevant TSO, shall be proportional to those in Annex VIII.
(a) the relevant system operator, in coordination with the relevant TSO shall specify the reactive power provision capability requirements for various voltage levels. In doing so, the relevant system operator, in coordination with the relevant TSO shall specify a U-Q/P max -profile of any shape and within the boundaries of which the remote-end HVDC converter station shall be capable of providing reactive power at its maximum HVDC active power transmission capacity;(b) the U-Q/P max -profile shall be specified by each relevant system operator, in coordination with the relevant TSO. The U-Q/Pmax -profile shall be within the range of Q/Pmax and steady-state voltage specified in Table 14, Annex VIII, and the position of the U-Q/Pmax -profile envelope shall lie within the limits of the fixed outer envelope specified in Annex IV. The relevant system operator, in coordination with the relevant TSO, shall consider the long term development of the network when determining these ranges.
(a) operational signals, providing at least the following: (i) start-up signals; (ii) AC and DC voltage measurements; (iii) AC and DC current measurements; (iv) active and reactive power measurements on the AC side; (v) DC power measurements; (vi) HVDC converter unit level operation in a multi-pole type HVDC converter; (vii) elements and topology status; and (viii) FSM, LFSM-O and LFSM-U active power ranges.
(b) alarm signals, providing at least the following: (i) emergency blocking; (ii) ramp blocking; (iii) fast active power reversal.
(a) operational signals, receiving at least the following: (i) start-up command; (ii) active power setpoints; (iii) frequency sensitive mode settings; (iv) reactive power, voltage or similar setpoints; (v) reactive power control modes; (vi) power oscillation damping control; and (vii) synthetic inertia.
(b) alarm signals, receiving at least the following: (i) emergency blocking command; (ii) ramp blocking command; (iii) active power flow direction; and (iv) fast active power reversal command.
(a) synthetic inertia, if applicable as referred to in Articles 14 and 41; (b) frequency sensitive modes (FSM, LFSM-O, LFSM-U) referred to in Articles 15, 16 and 17; (c) frequency control, if applicable, referred to in Article 16; (d) reactive power control mode, if applicable as referred to in Article 22; (e) power oscillation damping capability, referred to Article 30; (f) subsynchronous torsional interaction damping capability, referred to Article 31.
(a) AC and DC voltage; (b) AC and DC current; (c) active power; (d) reactive power; and (e) frequency.
(a) HVDC converter unit models; (b) AC component models; (c) DC grid models; (d) Voltage and power controller; (e) Special control features if applicable e.g. power oscillation damping (POD) function, subsynchronous torsional interaction (SSTI) control; (f) Multi terminal control, if applicable; (g) HVDC system protection models as agreed between the relevant TSO and the HVDC system owner.
(a) energisation operational notification (EON); (b) interim operational notification (ION); and (c) final operational notification (FON).
(a) itemised statement of compliance; (b) detailed technical data of the HVDC system with relevance to the network connection, that is specified with respect to the connection points, as specified by the relevant system operator, in coordination with the relevant TSOs; (c) equipment certificates of HVDC systems or HVDC converter units where these are relied upon as part of the evidence of compliance; (d) simulation models or a replica of the exact control system as specified by Article 54 and by the relevant system operator in coordination with the relevant TSOs; (e) studies demonstrating expected steady-state and dynamic performance as required by Titles II, III and IV; (f) details of intended compliance tests according to Article 72; (g) details of intended practical method of completing compliance tests pursuant to Title VI.
(a) itemised statement of compliance; and (b) update of applicable technical data, simulation models, a replica of the exact control system and studies as referred to in Article 57, including use of actual measured values during testing.
(a) the HVDC system is temporarily subject to either a significant modification or loss of capability, due to implementation of one or more modifications of significance to its performance; or (b) in case of equipment failures leading to non-compliance with some relevant requirements.
(a) the unresolved issues justifying the granting of the LON; (b) the responsibilities and timescales for expected solution; and (c) a maximum period of validity which shall not exceed 12 months. The initial period granted may be shorter with the possibility for extension if evidence to the satisfaction of the relevant system operator demonstrates that substantial progress has been made towards achieving full compliance.
(a) energisation operational notification (EON); (b) interim operational notification (ION); and (c) final operational notification (FON).
(a) itemised statement of compliance; (b) detailed technical data of the DC-connected power park module with relevance to the grid connection, that is specified by the connection points, as specified by the relevant system operator in coordination with the relevant TSO; (c) equipment certificates of DC-connected power park module, where these are relied upon as part of the evidence of compliance; (d) simulation models as specified in Article 54 and as required by the relevant system operator in coordination with the relevant TSO; (e) studies demonstrating expected steady-state and dynamic performance as required by Title III; and (f) details of intended compliance tests in accordance with Article 73.
