Ireland (EirGrid) ride-through requirements
Low-voltage ride-through for Ireland. 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 Ireland (EirGrid)?
The plant must ride through for any voltage that stays on or above this envelope. The envelope holds 0.15 pu from t = 0 to 625 ms; then ramps linearly from 0.15 pu at 625 ms to 0.9 pu at 3 s; then 0.9 pu from 3 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 Controllable wind farm power stations (WFPS)
| From | To | Voltage | Between the points |
|---|---|---|---|
| 0 | 625 ms | 0.15 pu | Held flat |
| 625 ms | 3 s | 0.15 → 0.9 pu | Ramps linearly |
| 3 s | no stated end | 0.9 pu | Held flat |
The clause this came from
EirGrid Grid Code v6 (22 July 2015), clause WFPS1.4.1 and Figure WFPS1.1 'Fault Ride-Through Capability of Controllable WFPSs': heavy black boundary at 15% U/Un from 0 to 625 ms, rising linearly to 90% at 3000 ms; axis ticks 0, 150, 625, 3000 ms. Verified by rendering the figure page directly. The code defines a linear recovery ramp; the vertices are read from the clause and the chart draws the segment between them.
Operating requirements beyond the envelopes.
The envelopes above are what Ireland (EirGrid) 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 |
|---|---|---|
| ESPS P-Q capability at connection point (rectangle, Q/Pmax 0.33) Reactive capability | Q/Pmax = +/-0.33 (equivalent to 0.95 power factor lagging/leading) at Registered Capacity; rectangular P-Q envelope holding the same Mvar from full export (Registered Capacity) down through 0 MW to Maximum Import Capacity, in PF control, voltage control or constant-Q mode Binds Grid Connected (transmission-connected) Controllable PPMs consisting of ESPSs at the Connection Point, over the normal and disturbed transmission voltage ranges of CC.8.3.2; reactive capability must be maintained during active-power changes including through zero MW. | PPM1.6.3.1(c) and Figure PPM 1.6.3.1.b |
The clause this row citesPPM1.6.3.1(c) and Figure PPM 1.6.3.1.b — “ Controllable PPMs consisting of ESPSs operating in Power Factor control mode, Voltage Control mode or constant Reactive Power mode shall be at least capable of operating at any point within the P-Q capability ranges illustrated in Figure PPM 1.6.3.1.b, as measured at the Connection Point over the normal and disturbed Transmission System Voltage ranges specified in CC.8.3.2 ... Point A represents the minimum Mvar absorption capability of the Controllable PPM at 100% Registered Capacity and is equivalent to 0.95 Power Factor leading [Registered Capacity and a Q/P ratio of -0.33 is -0.95 pf]; Point B represents the minimum Mvar production capability of the Controllable PPM at 100% Registered Capacity and is equivalent to 0.95 Power Factor lagging [Registered Capacity and Q/P ratio of 0.33 is 0.95 pf]; Point C represents the minimum Mvar production capability of the Controllable PPM at Maximum Import Capacity (kW) and is equivalent to the same Mvar as Point B ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-10) | ||
| ESPS frequency response — equivalent droop and deadband Frequency response | Equivalent Governor Droop settable over at least 2 % to 10 % (TSO-defined via 5 settable frequency-response modes); deadband = settable F1-F3 band with under-frequency trigger F1 settable 49.5-50 Hz and over-frequency trigger F3 settable 50-50.5 Hz; response required from any baseline in the Operating Range including 0 MW output Binds Grid Connected Controllable PPMs consisting of ESPSs (transmission-connected storage); the TSO specifies the settable parameters at least 120 Business Days before the scheduled Operational Date (PPM1.5.3.6). The count of five settable frequency-response modes is cited from the mode list of PPM1.5.3.2 but is not carried in the quoted text. | PPM1.5.3.1 and Table PPM 1.5.3.7.b |
The clause this row citesPPM1.5.3.1 and Table PPM 1.5.3.7.b — “ The Frequency Response System shall adjust the Active Power output of the Controllable PPM comprising of ESPSs according to an equivalent of Governor Droop, when operating in the ranges outside the deadband range F1-F3 in the Power-Frequency Response Curve. The equivalent Governor Droop minimum range is 2% to 10% and will be defined by the TSO through the settable parameters Table PPM 1.5.3.1 below. The Frequency Response System shall be capable of responding to both high and low frequency conditions from a baseline Active Power level anywhere within the Operating Range of the Controllable PPM consisting of ESPS, including at zero MW Output. ... Under frequency Trigger frequency F1 49.5 Hz – 50 Hz ... Over frequency Trigger frequency F3 50 Hz – 50.5 Hz ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-10) | ||
