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Uttarakhand Proposes Ancillary Services Framework to Strengthen Grid

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APTEL Sets Aside MERC Tariff Approval for 4 GWh Battery Storage Tender

Bengaluru Apartment Cuts Power Bills by 80% With 150 kW Rooftop Solar Project

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					</table>The Uttarakhand Electricity Regulatory Commission (<a href="https://uerc.uk.gov.in/" target="_blank" rel="noopener">UERC</a>) has issued the Draft Uttarakhand Electricity Regulatory Commission (Ancillary Services) Regulations, 2026, proposing a framework for procurement, deployment, and payment for ancillary services at the state level.
Stakeholders can submit their feedback by July 3, 2026. The draft regulations aim to maintain grid frequency close to 50 Hz, restore frequency within the allowable band specified in the Grid Code, relieve transmission congestion, support smooth power system operations, and ensure grid safety and security.
The proposed framework will apply to intra-state entities, including entities with energy storage resources and entities capable of providing demand response, if they qualify to provide ancillary services.
Scope of Ancillary Services
The draft classifies ancillary services into primary reserve ancillary service (PRAS), secondary reserve ancillary service (SRAS), tertiary reserve ancillary service (TRAS), and other services related to power system operation, such as load following, reactive power support, and black start capability.
While the proposed regulations provide detailed provisions for SRAS and TRAS, the mechanism for PRAS and other ancillary services will continue to be governed by the State Grid Code or separate regulations.
The framework is aligned with the Electricity Act, 2003; the UERC State Grid Code Regulations, 2016; the Indian Electricity Grid Code, 2023; the UERC Deviation Settlement Mechanism Regulations, 2024; and the UERC Multi-Year Tariff Regulations, 2024.
SLDC in Reserve Management
The State Load Despatch Center (SLDC) must coordinate with distribution companies and state generating stations to collect the information required to estimate the quantum of secondary and tertiary reserves needed at the state level.
The SLDC must publish the reserve requirement on its website. It must also publish reassessed secondary and tertiary reserve requirements on a day-ahead basis and, if any, incremental requirements in real time.
A generating station, an entity with energy storage resources, or an entity capable of providing demand response on a standalone or aggregated basis and connected to the intra-state transmission system will be eligible to provide SRAS.
Eligible providers must have a bidirectional communication system with the SLDC, as well as metering, supervisory control, data acquisition, and telemetry. They must be able to provide a minimum response of 1 MW.
Generating stations providing secondary reserves must be enabled for automatic generation control. Providers must be capable of responding to a secondary reserve signal within 30 seconds, delivering the entire capacity obligation within 15 minutes, and sustaining the response for at least 30 minutes. Secondary reserves must be gradually replaced by tertiary services within 30 minutes.
The draft provides that secondary reserves may be activated and deployed by the SLDC when the Area Control Error of the state exceeds the minimum threshold of 10 MW in either direction, or any other limit notified by the Commission after reviewing secondary reserve performance.
For TRAS, a generating station, energy storage resource, or demand response entity connected to the intra-State transmission system may qualify if it can vary active power output, drawal, or consumption in response to dispatch instructions from SLDC. It must be capable of providing TRAS within 15 minutes and sustaining it for at least the next 60 minutes.
The SLDC may operate secondary reserves through tie-line bias control, flat frequency control, or flat tie-line control, depending on grid requirements.
Payment and Incentive Structure
The Regulation provides that SRAS-Up providers will be paid their declared energy charge or compensation charge from the Regional Deviation and Ancillary Service Pool Account, while SRAS-Down providers will pay back to the pool account at the applicable rate.
No commitment charge has been proposed for SRAS capacity that is identified but not activated, although the Commission has left scope to introduce such a mechanism in the future.
A performance-linked incentive framework has been proposed.
Providers achieving at least 95% performance against secondary control signals will receive an incentive of ₹0.50 (~$0.0052)/kWh. Incentives decline to ₹0.40(~$0.0042)/kWh for performance between 75% and 95%, ₹0.30  (~$0.0031)/kWh for 60% to 75%, ₹0.20 (~$0.0021)/kWh for 50% to 60%, and ₹0.10 (~$0.0011)/kWh for 20% to 50%.
No incentive will be payable for performance below 20%. Generating stations that receive an incentive will receive an incentive after adjusting for normative auxiliary consumption. Providers recording performance below 20% for two consecutive days may be disqualified from SRAS participation for one week.
Market-Based Procurement for TRAS
The draft proposes procuring TRAS through the Day-Ahead and Real-Time Ancillary Service Markets. Eligible providers, including generating stations, entities with energy storage resources, and entities capable of providing demand response, must be able to provide TRAS within 15 minutes and sustain the service for at least 60 minutes.
Price discovery for TRAS-Up will follow the uniform market-clearing price principle, subject to market splitting in case of congestion. The highest Energy-Up bid corresponding to the TRAS-Up requirement will set the market-clearing price.
Price discovery for TRAS-Down will follow the pay-as-bid principle. Energy-Down bids will be ranked from highest to lowest, and providers will be selected in that order to meet the estimated requirement.
TRAS-Up providers will receive the applicable market-clearing price for the quantum of energy instructed for dispatch. They will also receive commitment charges at 10% of the applicable market-clearing price, subject to a ceiling of ₹0.20 (~$0.0021/kWh, for TRAS-Up cleared in the Day Ahead Ancillary Service Market or Real Time Ancillary Service Market but not instructed for dispatch.
TRAS-Down providers must repay the Deviation and Ancillary Service Pool Account at their Energy-Down bid rate for the capacity instructed for dispatch.
Settlement Mechanism and Emergency Provisions
The regulations require that all payments and settlements to be routed through the Regional Deviation and Ancillary Service Pool Accounts.
