India (CEA Connectivity Regs) ride-through requirements
Low-voltage ride-through, High-voltage ride-through, Frequency ride-through for India. Every breakpoint below is read from the code itself, and where a point was taken off a published figure rather than stated in the clause, the section under that chart says so — a boundary charted as approximate or an envelope the source only partly defines.
What is the low-voltage ride-through envelope for India (CEA Connectivity Regs)?
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 300 ms; then ramps linearly from 0.15 pu at 300 ms to 0.85 pu at 3 s; then ramps linearly from 0.85 pu at 3 s to 0.9 pu at 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, but does not give its vertices numerically — the points plotted here were read off the published figure.
Applies to Generating stations connecting to the Indian HV grid
| From | To | Voltage | Between the points |
|---|---|---|---|
| 0 | 300 ms | 0.15 pu | Held flat |
| 300 ms | 3 s | 0.15 → 0.85 pu | Ramps linearly |
| 3 s | 10 s | 0.85 → 0.9 pu | Ramps linearly |
| 10 s | no stated end | 0.9 pu | Held flat |
The clause this came from
CEA Connectivity Regs 2007 (am. 2019) clause B2(3) — profile is embedded as an image in the gazette PDF; the 0.15 pu / 300 ms corner matches how it is universally cited but the recovery ramp could not be read directly.
What is the high-voltage ride-through envelope for India (CEA Connectivity Regs)?
The plant must ride through for any voltage that stays on or below this envelope. The envelope holds 1.3 pu from t = 0 to 200 ms; then 1.2 pu from 200 ms to 2 s; then 1.1 pu from 2 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 stations connecting to the Indian HV grid
| From | To | Voltage | Between the points |
|---|---|---|---|
| 0 | 200 ms | 1.3 pu | Held flat |
| 200 ms | 2 s | 1.2 pu | Held flat |
| 2 s | no stated end | 1.1 pu | Held flat |
The clause this came from
CEA Regulations Compendium, August 2024, Part II clause B2(7) over-voltage table, footnote 20 'Substituted vide Second amendment, 2019 w.e.f. 06.02.2019'. Identical text in the 2019 gazette notification.
What is the frequency ride-through envelope for India (CEA Connectivity Regs)?
The plant must ride through between the upper and lower bands. The upper (over-frequency) band holds 52 Hz from t = 0 onward — the last band the envelope defines, with no stated end time. The lower (under-frequency) band holds 47.5 Hz from t = 0 onward — the last band the envelope defines, with no stated end time.
Covers only the part of the envelope the source defines.
Applies to Generating stations connecting to the Indian HV grid
Upper limit
| From | To | Frequency | Between the points |
|---|---|---|---|
| 0 | no stated end | 52 Hz | Held flat |
Lower limit
| From | To | Frequency | Between the points |
|---|---|---|---|
| 0 | no stated end | 47.5 Hz | Held flat |
The clause this came from
CEA Regulations Compendium, August 2024, Part II clause B2(2) (footnote: substituted vide Second amendment, 2019 w.e.f. 06.02.2019): 'capable of operating in the frequency range 47.5 to 52 Hz and be able to deliver rated output in the frequency range of 49.5 Hz to 50.5 Hz'. Identical wording in the 2019 gazette.
Operating requirements beyond the envelopes.
