The Rajasthan Renewable Energy Corporation Limited (RRECL) has implemented a Standard Operating Procedure (SOP) governing the integration of Battery Energy Storage Systems (BESS) into the state’s power network. Effective April 22, 2026, the SOP mandates procedures for the First Time Charging (FTC) of BESS units paired with renewable energy (RE) projects that are already commissioned or to-be-commissioned. This framework operates under the Rajasthan Integrated Clean Energy Policy 2024 and covers projects across captive and other categories.
BESS Mandates for Solar Projects
The SOP stipulates that new RE projects connected to the State Transmission Utility (STU) network with an installed capacity exceeding 5 MW must integrate an Energy Storage System (ESS). These projects are required to maintain a storage duration of at least two hours and a capacity equivalent to a minimum of 5% of the total RE capacity.
According to the technical definitions provided in the SOP, a BESS comprises the following mandatory components:
- Power Conversion System (PCS): A bi-directional inverter with four-quadrant control.
- Energy Storage: The battery units.
- Battery Management System (BMS): The system managing the battery electronics.
Optional components identified in the regulatory framework include isolation transformers, protection devices, cooling systems, and high-level control systems.
Capacity Thresholds and Storage Requirements
The regulations define specific permissible limits and storage mandates for captive power plants based on their contract demand:
- Maximum Permissible Capacity: Individual new RE-based captive power plants, including behind-the-meter installations, are permitted up to 200% of the consumer’s contract demand.
- Threshold for Mandatory BESS: Projects with a capacity up to 100% of the contract demand follow standard integration guidelines.
- Storage for Additional Capacity: For projects exceeding 100% and up to 200% of the contract demand, developers must install BESS to store a minimum of 20% of the energy generated by the additional capacity (the capacity installed beyond 100% of the contract demand).
Administrative Framework and Single-Window Approval
A single-window approval process has been introduced to streamline administrative tasks, including the issuance of No Objection Certificates (NOC), the signing of Power Purchase Agreements (PPA), and project commissioning. Adherence to the First Time Charging (FTC) guidelines is a mandatory prerequisite for grid connectivity.
Applicants must submit exhaustive technical documentation for batteries, Power Conditioning Units (PCUs), and control systems before FTC. Required data points include:
- Battery Specifications: Make, chemistry, design capacity (kWh), self-discharge rate, Depth of Discharge (DoD), life cycle, round-trip efficiency, and IEC test certificates.
- PCU Specifications: Make, DC-DC converter type, inverter power rating, efficiency, minimum response time, and IEC certificates.
- Measurement & Control: Details on sensors, sensitivity, accuracy, and precision.
The State Load Despatch Centre (SLDC) functions as the nodal agency for system operation and scheduling but is excluded from asset ownership. Developers must ensure the following technical parameters are telemetered to the SLDC:
| Parameter Category | Required Telemetry Data |
| Operating Modes | Grid/standalone status, auto/manual mode, charge/discharge status, AGC availability, and control mode. |
| Electrical Parameters | Voltage, current, active power, reactive power, frequency, and energy export/import data. |
| Energy Status | State of Charge (SoC) in MWh and Max SoC. |
| Operational Limits | Available capacity and charge/discharge ramp rates. |
| System Health | Ambient temperature, breaker status, and system alarms. |
Technical Testing and Compliance Standards
Before the commencement of a trial run, projects must pass mandatory tests and obtain certifications covering sensor and metering verification, control functions (local, remote, and auto), grid interface protection, and power quality parameters.
The PCS must meet specific operational requirements, including black start capability, remote synchronization, and load following for PV smoothing. It must maintain voltage within ±5% during normal operation and ±10% during emergency conditions.
Under Annexure-B, developers must conduct simulation studies and model validations in accordance with CEA Technical Standards for Connectivity:
| Test Domain | Standards Referenced | Key Deliverables |
| Power Quality | IEEE 519 / IEC 61000 | Reports on harmonics, DC injection, and flicker. |
| Reactive Capability | CEA B.2(1) | PQ capability curves at various voltage levels. |
| LVRT (Low Voltage Ride Through) | CEA B.2(5) | Balanced and unbalanced fault tests; reactive power priority. |
| HVRT (High Voltage Ride Through) | CEA B.2(7) | Testing at 100%, 50%, and 25% active power dispatch. |
| Active Power Control | CEA B.2(4)(i) | Set point capability and SLDC/RLDC communication. |
Key Compliance Deadlines:
- Model Submission: Validated Root Mean Square (RMS) and Electromagnetic Transient (EMT) models must be submitted within three months of commissioning.
- Plant Modifications: Models must be re-submitted within three months of any plant modification.
- Annual Reporting: An annual power quality assessment must be submitted every year post-commissioning.
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