The pool account will bear the cost of SRAS-Up energy charges, SRAS incentives, TRAS-Up dispatch payments and commitment charges, while credits will come from payments made by SRAS-Down and TRAS-Down providers.
Weekly settlement of liabilities will be carried out by the National Load Despatch Center (NLDC), the Regional Load Despatch Centers (RLDCs), the Regional Power Committees (RPCs), and SLDC as applicable. No transmission charges, transmission losses, or transmission deviation charges will apply to SRAS and TRAS transactions.
The draft also includes provisions for reserve shortfalls and emergency situations. Generating stations regulated under Section 62 of the Electricity Act that have requisitioned surplus power may be deemed available for ancillary services.
Such stations will incur energy charges and applicable incentives for SRAS deployment, while TRAS-Up deployment, due to market shortfalls, will be compensated at 110% of energy charges.
In emergency conditions, NLDC, RLDC, or SLDC may direct generating stations to provide ancillary services, with compensation based on tariff-determined energy charges or declared compensation charges.
The SLDC has been directed to prepare, within three months of the regulations&#8217; notification, a detailed procedure for Commission approval covering operational, metering, communication, settlement, and market participation requirements.
Recently, UERC <a href="https://www.mercomindia.com/uttarakhand-rules-against-connectivity-fees-for-ehv-load-enhancement" target="_blank" rel="noopener">clarified</a> that the Power Transmission Corporation of Uttarakhand is not required to execute a separate connection agreement directly with consumers seeking a new EHV connection, an enhancement or reduction of load, or a change in the distribution licensee.
Subscribe to Mercom’s real-time <a href="https://mercomindia.com/product/mercoms-renewable-energy-regulatory-updates/" target="_blank" rel="noopener">Regulatory Updates</a> to ensure you don’t miss any critical updates from the renewable industry.

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					</table>India’s push to <a href="https://www.mercomindia.com/bridging-the-solar-skills-gap-as-academia-races-to-catch-up" target="_blank" rel="noopener">expand</a> solar manufacturing is exposing a persistent gap between academic training and industry requirements, contributing to a growing shortage of skilled workforce, according to industry leaders. The widening skills gap has increasingly affected project costs, execution timelines, and overall productivity across the sector.
The Odisha Electricity Regulatory Commission <a href="https://www.mercomindia.com/odisha-proposes-ancillary-services-framework-for-grid-security" target="_blank" rel="noopener">issued</a> the draft Ancillary Services Regulations, 2026, which sets out a state-level framework for the procurement, deployment, payment, accounting, and settlement of ancillary services. The draft defines ancillary services as services necessary to support grid operation by maintaining power quality, reliability, and security.
India’s clean energy transition initiatives are <a href="https://www.mercomindia.com/msmes-gain-easier-access-to-clean-energy-financing-as-banks-expand-offerings" target="_blank" rel="noopener">increasingly</a> moving beyond utility-scale projects and into the country’s medium, small, and micro enterprises (MSME) segment, with businesses exploring strategies to lower their power costs and become more sustainable in their operations. According to banking executives, renewable energy financing has evolved significantly over the last few years, moving beyond conventional project lending into customized financial products designed specifically for MSMEs, commercial establishments, and industrial consumers seeking to reduce electricity costs and improve long-term operational efficiency.
NLC India <a href="https://www.mercomindia.com/nlc-india-invites-bids-to-lease-1500-acres-in-gujarat-for-solar-projects" target="_blank" rel="noopener">invited</a> bids to lease 1,500 acres of land in Gujarat for the development of solar projects. Bidders must arrange government or private land parcels through a lease arrangement on behalf of NLC India Renewables. The tender has specified the land requirement based on a benchmark of five acres per MW for solar project development.
For energy-intensive industries, the shift to solar is no longer being driven by sustainability targets alone. From food processing units to manufacturing plants, businesses are increasingly <a href="https://www.mercomindia.com/dp-cocoa-eyes-%E2%82%B911-million-power-bill-savings-with-rooftop-solar-project" target="_blank" rel="noopener">adopting</a> captive rooftop solar systems as a practical way to protect margins, stabilize energy costs, and reduce dependence on conventional grid power. The growing adoption reflects a broader shift in how industries no longer view energy as merely a utility cost but as a strategic business lever.
I Squared Capital, a global infrastructure investment manager, <a href="https://www.mercomindia.com/i-squared-capital-launches-1-billion-power-transmission-platform-in-india" target="_blank" rel="noopener">launched</a> Cube Grid, a power transmission platform targeting India’s electricity grid, with plans to deploy up to $1 billion in equity capital. The platform will acquire and build a portfolio of transmission assets across India. Cube Grid has signed agreements for seed assets totaling more than 1,450 circuit kilometers of transmission lines.
Rooftop solar solutions company Fujiyama Power Systems’ board of directors <a href="https://www.mercomindia.com/fujiyama-to-set-up-1-2-gw-solar-cell-manufacturing-plant-in-madhya-pradesh" target="_blank" rel="noopener">approved</a> a proposal to set up a 1.2 GW TOPCon solar cell manufacturing facility at its Ratlam plant in Madhya Pradesh for an estimated investment of ₹3.5 billion (~$36.48 million). The investment will be funded through a combination of debt and internal accruals.
Veda Solar <a href="https://www.mercomindia.com/veda-solar-begins-commercial-production-of-modules-at-1-5-gw-surat-plant" target="_blank" rel="noopener">commenced</a> commercial production of solar modules at its Surat, Gujarat, manufacturing facility, with capacities ranging from 550 MWp to 630 MWp. The company aims to enhance its commercial and utility-scale portfolio. Veda Solar said it combines 1.5 GW production capacity with TOPCon and bifacial technology. Its portfolio also includes monofacial, bifacial, black, and poly modules. Its manufacturing process incorporates advanced N-Type TOPCon technology.