The envelopes above are what India (CEA Connectivity Regs) 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 |
|---|---|---|
| No P-Q/PF envelope assigned to standalone ESS Reactive capability | No power-factor envelope binds a standalone ESS: the B2(1) requirement to maintain power factor within 0.95 lagging to 0.95 leading is not among the clauses assigned to energy storage systems, which must comply only with clause B1 (harmonics, DC injection, flicker) plus the Part I general connectivity conditions Storage binds explicitly: 'energy storage system' has been in the 'requester'/'user' definitions (Regulation 2(25)/(34)) since the 2019 amendment, and the proviso to Schedule Part II para B names energy storage systems directly — but only into B1 + Part I, so the B2 generator suite (PF envelope, frequency range, droop, ramp, ride-through, SCR) is not assigned to a standalone grid-scale BESS by the in-force CEA Connectivity Regulations. Co-located storage inside a 'wind - solar photo voltaic hybrid system' (defined in Regulation 2(38), inserted 2019, as 'with or without storage system') sits inside a station that does carry B2. Tension noted: IEGC (Indian Electricity Grid Code) 2023 Annexure on reactive energy charges (para 1(c)) expects 'All the Inverter Based Resources (IBRs) covering wind, solar and energy storage' to have reactive capability 'as per CEA Connectivity Standards' at all times, which the CEA text does not actually assign to standalone ESS; unresolved in the in-force instruments. | Schedule, Part II, para B, proviso — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 19: 'Substituted vide Second amendment, 2019 w.e.f. 06.02.2019') — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as printed in CEA Regulations Compendium, August 2024, printed p.40 + Schedule, Part II, clause B2(1), same regulations (B2(1) unamended by the 2019 substitution of B2(2)-(5)), CEA Regulations Compendium, August 2024, printed p.41 |
The clauses this row citesSchedule, Part II, para B, proviso — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 19: 'Substituted vide Second amendment, 2019 w.e.f. 06.02.2019') — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as printed in CEA Regulations Compendium, August 2024, printed p.40 — “ Provided that the energy storage systems shall comply, only with the requirements specified under clause B1 in addition to the general connectivity conditions specified under Part 1. ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) Schedule, Part II, clause B2(1), same regulations (B2(1) unamended by the 2019 substitution of B2(2)-(5)), CEA Regulations Compendium, August 2024, printed p.41 — “ The generating station shall be capable of supplying dynamically varying reactive power support so as to maintain power factor within the limits of 0.95 lagging to 0.95 leading. ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) | ||
| Droop 3-6%, deadband ±0.03 Hz, 10% PFR within 1 s (RE stations; not standalone ESS) Frequency response | Droop 3 to 6% with dead band not exceeding ±0.03 Hz; for frequency deviations in excess of 0.3 Hz, facility for an immediate (within 1 second) real-power primary frequency response of at least 10% of the maximum AC active power capacity (basis: maximum Alternating Current active power capacity) Binds generating stations with installed capacity of more than 10 MW connected at 33 kV and above, within Schedule Part II.B (wind generating stations, generating stations using inverters, wind-solar PV hybrid systems). Storage applicability: not assigned to standalone ESS — the para B proviso (2019) limits ESS to B1 + Part I; a hybrid's co-located storage binds via the hybrid generating station (generation-scoped rule). Under IEGC 2023 Table 4, 'WS Sellers' expressly have the option to deliver this primary response through an ESS at the unit or a common ESS at the pooling station. Measured at station level; response operating range 10%-100% of maximum AC active power capacity per B2(4)(iii). | Schedule, Part II, clause B2(4)(ii) and its proviso — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as printed in CEA Regulations Compendium, August 2024, printed p.42 + Regulation 30(10)(h), Table 4, proviso 1, Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 (unamended by First Amendment, 2024) |
The clauses this row citesSchedule, Part II, clause B2(4)(ii) and its proviso — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as printed in CEA Regulations Compendium, August 2024, printed p.42 — “ shall have governors or frequency controllers of the units at a droop of 3 to 6% and a dead band not exceeding ±0.03 Hz: Provided that for frequency deviations in excess of 0.3 Hz, the Generating Station shall have the facility to provide an immediate (within 1 second) real power primary frequency response of at least 10% of the maximum Alternating Current active power capacity; ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) Regulation 30(10)(h), Table 4, proviso 1, Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 (unamended by First Amendment, 2024) — “ WS Sellers commissioned after the date as specified in CEA Technical Standards for Connectivity shall have the option to provide primary response individually through ESS or through a common ESS installed at its pooling station. ” (Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023, accessed 2026-08-09) | ||
