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					</table>The renewable energy units traded at the Indian Energy Exchange (<a href="https://www.iexindia.com/" target="_blank" rel="noopener">IEX</a>) in October 2023 dropped further to 188 million units (MU), the lowest recorded in 2023, a 53.35% year-over-year (YoY) and 18.26% month-on-month drop.
The renewable energy trade continues its downward trend at the IEX this year, with a ~50% YoY drop in the second quarter of the financial year 2023-24.
The Green Day-Ahead Market (GDAM) and Green Term-Ahead Market (GTAM) segments witnessed a surge in the weighted average prices during the month, causing a drop in trading volumes.
The GDAM traded 180.80 MU volume during the month, a 38.29% YoY drop and a 29% MoM increase. The weighted average price recorded in the segment was ₹6.37 (~$0.076)/kWh, up 58% YoY. The segment saw participation from 194 participants during the month, a sharp 73% drop from 721 participants in October 2022.
The GTAM achieved 7.23 MU, a 93.4% YoY, and a 92% MoM decline, primarily due to lower liquidity in the segment. The average monthly price of non-solar was recorded at ₹8.40 (~$0.101)/kWh.
According to Mercom sources, the decline in renewable energy trading was due to the lower generation from wind and hydropower sources due to the seasonal changes and flooding in most regions of the country. Also, with solar generation mostly tied up in long-term power purchase agreements, the market experienced a considerable drop in overall renewable energy trading.
The total electricity volume traded at the Exchange was recorded at 9,260 MU in October, a 21% YoY increase. The overall volume, including Renewable Energy Certificates Energy Saving Certificates, was 9,483 MU during the month, an 18% YoY increase.
According to GRID-INDIA, the country’s energy consumption reached 139 billion units during the month, a 22% YoY increase due to the surge in demand driven by increased electricity consumption, below-average rainfall in October, and a lower base from the same month last year.
The surge in electricity trade was primarily due to distribution companies actively purchasing power on the exchange to meet the increased demand.
Renewable Energy Certificate Market
A total of 217,000 renewable energy certificates (REC), equivalent to 217 MU, were traded during the two sessions on October 11 and October 23, 2023, at a clearing price of ₹380 (~$4.56) /REC and ₹420 (~$5.04) REC, respectively.
Early last month, the Central Electricity Regulatory Commission had <a href="https://www.mercomindia.com/cerc-allows-fortnightly-trading-rec" target="_blank" rel="noopener">ordered</a> two REC trading sessions every month, the second and the last Wednesday of each month for the upcoming six months, starting October.
The next REC trading sessions are scheduled at the Exchange on November 8 and 29.
Energy Saving Certificate Market
A total of 5,814 energy-saving certificates (ESCert), equivalent to 5.8 MU, were traded at the IEX during October at a floor price of ₹1,840 (~$22.10) / ESCert.
Electricity Market: Day-Ahead, Term-Ahead, and Real-Time Market
The volume traded in the Day-Ahead Market (DAM) segment increased to 4,742 MU in October, an 8.3% YoY increase from 4,379 MU. The surge in demand pushed the DAM prices to ₹6.45 (~$0.077)/kWh, a 68% YoY increase on a lower base price.
The Real-Time Electricity Market (RTM) segment registered 2,402 MU volume, a 6.1% YoY from 2,265 MU.
The Day-Ahead Contingency and Term-Ahead Market (TAM) segments comprising contingency, daily, weekly, and monthly contracts up to three months traded 1,911 MU during the month, a 207.6% YoY increase from 621 MU.
IEX <a href="https://www.mercomindia.com/iex-21-jump-profits-green-energy-trade-drops" target="_blank" rel="noopener">recorded</a> a profit after tax of ₹865 million (~$10.39 million) for the second quarter of the financial year (FY) 2023-24, a 21.5% YoY increase from ₹712 million (~$8.55 million). The Exchange recorded an electricity trading volume of 26.35 billion units, a 15% YoY increase. The trading volume comprised 24.07 BU from the conventional power market and 747.64 MU from the green market segment.