| ESPS frequency response activation/full-delivery time Frequency response | >= 60 % of expected additional active-power response within 5 s and 100 % within 15 s of the frequency excursion leaving the F1-F3 deadband Binds Grid Connected Controllable PPMs consisting of ESPSs when acting to control Transmission System Frequency; parallel clause PPM1.5.3.3(a) applies the same 5 s / 15 s figures to non-ESPS Controllable PPMs. | PPM1.5.3.3(b) |
The clause this row citesPPM1.5.3.3(b) — “ When acting to control Transmission System Frequency, the Controllable PPM consisting of ESPSs shall provide at least 60% of its expected additional Active Power response within 5 seconds, and 100% of its expected additional Active Power response within 15 seconds of the start of the Transmission System Frequency excursion outside the range F1-F3. ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-10) | ||
| Frequency ranges: continuous 49.5-50.5 Hz at rated output; connected 47.5-52 Hz (60 min) / 47-47.5 Hz (20 s); parallel table 49-51 Hz unlimited Continuous operating range | Controllable PPMs shall be capable of: (a) continuous operation at normal rated output for 49.5-50.5 Hz; (b) remaining connected for 47.5-52.0 Hz for 60 minutes; (c) remaining connected for 47.0-47.5 Hz for 20 seconds each time frequency is below 47.5 Hz. A parallel demarcated provision (PPM1.5.1 g), Table PPM 1.5.1(e)) instead specifies: 47-47.5 Hz 20 s; 47.5-48.5 Hz 90 min; 48.5-49 Hz 90 min; 49-51 Hz Unlimited; 51-51.5 Hz 90 min; 51.5-52 Hz 60 min. Binds Controllable PPMs at the Connection Point to the transmission system. Storage: Energy Storage Power Stations (ESPS) are bound to the PPM1 conditions via PC.A9 ('The minimum technical, design and operational criteria to be met by ESPSs are specified in the Connection Conditions and the PPM1 section.', PDF p.79). Do not harmonize the two band sets - they differ (60 min vs 90 min tiers) and EirGrid states both. Demarcation classes (read from the marginal symbols on the printed pages, per Grid Code Table 1, PDF p.2): the (a)–(c) block carries the struck-through-circle symbol = Non-RfG Generation Units; the g)/Table PPM1.5.1(e) block carries the plain circle = RfG Generation Units. | EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.5.1 (a)–(c) (PPM1.5 Transmission System Frequency Ranges), PDF page 386 + EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.5.1 g) and Table PPM 1.5.1(e), PDF page 388 |
The clauses this row citesEirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.5.1 (a)–(c) (PPM1.5 Transmission System Frequency Ranges), PDF page 386 — “ Controllable PPMs shall have the capability to: (a) operate continuously at normal rated output at Transmission System Frequencies in the range 49.5 Hz to 50.5 Hz; (b) remain connected to the Transmission System at Transmission System Frequencies within the range 47.5 Hz to 52.0 Hz for a duration of 60 minutes; (c) remain connected to the Transmission System at Transmission System Frequencies within the range 47.0 Hz to 47.5 Hz for a duration of 20 seconds required each time the Transmission System Frequency is below 47.5 Hz; ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-08) EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.5.1 g) and Table PPM 1.5.1(e), PDF page 388 — “ Remain connected to the Transmission System and operate within the frequency ranges and time periods specified in Table PPM1.5.1(e). Table PPM 1.5.1(e): Minimum Time Periods for Generation Units to Remain Operational without Disconnecting: 47 – 47.5 Hz — 20 seconds; 47.5 – 48.5 Hz — 90 minutes; 48.5 – 49 Hz — 90 minutes; 49 – 51 Hz — Unlimited; 51 – 51.5 Hz — 90 minutes; 51.5 – 52 Hz — 60 minutes ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-08) | ||