| IEGC PRAS: full response within 45 s, sustain 5 min; ESS eligible on NLDC identification Frequency response | PRAS starts immediately when frequency leaves the ±0.03 Hz dead band, full PRAS capacity obligation within 45 seconds, sustained for at least the next 5 minutes; reference frequency 50.000 Hz; NLDC may identify ESS as PRAS providers Binds PRAS (Primary Reserve Ancillary Service) providers: generating stations are mandated to provide PRAS (Reg 30(10)(d)); primary control is defined as local automatic control 'in a generating unit or energy storage system or demand side resource' (Reg 30(10)(a)). Storage applicability: explicit but conditional — Reg 30(10)(e) says NLDC (National Load Despatch Centre) 'may also identify' ESS to provide PRAS ('may', not a blanket mandate on every BESS); a standalone grid-scale BESS is bound once identified as a PRAS provider (or when hosting a WS Seller's primary response per Table 4 proviso 1), with compensation under the Ancillary Services Regulations. Dead band per Reg 30(10)(k): inherent dead band of a generating unit or frequency controller shall not exceed ± 0.03 Hz, governor set to reference frequency 50.000 Hz. Pre-COD, every ESS must demonstrate 'Frequency response of ESS' at the point of interconnection (Reg 24(7)(b)(ii)). | Regulation 30(10)(m), Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 (No. L-1/265/2022/CERC, 29 May 2023; unamended by First Amendment, 2024) + Regulation 30(10)(e), Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 |
The clauses this row citesRegulation 30(10)(m), Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 (No. L-1/265/2022/CERC, 29 May 2023; unamended by First Amendment, 2024) — “ The PRAS shall start immediately when the frequency deviates beyond the dead band as specified in sub-clause (k) of this clause and shall be capable of providing its full PRAS capacity obligation within 45 seconds and sustaining at least for the next five (5) minutes. ” (Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023, accessed 2026-08-09) Regulation 30(10)(e), Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 — “ NLDC may also identify other resources such as ESS and demand resource to provide PRAS for which PRAS Providers shall be compensated in accordance with the Ancillary Services Regulations. ” (Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023, accessed 2026-08-09) | ||
| 47.5-52 Hz operating range; rated output 49.5-50.5 Hz (not assigned to standalone ESS) Continuous operating range | Operate 47.5 to 52 Hz; deliver rated output 49.5 Hz to 50.5 Hz; it shall be possible to activate the control system below 49.90 Hz and above 50.05 Hz; performance maintained with voltage variation of up to + 5% (as printed) Binds each generating unit of Schedule Part II.B stations (wind, inverter-based, wind-solar hybrid) getting connected on or after 6 months from publication of the regulations. Storage applicability: not assigned to standalone ESS — the para B proviso (2019) limits ESS to B1 + Part I, so the in-force CEA text leaves a standalone grid-scale BESS with no plant-level frequency operating band; a hybrid's storage binds through the station. System-level context: IEGC 2023 Reg 30(1) sets the National Reference Frequency at 50.000 Hz and the allowable operational band at 49.900-50.050 Hz (a system operating band binding LDC operations, not a plant withstand range). No time-limited frequency bands are defined — 47.5-52 Hz is stated without duration limits. Two qualifiers from the source that the value must not drop: the '+5%' voltage rider is printed 'up to + 5%' and sits beyond the passage quoted above, and the obligation is 'subject to availability of commensurate wind speed / solar insolation'. | Schedule, Part II, clause B2(2) — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA Regulations Compendium, August 2024, printed p.41 |
The clause this row citesSchedule, Part II, clause B2(2) — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA Regulations Compendium, August 2024, printed p.41 — “ The generating unit shall be capable of operating in the frequency range 47.5 to 52 Hz and be able to deliver rated output in the frequency range of 49.5 Hz to 50.5 Hz: Provided that in the frequency range below 49.90 Hz and above 50.05 Hz, or, as prescribed by the Central Commission, from time to time, it shall be possible to activate the control system to regulate the output of the generating unit as per frequency response requirement as provided in sub-clause (4): ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) | ||
| ±10%/min ramp-control facility (RE stations); ESS ramp test only 'as per design' Ramp rate | Facility for controlling rate of change of power output at not more than ± 10% per minute (stations >10 MW at 33 kV and above; not assigned to standalone ESS); for ESS the only in-force ramp obligation is a pre-COD test of 'Ramping capability as per design' at the point of interconnection — no numeric ESS limit, no separate charge/discharge values B2(4)(iv) binds generating stations with installed capacity of more than 10 MW connected at 33 kV and above within Schedule Part II.B (wind, inverter-based, wind-solar hybrid) — a generation-scoped rule. Storage applicability: standalone ESS excluded via the para B proviso (2019); co-located storage binds through a hybrid station. For a standalone grid-scale BESS, IEGC 2023 Regulation 24(7)(b)(iii) requires demonstrating ramping capability as per design before commercial operation, binding ESS explicitly, but sets no numeric ramp limit and does not distinguish charge vs discharge. Coverage: IEGC Reg 45(9) likewise sets no ESS ramp figure. | Schedule, Part II, clause B2(4)(iv) — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA Regulations Compendium, August 2024, printed p.42 + Regulation 24(7)(b), Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 (unamended by First Amendment, 2024) |
The clauses this row citesSchedule, Part II, clause B2(4)(iv) — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA Regulations Compendium, August 2024, printed p.42 — “ shall be equipped with the facility for controlling the rate of change of power output at a rate not more than ± 10% per minute. ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) Regulation 24(7)(b), Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023 (unamended by First Amendment, 2024) — “ The following tests shall be performed at the point of interconnection: (i) Power output capability in MW and energy output capacity in MWh. (ii) Frequency response of ESS. (iii) Ramping capability as per design. ” (Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2023, accessed 2026-08-09) | ||
