Finland (Fingrid VJV2024) ride-through requirements
Low-voltage ride-through, High-voltage ride-through, Frequency ride-through for Finland. Every breakpoint below is read from the code itself, and carries the clause it came from — so you can check it, not just cite it.
What is the low-voltage ride-through envelope for Finland (Fingrid VJV2024)?
The plant must ride through for any voltage that stays on or above this envelope. The envelope holds 0 pu from t = 0 to 200 ms; then ramps linearly from 0 pu at 200 ms to 0.85 pu at 1.5 s; then 0.85 pu from 1.5 s to 10 s; then 0.9 pu from 10 s onward — the last band the envelope defines, with no stated end time.
The clause states this boundary as a line; intermediate points are interpolated between its stated vertices.
Applies to Generating facilities, VJV size classes 1-4, any network level
| From | To | Voltage | Between the points |
|---|---|---|---|
| 0 | 200 ms | 0 pu | Held flat |
| 200 ms | 1.5 s | 0 → 0.85 pu | Ramps linearly |
| 1.5 s | 10 s | 0.85 pu | Held flat |
| 10 s | no stated end | 0.9 pu | Held flat |
The clause this came from
Fingrid, 'Grid Code Specifications for Power Generating Facilities VJV2024', unofficial English translation dated 15.1.2025 - section 10.5.3, Figure 10.10 (type D power park modules), p. 63. The code defines a linear recovery ramp; the vertices are read from the clause and the chart draws the segment between them.
What is the high-voltage ride-through envelope for Finland (Fingrid VJV2024)?
The plant must ride through for any voltage that stays on or below this envelope. The envelope holds 1.2 pu from t = 0 to 5 s; then 1.1 pu from 5 s onward — the last band the envelope defines, with no stated end time.
Every breakpoint is stated in the clause cited below.
Applies to Generating facilities, VJV size classes 1-4, any network level
| From | To | Voltage | Between the points |
|---|---|---|---|
| 0 | 5 s | 1.2 pu | Held flat |
| 5 s | no stated end | 1.1 pu | Held flat |
The clause this came from
Fingrid, 'Grid Code Specifications for Power Generating Facilities VJV2024', unofficial English translation dated 15.1.2025 - section 10.3.3 'Overvoltage withstand capability', Figure 10.4 (p. 48), extended by section 10.5.5.
What is the frequency ride-through envelope for Finland (Fingrid VJV2024)?
The plant must ride through between the upper and lower bands. The upper (over-frequency) band holds 51.5 Hz from t = 0 to 30 min; then 51 Hz from 30 min onward — the last band the envelope defines, with no stated end time. The lower (under-frequency) band holds 47.5 Hz from t = 0 to 30 min; then 49 Hz from 30 min onward — the last band the envelope defines, with no stated end time.
Every breakpoint is stated in the clause cited below.
Applies to Generating facilities, VJV size classes 1-4, any network level
Upper limit
| From | To | Frequency | Between the points |
|---|---|---|---|
| 0 | 30 min | 51.5 Hz | Held flat |
| 30 min | no stated end | 51 Hz | Held flat |
Lower limit
| From | To | Frequency | Between the points |
|---|---|---|---|
| 0 | 30 min | 47.5 Hz | Held flat |
| 30 min | no stated end | 49 Hz | Held flat |
The clause this came from
Fingrid, 'Grid Code Specifications for Power Generating Facilities VJV2024', unofficial English translation dated 15.1.2025 - section 10.5.2, Figure 10.7 (p. 60).
Operating requirements beyond the envelopes.