(a) itemised statement of compliance; and (b) update of applicable technical data, simulation models and studies as referred to in Article 62(3), including use of actual measured values during testing.
(a) the DC-connected power park module is temporarily subject to either a significant modification or loss of capability, due to implementation of one or more modifications of significance to its performance; or (b) in case of equipment failures leading to non-compliance with some relevant requirements.
(a) the unresolved issues justifying the granting of the LON; (b) the responsibilities and timescales for expected solution; and (c) a maximum period of validity which shall not exceed 12 months. The initial period granted may be shorter with the possibility for extension if evidence to the satisfaction of the relevant system operator demonstrating that substantial progress has been made towards achieving full compliance.
(a) include the cost-benefit analysis and a recommendation on how to proceed; (b) include a proposal for a transitional period for applying the requirement to existing HVDC systems or DC-connected power park modules. That transitional period shall not be more than two years from the date of the decision of the regulatory authority or where applicable the Member State on the requirement's applicability; (c) be subject to public consultation in accordance with Article 8.
(a) an operational notification procedure for demonstrating the implementation of the requirements by the owner of the existing HVDC system or DC-connected power park module; (b) a transitional period for implementing the requirements which shall take into account the category of HVDC system or DC-connected power park module and any underlying obstacles to the efficient implementation of the equipment modification/refitting.
(a) the relevant TSO, or HVDC system owner or DC-connected power park module owner, or their prospective owner, shall base its cost-benefit analysis on one or more of the following calculating principles: (i) the net present value; (ii) the return on investment; (iii) the rate of return; (iv) the time needed to break even.
(b) the relevant TSO, or HVDC system owner or DC-connected power park module owner, or their prospective owner, shall also quantify socioeconomic benefits in terms of improvement in security of supply and shall include at least: (i) the associated reduction in probability of loss of supply over the lifetime of the modification; (ii) the probable extent and duration of such loss of supply; (iii) the societal cost per hour of such loss of supply.
(c) the relevant TSO, or HVDC system owner or DC-connected power park module owner, or their prospective owner, shall quantify the benefits to the internal market in electricity, cross-border trade and integration of renewable energies, including at least: (i) the active power frequency response; (ii) the balancing reserves; (iii) the reactive power provision; (iv) congestion management; (v) defence measures.
(d) the relevant TSO shall quantify the costs of applying the necessary rules to existing HVDC systems or DC-connected power park modules, including at least: (i) the direct costs incurred in implementing a requirement; (ii) the costs associated with attributable loss of opportunity; (iii) the costs associated with resulting changes in maintenance and operation.
(a) allow the HVDC system owner or DC-connected power park module owner to carry out an alternative set of tests, provided that those tests are efficient and suffice to demonstrate that a HVDC system or DC-connected power park module complies with the requirements of this Regulation; and (b) require the HVDC system owner or DC-connected power park module owner to carry out additional or alternative sets of tests in those cases where the information supplied to the relevant system operator in relation to compliance testing under the provisions of Chapter 2 of Title VI, is not sufficient to demonstrate compliance with the requirements of this Regulation.
(a) allow the HVDC system owner or DC-connected power park module owner to carry out an alternative set of simulations, provided that those simulations are efficient and suffice to demonstrate that a HVDC system or DC-connected power park module complies with the requirements of this Regulation or with national legislation; and (b) require the HVDC system owner or DC-connected power park module owner to carry out additional or alternative sets of simulations in those cases where the information supplied to the relevant system operator in relation to compliance simulation under the provisions of Chapter 3 of Title VI, is not sufficient to demonstrate compliance with the requirements of this Regulation.
(a) all documentation and certificates to be provided by the HVDC system owner or DC-connected power park module owner; (b) details of the technical data of the HVDC system, HVDC converter station or DC-connected power park module with relevance to the grid connection; (c) requirements for models for steady-state and dynamic system studies; (d) timeline for the provision of system data required to perform the studies; (e) studies by the HVDC system owner or DC-connected power park module owner to demonstrate the expected steady-state and dynamic performance in accordance with the requirements set out in Titles II, III and IV; (f) conditions and procedures including the scope for registering equipment certificates; and (g) conditions and procedures for use of relevant equipment certificates, issued by an authorised certifier, by the DC-connected power park module owner.
(a) the HVDC converter unit or the HVDC converter station shall demonstrate its technical capability to provide leading and lagging reactive power capability according to Article 20; (b) the reactive power capability test shall be carried out at maximum reactive power, both leading and lagging, and concerning the verification of the following parameters: (i) Operation at minimum HVDC active power transmission capacity; (ii) Operation at maximum HVDC active power transmission capacity; (iii) Operation at active power setpoint between those minimum and maximum HVDC active power transmission capacity.