IEX Records Lowest Green Energy Trade in 2023 at 188 MU in October, 53% YoY Drop

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					</table>The <a href="https://posoco.in/" target="_blank" rel="noopener">Grid Controller of India</a> has issued the procedure to implement the uniform renewable energy tariff for the central pool of projects connected to interstate transmission systems (ISTS).
The procedure was issued as a follow-up to the announcement in August last year when the Ministry of Power <a href="https://www.mercomindia.com/ministry-proposes-renewable-central-pool-uniform-tariffs/" target="_blank" rel="noopener">proposed</a> establishing central pools of ISTS-connected renewable energy sources such as solar, wind, hybrid, and storage. Intermediary companies could use these pools to purchase power for distribution and retail supply to multiple states at a uniform tariff for each pool.
The Ministry emphasized that adopting a uniform renewable energy tariff incentivizes distribution companies (DISCOM) to engage in power purchase agreements (PPAs) and stimulate growth in the renewable energy sector. It is expected to alleviate issues wherein DISCOMs frequently delay PPA agreements or necessitate tariff renegotiations due to tariff discrepancies compared to previous PPAs.
According to the new procedure, each renewable energy source has been assigned an individual category of central pool:
<ul>
<li>Solar power central pool</li>
<li>Wind power central pool</li>
<li>Hydropower central pool</li>
<li>Solar-wind hybrid central pool</li>
<li>Round-the-clock power (solar wind hybrid + storage) central pool</li>
<li>Peaking power (solar wind hybrid + storage) central pool</li>
<li>Firm and dispatchable renewable power</li>
<li>Any other new pool as specified by the Central Government</li>
</ul>
There may be more than one category of central pool for solar-wind hybrid central pool, round-the-clock power (solar wind hybrid + storage) central pool, and peaking power (solar wind hybrid + storage) central pool depending upon the technology, generation mix, etc. as decided by the Central Government.
Validity
The Union government will independently announce the commencement date for each category of the central pool. Each of them will have a five-year duration.
Any capacity for which a power sale agreement (PSA) is signed within this five-year timeframe will be included in the central pool, provided all other eligibility criteria are met.
Beyond the initial five-year period from the pool&#8217;s start date, no additional capacity will be incorporated. All existing capacities will remain in the pool until their agreements expire.
The pool&#8217;s uniform renewable energy tariff calculation will be based solely on the energy from these existing capacities.
Eligibility criteria
Generators must use renewable energy sources and be connected to the ISTS network to qualify to supply energy to the uniform pool.
To become an end procurer, an entity must have a license to undertake the distribution and retail supply of electricity or be designated by the state government to procure power on behalf of the licensees undertaking the distribution and retail supply of electricity. It must obtain approval from the relevant state commission before procuring electricity from a pool.
Open access consumers can also become end procurers.
To qualify as an intermediary procurer, an entity must be designated by an order made by the central government as an intermediary between the end procurer and the generating company to purchase electricity from generating companies and resell it to the end procurer by aggregating the purchases. They must process a valid trading license.
Once eligible, they must submit their general details and a copy of the order issued by the central government designating them as an intermediary procurer. They must also submit approval from the appropriate commission allowing the end procurer to procure electricity through a uniform renewable energy tariff mechanism.
Implementing agency
The implementing agency will compute the uniform renewable energy tariff monthly based on information submitted by the intermediary procurer. They must then issue the monthly account statements to adjust any surplus or deficit tariff among the intermediary procurers based on information submitted by the intermediary procurer.
The implementing agency must publish the relevant details on its website, including the monthly accounts statements. It will have no liability except for monthly computing tariffs for the sale of power from the central pool as per these procedures and will be kept indemnified.
Data to compute uniform tariff
The intermediary procurer must provide energy schedule details from the relevant PPA and PSA as per information published in the Regional Energy Account (REA) by the respective Regional Power Committees. This data must be submitted to the Implementing Agency within four days of the REA publication, with a copy sent to the respective Regional Load Dispatch Centers (RLDCs).