The envelopes above are what Finland (Fingrid VJV2024) demands during a disturbance. The rows below are the same regime’s operating and fault-response requirements — reactive capability, frequency response, continuous operating range, ramp rate, RoCoF withstand and fault-current injection — each researched from the document its own row cites, separately from the plotted corpus. Every row carries its clause and a verbatim quote, so you can check it the same way.
| Requirement | What the code states | Clause |
|---|---|---|
| Q capability 0.33 Pmax,p (PF 0.95 basis), Type C/D storage Reactive capability | Generate and consume reactive power up to 0.33 x Pmax,p (reactive capacity corresponding to power factor 0.95 of rated power in production mode), over the entire active-power operating range from rated production capacity to rated demand capacity. Voltage split as stated in the text: 0-0.33 Q/Pmax,p 'from the grid' when connection-point voltage is 0.90-1.00 pu, and 0-0.33 Q/Pmax,p 'to the grid' when voltage is 1.00-1.05 pu (basis Pmax,p = rated capacity in production mode). Binds Type C (10-30 MW, <110 kV) and Type D (≥30 MW or ≥110 kV connection) grid energy storage systems explicitly — SJV2024 is a storage-specific code, no generation-scoped inference needed. Requirement is met primarily at the connection point; alternatively Pmax,p may be taken as the maximum active power measured on the HV side of the main transformer, in which case the requirement is met at that point (same clause). For Type B, the relevant network operator sets the reactive capacity requirement but it shall not exceed the C/D requirement (section 12.1, PDF p.64). Quoted from the Fingrid-hosted unofficial English translation; the Finnish version controls. Editorial caution: the source's own Figure 12.1b (both language versions) draws the opposite intake/supply pairing to the §12.2.1 text quoted here; the discrepancy is unresolved in the source — text quoted as printed, do not resolve silently. | Section 12.2.1 'Reactive power capacity requirement' and Figure 12.1 + Section 12.2.1, bullet list under 'The reactive power measured at the point where the reactive power capacity requirement is determined must be as shown in Figure 12.1b)' (PDF p.65) |
The clauses this row citesSection 12.2.1 'Reactive power capacity requirement' and Figure 12.1 — “ The grid energy storage system shall be able to generate and consume reactive power (Q) within the operating range limited by its maximum-rated production and demand capacity at a reactive power capacity corresponding to the facility's operating point at a power factor of 0.95 of rated power in production mode. Figure 12.1a) shows this reactive power capacity range. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 12.2.1, bullet list under 'The reactive power measured at the point where the reactive power capacity requirement is determined must be as shown in Figure 12.1b)' (PDF p.65) — “ 0–0.33 [Q/Pmax,p] from the grid, when the voltage at the connection point is 0.90–1.00 pu. • 0–0,33 [Q/Pmax,p] to the grid, when the voltage at the connection point is 1.00–1.05 pu. • This requirement applies to the entire operating range limited by the rated production and demand capacities. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
| FSM: droop 2-12% (default 4%), deadband 0.00-0.50 Hz, Type C/D Frequency response | Frequency control (FSM): droop adjustable between 2 and 12 per cent in steps of at most one percentage point, default 4% in all frequency ranges (droop defined on Pmax,p base, formula on PDF p.62); deadband adjustable between 0.00 and 0.50 Hz in steps of at most 0.01 Hz; power range for frequency control at least (0-100%) x Pmax,p, adjustable in 0.1 MW steps, asymmetric production/demand ranges settable. Binds Type C and D grid energy storage systems (section 11.3); storage-explicit. The code does not fix a full-activation time for FSM: per section 11.3.3.2 (PDF p.61), 'The requirements for the rate of change of active power and the maximum time allowed for full activation while the grid energy storage system operates under frequency control are determined according to the technical requirements set by the marketplace (e.g., FCR-N and FCR-D).' A separate commercial agreement is required for the use and settings of the frequency control operating mode (sentence merged into the section 11.3.3.4 heading, PDF p.62). Section 11.3.5 (PDF p.64) additionally requires frequency-control sensitivity of at least 10 mHz and a start delay of no more than 2 s for a step change in frequency. Quoted from the Fingrid-hosted unofficial English translation; Finnish controls. | Section 11.3.3.3 'Frequency control (FSM)' (droop paragraph) + Section 11.3.3.3 'Frequency control (FSM)' (deadband paragraph, same PDF page) |