Daily News Wrap-Up: India’s Solar Manufacturing Faces a Growing Skills Gap

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					</table>The Odisha Electricity Regulatory Commission (<a href="https://www.orierc.org/" target="_blank" rel="noopener">OERC</a>) has issued the draft Ancillary Services Regulations, 2026, which sets out a state-level framework for the procurement, deployment, payment, accounting, and settlement of ancillary services.
The draft defines ancillary services as services necessary to support grid operation by maintaining power quality, reliability, and security.
Stakeholders have until June 20, 2026, to submit their suggestions.
The proposed rules introduce Secondary Reserve Ancillary Service (SRAS), Tertiary Reserve Ancillary Service (TRAS), and other services, such as voltage control and black start ancillary services, as specified in the Odisha Grid Code.
The draft designates the State Load Despatch Centre (SLDC) as the nodal agency for implementing ancillary services.
Activation and Procurement of SRAS
For SRAS, the draft provides that activation will occur when the state’s area control error goes beyond the threshold of +10 MW or another limit notified by the Commission, or when required for congestion relief or replenishment of primary reserves.
SRAS will be procured at the state level by the nodal agency.
The proposed SRAS procurement mechanism requires providers to give standing consent for at least seven days. Generating stations must declare parameters such as installed capacity, declared capacity, maximum possible generation, schedule, technical minimum, and ramp-up and ramp-down capability.
Despatch of SRAS
Under the proposed rules, Secondary Reserve Ancillary Service (SRAS) will be activated through automatic generation control or secondary control signals.
The SRAS provider will be selected by the nodal agency for providing SRAS-Up or SRAS-Down based on the customer participation factor.
SRAS will be dispatched at the state level through secondary control signals by the nodal agency. The nodal agency will send the secondary control signal for SRAS-Up and SRAS-Down to the SRAS provider&#8217;s control center every four seconds. The SRAS provider will allow its control center to follow the secondary control signal for SRAS-Up or SRAS-Down automatically without manual intervention.
The average of SRAS-Up and SRAS-Down data will be calculated by the nodal agency for each five-minute time block, using archived SCADA data at the nodal agency, reconciled with data received at the SRAS provider&#8217;s control center, and used for payment of the energy charge or compensation charge.
Payment of SRAS Incentive
SRAS may be provided by generating stations, energy storage systems, or demand response entities connected to the intrastate transmission system, provided they have bi-directional communication with SLDC, metering and SCADA telemetry, and the ability to respond within 30 seconds, deliver the full SRAS capacity obligation within 15 minutes, and sustain it for at least 30 minutes.
The draft contains two different provisions on SRAS incentive treatment. No incentive will be provided during the introductory stage of SRAS implementation, while Regulation 12 sets out an incentive structure based on performance, ranging from ₹0.10 (~$0.001)/kWh to ₹0.50 (~$0.0052)/kWh for performance levels from 20% to 95% and above.
Performance below 20% on two consecutive days may result in disqualification from SRAS participation for one week.
Tertiary Reserve Ancillary Service
The draft also introduces Tertiary Reserve Ancillary Service (TRAS), which may be provided by generating stations, energy storage resources, or demand response entities connected to the interstate or intrastate transmission system.
TRAS providers must be capable of varying active power output, drawal, or consumption on receipt of SLDC dispatch instructions, and must be able to provide service within 15 minutes and sustain it for at least 60 minutes.
Procurement of TRAS
The procurement of TRAS through the Day Ahead Ancillary Service (AS) Market and the Real Time AS Market will be undertaken in accordance with the bidding timelines specified in the Grid Code. Until specific provisions in this regard are set out in the Grid Code, the bidding timelines for the Day Ahead AS Market and the Real Time AS Market will be the same as those of the Day Ahead Market for energy and the Real Time Market for energy, respectively.
The capacity offered as a sell bid for energy and for TRAS from the same resource in the same time block shall be separate and non-overlapping.
The capacity offered as a sell bid in the power exchange to provide TRAS-Up or TRAS-Down from a resource in the same time block will be separate and non-overlapping.
A TRAS Provider cleared in the Day Ahead AS Market may place incremental bids in the Real Time AS market. A TRAS Provider not cleared in the Day Ahead AS Market or that has not participated in the Day Ahead AS Market may also place bids in the Real Time AS market.
Price Discovery for TRAS-Up
The price discovery for TRAS-Up will be based on the uniform market-clearing price principle, subject to market splitting in the event of congestion. The highest energy-up bid corresponding to the requirement for TRAS-Up will be the market-clearing price for Energy-Up in the Day Ahead Ancillary Service market or in the Real Time Ancillary Service market.
Price Discovery for TRAS-Down
The price discovery for TRAS-Down will be based on the pay-as-bid principle. The Energy-Down bids will be ranked in descending order from the highest Energy-Down bid to the lowest, and the nodal agency will select the TRAS-Down.
Shortfall in SRAS and TRAS Procurement
In the event of a shortfall in SRAS or TRAS procurement, all generating stations whose tariffs are determined by the Commission, including those with surplus power, will be deemed available to the SLDC for use. If unrequisitioned surplus is dispatched for TRAS-Up due to a shortfall in market procurement, the generator will be paid 110% of energy charges; if dispatched for TRAS-Down, it will be paid back at 90% of energy charges.
Deviations by ancillary service providers will be calculated for each 15-minute time block and settled in accordance with the deviation settlement mechanism regulations. No transmission charges, transmission losses, or transmission deviation charges will be payable for SRAS and TRAS.
