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News and InformationIEX Bulletin

In thIs Issue...

PAGE REGULATORY NEWS

01Cabinet Approves Recommendations of Group of Ministers to Address the Issues of Stressed Thermal Power Projects

02 Cabinet Approves Measures to Promote Hydro Power Sector

02 CERC Notifies Cross Border Trade of Electricity Regulations

04 CERC Extends Waiver of ISTS Charges & Losses to Solar and Wind Projects

04 POSOCO Issues Draft Procedure for NOAR

06 HERC Determines Transmission Charges for FY 2019-20

06MERC Notifies DSM Regulations - Linked Intra-State DSM Charges with Power Exchange DAM Daily Average ACP

07 MERC Proposes Amendment in DOA and TOA Regulations

07

SERC Final Tariff Orders for FY20

Assam Andhra Pradesh Bihar Chhattishgarh Jharkhand Uttrakhand

PAGE POWER SECTOR AT A GLANCE

14 Power Sector at a Glance

PAGE MARkET NEWS

15 Power Market

16 REC Market

PAGE MARkET INSIGHTS

17 Market Performance Review: Fiscal 2018-19

PAGE TRAdE dATA

19 Trade Data: March’19

APRIL 2019, ISSUE 04 VOL. 06

RegulatoRy NeWS

Cabinet Approves Recommendations of Group of Ministers to Address the Issues of Stressed Thermal Power Projects

The Cabinet has approved recommendations of Group of Ministers constituted to examine the specific recommendations of High Level Empowered Committee (HLEC) constituted to address the issues of Stressed Thermal Power Projects. The summary of the recommendations are as hereunder:

Amendments made in Shakti Policy

z All such power plants including private generators which do not have PPAs will be allowed Coal linkage under Shakti Policy for a period of minimum 3 months upto a maximum of 1 year.

z The power generated through that linkage should be sold in DAM through power exchanges or in short term through DEEP portal. A methodology in this regard to be formulated by MoP in consultation with Ministry of Coal.

z A generator which terminates PPA in case of default in payment by the DISCOM, may be allowed to use existing linkage coal for sale of power through short-term PPAs using DEEP portal or power exchange for a period of maximum 2 years or until they find another buyer of power under long/medium term PPA whichever is earlier.

z The provisions of Shakti Policy above will also be applicable in cases where the nodal agency designated by MoP aggregates/procures the power requirement for a group of States even without requisition from such states.

z Central and State generating companies can act as an aggregator of power of such stressed power assets and procure it through transparent bidding process and offer that power to the DISCOM against their existing PPAs to such DISCOMS, till such time their own plants get commissioned. It is proposed that Central and State generating companies may be allowed to use the existing unutilized Bridge Linkages for such stressed power assets provided they meet other parameters of tolling guidelines including competitive bidding.

Increase in quantity of Coal for E-Auction

z Ministry of Coal may earmark more coal for power sector under special forward e-auction by reducing the equivalent quantity from the spot e-auction.

z The Coal India Ltd. may earmark at least 50 percent of the total coal meant for e-auction for power.

z The increase in supply of coal for forward e-auction will be in addition to regular requirement of linkage coal for the power sector and the requirements of other sectors.

Non-Lapsing of Short Supplies of Coal

z If the power plant fulfills its obligations limited to making advance payments to coal companies, payments to Indian Railways and making arrangements for unloading of the rakes at its plants, then any short supply for that month of coal, either on account of short supply of coal in the

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coal company or on account of unavailability of rakes, may not lapse and be carried over (without current limitations of 5% or same quarter) to the subsequent months upto a maximum period of 3 months. In this regard, a suitable methodology would be evolved for implementation.

ACq based on Efficiency

z ACQ per MW entitlements for all thermal power plants, irrespective of their age or technical parameters, will be calculated based on Normative Station Heat Rate with upper ceiling of 2600 kcal/kWh.

Mandatory Payment of Late Payment Surcharge

z MoP may engage with the Regulators to ensure that Late Payment Surcharge is paid in case of delay in payment by DISCOMs as per the provisions of PPA.