(c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the HVDC converter unit or the HVDC converter station has been operating no shorter than 1 hour at maximum reactive power, both leading and lagging, for each parameter as referred to in point (b); (ii) the HVDC converter unit or the HVDC converter station demonstrates its capability to change to any reactive power setpoint within the applicable reactive power range within the specified performance targets of the relevant reactive power control scheme; and (iii) no action of any protection within the operation limits specified by reactive power capacity diagram occurs.
(a) the HVDC converter unit or the HVDC converter station shall demonstrate its capability to operate in voltage control mode in the conditions set forth in Article 22(3); (b) the voltage control mode test shall apply concerning the verification of the following parameters: (i) the implemented slope and deadband of the static characteristic; (ii) the accuracy of the regulation; (iii) the insensitivity of the regulation; (iv) the time of reactive power activation.
(c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the range of regulation and adjustable droop and deadband is compliant with agreed or decided characteristic parameters, according to Article 22(3); (ii) the insensitivity of voltage control is not higher than 0,01 pu; (iii) following a step change in voltage, 90 % of the change in reactive power output has been achieved within the times and tolerances according to Article 22(3).
(a) the HVDC converter unit or the HVDC converter station shall demonstrate its capability to operate in reactive power control mode, according to the conditions referred to in Article 22(4); (b) the reactive power control mode test shall be complementary to the reactive power capability test; (c) the reactive power control mode test shall apply concerning the verification of the following parameters: (i) the reactive power setpoint range and step; (ii) the accuracy of the regulation; and (iii) the time of reactive power activation.
(d) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the reactive power setpoint range and step is ensured according to Article 22(4); (ii) the accuracy of the regulation is compliant with the conditions as referred to in Article 22(3).
(a) the HVDC converter unit or the HVDC converter station shall demonstrate its capability to operate in power factor control mode according to the conditions referred to in Article 22(5); (b) the power factor control mode test shall apply concerning the verification of the following parameters: (i) the power factor setpoint range; (ii) the accuracy of the regulation; (iii) the response of reactive power due to step change of active power.
(c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the power factor setpoint range and step is ensured according to Article 22(5); (ii) the time of reactive power activation as result of step active power change does not exceed the requirements specified in accordance with Article 22(5); (iii) the accuracy of the regulation is compliant with the value, as referred to in Article 22(5).
(a) the HVDC system shall demonstrate its technical capability to continuously modulate active power over the full operating range between maximum HVDC active power transmission capacity and minimum HVDC active power transmission capacity to contribute to frequency control and shall verify the steady-state parameters of regulations, such as droop and deadband and dynamic parameters, including robustness during frequency step change response and large, fast frequency changes; (b) the test shall be carried out by simulating frequency steps and ramps big enough to activate at least 10 % of the full active power frequency response range in each direction, taking into account the droop settings and the deadband. Simulated frequency deviation signals shall be injected into the controller of the HVDC converter unit or the HVDC converter station; (c) the test shall be deemed to be passed, provided that the following conditions are all fulfilled: (i) activation time of full active power frequency response range as result of a step frequency change has been no longer than required by Annex II; (ii) undamped oscillations do not occur after the step change response; (iii) the initial delay time has been according to Annex II; (iv) the droop settings are available within the range provided for in Annex II and deadband (thresholds) is not more than the value in Annex II; (v) insensitivity of active power frequency response at any relevant operating point does not exceed the requirements set forth in Annex II.
(a) the HVDC system shall demonstrate its technical capability to continuously modulate active power to contribute to frequency control in case of large increase of frequency in the system and shall verify the steady-state parameters of regulations, such as droop and deadband, and dynamic parameters, including frequency step change response; (b) the test shall be carried out by simulating frequency steps and ramps big enough to activate at least 10 % of the full operating range for active power, taking into account the droop settings and the deadband. Simulated frequency deviation signals shall be injected into the controller of the HVDC converter unit or the HVDC converter station; (c) the test shall be deemed passed, provided that the following conditions are both fulfilled: (i) the test results, for both dynamic and static parameters, are in line with the requirements as referred to in Annex II; (ii) undamped oscillations do not occur after the step change response.
(a) the HVDC system shall demonstrate its technical capability to continuously modulate active power at operating points below maximum HVDC active power transmission capacity to contribute to frequency control in case of large drop of frequency in the system; (b) the test shall be carried out by simulating at appropriate active power load points with low frequency steps and ramps big enough to activate at least 10 % of the full operating range for active power, taking into account the droop settings and the deadband. Simulated frequency deviation signals shall be injected into the controller of the HVDC converter unit or the HVDC converter station; (c) the test shall be deemed passed, provided that the following conditions are both fulfilled: (i) the test results, for both dynamic and static parameters, are in line with the requirements as referred to in Annex II; (ii) undamped oscillations do not occur after the step change response.