The clauses this row citesSection 11.3.3.3 'Frequency control (FSM)' (droop paragraph) — “ It shall be possible to adjust the droop of frequency control between 2 and 12 per cent in steps of a maximum of one percentage point. It shall be possible to adjust the droop for specific frequency ranges, taking into account the LFSM-O and LFSM-U modes. The default value for droop set on the regulator during commissioning is 4% in all frequency ranges. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 11.3.3.3 'Frequency control (FSM)' (deadband paragraph, same PDF page) — “ It shall be possible to adjust the deadband of frequency control between 0.00 and 0.50 Hz in steps of a maximum of 0.01 Hz. If a deadband is used, the frequency control curve starts at the deadband boundary. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
| LFSM-O above 50.5 Hz / LFSM-U below 49.5 Hz; droop 2-12%, delay ≤2 s, always enabled Frequency response | LFSM-O: activates when system frequency exceeds 50.5 Hz; droop adjustable 2-12%, recommended setpoint 4%; frequency response activated with initial delay as short as possible, at most two seconds; status must always be enabled. LFSM-U: in demand mode, reduce demand as a linear function of frequency below 49.5 Hz down to the zero-transfer operating point; droop adjustable 2-12%, recommended setpoint 4%; initial delay at most two seconds; status must always be on. LFSM-O binds Type A storage directly (section 11.1.2), Type B via section 11.2 ('Type B grid energy storage systems shall have the functionalities required by active power control and frequency control, and maintenance of power output as described in section 11.1'), and Type C/D via section 11.3 ('type C and D grid energy storage systems shall have the LFSM-O functionalities as described in section 11.1.2'). In demand mode LFSM-O requires the storage to increase demand above 50.5 Hz and to switch steplessly between production and demand along the droop (PDF p.57). LFSM-U is specified in section 11.3.3.4 under the Type C/D chapter; no LFSM-U requirement is stated for Types A/B. Storage-explicit code. Quoted from Fingrid-hosted unofficial English translation; Finnish controls. | Section 11.1.2 'Limited frequency-sensitive mode – over-frequency (LFSM-O)' + Section 11.3.3.4 (LFSM-U; heading as printed is merged with a stray sentence: 'A separate commercial agreement shall be signed on the use and settings of the frequency control operating mode. Limited frequency sensitive mode – under-frequency (LFSM-U)'), PDF p.63 |
The clauses this row citesSection 11.1.2 'Limited frequency-sensitive mode – over-frequency (LFSM-O)' — “ It shall be possible to adjust the droop of LFSM-O between 2 and 12 per cent. The recommended setpoint is 4%. A frequency response shall be activated with an initial delay that is as short as possible, within two seconds at the most, when the electricity system’s frequency exceeds 50.5 Hz. Active power must be reduced at the maximum rate permitted by the installation. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 11.3.3.4 (LFSM-U; heading as printed is merged with a stray sentence: 'A separate commercial agreement shall be signed on the use and settings of the frequency control operating mode. Limited frequency sensitive mode – under-frequency (LFSM-U)'), PDF p.63 — “ It shall be possible to adjust the droop of LFSM-U between 2 and 12 per cent. The recommended setpoint is 4%. A frequency response shall be activated with an initial delay that is as short as possible, within two seconds at the most, when the electricity system’s frequency is below 49.5 Hz. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
