Energy Storage Systems(ESS) Policies and Guidelines ; Title Date View / Download; Operational Guidelines for Scheme for Viability Gap Funding for development of Battery Energy Storage Systems by Ministry of Power: 15/03/2024 . Government of India. Last Updated: Nov 26, 2024. Contact online >>
Energy Storage Systems(ESS) Policies and Guidelines ; Title Date View / Download; Operational Guidelines for Scheme for Viability Gap Funding for development of Battery Energy Storage Systems by Ministry of Power: 15/03/2024 Government of India. Last Updated: Nov 26, 2024.
NATIONAL FRAMEWORK FOR PROMOTING ENERGY STORAGE 1. Context: Energy Transition and Sustainability India is taking all steps necessary to achieve energy transition. India has set a target to achieve 50 percent cumulative installed capacity from non-fossil fuel-based energy
an Energy Storage Roadmap for India 2019 – 2032 in association with India Energy Storage Alliance (IESA). The initial objective of the roadmap was to study in detail the grid integration issues related to 40 GW of solar rooftop that will be connected to medium and low voltage grid (MV and LV grid). We
India Energy Storage Alliance (IESA) is a leading industry alliance focused on the development of advanced energy storage, green hydrogen, and e-mobility techno.
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India''s electric power system is in the midst of a dramatic shift. The combined changes in the mix of generation resources and patterns of electricity demand present new challenges and opportunities in operating and maintaining a reliable power system. Energy storage has the potential to meet these challenges and accelerate India''s energy transition. The potential for storage to meet these needs depends on many factors, including physical characteristics of the power system and the policy and regulatory environments in which these investments would operate.
Read the full NREL technical report: Policy and Regulatory Environment for Utility-Scale Energy Storage: India.
The technical characteristics of the Indian power system are favorable for energy storage investments and operation. There are opportunities for storage to provide energy arbitrage, ancillary services, and potentially defer transmission investments.
Load factor is an expression of the utilization of the system. Low load factors indicate volatility in demand and sometimes require that capital-intensive generation or transmission resources be built to serve load only for a short time. Load factors in India have been declining and are projected to continue to do so, indicating a growing opportunity for energy storage to provide energy arbitrage or resource adequacy services. Over the 2016 to 2020 period, India''s load factor declined by 2%. CEA forecasts that the total load factor will decline by an additional 4% by 2037 before stabilizing. Regions predicted to see the steepest declines include the Western and Southern regions with declines of 7% and 6%, respectively, from 2020 to 2037.
As the daily load profile in these regions becomes more variable with larger swings between peak and off-peak electricity demand, energy storage technologies can help stabilize electricity demand by providing load following or peak demand management services. These opportunities already exist in some locations, such as Delhi and Kerala, that already experience large daily swings in electricity demand.
India is in the process of expanding its ancillary services sector, presenting a growing opportunity for energy storage. The current ancillary services include inertial, primary, and slow tertiary response. There is no ancillary services market in India; system needs are met through regulatory requirements in the grid code or through unscheduled surplus capacity.
Inertial and primary response services are automatic adjustments to maintain grid stability within seconds or minutes of a deviation. While generators are required to provide these services, actual primary response has been lower than desired at times due to technical difficulties for units to respond in time and some generators not retaining adequate capacity on reserve.
Slow tertiary response, also referred to as reserves regulation ancillary services, is provided by unscheduled capacity from interstate generating stations. Because these services are only obtained through uncommitted surplus capacity, there is no guarantee the generation capacity will be available when needed. POSOCO reports inadequate surplus to meet requirements for reserves regulation ancillary services during some peak demand hours. Over the 2018–2020 operating years, India''s grid frequency fell below its lower limit of 49.9 Hz in 9% of operating periods. Further, the primary sources of ancillary support are thermal generators, which are limited in how quickly they can ramp their output levels up or down.
CERC has outlined the need to expand the range of ancillary services and types of technologies eligible to provide these services. For example, secondary reserves through automatic generation control (AGC) connected to generating units and controlled centrally are currently being piloted. And a separate pilot was initiated in 2018 to capitalize on the inherent flexibility of hydropower technologies.
Energy storage—including hydropower and non-hydropower technologies—could further expand the quantum of fast-response technologies available for ancillary services. Technologies such as flywheels and batteries can respond to control signals at subsecond time levels. Further, improving the accuracy and speed of response can reduce the amount of ancillary services that must be procured.