Recently, OERC <a href="https://www.mercomindia.com/odisha-proposes-new-transmission-tariff-framework-for-fy-2028-and-2029" target="_blank" rel="noopener">issued</a> the draft ‘Terms and Conditions for Determination of Transmission Tariff Regulations, 2026,’ establishing the framework for determining transmission tariffs for intrastate transmission systems.
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Odisha Proposes Ancillary Services Framework for Grid Security

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					</table>The Karnataka Electricity Regulatory Commission (<a href="https://kerc.karnataka.gov.in/en" target="_blank" rel="noopener">KERC</a>) has released draft regulations to strengthen the framework for ancillary services to maintain the state’s grid.
These regulations are driven by an increasing renewable energy penetration, rising demand, and diverse grid integration challenges.
KERC has invited stakeholders&#8217; objections, suggestions, and views on the proposed draft within 30 days.
The regulations apply to intra-state entities, including entities with energy storage resources and entities capable of providing demand response and qualified to provide ancillary services.
The regulations will be applicable from the date of their publication in the official gazette.
The nodal agency will estimate the quantum of the secondary reserve ancillary service (SRAS) requirement at the state level. It will access the quantum of the requirement of SRAS a day before and incremental requirements on a real-time basis and update it on its website.
Eligibility and Selection of SRAS Provider 
<ul>
<li>The provider must have a bi-directional communication system with the state load dispatch centre (SLDC).</li>
<li>The communication system should be automatic generation control (AGC)-enabled and provide a minimum response of 1 MW.</li>
<li>Metering and supervisory control and data acquisition (SCADA) telemetry must be enabled to monitor and measure energy delivered under SRAS.</li>
<li>The communication system must respond to the SRAS signal within 30 seconds, provide the entire SRAS capacity within 15 minutes, and sustain it for 30 minutes.</li>
</ul>
Dispatch and Payment for SRAS
SRAS signal will be allocated among the SRAS providers to meet the system requirement based on the merit order of variable or compensation charges.
The SRAS providers must increase or decrease active power injection or increase or decrease drawal or consumption, per the automatic signal from the nodal agency.
The secondary control signal for SRAS-Up and SRAS-Down will be sent to the control center of the SRAS providers every four seconds.
SRAS providers will be paid from the state deviation settlement mechanism account (SDSMA) at the rate of their energy charge or compensation charge for the SRAS-Up MW quantum despatched for every 15-minute time block.
SRAS providers must pay the SDSMA back, at the rate of their energy or compensation charge, for the SRAS-Down MW quantum despatched for every 15-minute time block.
The nodal agency will monitor the actual response of the SRAS providers against the secondary control signals. All measurements of secondary control signals from the nodal agency to the SRAS provider’s control center and the actual response of the provider will be carried out on a post-facto basis using SCADA data.
Performance below 20% for two consecutive days by an SRAS provider will make them liable for disqualification for participation in SRAS for a week by the nodal agency.
Emergency conditions 
All generating stations whose tariff is determined by the Commission are deemed available for use by the nodal agency subject to any technical constraints.
If the nodal agency requires any generating station to provide ancillary services to meet the emergency conditions for reasons of grid security per the provisions of the Grid Code, such generating station will be compensated at the energy charge rate specified by the Commission.
Accounting for SRAS will be done by the nodal agency every week based on the interface meter data.
No retrospective settlement of energy or compensation charges can be undertaken. No transmission, losses, or deviation charges will be payable for SRAS.
The nodal agency must submit the detailed procedure through an application and a gist of the application before the Commission for approval within three months of these regulations. On admitting the application, the Commission will ask the nodal agency to publish the gist of the application within seven working days.
The detailed procedure shall contain SRAS’ operational aspects, including bi-directional communication system, metering, and SCADA telemetry.
In April 2024, the Central Electricity Regulatory Commission <a href="https://www.mercomindia.com/regulator-ancillary-services-peak-power-demand" target="_blank" rel="noopener">expanded</a> the scope of operation of the Reserve Regulation Ancillary Services Regulations, 2015, to facilitate the availability of adequate power reserves with the system operator to manage the peak demand.
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Karnataka Releases Draft Regulations for Grid Ancillary Services

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					</table>The Assam Electricity Regulatory Commission (<a href="https://aerc.gov.in/" target="_blank" rel="noopener">AERC</a>) has released the draft of the Assam Electricity Regulatory Commission (Deviation Settlement Mechanism and Related Matters) Regulations, 2024.
The regulations, which will take effect on April 1, 2025, aim to streamline the deviation settlement process, enhance grid reliability, and more effectively integrate renewable energy sources into Assam&#8217;s power system.
The AERC has invited feedback from individuals and corporate bodies by November 12, 2024.
These regulations apply to the conveyance of electricity transactions through short-term, medium-term, or long-term open access using the intra-state transmission or distribution systems, including inter-state power wheeling, under the following conditions:
<ul>
<li>The Deviation Settlement Mechanism (DSM) outlined in these regulations will apply to all sellers, including generators, captive generators, Renewable Energy Generators (REGS), and Run-of-River Hydroelectric Generators (RHGS), connected to the intra-state transmission system.</li>
<li>The DSM will also apply to all buyers within the state, including distribution licensees and deemed distribution licensees.</li>
</ul>
To ensure the safe and stable operation of the grid, all regional entities connected to the grid must follow their designated schedules as outlined in the Indian Electricity Grid Code (IEGC) 2023 (including any amendments) until the AEGC 2024 is implemented. These entities should also aim to minimize deviations from their schedules.
State entities must notify the State Load Despatch Center (SLDC) of all energy exchange contracts they have entered into. State entities must also operate their equipment and loads under the provisions of the IEGC, 2023 (and its amendments) until the AEGC, 2024, comes into effect.