| 49.0-51.0 Hz continuous; 51.0-51.5 and 47.5-49.0 Hz for 30 minutes Continuous operating range | Continuous normal operation at 49.0-51.0 Hz; operation for a period of 30 minutes when frequency is 51.0-51.5 or 49.0-47.5 (ranges as printed, second pair without repeated 'Hz' unit). Voltage: Types A-C operate continuously in the voltage range defined by the relevant network operator (normal fluctuation range at least 0.90-1.05 pu per section 10.1); Type D must operate continuously at 90-105% of the normal operating voltage with 49.0-51.0 Hz, and remain connected outside those values for at least the times in Figure 10.5. Section 10.2.1 is written for Type A and cascades to Types B, C and D via the section 10.3/10.4/10.5 intro sentences (the exceptions listed there do not include 10.2.1). Section 10.5.2 adds the Type D combined voltage/frequency envelope; its Figure 10.5 (PDF p.54) is the time-limited U-f connection-retention envelope, not extracted here per the ride-through exclusion. In the 400 kV grid the 100% voltage of the continuous operating range is always 400 kV; at other voltages the 100% value is requested from the relevant network operator (Figure 10.5 caption, PDF p.54). Storage-explicit code. Quoted from Fingrid-hosted unofficial English translation; Finnish controls. | Section 10.2.1 'Operating voltage and frequency range of the grid energy storage system' + Section 10.5.2 'Operating voltage and frequency range of the grid energy storage system' (Type D), PDF p.53 |
The clauses this row citesSection 10.2.1 'Operating voltage and frequency range of the grid energy storage system' — “ The grid energy storage system shall be able to operate continuously and normally when the electricity system’s frequency is 49.0‒51.0 Hz. The grid energy storage system must be able to operate for a period of 30 minutes when the electricity system’s frequency is 51.0–51.5 or 49.0–47.5. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 10.5.2 'Operating voltage and frequency range of the grid energy storage system' (Type D), PDF p.53 — “ The grid energy storage system shall be able to operate continuously and normally when the voltage at the connection point is 90‒105% of the normal operating voltage and the frequency is 49.0‒51.0 Hz. If the voltage, frequency or both at the connection point differ from these values, the grid energy storage system shall remain connected to the network for at least the periods of time specified in Figure 10.5. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
| Grid-forming: converters must operate constantly in grid-forming mode Continuous operating range | Grid energy storage systems must use grid-forming converters that operate constantly in grid-forming mode. The control must be operational whenever the system is connected and must not change mode on a network change or disturbance; it must hold at any point within the rated capacity in production and demand mode and regardless of charging state; it must coordinate at the converters’ current limits so that restricting the current never interrupts the grid-forming controller function, with the limits set to the installation’s actual performance and using the short-term overloading capability of the equipment; and overdimensioning the system’s capacity for grid-forming control features is expressly not required. The plant must not amplify frequency or voltage oscillations, with particular attention to three ranges interpreted in the dq plane — 0.2-1.0 Hz interarea power oscillations, 1-15 Hz voltage oscillations in grid-following converters in a weak network, and 15-45 Hz resonance in a series-compensated network — and needs a separate damping control where its own properties do not achieve that. Type C is 10 MW ≤ Pmax,p < 30 MW below 110 kV; type D is Pmax,p ≥ 30 MW or a connection point at 110 kV or above. Section 10.4.3 sits in the type C requirements, and the section 10.5 intro applies sections 10.2-10.4 to type D with exceptions that do not include it, so the operating mandate reaches both types; section 10.5.3 refers back to it when it asks type D fault ride-through design to take the converters’ current limits and the functioning of the grid-forming control into account. Read the type D exception list carefully: section 10.3.4 reactive current supply is excepted for type C and NOT for type D, so a type D storage system owes the section 10.3.4 reactive current supply requirement AND the grid-forming requirements of this section — the routing is by type category, never by control mode. Storage rated below 10 MW is exempted when it runs as part of an integrated type C or D hybrid facility (section 3, PDF p.10). Storage-explicit code. Quoted from Fingrid-hosted unofficial English translation; Finnish controls. | Section 10.4.3 'Grid-forming capabilities', general requirements a), c) and f), the closing capacity sentence, and functional requirements 1) c) and 3) + Table 3.1 'The grid energy storage system's type category based on the rated capacity in production mode and the connection point's voltage level' (PDF p.9) and section 10.5 intro 'General requirements for a type D grid energy storage system' (PDF p.53) |