The data should include contracted capacity, tariff based on PPA and PSA, the source pool category, or any other details requested by the implementing agency. Additionally, if energy from the central pool is sold to entities other than end procurers, the intermediary procurer must provide their details and pricing.
The intermediary procurer must submit PPA and PSA for the capacity which is part of the central pool. The intermediary procurer must provide the associated agreements if new capacity is added to the central pool, including partial capacity. Data for energy transactions from this additional capacity should be submitted according to the standard procedure, along with the next month&#8217;s data.
If there is a modification in the central pool due to a change in the PPA /PSA affecting the contracted capacity or change in the end procurer, the intermediary procurer should submit the related PPA and PSA to the implementing agency as per the routine procedure, i.e., along with the data of the next month.
Data verification
The data submitted by the intermediary procurer will be verified by the respective RLDC, where the generator is geographically located, within three days, and submit the details to the intermediary procurer.
In case of any discrepancy observed or any further clarification required by the respective RLDCs, the same will be informed to the intermediary procurer within two working days after receiving the data from the concerned RLDCs. The intermediary procurer must provide the clarification within three working days.
After final receipt of the data, the RLDCs will verify the details within two working days and submit the details to the implementing agency.
Tariff Calculation Method
Once the RLDC has verified the data, it is consolidated for each source-wise central pool. The implementing agency will then calculate the tariff for each pool within three working days.
Subsequently, the implementing agency will promptly release the uniform renewable energy tariff for each source-wise central pool on its website, typically within three working days of receiving the verified data from the RLDCs.
The tariff for the month is computed by aggregating the total amount to be paid for the energy supplied under the tariff, which includes the trading margin for each renewable energy source. This aggregated sum is then divided by the total scheduled energy of the qualified project under this program.
The implementing agency will publish these calculations and the uniform renewable energy tariff for each source-wise central pool on its website every month.
Adjustments
The implementing agency will provide monthly account statements for adjusting any surplus or deficit in the tariff among intermediary procurers.
The agency will publish these tariff adjustment addend and monthly account statements within seven days of receiving data from the intermediary procurers and verification by the RLDCs for all intermediary procurers.
If REA is revised, the implementing agency will reevaluate the uniform renewable energy tariff for the relevant pool and the monthly account statements for adjusting any surplus or deficit among intermediary procurers. Such revisions will be conducted by the implementing agency once a month.
Intermediary procurers must make payments based on the monthly account statements within fifteen days. Failure to do so within this stipulated period will result in carrying costs at a rate calculated as the State Bank of India&#8217;s marginal cost of funds-based lending rate (1-year tenor) plus an additional five percent for the duration of the delay.
Legal obligations
All the contractual obligations between power generators and intermediary procurer and end procurer, including but not limited to liquidated damages,  penalties, extension charges, and dispute resolutions, will be governed by respective bidding documents, including PPA and PSA, and will have no bearing on uniform renewable energy tariff.
The impact on the tariff due to the change in law provisions will be under the bidding documents and reflected in the pooled tariff computed as per these procedures.
The Grid Controller of India will be indemnified against any consequences or liability, including the cost of litigation arising from action taken under these procedures by the concerned end procurer, intermediary procurer, or generating company.
Also, the Grid Controller will have no liability except for computing tariff monthly for the sale of power from the central pool as per these procedures and will be kept indemnified.
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Grid India Issues Procedure to Implement Uniform Renewable Energy Tariff

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					</table>The Central Electricity Regulatory Commission (<a href="https://cercind.gov.in/" target="_blank" rel="noopener">CERC</a>) recently issued an order clarifying certain issues raised by Grid-India related to the implementation of General Network Access (GNA) regulations for projects connected to both state and central transmission utilities.
In its submission, Grid-India highlighted the difficulties of implementing GNA Regulations and requested clarification on a few aspects.