State entities must sign a Connection Agreement or Open Access Agreement with the relevant transmission licensee, specifying the physical and operational requirements for reliable operations and gaining access to the intra-state transmission system (InSTS) or with the distribution licensee for distribution system use as per the Open Access Regulations.
They must also install interface meters that record energy flows at 15-minute intervals at the points of injection and withdrawal.
Metering systems should be synchronized using a Global Positioning System with a cross-check from the SLDC.
The SLDC will make all decisions regarding MW dispatch from generating stations, considering network parameters, constraints, and congestion within the transmission network. In case of network anomalies, SLDC’s instructions regarding dispatch and drawal will be binding on all state entities.
It will also publish relevant information to inform all state entities about energy exchanges and any urgent conditions related to power dispatch.
Deviation charges for the injection of infirm power will  be set at zero. However, if the infirm power is scheduled after a trial run as per the IEGC, 2023 (or AEGC, 2024, once it takes effect), the applicable deviation charges will follow the rules for either a general seller or WS seller, depending on the case.
Deviation charges for drawing start-up power prior to a generating unit&#8217;s commercial operation date for power used to operate auxiliaries during a station’s shutdown will be paid at the reference charge rate, contract rate, or, if neither is available, the weighted area clearing price (ACP) from the Day Ahead Market (DAM) segments of power exchanges for the specific time block.
In case of forced or partial outages for sellers, deviation charges will be based on the reference charge rate for a maximum of eight-time blocks or until the schedule is revised, whichever comes first.
For sellers whose bids are cleared in the HP-DAM, the reference charge rate for deviations due to under-injection will be equivalent to the weighted average ACP of the HP-DAM Market segments from all power exchanges for that time block.
If a state has net injection at the regional periphery, deviation charges will be applied as if the state were a buyer.
Accounting of Deviation and Ancillary Service Charges
<ol>
<li>The tate power committee will issue a weekly statement of deviation charges to all constituents, based on available data, by Tuesday for the previous week ending on Sunday at midnight.</li>
</ol>
<ul>
<li>Inter-state entities will not have transaction-wise DSM accounting at the state level.</li>
<li>QCAs for REGS/RHGS will follow the roles outlined in the IEGC, 2023 until the AEGC, 2024 is in force.</li>
</ul>
<ol start="2">
<li>All deviation charges, including interest from late payments, will be deposited into the “State Deviation and Ancillary Services Pool Account,” managed by SLDC as per regulations.</li>
</ol>
<ul>
<li>The Commission may designate another entity to operate the account.</li>
<li>SLDC will maintain separate accounts for principal and interest components of deviation charges.</li>
<li>State entities must comply with applicable tax and levy requirements (e.g., GST, TDS) and support SLDC in meeting reporting obligations.</li>
</ul>
<ol start="3">
<li>SLDC will prepare a detailed procedure for operating the Pool Account within three months of the regulation&#8217;s commencement, subject to Commission approval.</li>
</ol>
Schedule of Payment of Deviation Charges
<ul>
<li>Deviation charges must be paid into the Pool Account within ten days of SLDC issuing the statement.</li>
<li>If payment is delayed beyond ten days, the defaulting entity must pay simple interest at a rate of 0.04% per day of delay.</li>
<li>Entities failing to pay deviation charges within the previous year’s deadline must open a Letter of Credit equal to 110% of their average weekly liability from the previous financial year.</li>
</ul>
Within three months of notification, SLDC will draft Operating Procedures and Business Rules for the state power committee. The committee will coordinate intra-state energy exchange, monitor regulation compliance, and guide SLDC in modifying procedures as needed.
In September, AERC <a href="https://www.mercomindia.com/assam-regulator-unveils-and-virtual-net-metering" target="_blank" rel="noopener">released</a> draft guidelines for implementing group net metering and virtual net metering frameworks for renewable energy systems. These guidelines, which will become effective upon issuance, aim to promote the adoption of renewable energy and provide more flexible options for consumers.
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Assam Regulator Unveils Draft Deviation Settlement Mechanism Rules

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					</table>The Central Electricity Regulatory Commission (<a href="https://cercind.gov.in/" target="_blank" rel="noopener">CERC</a>) has approved the introduction of the Tertiary Reserve Ancillary Services (TRAS) market segment on all three power exchanges.
TRAS are frequency control ancillary service capacities that are used to keep the grid frequency in the designated range. It comprises qualified power plants, energy storage systems, and interruptible loads readily available for dispatch to restore the secondary reserve and cover variations of renewable energy generations.
The Commission also directed the power exchanges to incorporate provisions in their bye-laws, rules, and business rules concerning the Ancillary Services market segment on their platform and submit them to the Commission for records within a week.
Further, the Central Commission noted that the TRAS framework was scheduled to be made effective from May 1, 2023. However, the Commission decided to give more time to the National Load Despatch Center (NLDC) and the power exchanges to align and test the processes involved in the bidding, information exchange, and price discovery to ensure a smooth rollout of the TRAS from June 1, 2023.
Hindustan Power Exchange (HPX), Power Exchange of India (<a href="https://powerexindia.in/" target="_blank" rel="noopener">PXIL</a>), and Indian Energy Exchange (<a href="https://www.iexindia.com/" target="_blank" rel="noopener">IEX</a>) had filed separate petitions for the introduction of ancillary services on the platforms.
Background
CERC notified the Ancillary Services Regulations on January 31, 2022. The operation of the Ancillary Services Regulations 2022, except for certain provisions about TRAS, came into effect on December 5, 2022. Subsequently, the provisions related to TRAS were notified with an effective date of April 1, 2023.
The Commission later changed the date to May 1, 2023.
The three major exchanges presented their arguments regarding implementing TRAS in their respective petitions.