The clauses this row citesSection 10.4.3 'Grid-forming capabilities', general requirements a), c) and f), the closing capacity sentence, and functional requirements 1) c) and 3) — “ Grid energy storage systems must use grid-forming converters that operate constantly in grid-forming mode. … Grid-forming control features: a) must be operational whenever the grid energy storage system is connected to the network. In addition, the operating mode must not change in the event of changes or disturbances in the network. … c) must be operational regardless of the grid energy storage system’s charging state … f) must operate in a coordinated manner at the converters’ current limits so that any need to restrict the current does not result in discontinuity of the grid-forming controller function or otherwise jeopardise the stable operation of the grid energy storage system. The current limits set for the control shall correspond to the installation’s actual performance and take advantage of the short-term overloading capability of the equipment. … The response to the requirements stated in items a) and b) shall occur at the terminals of the grid energy storage system’s converters almost instantly (the current shall start to change according to the control within a few milliseconds of a stepwise change in the network). … It is not necessary to overdimension the capacity of the grid energy storage system or a certain device because of grid-forming control features. … The grid energy storage system’s response to frequency and voltage oscillations in the electricity network must not amplify such oscillations or must dampen them. … The grid energy storage system must not weaken the damping of power system oscillations at frequencies deviating from the operating frequency. Particular attention shall be paid to the damping of oscillations in the frequency range i. 0.2–1.0 Hz (interpreted in the dq plane) of interarea power oscillations ii. 1–15 Hz (interpreted in the dq plane) of voltage oscillations in grid-following converters in a weak network, and iii. 15–45 Hz (interpreted in the dq plane) at which resonant frequencies occur in a series-compensated network. … If the requirements of a) and b) are not met due to the grid energy storage system’s natural properties, the grid energy storage system shall be equipped with a separate damping control. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-16) Table 3.1 'The grid energy storage system's type category based on the rated capacity in production mode and the connection point's voltage level' (PDF p.9) and section 10.5 intro 'General requirements for a type D grid energy storage system' (PDF p.53) — “ [Table 3.1] Type C — The connection point’s voltage level is less than 110 kV — and (*) — The grid energy storage system’s rated capacity in production mode is at least 10 MW but less than 30 MW. (10 MW ≤ Pmax < 30 MW). Type D — The connection point’s voltage level is at least 110 kV — or (+) — The grid energy storage system’s rated capacity in production mode is at least 30 MW. (Pmax,p ≥ 30 MW). … [Section 10.5] The same general requirements as for type A, B and C grid energy storage systems (sections 10.2, 10.3 and 10.4) are applicable to type D grid energy storage systems, with the exception of remote control capability (sections 10.2.3 and 10.3.1), autonomous connection (section 10.2.4) and fault ride-through (section 10.3.2). Type D grid energy storage systems must also fulfil the requirements set out in this section. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-16) | ||