(a) the HVDC system shall demonstrate its technical capability to continuously modulate active power over the full operating range according to Article 13(1)(a) and (d); (b) the test shall be carried out by sending manual and automatic instructions by the relevant TSO; (c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the HVDC system has demonstrated stable operation; (ii) the time of adjustment of the active power is shorter than the delay specified pursuant to Article 13(1)(a); (iii) the dynamic response of the HVDC system when receiving instructions for the purposes of exchange or sharing of reserves, or for participating in imbalance netting processes, if capable of fulfilling the requirements for these products, as specified by the relevant TSO, has been demonstrated.
(a) the HVDC system shall demonstrate its technical capability to adjust the ramping rate according to Article 13(2); (b) the test shall be carried out by relevant TSO sending instructions of ramping modifications; (c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) ramping rate is adjustable; (ii) the HVDC system has demonstrated stable operation during ramping periods.
(a) the HVDC system shall demonstrate its technical capability to energise the busbar of the remote AC substation to which it is connected, within a time frame specified by the relevant TSO, according to Article 37(2); (b) the test shall be carried out while the HVDC system starts from shut down; (c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the HVDC system has demonstrated being able to energise the busbar of the remote AC-substation to which it is connected; (ii) the HVDC system operates from a stable operating point at agreed capacity, according to the procedure of Article 37(3).
(a) the DC-connected power park module shall demonstrate its technical capability to provide leading and lagging reactive power capability according to Article 40(2); (b) the reactive power capability test shall be carried out at maximum reactive power, both leading and lagging, and concerning the verification of the following parameters: (i) operation in excess of 60 % of maximum capacity for 30 minutes; (ii) operation within the range of 30-50 % of maximum capacity for 30 minutes; and (iii) operation within the range of 10-20 % of maximum capacity for 60 minutes.
(c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the DC-connected power park module has been operating no shorter than requested duration at maximum reactive power, both leading and lagging, in each parameter as referred to in point (b); (ii) the DC-connected power park module has demonstrated its capability to change to any reactive power setpoint within the agreed or decided reactive power range within the specified performance targets of the relevant reactive power control scheme; and (iii) no action of any protection within the operation limits specified by reactive power capacity diagram occurs.
(a) the HVDC converter unit or the HVDC converter station shall demonstrate its technical capability to provide leading and lagging reactive power capability according to Article 48(2); (b) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the HVDC converter unit or the HVDC converter station has been operating no shorter than 1 hour at maximum reactive power, both leading and lagging, at: minimum HVDC active power transmission capacity; maximum HVDC active power transmission capacity; and an active power operating point between those maximum and minimum ranges.
(ii) the HVDC converter unit or the HVDC converter station demonstrates its capability to change to any reactive power setpoint within the agreed or decided reactive power range within the specified performance targets of the relevant reactive power control scheme; and (iii) no action of any protection within the operation limits specified by reactive power capacity diagram occurs.
(a) the DC-connected power park module shall demonstrate its capability to operate in voltage control mode in the conditions set forth in Article 21 of Regulation (EU) 2016/631; (b) the voltage control mode test shall apply concerning the verification of the following parameters: (i) the implemented slope and deadband of the static characteristic; (ii) the accuracy of the regulation; (iii) the insensitivity of the regulation; (iv) the time of reactive power activation.
(c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the range of regulation and adjustable the droop and deadband is compliant with agreed or decided characteristic parameters, according to Article 21(3)(d) of Regulation (EU) 2016/631; (ii) the insensitivity of voltage control is not higher than 0,01 pu, according to Article 21(3)(d) of Regulation (EU) 2016/631; (iii) following a step change in voltage, 90 % of the change in reactive power output has been achieved within the times and tolerances according to Article 21(3)(d) of Regulation (EU) 2016/631.
(a) the DC-connected power park module shall demonstrate its capability to operate in reactive power control mode, according to the conditions referred to in Article 21(3)(d)(iii) of Regulation (EU) 2016/631; (b) the reactive power control mode test shall be complementary to the reactive power capability test; (c) the reactive power control mode test shall apply concerning the verification of the following parameters: (i) the reactive power setpoint range and step; (ii) the accuracy of the regulation; (iii) the time of reactive power activation.
(d) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the reactive power setpoint range and step is ensured according to Article 21(3)(d) of Regulation (EU) 2016/631; (ii) the accuracy of the regulation is compliant with the conditions as referred to in Article 21(3)(d) of Regulation (EU) 2016/631.