Some of the key issues raised by Grid-India are as follows:
Generating station connected to both STU and CTU system
Issue: Scheduling of Kanti Bijlee Utpadan Nigam
Grid-India raised concerns regarding Kanti Bijlee Utpadan Nigam Limited (KBUNL) Stage-II. KBUNL, currently considered a regional entity, generates 390 MW of power. However, it has been granted General Network Access (GNA) for only 121.6 MW, connectivity and Long Term Access to ISTS for 126 MW and 121.6 MW, respectively. It has dual connectivity, connecting with both the State Transmission Utility (STU) in Bihar and the Central Transmission Utility (CTU) for interstate transmission. The host state has the right to receive 289 MW of power from KBUNL, with 101 MW allocated for supply outside Bihar.
The primary challenge lies in how the Eastern Regional Load Dispatch Center (ERLDC) schedules the entire 390 MW of power from KBUNL, especially when deemed GNA is limited to 121.6 MW for interstate transmission. This issue becomes more intricate when Bihar does not request its allocated power. In such cases, KBUNL may face difficulties selling surplus power in the day-ahead market or scheduling it for other beneficiaries.
Commission’s Analysis
In KBUNL&#8217;s specific case, it has been granted Connectivity and Long Term Access to ISTS for 126 MW and 121.6 MW, respectively, with the remainder of the capacity effectively managed by the state system. Consequently, ERLDC could consider GNA equal to the installed capacity of KBUNL minus 126 MW for scheduling power from KBUNL&#8217;s bus bar.
In scenarios where KBUNL intends to transmit more than 126 MW of power to ISTS, it must obtain a &#8220;No Objection Certificate&#8221; (NOC) from Bihar. This certificate allows power scheduling outside the state, subject to wheeling charges as per SERC regulations.
Given KBUNL&#8217;s regional entity status, the power capacity will be scheduled at the generating station&#8217;s bus bar. The generator must submit the NOC to CTUIL and ERLDC to facilitate this process.
The generator is also allowed to surrender its connectivity to the host state and increase connectivity to ISTS, ensuring it does not exceed the installed capacity by paying applicable state charges as per SERC regulations.
This methodology applies to similar cases with comparable circumstances.
Issue: Scheduling of Dhariwal Infrastructure
Grid-India raised concerns about operating the first unit at Dhariwal Infrastructure (DIL) power station following the CERC order in the petition. According to this order, this unit falls under the jurisdiction of WRLDC for scheduling, and it was directed to consider any power injection from this unit as occurring through the STU network.
Maharashtra SLDC and STU have both consented to these arrangements. The Maharashtra state&#8217;s GNA calculation involved meter data from 2017-20 when the first unit was solely connected to the STU network and considered an intrastate entity. This unit has physical connectivity with STU and CTU but is not deemed as GNA. The CTU has approved a deemed GNA of 270 MW, and an additional 30 MW GNA application for another unit is under process.
DIL faced challenges due to the absence of GNA for its 39 MW merchant capacity since the implementation of the latest CERC GNA Regulations. It applied for an additional GNA of 39 MW to continue inter-state transactions through InSTS by paying a bank guarantee of ₹78 million (~$936,907). They requested the Commission to resolve this scheduling difficulty for 39 MW of merchant capacity from the first unit.
Commission’s Analysis
The CERC order mentioned that MSLDC and MSETCL had no objection to the proposed arrangement, provided that connectivity issues, commercial arrangements, scheduling, control area issues, transmission charges, and losses are addressed. WRLDC and Grid-India also saw no technical issues. Still, they suggested that DIL could surrender STU connectivity for the first unit and obtain an additional 300 MW ISTS connectivity from CTU for more scheduling flexibility.
In this context, it&#8217;s noted that DIL&#8217;s first unit was initially connected only to the STU system. The power station is scheduled by RLDC and is considered a regional entity. DIL has applied for the conversion of its connectivity to ISTS to GNA. The challenge is treating power beyond 300 MW, considering its connectivity to ISTS has been converted into GNA. This power may be sold to the host state or outside it.
Based on the CERC order and the consent of MSLDC and MSETCL, the Commission suggested that for scheduling power to the host state, RLDC should consider the quantum of connectivity with the host state as GNA at the generation busbar, including the connectivity quantum with STU.