| Ramp-rate limiter settable 10-100% Pmax,p/min; default may be 100%/min Ramp rate | Adjustable active-power rate-of-change setpoint required in production and demand modes: settable at least over a range whose minimum value is 10% of rated capacity per minute (0.1 x Pmax,p/minute) and whose maximum is the system's maximum possible rate of change, which must be at least 100% of rated capacity per minute (1.0 x Pmax,p/minute); smallest setpoint change at least 1 MW/minute; default value may be 100% of rated capacity per minute; power change linear with no stepwise changes greater than 5%. This is a controllability/limiter requirement, not a standing ramp cap: the code requires the limiter function when a new setpoint is given, when the limiter setpoint changes, and under frequency control. Fingrid may impose a rate-of-change limit when the network operating state requires it (quote2). Under frequency control, ramp and full-activation requirements follow marketplace technical requirements (e.g., FCR-N and FCR-D) (PDF p.61). Binds Type C and D storage (section 11.3); storage-explicit. Separately, autonomous connection for Type A (cascading to B-D with exceptions) is permitted only if 'the maximum allowed rate of change of the grid energy storage system's active power is 100% of the rated capacity in one minute if the relevant operator has not defined a smaller value' (section 10.2.4, PDF p.36). Quoted from Fingrid-hosted unofficial English translation; Finnish controls. | Section 11.3.3.2 'Restriction of rate of change of active power' + Section 11.3.3.2, last paragraph of p.60 (penultimate paragraph of §11.3.3.2) (same PDF page) |
The clauses this row citesSection 11.3.3.2 'Restriction of rate of change of active power' — “ It shall be possible to specify the setpoint of the rate of change of active power in production and demand modes, at least within a range where the minimum value is 10% of the rated capacity per minute (0.1 × Pmax,p/minute) and the maximum value is the maximum possible rate of change for the grid energy storage system, which must be at least 100% of its rated capacity per minute (1.0 × Pmax,p/minute) The smallest change in the setpoint shall be at least one megawatt per minute (1 MW/minute). The default value for the rate of change of active power may be 100% of the rated capacity per minute. The change in power shall occur linearly, with no stepwise changes greater than 5%. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 11.3.3.2, last paragraph of p.60 (penultimate paragraph of §11.3.3.2) (same PDF page) — “ Fingrid may limit the rate of change of active power (see section 10.4.1 and Table 10.1) If the electricity network’s operating state requires it. The limit shall apply to setpoint changes and changes due to the availability of primary energy. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
| ROCOF withstand 2.0 Hz/s; RoCoF protection may trip only above 4 Hz/s for 250 ms RoCoF withstand | Continue to operate normally when the rate of change of frequency is less than 2.0 Hz/s (no measuring window stated). If a RoCoF-detecting protective device is used (discouraged; prohibited for Type C), it may disconnect the storage only when RoCoF exceeds 4 Hz/s for at least 250 ms. Section 10.2.2 is written for Type A storage and cascades upward: Type B inherits section 10.2 except 10.2.3 (section 10.3 intro, PDF p.37); Type C inherits 10.2 and 10.3 except 10.2.3, 10.3.1 and 10.3.4 (section 10.4 intro, PDF p.43); Type D inherits 10.2-10.4 except 10.2.3, 10.3.1, 10.2.4 and 10.3.2 (section 10.5 intro, PDF p.53) — so the 2.0 Hz/s withstand binds all types A-D. The RoCoF measurement 'shall not react to the sudden changes in the waveform of voltage caused by disturbances in the system' (section 10.2.2, PDF p.36). For Type C, section 10.4.8 (PDF p.53) states: 'Protective devices that detect the rate of change of frequency must not be used.' Storage-explicit code. Quoted from Fingrid-hosted unofficial English translation; Finnish controls. | Section 10.2.2 'Rate of change of frequency withstand capability' + Section 10.2.5 'Protection' (sentence spans PDF pp.36-37) |
The clauses this row citesSection 10.2.2 'Rate of change of frequency withstand capability' — “ The grid energy storage system shall be capable of continuing to operate normally when the rate of change of frequency is less than 2.0 Hz/s. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 10.2.5 'Protection' (sentence spans PDF pp.36-37) — “ When using a protective device that detects the RoCoF, it may only disconnect the grid energy storage system from the network when the RoCoF exceeds 4 Hz/s for at least 250 ms. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