Cancellation of PPA/FSA/Transmission Connectivity/EC/FC/Water etc

z DISCOMS, CIL, PGCIL, Ministry of Environment and Forests, and appropriate Governments may be advised not to cancel PPA, FSA, transmission connectivity, EC/FC, and all other approvals including water, even if the project is referred to NCLT or is acquired by another entity subject to the provisions of the contracted PPA and/or applicable rules. All clearances may be linked to the plant and not to the promoter.

Cancellation of PPA for Non-Compliance of COd

z If there is any delay in the commissioning of a project for reasons not attributable to the generator, the DISCOMs may be advised not to cancel those PPAs. The PPA may be kept on hold for a certain period, so as to enable removal of impediments in the execution of the project. In the meantime, power can be procured through the mechanism suggested in previous proposals.

Cabinet Approves Measures to Promote Hydro Power Sector

z The Union Cabinet has approved measures to promote Hydro Power Sector which includes declaring Large Hydro Power Projects (LHP) as a part of Non-Solar RPO. The summary of the decision is has hereunder:

z Large Hydro Power Projects (LHPs) to be declared as RE source.

z Hydro Purchase Obligation (HPO) to be introduced as a separate entity within Non-Solar RPO to cover LHPs commissioned post notification of these measures. The trajectory of annual HPO targets will be notified by MoP based on the projected capacity addition plans in hydropower sector. The necessary amendments will be introduced in the Tariff Policy and Tariff Regulations to operationalize HPO.

z Tariff rationalization measures of providing flexibility to the developers to determine tariff by back loading of tariff after increasing project life to 40 years, increasing debt repayment period to 18 years and introducing escalating tariff of 2%.

z Budgetary support for funding flood moderation component of hydropower projects on case to case basis.

z Budgetary support for funding cost of enabling infrastructure i.e. roads and bridges on case to case basis as per actual, limited to `1.5 crore per MW for upto 200 MW projects and `1.0 crore per MW for above 200 MW projects.

More information: www.powermin.nic.in

CERC Notifies Cross Border Trade of Electricity Regulations

CERC has notified Central Electricity Regulatory Commission (Cross Border Trade of Electricity) Regulations, 2019 on 8th March 2019. The key features of the Regulations are as hereunder:

Scope

z These regulations will be applicable to the participating entities in India and the neighbouring countries.

z CBT between India and the neighbouring country(ies) will be allowed through mutual agreements between Indian entity(ies) and entity(ies) of the neighbouring country(ies) under the overall framework of agreements signed between India and the neighbouring country(ies).

z In case of tripartite agreements, the cross border trade of electricity across India will be allowed under the overall framework of bilateral agreements signed between GoI and the Governments of the respective neighbouring countries of the Participating Entities.

Institutional Framework

z Designated Authority appointed by the MoP, GoI will be responsible for facilitating the process of approval and laying down the procedure for import and export of electricity.

z Transmission Planning Agency will be responsible for planning of transmission system.

z Settlement Nodal Agency (SNA) will be responsible for settling all charges pertaining to grid operations including operating charges, deviation charges and other charges with a particular neighbouring country.

z NLDC will act as the System Operator and will be responsible for granting STOA and for billing, collection and disbursement of the transmission charges for STOA transactions.

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z Central Transmission Utility will be responsible for granting LTOA and MTOA.

Tariff determination

z For import/export: Either determined through competitive bidding or mutual agreement or government to government agreements.

z For import from Hydro Plant : CERC may determine tariff based on request of the entity of neighbouring country through its government.

Trade through Indian Power Exchanges

z Participating Entity of neighbouring country can trade on Power Exchange only through Indian trading licensee.

z For such trading, the trading licensee is required to take approval from designated authority for specific quantum.

z There is no restriction on the market i.e. DAM/TAM in which such transactions can be executed.

z There are no restrictions on import or export of power through Power Exchange.