However, if DIL wishes to schedule power outside the host state for more than 300 MW, it should be considered flowing through Maharastra’s transmission system. DIL would need an NOC from SLDC of Maharashtra to ensure the available capacity in the STU system to evacuate such power. They must also pay wheeling charges in case power exceeding 300 MW is scheduled to ISTS.
DIL&#8217;s application for additional GNA should be closed, and any bank guarantees submitted should be returned.
Issue: GNARE for the entity drawing renewable energy 
Delhi Metro Rail Corporation (DMRC) has been availing power from the Rewa Ultra Mega Solar (RUMSL) project through Open Access since 2019, using the inter-state transmission network. CTU granted Long Term Access (LTA) to the solar power park developer for 99 MW, and DMRC obtained NOC for Long Term Open Access Power from DTL (STU) for 25 years.
DMRC&#8217;s average power consumption for operating metro trains in Delhi is 200MW, with a maximum of 250 MW. DMRC has 15 substations in Delhi, with direct connections to Delhi Transco Limited (DTL) substations at 66 and 220 kV levels. It draws 99 MW of solar power through open access, scheduling it in 15-minute blocks from 6:00 AM to 6:00 PM, and obtain the remaining energy from DISCOMs.
Delhi SLDC provisionally allocated GNA to DMRC, but there is no provision for GNARE allocation for entities exclusively using renewable energy. DMRC sought directions to ensure that its existing open access arrangement is covered in the new regime and that GNARE for 99 MW is granted.
The relevant GNA regulations state that entities covered under certain clauses may apply to GNARE for power drawn exclusively from renewable sources, and DMRC’s power consumption falls under this clause.
Regulation 18.1 of the GNA Regulations discusses the allocation of GNA to intra-state entities. DMRC has received provisional GNA from Delhi SLDC.
However, the transition of deemed GNA to GNARE for entities drawing power exclusively from renewable sources under the 2009 Connectivity Regulations is not explicitly addressed in the GNA Regulations.
Commission’s Analysis 
Considering the regulations and DMRC&#8217;s situation, the central regulagtor suggested that entities transitioning from the 2009 Connectivity Regulations to the GNA Regulations, which qualify for GNARE, should have the option to convert their deemed GNA to GNARE. This should be a one-time provision during the transition, subject to proof of eligibility and an NOC from the host State&#8217;s SLDC to ensure adequate capacity in the STU system.
Any such consideration for GNARE, however, is subject to the condition that an entity having GNARE cannot have T-GNA or GNA as per the GNA Regulations.
Entities with GNARE can schedule power from any renewable source as per the regulations. Based on its specific contract with REWA, DMRC&#8217;s existing NOC for scheduling from 6 AM to 6 PM will suffice until it obtains a new NOC for scheduling power within 24 hours under GNARE.
Recently, CERC <a href="https://www.mercomindia.com/pending-provisions-gna-regulations-effect-october-1-2023" target="_blank" rel="noopener">notified</a> that certain provisions of the GNA Regulations and the First Amendment to the GNA Regulations 2022 will come into effect from October 1, 2023.
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CERC Addresses Challenges in Implementing GNA Regulations at STU Level

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					</table>In response to a significant surge in power demand and subsequent reports of load-shedding incidents, the Central Electricity Regulatory Commission (<a href="https://cercind.gov.in/" target="_blank" rel="noopener">CERC</a>) has taken a series of strategic measures to mitigate the current power shortage and enhance the grid&#8217;s efficiency.
During a high demand period, specifically on August 11, 2023, states across the grid reportedly experienced load shedding of approximately 6-7 GW. These incidents occurred despite the availability of substantial generation capacity, including 3 GW from reserve shutdown units and operational units. This capacity was not even offered for sale in the market, raising concerns about the grid&#8217;s optimal operation and power supply.
The Ministry of Power <a href="https://www.mercomindia.com/discoms-allowed-clear-dues-generators-48-installments" target="_blank" rel="noopener">introduced</a> the Electricity (Late Payment Surcharge and Related Matters) Rules, 2022, in June last year. According to these rules, distribution licensees are required to inform generating companies about their power requisition schedules for each day. Failure to do so on time allows generating companies to sell the unrequisitioned power on the power exchange.