(a) the DC-connected power park module shall demonstrate its capability to operate in power factor control mode according to the conditions referred to in Article 21(3)(d)(iv) of Regulation (EU) 2016/631; (b) the power factor control mode test shall apply concerning the verification of the following parameters: (i) the power factor setpoint range; (ii) the accuracy of the regulation; (iii) the response of reactive power due to step change of active power.
(c) the test shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the power factor setpoint range and step is ensured according to Article 21(3)(d) of Regulation (EU) 2016/631; (ii) the time of reactive power activation as result of step active power change does not exceed the requirement according to Article 21(3)(d) of Regulation (EU) 2016/631; (iii) the accuracy of the regulation is compliant with the value, as referred to in Article 21(3)(d) of Regulation (EU) 2016/631.
(a) the HVDC converter unit owner or the HVDC converter station owner shall simulate fast fault current injection in the conditions set forth in Article 19; (b) the simulation is deemed passed, provided that compliance with the requirements specified in accordance with Article 19 is demonstrated.
(a) the HVDC system owner shall simulate the capability for fault-ride-through in the conditions set forth in Article 25; and (b) the simulation is deemed passed, provided that compliance with the requirements specified in accordance with Article 25 is demonstrated.
(a) the HVDC system owner shall simulate the capability for post fault active power recovery in the conditions set forth in Article 26; (b) the simulation is deemed passed, provided that compliance with the requirements specified in accordance with Article 26 is demonstrated.
(a) the HVDC converter unit owner or the HVDC converter station owner shall simulate the capability for leading and lagging reactive power capability in the conditions referred to in Article 20(2) to (4); (b) the simulation shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the simulation model of the HVDC converter unit or the HVDC converter station is validated against the compliance tests for reactive power capability as referred to in Article 71; (ii) compliance with the requirements as referred to in Article 20(2) to (4) is demonstrated.
(a) the HVDC system owner shall demonstrate the performance of its control system (POD function) to damp power oscillations in the conditions set forth in Article 30; (b) the tuning shall result in improved damping of corresponding active power response of the HVDC system in combination with the POD function compared to the active power response of the HVDC system without POD; (c) the simulation shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the POD function damps the existing power oscillations of the HVDC system within a frequency range specified by the relevant TSO. This frequency range shall include the local mode frequency of the HVDC system and the expected network oscillations; and (ii) a change of active power transfer of the HVDC system as specified by the relevant TSO does not lead to undamped oscillations in active or reactive power of the HVDC system.
(a) the HVDC system owner shall simulate the capability to quickly modify active power according to Article 13(1)(b); and (b) the simulation shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the HVDC system has demonstrated stable operation when following the pre-specified sequence of active power variation; (ii) the initial delay of the adjustment of the active power is shorter than the value specified in Article 13(1)(b) or reasonably justified if greater.
(a) the HVDC system owner shall simulate the capability to quickly reverse active power according to Article 13(1)(c); (b) the simulation shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the HVDC system has demonstrated stable operation; (ii) the time of adjustment of the active power is shorter than the value specified in Article 13(1)(c) or reasonably justified if greater.
(a) the DC-connected power park module owner shall simulate the capability for fast fault current injection in the conditions set forth in Article 20(2)(b) of Regulation (EU) 2016/631; and (b) the simulation shall be deemed passed, provided that compliance with the requirement according to Article 20(2)(b) of Regulation (EU) 2016/631 is demonstrated.
(a) the DC-connected power park module owner shall simulate the capability for post fault active power recovery in the conditions set forth in Article 20(3)(a) of Regulation (EU) 2016/631; and (b) the simulation shall be deemed passed, provided that compliance with the requirement according to Article 20(3)(a) of Regulation (EU) 2016/631 is demonstrated.
(a) the DC-connected power park module owner shall simulate the capability for leading and lagging reactive power capability in the conditions referred to in Article 40(2); and (b) the simulation shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the simulation model of the DC-connected power park module is validated against the compliance tests for reactive power capability as referred to in Article 72(2); (ii) compliance with the requirements as referred to in Article 40(2) is demonstrated.
(a) the remote-end HVDC converter unit owner or the remote-end HVDC converter station owner shall simulate the capability for leading and lagging reactive power capability in the conditions referred to in Article 48(2); and (b) the simulation shall be deemed passed, provided that the following conditions are cumulatively fulfilled: (i) the simulation model of the remote-end HVDC converter unit or the remote-end HVDC converter station is validated against the compliance tests for reactive power capability at the as referred to in Article 72(3); (ii) compliance with the requirements as referred to in Article 48(2) is demonstrated.