HPX had sought to introduce ancillary services contracts in Day-Ahead Market (DAM) and Real-Time Market (RTM) contracts on its trading platform to implement the provisions about TRAS.
HPX argued that Order Carry Forward (OCF) basis from Integrated Day Ahead Market (I-DAM) to Ancillary Service Day Ahead Market (AS-DAM) would effectively render the AS-DAM and AS-RTM market segments anti-competitive and hinder market penetration.
Adhering to the OCF mechanism would limit trading to the liquid exchange, leaving stakeholders with no alternative but to engage exclusively in these specific segments. This could result in an unintentional concentration of bidding activity on one power exchange without any clear stakeholder advantages.
According to PXIL, the AS Regulations 2022 provide guidelines for determining prices in TRAS-Up and TRAS-Down. However, there needs to be an indication in the regulations about the approach market participants should take when placing orders to participate in the TRAS market.
PXIL argued that the power exchange platform is responsible for soliciting bids from market participants for TRAS-Up and TRAS-Down contracts and forwarding the bids to the nodal agency for price discovery. This requires &#8216;PRATYAY,&#8217; PXIL’s trading platform, to operate 24/7 and maintain full exchange infrastructure availability to collect and transmit bid information.
According to IEX, implementing a distinct price cap of ₹12 (~$0.147)/kWh for DAM and RTM and ₹50 (~$0.611)/kWh for the ancillary services market would enable sellers to exploit arbitrage opportunities.
This could incentivize generators to prioritize capacity allocation in the market to increase revenue, potentially exacerbating supply and demand imbalances and driving up energy prices. IEX recommended that the ancillary services market should have two segments with price caps of ₹12 (~$0.147)/kWh and ₹50 (~$0.611)/kWh, similar to the energy market.
Commission&#8217;s analysis
The Commission observed that introducing TRAS through a market-based mechanism would play a critical role in ensuring the power system&#8217;s smooth operation and the grid&#8217;s safety and security while providing a new avenue for market participants under the ancillary services mechanism.
The Commission noted that it was crucial to recognize the inherent differences between the ancillary services market and the energy market. Unlike the energy market, the ancillary services market was characterized by less certainty of dispatch due to its reliance on grid conditions, despite the availability of commitment charges for transactions.
CERC acknowledged that the OCF mechanism effectively promotes participation in the ancillary services market. By doing so, TRAS providers could provide the reserve capacity required for grid stability and security without affecting energy market availability.
The Commission directed that the bids placed under TRAS-DAM should be subject to the same price caps as applicable for the energy segment of I-DAM. Additionally, bids placed under TRAS-RTM will be subject to the same price caps as TRAS-DAM.
The central regulator noted that settlement in the ancillary services market should be retained by NLDC for operational convenience as it performs essential functions in the ancillary services market, such as assessing TRAS requirements, determining prices, and dispatching instructions to TRAS providers.
It added that the ancillary services market needed detailed examination.
The Commission has already directed its staff to examine all the factors that have a bearing on transaction fees, including the risks involved in power exchange operations.
The Commission approved introducing the TRAS market segment on all three power exchanges from June 1, 2023.
Recently, CERC <a href="https://www.mercomindia.com/changes-power-exchanges-bidding-software" target="_blank" rel="noopener">directed</a> all power exchanges to redesign their bidding software to allow members to quote prices within a specified range for different types of contracts. The Commission said that redesigning the bidding software would reduce the cost of power for buyers while also providing an opportunity for high-cost generators and willing buyers to participate in the High Price Day Ahead Market (HP-DAM) market.
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CERC Approves Introduction of Ancillary Services Segment on Power Exchanges

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					</table>The Central Electricity Regulatory Commission (<a href="https://cercind.gov.in/" target="_blank" rel="noopener">CERC</a>) has expanded the scope of operation of the Reserve Regulation Ancillary Services (RRAS) Regulations, 2015, to facilitate the availability of adequate power reserves with the system operator to manage the peak demand.
The aim of the RRAS Regulations 2015 is to restore the frequency at the desired level and to reduce congestion in the transmission network.
The ancillary services ensure generation to meet the excess demand during peak hours.
Expanding the scope of RRAS Regulations, the Central Commission has included state-generating stations whose tariffs have been determined or adopted by the State Commission and are willing to participate in RRAS.
Also, included under the purview of RRAS Regulations are generating stations that have been mandated by the central government to participate in RRAS and have their tariffs discovered through a competitive bidding process.
This is in addition to the regional entities whose tariffs have been determined and adopted by the Central Commission.
Also, the nodal agency’s merit order stack must now encompass state-generating stations whose tariffs have been determined or adopted by the State Commission and generating stations mandated by the central government to participate in RRAS, as well as regional generating stations whose tariffs have been determined and adopted by the Commission.
Under the existing RRAS Regulations 2015, only generating stations that are regional entities with their tariff determined or adopted by the Central Commission are eligible to offer RRAS.
Grid-India reported that this made it difficult to use other projects whose tariffs had yet to be determined or adopted by the Commission for RRAS.
After examining the power supply status across the nation, the Commission noted that on April 18, 2023, the highest level of demand reached 215.9 GW. This is anticipated to escalate even more due to rising temperatures in the coming months.
Grid-India informed the Commission of the steps taken by the system operator to guarantee the dependable operation of the grid.
Furthermore, to ensure that reserves are sufficient, Grid-India requested the Commission to expand the scope of RRAS Regulations 2015 to include resources other than the generating stations regulated by the Central Commission.
Recently, CERC  <a href="https://www.mercomindia.com/measures-reduce-grid-frequency-fluctuations" target="_blank" rel="noopener">issued</a> regulations to limit frequency fluctuations within the operating band in the interest of grid security. The regulator has set the normal rate of charges for deviation for a given time block.