| Voltage: ESPS PPMs continuously connected for 10% voltage step changes; disturbance ranges 350-420/200-245/99-123 kV Continuous operating range | Controllable PPMs consisting of ESPSs (excluding Offshore PPMs) shall remain continuously connected at Dispatched Active Power, Controlled Active Power or Frequency Response output for normal and disturbed system conditions and for step changes in Transmission System Voltage of up to 10%. Ranges which may arise during disturbances or following transmission faults: 400 kV system 350-420 kV; 220 kV system 200-245 kV; 110 kV system 99-123 kV. A parallel RfG-demarcated provision for Controllable PPMs generally requires operation for unlimited time within 360-420 kV (0.9-1.05 p.u.), 198-245 kV (0.9-1.114 p.u.), 99-123 kV (0.9-1.118 p.u.) at the Connection Point. The first (quoted) block names ESPSs explicitly - a storage-specific voltage-range obligation, binding at the Connection Point. The second block (quote 2) carries the RfG Generation Units demarcation symbol and binds Controllable PPMs excluding Offshore PPMs at maximum Available Active Power or Controlled Active Power. Note the two blocks state different lower bounds for the 400 kV system (350 kV disturbed-range vs 360 kV/0.9 pu unlimited-operation) - they are different demarcation classes and different framings (ranges that 'may arise' vs operating requirement); both reported as printed. | EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.6.1 Transmission System Voltage Range (ESPS provision), PDF pages 404–405 + EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.6.1 (RfG-demarcated provision), PDF pages 404–405 |
The clauses this row citesEirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.6.1 Transmission System Voltage Range (ESPS provision), PDF pages 404–405 — “ Controllable PPMs, excluding Offshore PPMS, consisting of ESPSs, shall remain continuously connected to the Transmission System at Dispatched Active Power or Controlled Active Power or Frequency Response output, for normal and disturbed system conditions and for step changes in Transmission System Voltage of up to 10 %. The following are the ranges which may arise during Transmission System disturbances or following transmission faults: (a) 400 kV system: 350 kV to 420 kV; (b) 220 kV system: 200 kV to 245 kV; (c) 110 kV system: 99 kV to 123 kV. ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-08) EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.6.1 (RfG-demarcated provision), PDF pages 404–405 — “ Controllable PPMs, excluding Offshore PPMs, shall remain continuously connected to the Transmission System at maximum Available Active Power or Controlled Active Power and operate within the ranges of the Transmission System Voltage at the Connection Point, for an unlimited time period, as specified below: (a) 400 kV system: 360 kV to 420 kV (0.9 p.u. – 1.05 p.u.) (b) 220 kV system: 198 kV to 245 kV (0.9 p.u. – 1.114 p.u.) (c) 110 kV system: 99 kV to 123 kV (0.9 p.u. – 1.118 p.u.) ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-08) | ||
| ESPS settable ramp-rate ranges Ramp rate | Active Power Control Set-Point Ramp Rate settable 1 %-100 % of Registered Capacity per minute; Capacity Limited Ramp Rate settable from a minimum of the lower of 10 % Registered Capacity/min or 5 MW/min (floored at 1 % RC/min) up to 100 % RC/min; TSO specifies settings >=120 Business Days before the Operational Date Binds Grid Connected Controllable PPMs consisting of ESPSs; ESPS has three ramp-rate capabilities (Capacity Limited, APC Set-Point, Frequency Response) with priority Capacity Limited > Frequency Response > APC Set-Point (PPM1.5.4.1(b)); temporary deviations should not exceed 3 % of Registered Capacity. The 120-Business-Day notification rule and the 3 % Registered Capacity deviation tolerance are cited from the PPM1.5.4 ramp-rate provisions but are not carried in the quoted text. | PPM1.5.4.2(b) |
The clause this row citesPPM1.5.4.2(b) — “ For Controllable PPMs consisting of ESPSs, it shall be possible to vary the Capacity Limited Ramp Rate and the Active Power Control Set-Point Ramp Rate each independently over a range between the following values. Capacity Limited Ramp Rate: Minimum value shall be the lower of 10% Registered Capacity per minute or 5MW per minute. If 5MW is lower than 1% of Registered Capacity, then the minimum value shall be 1% of Registered Capacity per minute. Maximum value shall be 100% of Registered Capacity per minute. Active Power Control Set-Point Ramp Rate: Minimum value shall be 1% of Registered Capacity per minute. Maximum value shall be 100% of Registered Capacity per minute. ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-10) | ||
| RoCoF ride-through RoCoF withstand | Remain connected for RoCoF up to and including 1 Hz/s, measured over a rolling 500 ms period Binds Controllable PPMs; clause PPM1.5.1(d)(i) carries the non-RfG demarcation symbol — the variant applicable to battery ESPS, which EirGrid/SONI classify as non-RfG units (Battery ESPS Grid Code Implementation Note v3.0: 'In the EirGrid and SONI Grid Codes, energy storage units are considered to be non-RfG'); the RfG-marked twin clause PPM1.5.1(d)(ii) states the identical 1 Hz/s / 500 ms figure; during voltage dips the fault-ride-through clause PPM1.4.1 supersedes it. | PPM1.5.1(d)(i) |