(a) the DC-connected power park module owner shall simulate the capability for power oscillations damping under the conditions as referred to in Article 21(3)(f) of Regulation (EU) 2016/631; and (b) the simulation shall be deemed passed, provided that the model demonstrates compliance with the conditions of Article 21(3)(f) of Regulation (EU) 2016/631.
(a) the DC-connected power park module owner shall simulate the capability for fault-ride-through under the conditions as referred to in Article 16(3)(a) of Regulation (EU) 2016/631; (b) the simulation shall be deemed passed, provided that the model demonstrates compliance with the conditions of Article 16(3)(a) of Regulation (EU) 2016/631.
(a) identification of any divergences in the national implementation of this Regulation; (b) assessment of whether the choice of values and ranges in the requirements applicable to HVDC systems and DC-connected power park modules under this Regulation continues to be valid.
(a) an identification of the HVDC system owner or DC-connected power park module owner, or their prospective owner, and a contact person for any communications; (b) a description of the HVDC system or DC-connected power park module for which a derogation is requested; (c) a reference to the provisions of this Regulation from which a derogation is requested and a detailed description of the requested derogation; (d) detailed reasoning, with relevant supporting documents, and cost-benefit analysis pursuant to the requirements of Article 66; (e) demonstration that the requested derogation would have no adverse effect on cross-border trade; (f) in the case of a DC-connected power park module connected to one or more remote-end HVDC converter stations, evidence that the converter station will not be affected by the derogation or, alternatively, agreement from the converter station owner to the proposed derogation.
(a) the regulatory authority decides to provide an extension; or (b) the HVDC system owner or DC-connected power park module owner, or their prospective owner, informs the regulatory authority by means of a reasoned submission that the request for a derogation is complete.
(a) identification of the relevant system operator or relevant TSO, and a contact person for any communications; (b) a description of the HVDC systems or DC-connected power park modules for which a derogation is requested and the total installed capacity and number of HVDC systems or DC-connected power park modules; (c) the requirement or requirements of this Regulation for which a derogation is requested, with a detailed description of the requested derogation; (d) detailed reasoning, with all relevant supporting documents; (e) demonstration that the requested derogation would have no adverse effect on cross-border trade; (f) a cost-benefit analysis pursuant to the requirements of Article 66. If applicable, the cost-benefit analysis shall be carried out in coordination with the relevant TSO and any adjacent DSOs.
(a) the regulatory authority decides to provide an extension; or (b) the relevant system operator informs the regulatory authority by means of a reasoned submission that the request for a derogation is complete.
(a) the requirement or requirements for which the derogation is granted or refused; (b) the content of the derogation; (c) the reasons for granting or refusing the derogation; (d) the consequences resulting from granting the derogation.
| Frequency range | Time period for operation |
|---|---|
| 47,0 Hz-47,5 Hz | 60 seconds |
| 47,5 Hz-48,5 Hz | To be specified by each relevant TSO, but longer than established times for generation and demand according to Regulation (EU) 2016/631 and Regulation (EU) 2016/1388 respectively, and longer than for DC-connected PPMs according to Article 39 |
| 48,5 Hz-49,0 Hz | To be specified by each relevant TSO, but longer than established times for generation and demand according to Regulation (EU) 2016/631 and Regulation (EU) 2016/1388 respectively, and longer than for DC-connected PPMs according to Article 39 |
| 49,0 Hz-51,0 Hz | Unlimited |
| 51,0 Hz-51,5 Hz | To be specified by each relevant TSO, but longer than established times for generation and demand according to Regulation (EU) 2016/631 and Regulation (EU) 2016/1388 respectively, and longer than for DC-connected PPMs according to Article 39 |
| 51,5 Hz-52,0 Hz | To be specified by each relevant TSO, but longer than for DC-connected PPMs according to Article 39 |
(a) the HVDC system shall be capable of responding to frequency deviations in each connected AC network by adjusting the active power transmission as indicated in Figure 1 and in accordance with the parameters specified by each TSO within the ranges shown in Table 2. This specification shall be subject to notification to the regulatory authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework; (b) the adjustment of active power frequency response shall be limited by the minimum HVDC active power transmission capacity and maximum HVDC active power transmission capacity of the HVDC system (in each direction); 
Figure 1 : Active power frequency response capability of an HVDC system in FSM illustrating the case of zero deadband and insensitivity with a positive active power setpoint (import mode). ΔΡ is the change in active power output from the HVDC system. fn is the target frequency in the AC network where the FSM service is provided and Δf is the frequency deviation in the AC network where the FSM service is provided.Parameters Ranges Frequency response deadband 0-±500 mHz Droop s 1 (upward regulation)Minimum 0,1 % Droop s 2 (downward regulation)Minimum 0,1 % Frequency response insensitivity Maximum 30 mHz Table 2 : Parameters for active power frequency response in FSM(c) the HVDC system shall be capable, following an instruction from the relevant TSO, of adjusting the droops for upward and downward regulation, the frequency response deadband and the operational range of variation within the active power range available for FSM, set out in Figure 1 and more generally within the limits set by points (a) and (b). These values shall be subject to notification to the regulatory authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework; (d) as a result of a frequency step change, the HVDC system shall be capable of adjusting active power to the active power frequency response defined in Figure 1, in such a way that the response is: (i) as fast as inherently technically feasible; and (ii) at or above the solid line according to Figure 2 in accordance with the parameters specified by each relevant TSO within the ranges according to Table 3: the HVDC system shall be able to adjust active power output ΔΡ up to the limit of the active power range requested by the relevant TSO in accordance with the times t 1 and t2 according to the ranges in Table 3, where t1 is the initial delay and t2 is the time for full activation. The values of t1 and t2 shall be specified by the relevant TSO, subject to notification to the regulatory authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework;if the initial delay of activation is greater than 0,5 second, the HVDC system owner shall reasonably justify it to the relevant TSO.