| No RoCoF withstand requirement RoCoF withstand | No RoCoF immunity requirement (Hz/s) for generating stations or ESS in either instrument; df/dt appears only as load-shedding relays required of distribution licensees, STUs and bulk consumers Checked absence. In the CEA Connectivity Regulations, df/dt appears solely in Schedule Part IV para 1 (under-frequency/df/dt relays for automatic load control in distribution and bulk-consumer systems); Parts I-II impose no RoCoF withstand on any generation class. In IEGC 2023, df/dt appears in Regulation 29(12) and its notes (UFR and df/dt load-shedding schemes for distribution licensees, STUs and bulk consumers) — again not a plant immunity parameter. Storage applicability: no RoCoF withstand binds a grid-scale BESS either way; standalone ESS is in any case limited to B1 + Part I of the CEA schedule by the 2019 storage proviso. | Schedule, Part IV, para 1 ('Under Frequency/df/dt Relays'), CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as printed in CEA Regulations Compendium, August 2024, printed p.44 |
The clause this row citesSchedule, Part IV, para 1 ('Under Frequency/df/dt Relays'), CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as printed in CEA Regulations Compendium, August 2024, printed p.44 — “ Under frequency and df/dt (rate of change of frequency with time) relays shall be employed for automatic load control in a contingency to ensure grid security under conditions of falling grid frequency in accordance with the decision taken in the Regional Power Committee. ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) | ||
| Reactive priority during dips; HVRT absorption per 'K' factor (no numeric gain) Fault-current injection | During voltage dips reactive power supply has first priority and active power second; active power restored to at least 90% of pre-fault level within 1 sec of voltage restoration; in HVRT mode reactive absorption proportional to voltage rise per the HVRT 'K' factor — no numeric gain k, response time, or negative-sequence requirement fixed B2(3) proviso binds Schedule Part II.B generating stations (wind, inverter-based, wind-solar hybrid) at the interconnection point. Storage applicability: not assigned to standalone ESS — the para B proviso (2019) limits ESS to B1 + Part I, so the in-force CEA text imposes no fault-current-injection duty on a standalone grid-scale BESS; a hybrid's storage binds through the station. The 6 Jan 2023 CEA clarification (issued for 'RE Generating stations' with reference to B2(7) of the 2019 amendment) adds that HVRT reactive absorption follows a system-dependent reactive current gain ('K' factor) with current limited to the plant's transient rated current — it names the gain concept but assigns no numeric value. | Schedule, Part II, clause B2(3), proviso — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA Regulations Compendium, August 2024, printed p.42 + CEA Clarification No. 12/X/STD/CONN/GM/2023/438 dated 06.01.2023, re clause B2(7) of the CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 |
The clauses this row citesSchedule, Part II, clause B2(3), proviso — substituted vide CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 (compendium footnote 20) — CEA Regulations Compendium, August 2024, printed p.42 — “ Provided that during the voltage dip, the supply of reactive power has first priority, while the supply of active power has second priority and the active power preferably be maintained during voltage drops, provided, a reduction in active power within the plant’s design specifications is acceptable and active power be restored to at least 90% of the pre-fault level within 1 sec of restoration of voltage. ” (CEA Regulations Compendium, August 2024 — CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007, as amended, accessed 2026-08-09) CEA Clarification No. 12/X/STD/CONN/GM/2023/438 dated 06.01.2023, re clause B2(7) of the CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 — “ In HVRT mode, the generating station shall provide reactive power support (absorption) proportional to the voltage rise at point of interconnection. During this phase, the quantum of reactive current absorption shall be dependent on reactive current gain in the system i.e. HVRT “K” factor. The active current and overall current shall be limited as per the transient rated current limit of the plant. ” (Clarification in CEA (Technical Standards for connectivity to the Grid), Regulations, 2007 as amended from time to time for clause - B2(7), accessed 2026-08-09) | ||
Who does India (CEA Connectivity Regs) bind, and since when?
Generating stations connecting to the Indian HV grid. 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 India (CEA Connectivity Regs)
- Does India (CEA Connectivity Regs) 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 India (CEA Connectivity Regs) 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 India (CEA Connectivity Regs) itself?
- Every breakpoint is read from the code, and where a point was taken off a published figure rather than stated in the clause, the section under that chart says so — on this page that includes a boundary charted as approximate or an envelope the source only partly defines. The clause each curve came from is quoted under it.
- Which events are charted for India (CEA Connectivity Regs)?
- India (CEA Connectivity Regs) 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.
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