No. L-1/260/2021/CERC
Dated: 14th March, 2022
Whereas it is necessary to provide for a regulatory mechanism for treatment and settlement of deviation from schedule of drawal or injection of electricity in the interest of reliability, security and stability of the grid, it is hereby specified as follows:
No. L-1/260/2021/CERC - In exercise of the powers conferred under Section 178 read with clauses (c) and (h) of sub-section (1) of Section 79 of the Electricity Act, 2003 (36 of 2003), and all other powers enabling it in this behalf, and after previous publication, the Central Electricity Regulatory Commission hereby makes the following regulations, namely:
These regulations seek to ensure, through a commercial mechanism that users of the grid do not deviate from and adhere to their schedule of drawal and injection of electricity in the interest of security and stability of the grid.
(e) ‘Ancillary Services Regulations’ means the Central Electricity Regulatory Commission (Ancillary Services Operations) Regulations, 2015 as amended from time to time and shall include any re-enactment thereof;
(f) ‘Area Clearing Price’ or ‘ACP’ means the price of electricity contract for a time-block transacted on a Power Exchange after considering all valid buy and sale bids in particular area(s) after market-splitting;
(g) ‘Available Capacity’ for generating station based on wind or solar or hybrid of wind-solar resources which are regional entities, is the cumulative capacity rating of wind turbines or solar inverters that are capable of generating power in a given time block;
(h) ‘Buyer’ means a person purchasing electricity through a transaction scheduled in accordance with the Grid Code;
(i) ‘Commission’ means the Central Electricity Regulatory Commission referred to in sub-section (1) of Section 76 of the Act;
(j) ‘Contract rate’ means the tariff for sale or purchase of power, as determined under Section 62 or adopted under Section 63 or approved under Section 86(1)(b) of the Act by the Appropriate Commission or the price as discovered in the Power Exchange, as the case may be;
(k) ‘Deviation’ in a time block for a seller of electricity means its total actual injection minus its total scheduled generation; and for a buyer of electricity means its total actual drawal minus its total scheduled drawal, and shall be computed as per Regulation 6 of these regulations;
(l) ‘Deviation and Ancillary Service Pool Account’ means the Account to be maintained and operated by the concerned Regional Load Despatch Centre in each region as per Regulation 9 of these regulations;
(m) ‘General seller’ means a seller in case of a generating station based on other than wind or solar or hybrid of wind-solar resources;
(n) ‘Grid Code’ means the Grid Code specified by the Commission under clause (h) of sub-section (1) of Section 79 of the Act;
(o) ‘Interface meters’ means interface meters as defined under the Central Electricity Authority (Installation and Operation of Meters) Regulations, 2006, as amended from time to time and any re-enactment thereof;
(p) ‘Load Despatch Centre’ means National Load Despatch Centre, Regional Load Despatch Centre or State Load Despatch Centre, as the case may be;
(q) ‘Normal Rate of Charges for Deviation’ means the charges for deviation (in paise/kWh) as referred to in Regulation 7 of these regulations;
(r) ‘Open Access Regulations’ means the Central Electricity Regulatory Commission (Open Access in inter-State Transmission) Regulations, 2008 as amended from time to
time and shall include any re-enactment thereof;
(s) ‘Regional Entity’ means a person whose metering and energy accounting are done at the regional level by Regional Load Despatch Centre;
(t) ‘Renewable Rich State’ or ‘RE-rich State’ means a State whose combined installed capacity of solar and wind generating stations under the control area of the State is 1000 MW or more;
(u) ‘Reference Charge Rate’ means (i) in respect of a general seller whose tariff is determined under Section 62 or Section 63 of the Act, Rs/ kWh energy charge as determined by the Appropriate Commission, or (ii) in respect of a general seller whose tariff is not determined under Section 62 or Section 63 of the Act, the daily weighted average ACP of the Day Ahead Market segments of all the Power Exchanges, as the case may be;
(v) ‘RLDC Fees and Charges’ means the fees and charges as specified under the Central Electricity Regulatory Commission (Fees and Charges of Regional Load Despatch Centre and other related matters) Regulations, 2019 as amended from time to time and shall include any re-enactment thereof;
(w) ‘Run-of-River Generating Station’ or ‘RoR generating station’ means a hydro generating station which does not have upstream pondage;
(x) ‘Scheduled generation’ or ‘Scheduled injection’ for a time block or any period means the schedule of generation or injection in MW or MWh ex-bus including the schedule for Ancillary Services given by the concerned Load Despatch Centre;
(y) ‘Scheduled drawal’ for a time block or any period means the schedule of drawal in MW or MWh ex-bus including the schedule for Ancillary Services given by the concerned Load Despatch Centre;
(z) “Seller” means a person, including a generating station, supplying electricity through a transaction scheduled in accordance with the Grid Code;
(aa) ‘Time Block’ means the time block as defined in the Grid Code;
(bb) ‘WS seller’ means a seller in case of a generating station based on wind or solar or hybrid of wind-solar resources.