Earlier, CERC had <a href="https://www.mercomindia.com/cerc-new-deviation-guidelines-maintain-grid-security" target="_blank" rel="noopener">issued</a> new guidelines to supplement the Deviation Settlement Mechanism (DSM) Regulations 2022 to maintain grid security. The Commission added a new category of wind-solar generators and introduced charges for DSM. Further, it also hiked monetary incentives for both generators and procurers to maintain the grid frequency between the safe range of 49.95-50.05 Hz.
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Regulator Amends Ancillary Services Norms to Meet Peak Power Demand

In a joint study, Finnish power conglomerate <a href="https://www.wartsila.com/" target="_blank" rel="noopener">Wartsila</a> and consulting firm KPMG have said that supply-side flexibility is needed at the pan-India level to integrate 450 GW of renewables by 2030 efficiently.
The report notes that ancillary services&#8217; current market design and structure need to be enhanced to manage imbalances efficiently at the state boundary. Efficient market design where energy and ancillary services are co-optimized will encourage investments in flexible resources for imbalance management. Even with large balancing areas facilitated by the market-based economic dispatch (MBED) mechanism, investment in flexible assets is required to achieve reliable grids.
The study demonstrates that India&#8217;s power system would not require any new coal-fired power plants to be commissioned beyond what is planned to meet the 340 GW peak demand. It suggests that India&#8217;s power grid could use internal combustion gas engines (ICE) and battery storage to meet the flexibility requirements. The study indicates that by 2030, India would need 38 GW of four-hour battery storage and 9 GW of thermal balancing power project for the cost-efficient and reliable integration of 450 GW of renewables.
More than 35 GW of wind and solar capacities would need to be consistently added annually between now and 2030. It suggests that higher supply-side flexibility reduces the cost of power in the system by enabling the full dispatch of low-cost generators while at the same time ensuring grid resilience.
The study finds that centralized or regional procurement helps lower costs. It advocates that co-optimization of the energy and ancillary services market is more efficient than separate markets for energy and ancillary services.
Managing India&#8217;s power system is becoming increasingly complex as its resource mix includes more weather-dependent and decentralized energy sources. To deal with such complexity, the system operator needs greater operational flexibility to reliably serve the load, increasing the need for ancillary services to keep the grid stable.
The analysis reveals that the addition of 1 GW of thermal balancing power plants, together with 500 MW 4-hour of battery storage in the electricity mix in each state, even in 2021, optimizes the existing power plants&#8217; dispatch for better efficiency, lower operational and maintenance costs, and reduced renewable curtailment.
The findings suggest that the addition of thermal balancing with battery storage results in cost savings of at least ₹32 million (~$428,810) to ₹70 million (~$938,022) per day for states like Gujarat, Tamil Nadu, and Rajasthan. Thermal balancing plants can achieve 100% loading in less than five minutes.
In India, ancillary services have historically been delivered by identified thermal power plants. However, India&#8217;s policymakers and stakeholders are now convinced that energy and ancillary services markets require reforms in response to the changing resource mix and load profiles.
The Ministry of Power had <a href="https://mercomindia.com/ministry-proposes-new-mechanism/" target="_blank" rel="noopener">proposed</a> a new MBED mechanism to bring down the cost of power for distribution companies and consumers. The mechanism is also expected to enhance renewable energy integration with the balancing area increased from the state to the national level leading to a considerable drop in renewable energy curtailment.
In June, the Central Electricity Regulatory Commission had <a href="https://mercomindia.com/cerc-proposes-energy-storage-in-maintaining-grid-stability/" target="_blank" rel="noopener">issued</a> the draft &#8216;Ancillary Services Regulations, 2021&#8217;. The guidelines aim to provide power procurement through the administered process and from the spot market through power exchanges to pay for ancillary services and maintain the grid frequency close to 50 Hz.

India Needs 38 GW of 4-Hour Battery Storage to Integrate 450 GW of Renewables by 2030: Study

The Central Electricity Regulatory Commission (<a href="http://www.cercind.gov.in/" target="_blank" rel="noopener">CERC</a>) has drafted the Ancillary Services Regulations, 2021. The guidelines aim to provide for power procurement through the administered process as well as from the spot market through power exchanges to pay for ancillary services and maintaining the grid frequency close to 50 Hz. The regulations have made provisions for allowing for energy storage and demand response resources to participate in providing ancillary services.
CERC has invited comments and suggestions from stakeholders and interested parties on the proposal within June 30, 2021.
These regulations are to help restore the grid frequency as specified in the Grid Code and for relieving congestion in the transmission network to ensure smooth operation of the grid.
The types of ancillary services covered under these regulations are Primary Reserve Ancillary Service (PRAS), Secondary Reserve Ancillary Service (SRAS), and Tertiary Reserve Ancillary Service (TRAS). Apart from the three services, other ancillary services as specified in Grid Code will also be created.
The draft regulations provide more details on procurement, assessment, and compensation for SRAS and TRAS, which are open to entities with energy storage or demand response resources connected to the transmission system.
Secondary Reserve Ancillary Service 
Secondary Reserve Ancillary Services are frequency control ancillary service capacities of qualified generating plants and energy storage systems that are assigned to restore the system frequency to 50 Hz. They are used to provide supply-demand balance during small frequency deviations.