Cross Border Transmission Link (CBTL)

z The CBTL between India and any neighbouring country will be planned jointly by Transmission Planning Agencies of the two countries with the approval of the respective Governments.

z The CBTL will not form part of the basic ISTS network for the determination of PoC charges under the Sharing Regulations.

z A generating station located in a neighbouring country may develop, operate and maintain the dedicated transmission system from the generating station to the pooling station within India at its own cost after obtaining all the necessary approvals from respective countries.

Connectivity & Transmission Access

z Applications for grant of connectivity or LTOA/MTOA access will be made to CTU and applications for grant of STOA will be made to NLDC under these Regulations with approval of designated authority.

z Except where specifically provided in these Regulations, the provisions contained in the STOA Regulations and Connectivity Regulations will apply mutatis mutandis to the participating entities for CBT of electricity.

declaration of Available Transfer Capability (ATC)

z ATC for the CBT of electricity will be assessed in advance by System Operators in India and the concerned neighbouring country and lower of the two

values of ATC assessed by the two countries to be considered.

Scheduling

Scheduling to be carried out for each 15-minute time block:

z Transmission System losses declared on weekly basis will be borne in kind by the buying entity or the selling entity, as the case may be, as per the quantum declared by the concerned System Operator of India or the neighbouring country.

z The selling entity or the buying entity to inform their requisitions to the SNA.

z SNA will co-ordinate with System Operators of respective neighbouring countries for scheduling of cross border transactions and revisions during the day of operation.

Curtailment

z The STOA will be curtailed first, followed by the MTOA followed by LTOA.

z Amongst the grantees of access of a particular category, curtailment will be carried out on pro-rata basis.

z In case of curtailment of the approved schedule by NLDC, transmission charges to be payable on a pro-rata basis in accordance with the curtailed schedule.

z The operating charges will not be revised in case of curtailment.

Transmission Charges

z PoC injection charges or PoC withdrawal charges for delivery of electricity at the pooling station within India will be governed as per provisions of sharing regulations.

Transmission Losses

z Withdrawal PoC losses as applicable will be applied at the interface.

z Injection PoC losses of respective injection grid will be applied at the interface.

z Net schedule at Indian end of the CBTL will be arrived at after applying injection PoC loss of the concerned injection zone and withdrawal PoC loss.

dispute Settlement and Resolution Mechanism

z The disputes in relation to the CBT of electricity within the Indian Territory will be settled as per the provisions of Electricity Act, 2003.

z Disputes involving entities of separate countries may be resolved mutually by the participating entities within a period of 60 days from the date of raising of the dispute.

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z In case the dispute remains unresolved even after 60 days from the date of raising of the dispute, the same will be attempted to be mutually resolved at the Government level.

z In case the dispute still remains unresolved, it will be settled through the International Arbitration Centre as may be mutually acceptable to the parties to the dispute.

More information: www.cercind.gov.in

CERC Extends Waiver of ISTS Charges & Losses to Solar and Wind Projects

CERC has notified 6th amendment to POC Regulations. As per this amendment, Solar and Wind projects commissioned upto 31.03.2022 will be eligible for waiver of inter-state transmission charges and losses for 25 years provided such power has been awarded through competitive bidding for fulfilling RPO of the obligated entities.

Presently Solar projects commissioned upto 31.12.2019 and Wind projects commissioned upto 31.03.2019 are eligible for waiver of POC charges and losses.

More information: www.cercind.gov.in

POSOCO Issues draft Procedure for NOAR

POSOCO has issued draft Procedure ‘Draft Procedure for STOA in Interstate Transmission Through National Open Access Registry (NOAR) as mandated by the 5th Amendment of CERC STOA Regulations. The summary of the procedure is as hereunder:

Scope of the Procedure

z Applications made for scheduling of Bilateral and Collective Transactions.

z Standing Clearance by NLDC/RLDC/SLDC.

z STOA applications for bilateral transactions by the nodal RLDC, cross border transactions by NLDC and collective transactions through Power Exchange(s) by NLDC.

z All information related to approvals, rejections, revisions, curtailment, payment schedules, etc. to be made available.