Investments in generation and transmission infrastructure have reduced India''s supply deficit in recent years. Total and peak demand shortfalls have fallen to less than 0.5% nationally. At the regional levels, there are persistent differences in system reliability with the Northern region experiencing the highest levels of unmet demand; however, these deficits amounted to less than 2% of Northern region annual and peak demand not met in 2019.
Generation deficits follow a seasonal pattern, with higher instances of unmet demand during the June-October months.
The COVID-19 pandemic has affected the outlook for energy demand and supply in India. Recently published CEA projections forecast an energy surplus of 3% and a peak surplus of 9% for the year 2020–2021. According to the forecast, only the Eastern region is forecast to experience an energy deficit; however, as economic activity increases in the coming months and years, growing demand may once again strain existing supplies.
Energy storage technologies with one- to four-hour discharge could contribute to peak demand management and avoid the need for investments in new generation capacity with low anticipated utilization.
India experiences limited instances of congestion on the ISTS but instances of localized congestion may present a growing concern. Over the 2017–2020 period, POSOCO reports monthly violations of total transfer capacity (TTC) in 3% of hours. TTC violations are highest June–October and are more pronounced over import corridors into the Northern and Northeastern regions. It is also notable that, in most cases, instances of TTC violations are not increasing over time. In cases where transmission congestion is intermittent and not increasing, energy storage may be a viable alternative to building new transmission infrastructure.
Localized transmission congestion due to injections of RE are a growing concern. For example, POSOCO reports output from the Bhadla Solar Park in Rajasthan has resulted in overloaded lines for the last five quarters. Similarly, Gujarat has experienced overloading transmission lines during high wind generation periods due, in part, to the remote location of the wind farms. Storage co-located with renewables can improve transmission operations by absorbing excess generation and providing frequency and voltage support.
Energy storage can potentially delay, reduce, or avoid the costs of transmission investments by providing extra capacity to meet peak demand needs. NREL''s production cost modeling of India''s planned 2030 power system reveals that 71% of the ISTS transmission corridors (out of 663 modeled) may experience an average annual utilization rate of 30% or less. Further, 9% of lines are anticipated to have zero power flow for over a quarter of the year. Low levels of utilization tend to occur during the night and middle of the day when net electricity demand is low. These results suggest that, for certain underutilized transmission corridors, energy storage may be an economic alternative to transmission upgrades.
India''s growing penetration of renewable energy will increase the flexibility needs of the rest of the generation fleet to balance supply and demand. POSOCO reports that the daily variation in output from the thermal fleet has increased from 8%–10% in 2009 to 15%–18% in 2019. On average, the daily change in net load that must be met by the thermal fleet is 15–17 GW. However, this requirement is increasing rapidly at a rate of 5–7 GW per year, reaching as high as 56 GW during the winter of 2019–2020.
Fast-ramping hydropower and gas units are also contributing to meet ramping needs. During the "Lights Off" event on April 5, 2020, system operators managed unprecedented ramp rates on the order of 3 to 4 GW per minute during the 9 p.m. 9-minute event. In preparation for the event, system operators adjusted the droop settings of some hydro generators to 1%–2% from the normal range of 4%–5% to allow faster response to frequency changes.
The hourly ramping requirements are also anticipated to increase significantly. The following figure shows the maximum and 90th percentile 1-hour net load requirements for ramping up and down for the years 2022 and 2030 based on NREL''s operational modeling.
Nationally, the maximum 1-hour ramp up could reach 32 GW by 2022 and 44 GW by 2030. The Southern and Western regions are expected to see the largest increases in net-load ramping as investments in new renewable energy capacity are expected to be concentrated in these areas.
Under higher penetrations of renewables, India''s power system will need more fast-responding resources for system flexibility. Recent estimates suggest the additional costs of refurbishing India''s thermal units to operate more flexibly could reach 5%–10% of the total project cost. The fast response of the hydropower fleet during the Lights Off event, while successful, does not present a long-term solution, as this requires advanced knowledge that the event would occur and running the plants outside of their normal operating range. Energy storage, particularly battery storage that is not subject to the droop setting limits faced by hydropower plants could be a cost-effective solution to meet increasing needs for system flexibility.
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