A generating station having energy storage resource and connected to the interstate transmission system (ISTS) or intrastate transmission system will be eligible to provide SRAS, provided:
<ul>
<li>It has a bi-directional communication system with the national load dispatch center and the regional load dispatch center</li>
<li>It is automatic gain control-enabled</li>
<li>It can provide a minimum response of 1 MW</li>
<li>Has metering and supervisory control and data acquisition (SCADA) telemetry in place for measuring the energy delivered under SRAS</li>
<li>It is capable of responding to SRAS signal within 30 seconds and providing the entire SRAS capacity within 15 minutes and sustained for at least the next 30 minutes</li>
</ul>
The SRAS provider willing to participate will be required to provide consent to the state nodal agency for participation, which will remain valid until it is modified or withdrawn. The SRAS providers who are generating stations will be required to declare the technical parameters by the nodal agency. The SRAS providers other than generating stations will be required to pay the variable and the compensation charges upfront every month.
The nodal agency will also ascertain the availability of adequate reserves on a day-ahead and on a real-time basis before the closure of the real-time market. The SRAS provider will be selected on a regional basis by the nodal agency for providing the SRAS-Up and SRAS-Down based on custom participation factors. The custom participation factor for SRA-Up will be directly proportional to the normalized cost factor, and the custom participation factor for the SRAS-Down will be directly proportional to the product of the normalized rate participation factor and the normalized cost factor.
The SRAS will be despatched on a regional basis through secondary control signals by the nodal agency. The SRAS provider should increase or decrease active power injection or the withdrawal or consumption as per the automatic signal from the nodal agency.
The average of SRAS-Up and SRAS-Down MW data will be calculated by the nodal agency every five minutes in absolute terms using archived SCADA data at the nodal agency and will be used to pay incentive. The average of SRAS-up and SRAS-down MW data will be calculated for every 15 minutes time block in MWh for every SRAS provider by the nodal agency using the archived SCADA data. It will be used for paying variable or compensation charges.
Performance below 20% for two consecutive days will make the provider liable for disqualification for participation in SRAS for a week.
Tertiary Reserves Ancillary Services 
Tertiary Reserve Ancillary Services are frequency control ancillary service capacities of qualified power plants and energy storage systems and interruptible loads readily available for dispatch to restore the secondary reserve and cover variation of renewable energy generations. This service must also be used in maintaining the grid frequency as prescribed levels in case the primary and secondary reserves are not sufficient or already exhausted. A generating station or energy storage resource connected to an ISTS or intrastate transmission system will be eligible for participation as a TRAS provider. The TRAS will be activated and deployed by the nodal agency on account of the following factors:
<ul>
<li>In case the secondary reserve has been deployed continuously in one direction for 15 minutes for more than 100 MW</li>
<li>Other events as specified in the Grid Code</li>
</ul>
As per the order, the nodal agency will communicate to the power exchanges the quantum of TRAS-Up and TRAS-Down needed on a day-ahead basis before the commencement of the day-ahead market.
The TRAS providers will submit bids in the following manner:
<ul>
<li>Bids will be submitted for each time block or for a minimum of two consecutive time blocks in the day-ahead market or the real-time market</li>
<li>For TRAS-UP, energy up bid in ₹/MWh should be submitted for the offer volume in MW</li>
<li>For TRAS-Down, energy down bid in ₹/MW should be submitted for the offer volume in MW</li>
</ul>
The TRAS provider cleared in the day-ahead market may place incremental bids in the real-time market. The TRAS provider not cleared in the day-ahead market or not participating in the day-ahead market may also place bids in the real-time market. The price discovered for the TRAS-Up will be based on the principle of uniform market clearing price. The price discovery for TRAS-Down will be based on the principle of Pay-as-bid.
The scheduling and despatch of TRAS will be according to the provisions of the Grid Code. Information regarding the TRAS-Up and TRAS-Down cleared for the day-ahead market, and the real-time market will be published on the website of the nodal agency. It will be simultaneously communicated to the power exchanges concerned for onward communication to the selected TRAS providers.
The TRAS-Up provider will receive MCP-Energy-Up, as discovered in the day-ahead market or the real-time market, as the case may be, for the quantum of energy instructed to be despatched by the nodal agency.
The TRAS-Up Provider shall receive commitment charges at the rate of 10% of the MCP-Energy-Up-day-ahead market or the MCP-Energy-Up-real-time market, as the case may be, subject to the ceiling of ₹0.20/kWh for the quantum of TRAS-Up cleared in the day-ahead market or the real-time market.
The accounting of SRAS shall be done by the regional power committee every week, based on SCADA data. The accounting of TRAS will be done by the committee every week, based on interface meter data and schedules.
The deviation and ancillary service pool account will be charged for:
<ul>
<li>The full cost of despatched SRAS-Up, including the variable charge or the energy charge or the compensation charge for every time-block on a regional basis, as well as the incentive for SRAS, payable to the concerned SRAS provider.</li>
<li>The full cost towards TRAS-Up, including the charges for the quantum, cleared and despatched and the commitment charge for the quantum cleared but not despatched</li>
</ul>
The deviation and ancillary service pool account will receive credits for:
<ul>
<li>Payments made by SRAS provider for the SRAS-Down despatched</li>
<li>Payments made by TRAS provider for the TRAS-Down despatched</li>
</ul>
As per the order document, no transmission charges or transmission losses, or transmission deviation charges will be payable for SRAS and TRAS.
Recently, the Union Cabinet <a href="https://mercomindia.com/production-linked-incentive-battery-storage-approval/" target="_blank" rel="noopener">approved</a> the ‘National Program on Advanced Chemistry Cell Battery Storage’ under the production-linked incentive initiative. According to the Cabinet’s notification, the program aims to achieve 50 GWh of advanced chemistry cell and 5 GWh of niche advanced chemistry cell manufacturing capacity with an outlay of ₹181 billion (~$2.46 billion).
Subscribe to Mercom’s real-time <a href="https://mercomindia.com/product/mercoms-renewable-energy-regulatory-updates/" target="_blank" rel="noopener">Regulatory Updates </a>to ensure you don’t miss any critical updates from the renewable industry.

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