| Fast reactive current: k-factor 2-6 (default 2.5), 90% in 30-50 ms, target within 80 ms Fault-current injection | k-factor of reactive current supply settable separately for capacitive and inductive current between 2 and 6; default k-factor 2.5; in asymmetrical faults, positive and negative sequence components supplied in the ratio defined by the k-factor. Reactive current must rise to 90% of target in 30-50 ms and reach target (tolerance +20% to -10%) within 80 ms from the start of the stepwise voltage change. Activation: undervoltage mode at phase voltage <0.85 pu (deactivate above 0.90 pu); overvoltage mode at >1.10 pu (deactivate under 1.05 pu) (PDF p.41). Reactive current (Iq) is prioritised over active current (Ip) while the mode is active; within the normal voltage range active current has priority (PDF p.40). Section 10.3.4 is written for Type B storage. Type C is explicitly excepted from section 10.3.4 by the section 10.4 intro ('with the exception of remote control capability (sections 10.2.3 and 10.3.1) and reactive current supply (section 10.3.4)', PDF p.43) — Type C must instead meet the grid-forming capability requirements of section 10.4.3. Type D inherits sections 10.2-10.4 with exceptions that do not include 10.3.4 (section 10.5 intro, PDF p.53), so the reactive current supply requirement applies to Type D. For Type B systems with grid-forming converters, the supply characteristics may differ subject to Fingrid's compliance assessment (PDF p.41). Storage-explicit code. Quoted from Fingrid-hosted unofficial English translation; Finnish controls. | Section 10.3.4 'Reactive current supply' (k-factor paragraph) + Section 10.3.4 'Reactive current supply' (response-time paragraph, same PDF page) |
The clauses this row citesSection 10.3.4 'Reactive current supply' (k-factor paragraph) — “ It must be possible to set the k-factor of the reactive current supply separately for capacitive and inductive reactive current between 2 and 6. The default k-factor of reactive current injection is 2.5, and in asymmetrical faults, the positive and negative sequence component must be supplied in the ratio defined by the k-factor. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) Section 10.3.4 'Reactive current supply' (response-time paragraph, same PDF page) — “ When operating at a voltage where the reactive current supply mode is not active, the supply of active current (Ip) shall be prioritised. The time taken for the reactive current to rise to 90% of the target value shall be between 30 and 50 ms, and the reactive current shall reach the target value (tolerance +20% to -10%) within 80 ms. The delay shall be determined from the start of the stepwise change in voltage. ” (Grid Code Specifications for Grid Energy Storage Systems SJV2024 (unofficial English translation), accessed 2026-08-08) | ||
Who does Finland (Fingrid VJV2024) bind, and since when?
Generating facilities, VJV size classes 1-4, any network level. No date of effect is published here — grid codes are reissued, so check the current issue before relying on it.
These figures are a reading aid, not legal advice. Grid codes are reissued: verify against the current edition before you design to them.
Curve data last checked against the code on — 66 standards, 130 envelopes, published by bess.engineer under CC BY 4.0.
Questions this page answers about Finland (Fingrid VJV2024)
- Does Finland (Fingrid VJV2024) require ride-through, or only that the plant does not trip?
- Ride-through. Every envelope on this page is a performance duty the plant must meet, not a protection-setting no-trip boundary — they are different obligations. That is what these curves are; they are not everything Finland (Fingrid VJV2024) contains. The requirement sentence under each chart says which side of the curve is the compliant one.
- Are the numbers on this page taken from Finland (Fingrid VJV2024) itself?
- Yes. Every breakpoint is read from the code, and each envelope carries the clause it came from, quoted in full under its chart — so you can check the figure against the standard rather than cite it from this page.
- Which events are charted for Finland (Fingrid VJV2024)?
- Finland (Fingrid VJV2024) is charted here with 3 envelopes — low-voltage ride-through, high-voltage ride-through, frequency ride-through (LVRT, HVRT, FRT).
Ride-through, in context.
An envelope is a compliance boundary; understanding why it exists is a different question. The ride-through and grid-forming entries cover the engineering, and the Engineering Foundations course builds it from the physics up.
Elsewhere in Europe: UK G99 (Type A-C), UK G99 (Type D), Austria (E-Control TOR Typ D), Belgium (Federal Grid Code), Denmark (TR 3.3.1), France (RTE), and 13 more