Underlining the importance of effective communication, the LPS Rules stipulate that distribution licensees must communicate their power requisition schedules to generating companies at least two hours before the closing time for placing proposals or bids in the day-ahead market. This proactive approach aims to prevent unnecessary load shedding by optimally using available generation capacity.
Additionally, the Commission has taken a decisive step by notifying the Indian Electricity Grid Code Regulations, 2023 (Grid Code 2023), scheduled to take effect from October 1, 2023.
The directive also highlighted key aspects of the existing Grid Code 2010. It includes provisions related to the consent required for power sale by inter-state generating stations (ISGS) in the day-ahead market. ISGS, whose tariff is determined by the Commission under section 62 of the Act, can sell power from their original beneficiaries&#8217; share with the consent of these beneficiaries.
However, the document underscores that the original beneficiary cannot reschedule the sold power in the day-ahead market, aiming to maintain stability and predictability in power scheduling.
The Commission has also issued specific directives to address the current power shortage and promote optimal grid management. The directives include:
<ul>
<li>State Load Dispatch Centers (SLDCs) must advise drawal schedules to the respective Regional Load Dispatch Centers (RLDCs) by 10 AM on a day-ahead basis.</li>
<li>RLDCs must communicate ex-power plant dispatch schedules to ISGS by 10:30 AM on a day-ahead basis.</li>
<li>ISGS is being allowed to sell unrequisitioned power after SLDCs provide drawal schedules.</li>
<li>A prohibition on rescheduling power sold by ISGS in the day-ahead market by the original beneficiaries.</li>
<li>Gains from the sale of unrequisitioned power are to be shared based on the LPS Rules.</li>
</ul>
These directives will be effective until the implementation of the Grid Code 2023. The regulatory body has urged widespread dissemination of these directives to ensure all stakeholders are informed and can take action to ensure an uninterrupted power supply.
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CERC Directs DISCOMs to Promptly Requisition Power Needs as Demand Gallops

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					</table>The replacement and upgradation of Supervisory Control and Data Acquisition (SCADA) systems at various State Load Despatch Centers (SLDC) will be completed by 2026, Union Minister for Power and New &amp; Renewable Energy R. K. Singh told Parliament.
The government has put in place a comprehensive range of advanced technologies and strategic regulations to bolster the power grid&#8217;s efficiency, reliability, and security. These encompass real-time monitoring, predictive maintenance utilizing Artificial Intelligence (AI) and Machine Learning (ML) algorithms, cybersecurity enhancements, and innovative methods for construction and inspection.
Singh said <a href="https://posoco.in/en/" target="_blank" rel="noopener">GRID-INDIA</a> actively monitors real-time parameters originating from various substations and generating stations. This monitoring is centralized at both the National and Regional Load Despatch Centres (NLDC / RLDC), facilitated by a robust SCADA and Energy Management Systems (EMS) infrastructure. This system ensures the continuous oversight of the power system by SLDCs and RLDCs.
Under Regulation 43(4) of the Central Electricity Authority (CEA) (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations, 2022, the deployment of SCADA systems facilitates centralized remote monitoring and operation of substations, bolstering the efficiency and resilience of the power infrastructure.
The minister said the government has been taking steps for predictive maintenance employing AI and ML algorithms. Sensors installed in grid substations gather critical data, such as oil and winding temperatures and dissolved gas analysis of transformers. Computer-aided tools then analyze this data, enabling precise predictive maintenance.
To fortify the cybersecurity framework of the power sector, the Central Electricity Authority introduced comprehensive guidelines in October 2021. This initiative has led to the development and implementation of robust cybersecurity measures, ensuring the integrity and safety of critical power infrastructure.
Singh said establishing a Computer Security Incident Response Team for the Power sector (CSIRT-Power) under the guidance of CERT-In has been pivotal in coordinating responses to cybersecurity incidents and providing essential support to utilities for preventing, detecting, handling, and responding to such incidents.