Figure 2 : Active power frequency response capability of an HVDC system. ΔΡ is the change in active power triggered by the step change in frequency.Parameters Time Maximum admissible initial delay t 1 0,5 seconds Maximum admissible time for full activation t 2 , unless longer activation times are specified by the relevant TSO30 seconds Table 3 : Parameters for full activation of active power frequency response resulting from frequency step change.
(e) for HVDC systems linking various control areas or synchronous areas, in frequency sensitive mode operation the HVDC system shall be capable of adjusting full active power frequency response at any time and for a continuous time period; (f) as long as a frequency deviation continues active power control shall not have any adverse impact on the active power frequency response.
1. In addition to the requirements of Article 11 the following shall apply with regard to limited frequency sensitive mode — overfrequency (LFSM-O): (a) the HVDC system shall be capable of adjusting active power frequency response to the AC network or networks, during both import and export, according to Figure 3 at a frequency threshold f 1 between and including 50,2 Hz and 50,5 Hz with a droopS adjustable from 0,1 % upwards;3 (b) the HVDC system shall be capable of adjusting active power down to its minimum HVDC active power transmission capacity; (c) the HVDC system shall be capable of adjusting active power frequency response as fast as inherently technically feasible, with an initial delay and time for full activation determined by the relevant TSO and notified to the regulatory authority in accordance with the applicable national regulatory framework; (d) the HVDC system shall be capable of stable operation during LFSM-O operation. When LFSM-O is active, hierarchy of control functions shall be organised in accordance with Article 35.
2. The frequency threshold and droop settings referred to in point (a) of paragraph 1 shall be determined by the relevant TSO and be notified to the regulatory authority in accordance with the applicable national regulatory framework. 
Figure 3 : Active power frequency response capability of HVDC systems in LFSM-O. ΔΡ is the change in active power output from the HVDC system and, depending on the operational conditions, either a decrease of import power or an increase of export power.f n is the nominal frequency of the AC network or networks the HVDC system is connected to and Δf is the frequency change in the AC network or networks the HVDC is connected to. At overfrequencies wheref is abovef 1 the HVDC system shall reduce active power according to the droop setting.
1. In addition to the requirements of Article 11, the following shall apply with regard to limited frequency sensitive mode — underfrequency (LFSM-U): (a) the HVDC system shall be capable of adjusting active power frequency response to the AC network or networks, during both import and export, according to Figure 4 at a frequency threshold f2 between and including 49,8 Hz and 49,5 Hz with a droop S4 adjustable from 0,1 % upwards; (b) in the LFSM-U mode the HVDC system shall be capable of adjusting active power up to its maximum HVDC active power transmission capacity; (c) the active power frequency response shall be activated as fast as inherently technically feasible, with an initial delay and time for full activation determined by the relevant TSO and notified to regulatory authority in accordance with the applicable national regulatory framework; (d) the HVDC system shall be capable of stable operation during LFSM-U operation. When LFSM-U is active, hierarchy of control functions shall be organised in accordance with Article 35.
2. The frequency threshold and droop settings referred to in point (a) of paragraph 1 shall be determined by the relevant TSO and be notified to the regulatory authority in accordance with the applicable national regulatory framework. 