These regulations shall be applicable to all grid connected regional entities and other entities engaged in inter-State purchase and sale of electricity.
Deviation-general seller (in MWh) = [(Actual injection in MWh) – (Scheduled generation in MWh)].
Deviation-general seller (in %) = $100 \times \frac{[(\text{Actual injection in MWh}) - (\text{Scheduled generation in MWh})]}{[(\text{Scheduled generation in MWh})]}$ .
Deviation-WS seller (in MWh) = [(Actual Injection in MWh) – (Scheduled generation in MWh)].
Deviation-WS seller (in %) = $100 \times \frac{[(\text{Actual Injection in MWh}) - (\text{Scheduled generation in MWh})]}{[(\text{Available Capacity})]}$ .
Deviation- buyer (in MWh) = [(Actual drawal in MWh) – (Scheduled drawal in MWh)].
Deviation- buyer (in %) = $100 \times \frac{[(\text{Actual drawal in MWh}) - (\text{Scheduled drawal in MWh})]}{[(\text{Scheduled drawal in MWh})]}$ .
Provided that for a period of one year from the date of effect of these regulations or such further period as may be notified by the Commission, the normal rate of charges for deviation for a time block shall be equal to the highest of [the weighted average ACP of the Day Ahead Market segments of all the Power Exchanges; or the weighted average ACP of the Real Time Market segments of all the Power Exchanges; or the Weighted Average Ancillary Service Charge of all the regions] for that time block:
Provided further that in case of non-availability of ACP for any time block on a given day, ACP for the corresponding time block of the last available day shall be considered:
| Entity | Charges for deviation payable to Deviation and Ancillary Service Pool Account |
|
|---|---|---|
| Seller | Deviation by way of over injection |
Deviation by way of under injection |
| For a general seller other than an RoR generating station or a generating station based on municipal solid waste | (i) Zero up to [2% Deviation-general seller (in %)]; Provided that such seller shall be paid back for over injection @ the reference charge rate for deviation up to [2% Deviation-general seller (in %)]; and (ii) @ 10% of the normal rate of charges for deviation beyond [2% Deviation-general seller (in %)]. |
(i) @ the reference charge rate up to [2% Deviation-general seller (in %)]; (ii) @ 120% of the normal rate of charges for deviation beyond [2% Deviation-general seller (in %)] and up to [10% Deviation-general seller (in %)]; and (iii) @ 150% of the normal rate of charges for deviation beyond [10% Deviation-general seller (in %)]. |
| For a general seller being an RoR generating station | Zero: Provided that such seller shall be paid back for over injection up to [2% Deviation-general seller (in %)] @ the reference charge rate. |
(i) @ the reference charge rate up to [2% Deviation-general seller (in %)]; (ii) @ normal rate of charges for deviation beyond [2% Deviation-general seller (in %)] and up to [10% Deviation-general seller (in %)]; and (iii) @ 110% of the normal rate of charges for deviation beyond [10% Deviation-general seller (in %)]. |
For a general seller being a generating station based on municipal solid waste |
Zero: Provided that such seller shall be paid back for over injection up to [20% Deviation-general seller (in %)] @ contract rate, or in the absence of a contract rate, @ the weighted average ACP of the Day Ahead Market segments of all Power Exchanges for the respective time block. |
(i) Zero up to [20% Deviation-general seller (in %)]; Provided that such seller shall pay back for the shortfall in energy against its schedule in any time block due to under injection up to [20% Deviation-general seller (in %)] @ 50% of the contract rate, or in the absence of a contract rate, @ 50% of the weighted average ACP of the Day Ahead Market segments of all Power Exchanges for the respective time block; and (ii) @ normal rate of charges for deviation beyond [20% Deviation-general seller (in %)]. |
For WS seller |
Zero: Provided that such seller shall be paid back for over injection as under: (i) @ contract rate, or in the absence of a contract rate, @ the weighted average ACP of the Day Ahead Market segments of all Power Exchanges for the respective time block, up to [5% Deviation -WS seller (in %)]; and (ii) @ 90% of the contract rate, or in the absence of a contract rate, @ 90% of the weighted average ACP of the Day Ahead Market segments of all Power Exchanges for the respective time block for deviation beyond [5% Deviation-WS seller (in %)] and up to [10% Deviation-WS seller (in %)]. |
(i) Zero up to [10% Deviation-WS seller (in %)]; and (ii) @ 10% of the normal rate of charges for deviation beyond [10% Deviation-WS seller (in %)]; Provided that such seller shall pay back for the total shortfall in energy against its schedule in any time block due to under injection, @ the contract rate, or in the absence of a contract rate, @ the weighted average ACP of the Day Ahead Market segments of all Power Exchanges, for the respective time block. |
(2) Charges for deviation in a time block by a buyer shall be payable by such buyer as under:
| Entity | Charges for deviation payable to Deviation and Ancillary Service Pool Account |
|
|---|---|---|