The clause this row citesPPM1.5.1(d)(i) — “ remain connected to the Transmission System for a Rate of Change of Frequency up to and including 1 Hz per second as measured over a rolling 500 milliseconds period. Voltage dips may cause localised ROCOF values in excess of 1 Hz per second for short periods, and in these cases, the Fault-Ride Through clause PPM1.4.1 supercedes this clause (PPM1.5.1(d)(i)) ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-10) | ||
| Reactive current response during dips: rise time ≤100 ms, settling ≤300 ms - with priority to Active Power Fault-current injection | During and after faults, priority shall always be given to the Active Power response (PPM1.4.2(a)-(b)). The reactive current response shall attempt to control the voltage back towards nominal and should be at least proportional to the Voltage Dip ('should' as printed); it shall be supplied within the rating of the Controllable PPM with a Rise Time no greater than 100 ms and a Settling Time no greater than 300 ms. The response may come from individual Generation Units, additional dynamic reactive devices on site, or both. No numeric injection gain (k / % current per % voltage) and no negative-sequence requirement is stated. Binds Controllable PPMs during Transmission System Voltage Dips (PPM1.4 Fault Ride Through Requirements); ESPSs are bound to PPM1 via PC.A9 (quote 2). Under PPM1.4.2(a) the PPM provides Active Power in proportion to retained Voltage plus reactive current per PPM1.4.2(c); demarcated side-blocks to (a) (PDF p.382-383) add that the provision of reactive current shall continue until Transmission System Voltage recovers to the normal operational range (CC.8.3.1 / CC.7.3.1.1(x) depending on user class) or for at least 500 ms, whichever is sooner. Glossary (PDF p.488-489): Rise Time = time from Fault Inception for reactive current to reach 90% of its steady-state value; Settling Time = time to settle within ±10% of steady-state. Note the priority order is the opposite of GB G99 §13.6 (which prioritizes reactive current injection). | EirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.4.2(c), PDF page 383 + EirGrid Grid Code Version 17 (issued 5 Aug 2026), PC.A9 ESPS Requirements, PDF page 79 |
The clauses this row citesEirGrid Grid Code Version 17 (issued 5 Aug 2026), PPM1.4.2(c), PDF page 383 — “ During and after faults, priority shall always be given to the Active Power response as defined in PPM1.4.2(a) and PPM1.4.2(b). The reactive current response of the Controllable PPM shall attempt to control the Voltage back towards the nominal Voltage, and should be at least proportional to the Voltage Dip. The reactive current response shall be supplied within the rating of the Controllable PPM, with a Rise Time no greater than 100ms and a Settling Time no greater than 300ms. For the avoidance of doubt, the Controllable PPM may provide this reactive response directly from individual Generation Units, or other additional dynamic reactive devices on the site, or a combination of both. ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-08) EirGrid Grid Code Version 17 (issued 5 Aug 2026), PC.A9 ESPS Requirements, PDF page 79 — “ The minimum technical, design and operational criteria to be met by ESPSs are specified in the Connection Conditions and the PPM1 section. ” (EirGrid Grid Code, Version 17 (issued 5 Aug 2026), accessed 2026-08-08) | ||
Who does Ireland (EirGrid) bind, and since when?
Controllable wind farm power stations (WFPS). 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 Ireland (EirGrid)
- Does Ireland (EirGrid) 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 Ireland (EirGrid) 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 Ireland (EirGrid) 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 Ireland (EirGrid)?
- Ireland (EirGrid) is charted here with 1 envelope — low-voltage ride-through (LVRT). No high-voltage or frequency envelope is charted here — check Ireland (EirGrid) itself before concluding it sets none.
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: Denmark (TR 3.3.1), Finland (Fingrid VJV2024), France (RTE), Germany (VDE-AR-N 4120, draft summary), Greece (ADMIE/IPTO RfG), Italy (TERNA), and 13 more