In a bid to overcome challenges posed by difficult and inaccessible terrains, Regulation 87 of the CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations, 2022, has introduced provisions for the use of unmanned aerial vehicles in the construction and inspection of transmission assets. This innovation ensures efficiency and promotes safety in the execution of tasks.
Earlier this year, the Central Electricity Regulatory Commission <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.
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SCADA Upgradation at Load Despatch Centers to be Completed by 2026: R K Singh

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					</table>The Central Electricity Regulatory Commission (<a href="https://cercind.gov.in/Regulations/168-SOR-DSM.pdf" target="_blank" rel="noopener">CERC</a>) has reverted to frequency-linked deviation settlement mechanism (DSM) as an interim measure to protect grid stability which has been under pressure over the last three weeks owing to a change in regulations.
The grid frequency deviated <a href="https://mercomindia.com/explainer-why-new-regulations-made-grid-unstable/" target="_blank" rel="noopener">dangerously</a> away from the acceptable range of 49.90 -50.05 Hz. It oscillated from 50.5 Hz and 49.41 Hz on December 20.
The Commission, in its order, inserted provisions of the older mechanism that would override the latest regulations until such time amendments are made in the 2022 regulations.
The commission had <a href="https://mercomindia.com/cerc-dsm-regulations/" target="_blank" rel="noopener">revised</a> the DSM framework to delink frequency and link deviation charges to the prices observed on market platforms in the day-ahead market (DAM), real-time market, and ancillary services market during a particular time slot.
It also directed Grid-India to provide weekly reports on frequency fluctuation causes, primary and automatic gain control responses from generating stations, efforts to obtain and deploy secondary reserve ancillary service (SRAS) and reserves regulation ancillary services (RRAS) to control frequency, and any remedial measures taken.
These new rules will take effect at midnight on December 28, 2022. They will remain in place until further notice from the Commission.
“The normal rate of charges for deviations are now capped at ₹12 (~$0.15)/kWh. The frequency-linked DSM is back &#8211; albeit partially now. The broader question is &#8211; the regulatory provisions are extremely nonlinear for over and under-injections. Sellers and buyers would always strive to reduce the DSM payments. RRAS and SRAS would still be critical to watch out for and would determine how the stakeholders (buyers and sellers) respond to the grid plus ancillary market,” said Vishal Pandya, Cofounder, REConnect Energy.
The Commission’s order noted instances where the frequency has been outside the desired range of 49.90 Hz to 50.05 Hz due to both over-injection and under-drawal occurring at different time slots.
To address this issue, general sellers (except for run-of-river generating stations or generating stations based on municipal solid waste) will not be paid from the deviation and ancillary service pool account for over-injection in time blocks where the system frequency is 50.05 Hz or higher.
Further, the order said that when system frequency falls below 49.90 Hz in a certain time block, the general seller will receive 150% of the reference charge rate for excess injection deviation from the deviation and ancillary service pool account during that time block, regardless of volume limits.
General sellers will pay back to the deviation and ancillary service pool account for any shortfall in energy due to under-injection in any time block at 50% of the reference charge rate.
Buyers will be paid back from the deviation and ancillary service pool account for under-drawal in time blocks where the system frequency is 50.05 Hz or higher.
The deviations are attributed to entities scheduling more energy production or consumption than necessary and capacity shortages during peak times. These issues, along with under-injection by generators and over-withdrawal by distribution companies, have made it difficult to use secondary reserve ancillary services and reserve regulations to manage large frequency fluctuations.
As a result, the system frequency and applicable DSM rates have often remained high, and the system operator has occasionally had to use gas generation based on regasified liquefied natural gas to address capacity shortages for ancillary services.
CERC has capped deviation charges at ₹12 (~$0.15)/kWh due to instances of high charges (nearly ₹ 40 (~$0.48)/kWh) resulting from the use of costly ancillary services. These high charges can discourage over-drawing or under-injecting, but they can also incentivize under-drawing or over-injecting if the deviation charge is linked to the normal rate.
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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