| Buyer | Deviation by way of under drawal |
Deviation by way of over drawal |
| Buyer (other than the buyer with schedule less than 400 MW and the RE-rich State) | Zero: Provided that such buyer shall be paid back for under drawal as under: (i) @ 90% of normal rate of charges, for deviation up to [10% Deviation-buyer (in %) or 100 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; and (ii) @ 50% of normal rate of charges, for deviation beyond [10% Deviation-buyer (in %) or 100 MW Deviation-buyer (in MWh) in a time block, whichever is lower] and up to [15% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower]. |
(i) @ normal rate of charges for deviation up to [10% Deviation-buyer (in %) or 100 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; (ii) @120% of normal rate of charges for deviation beyond [10% Deviation-buyer (in %) or 100 MW Deviation-buyer (in MWh) in a time block, whichever is lower] and up to [15% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; and (iii) @150% of normal rate of charges for deviation beyond [15% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower]. |
| Buyer (with schedule up to 400 MW) | Zero: Provided that such buyer shall be paid back for under drawal @ 90% of normal rate of charges for deviation up to [20% Deviation-buyer (in %) or 40 MW Deviation-buyer (in MWh) in a time block, whichever is lower]. |
(i) @ normal rate of charges for deviation up to [20% Deviation-buyer (in %) or 40 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; and (ii) @120% of normal rate of charges for deviation beyond [20% Deviation-buyer (in %) or 40 MW Deviation-buyer (in MWh) in a time block, whichever is lower]. |
| Buyer (being an RE Rich State) | Zero: Provided that such buyer shall be paid back for under drawal as under: (i) @ 90% of normal rate of charges for deviation up to [10% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; and (ii) @ 50% of normal rate of charges for deviation beyond [10% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower] and up to [15% Deviation-buyer (in %) or 300 MW Deviation-buyer (in MWh) in a time block, whichever is lower]. |
(i) @ normal rate of charges for deviation up to [10% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; (ii) @120% of normal rate of charges for deviation beyond [10% Deviation-buyer (in %) or 200 MW Deviation-buyer (in MWh) in a time block, whichever is lower] and up to [15% Deviation-buyer (in %) or 300 MW Deviation-buyer (in MWh) in a time block, whichever is lower]; and (iii) @150% of normal rate of charges for deviation beyond [15% Deviation-buyer (in %) or 300 MW Deviation-buyer (in MWh) in a time block, whichever is lower]. |
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(3) (a) The charges for deviation for injection of infirm power shall be zero.
(b) The charges for deviation for drawal of start-up power before COD of a generating unit or for drawal of power to run the auxiliaries during shut-down of a generating station shall be payable at the normal rate of charges for deviation.
(4) The charges for inter-regional deviation and for deviation in respect of cross-border transactions, caused by way of over-drawal or under-injection shall be payable at the normal rate of charges for deviation.
(1) By every Thursday, the Regional Load Despatch Centres shall provide the data for deviation calculated as per Regulation 6 of these regulations, for the previous week ending on Sunday mid-night to the Secretariat of the respective Regional Power Committees.
(2) After receiving the data for deviation from the Regional Load Despatch Centre, the Secretariat of the Regional Power Committee shall prepare and issue the statement of charges for deviation prepared for the previous week, to all regional entities by ensuing Tuesday:
Provided that transaction-wise DSM accounting for intra-State entities shall not be carried out at the regional level.
Provided that the Commission may by order direct any other entity to operate and maintain the Deviation and Ancillary Service Pool Account.
Provided that in case the surplus amount in the Deviation and Ancillary Service Pool Accounts of all other regions is not sufficient to meet such deficit, the balance amount shall be recovered through the RLDC Fees and Charges.
The Commission may by general or special order, for reasons to be recorded in writing, and after giving an opportunity of hearing to the parties likely to be affected, may relax any of the provisions of these regulations on its own motion or on an application made before it by the affected party.
If any difficulty arises in giving effect to these regulations, the Commission may on its own motion or on an application filed by any affected party, issue such practice directions as may be considered necessary in furtherance of the objective of these regulations.
(b) all amounts due to and from the said Regional Deviation Pool Account Fund shall be deemed as being due to and from the Deviation and Ancillary Service Pool Account; and
(c) any reference to the Regional Deviation Pool Account Fund shall be construed as reference to the Deviation and Ancillary Service Pool Account.
-sd-
Sushanta K. Chatterjee
Chief (Regulatory Affairs)