Figure 4 : Active power frequency response capability of HVDC systems in LFSM-U. ΔΡ is the change in active power output from the HVDC system, depending on the operation condition a decrease of import power or an increase of export power. fn is the nominal frequency in the AC network or networks the HVDC system is connected and Δf is the frequency change in the AC network or networks the HVDC is connected. At underfrequencies where f is below f2 , the HVDC system has to increase active power output according to the droops .4
| Synchronous Area | Voltage Range | Time period for operation |
|---|---|---|
| Continental Europe | 0,85 pu-1,118 pu | Unlimited |
| 1,118 pu-1,15 pu | To be established by each relevant system operator, in coordination with the relevant TSO but not less than 20 minutes | |
| Nordic | 0,90 pu-1,05 pu | Unlimited |
| 1,05 pu-1,10 pu | 60 minutes | |
| Great Britain | 0,90 pu-1,10 pu | Unlimited |
| Ireland and Northern Ireland | 0,90 pu-1,118 pu | Unlimited |
| Baltic | 0,85 pu-1,118 pu | Unlimited |
| 1,118 pu-1,15 pu | 20 minutes |
| Synchronous Area | Voltage Range | Time period for operation |
|---|---|---|
| Continental Europe | 0,85 pu-1,05 pu | Unlimited |
| 1,05 pu-1,0875 pu | To be specified by each TSO, but not less than 60 minutes | |
| 1,0875 pu-1,10 pu | 60 minutes | |
| Nordic | 0,90 pu-1,05 pu | Unlimited |
| 1,05 pu-1,10 pu | To be specified by each TSO, but not more than 60 minutes | |
| Great Britain | 0,90 pu-1,05 pu | Unlimited |
| 1,05 pu-1,10 pu | 15 minutes | |
| Ireland and Northern Ireland | 0,90 pu-1,05 pu | Unlimited |
| Baltic | 0,88 pu-1,097 pu | Unlimited |
| 1,097 pu-1,15 pu | 20 minutes |
| Synchronous Area | Maximum range of Q/Pmax | Maximum range of steady-state Voltage level in PU |
|---|---|---|
| Continental Europe | 0,95 | 0,225 |
| Nordic | 0,95 | 0,15 |
| Great Britain | 0,95 | 0,225 |
| Ireland and Northern Ireland | 1,08 | 0,218 |
| Baltic States | 1,0 | 0,220 |
| Voltage parameters [pu] | Time parameters [seconds] | ||
|---|---|---|---|
| U | 0,00-0,30 | t | 0,14-0,25 |
| U | 0,25-0,85 | t | 1,5-2,5 |
| U | 0,85-0,90 | t | T |
| Frequency range | Time period for operation |
|---|---|
| 47,0 Hz-47,5 Hz | 20 seconds |
| 47,5 Hz-49,0 Hz | 90 minutes |
| 49,0 Hz-51,0 Hz | Unlimited |
| 51,0 Hz-51,5 Hz | 90 minutes |
| 51,5 Hz-52,0 Hz | 15 minutes |
| Voltage Range | Time period for operation |
|---|---|
| 0,85 pu-0,90 pu | 60 minutes |
| 0,90 pu-1,10 pu | Unlimited |
| 1,10 pu-1,118 pu | Unlimited, unless specified otherwise by the relevant system operator, in coordination with the relevant TSO. |
| 1,118 pu-1,15 pu | To be specified by the relevant system operator, in coordination with the relevant TSO. |
| Voltage Range | Time period for operation |
|---|---|
| 0,85 pu-0,90 pu | 60 minutes |
| 0,90 pu-1,05 pu | Unlimited |
| 1,05 pu-1,15 pu | To be specified by the relevant system operator, in coordination with the relevant TSO. Various sub-ranges of voltage withstand capability can be specified. |
| Range of width of Q/Pmax profile | Range of steady-state Voltage level in pu |
|---|---|
| 0-0,95 | 0,1-0,225 |
| Voltage range | Time period for operation |
|---|---|
| 0,85 pu-0,90 pu | 60 minutes |
| 0,90 pu-1,10 pu | Unlimited |
| 1,10 pu-1,12 pu | Unlimited, unless specified otherwise by the relevant system operator, in coordination with the relevant TSO. |
| 1,12 pu-1,15 pu | To be specified by the relevant system operator, in coordination with the relevant TSO. |
| Voltage range | Time period for operation |
|---|---|
| 0,85 pu-0,90 pu | 60 minutes |
| 0,90 pu-1,05 pu | Unlimited |
| 1,05 pu-1,15 pu | To be specified by the relevant system operator, in coordination with the relevant TSO. Various sub-ranges of voltage withstand capability may be specified. |
| Maximum range of Q/Pmax | Maximum range of steady-state voltage level in PU |
|---|---|
| 0,95 | 0,225 |