Role of NLdC

z To facilitate smooth functioning of NOAR.

z To determining the TTC/RM/ATC of each of the bid area/control area/group of control areas and incorporate in NOAR.

z NLDC to provide the access to RLDCs for interfacing the scheduling application with NOAR for exchange of

information related to Long Term and Medium Term transactions for each bid area/control area/group of control areas and installed/declared/requisitioned quantum of ISGS as well.

z To provide standing clearance to the cross border open access.

z NLDC to also provide access of NOAR to the Market Monitoring Cell (MMC) of CERC.

z Mandatory use of payment gateway for transactions through NOAR.

z NLDC to incorporate the ISTS charges (POC charges) for the regional entities.

Role of RLdC

z To process the registrations of all inter-state utilities in NOAR.

z To give standing clearance through NOAR.

z The RLDC will be responsible for collection, accounting and disbursement of STOA charges through NOAR.

Role of SLdC

z To process the registrations of all intra state utilities in NOAR.

z To give standing clearance through NOAR.

z Updating respective STU charges and SLDC Operating charges in NOAR.

z To incorporate the interstate transactions to/from the point of injection/drawl in the Daily schedules.

Registration

z New/First time applicant to register through applicant registration by paying fee of `5000.

z Applicant will required to submit following document with other details:

� COD certificate. � In case of Renewable Energy Source:

a) Certificate of Commercial Operation Declaration.

b) Documentary proof of award of RE capacity by competitive bidding.

c) Documentary proof that the purchase of RE power by the DISCOM is under RPO.

z Indemnity bond on notarized non-judicial Stamp paper indemnifying RLDC.

z Signed and stamped hard copy of the same to the host NLDC/RLDC/SLDC.

z In case of a regional entity, the application to be processed by concerned RLDC and for intra state entity, the application to be processed by the

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concerned SLDC. For interstate electricity trader and Power exchanges, NLDC to process registration.

z Registration to be processed within 7 days for new and 3 days for renewals. Any discrepancy in application can be rectified in 2 days failing which application for registration will be cancelled and fee would beforfeited.

z The registration will be valid for a period of 3 years and will be renewed thereafter with the payment of renewal charges of `2000/-

Standing Clearance

z OA customer to apply through an online application, through NOAR, along with the requisite affidavit.

z For regional entities, RLDC to provide the standing clearance for all transactions through LT, MT and ST taken together and for intra state entities the quantum for standing clearance will be restricted up to the quantum of inter-state short term transactions only.

z Standing clearance to be issued to the open access customer within 7 working days from the date of application for a new open access customer and within 3 working days from the date of application for an existing open access customer for a maximum period of three months at a time.

z If not standing clearing not provided in the above timeline than it will be deemed to have been granted.

z For renewal, the OA customer will contact the nodal agency at least one week before expiry of the standing clearance.

z The OA customer to whom the standing clearance has been issued will ensure that the aggregated quantum of all scheduled transactions including LT, MT, ST bilateral and collective, does not exceed the quantum of standing clearance issued by the concerned RLDC/SLDC.

z The concerned RLDC/SLDC may revise the quantum (MW) or period of the standing clearance issued in respect of any open access customer in case of transmission constraint or in the interest of secure grid operation.

z If the allocated transmission corridor is observed to be under-utilized persistently for a period more than 15 days, then the concerned SLDC/RLDC may revise the standing clearance after giving a notice of 2 days to the OA customer.

Application for Scheduling

z Application for scheduling of Bilateral Transaction will be made through NOAR having a valid standing clearance.

z The applicant will apply for STOA transaction in such a manner such that the requirement of ramp-up and ramp-down, if required, in the Daily Schedules (issued by the RLDC) on account of such transactions, is incorporated in the application.

z The minimum requested quantum can be up to 0.10 MW.

z Procedures have been specified for Advance Scheduling of Bilateral Transaction, Bilateral Transaction On ‘First-Come-First-Served’ Basis, Day-Ahead Bilateral Transaction, Contingency Bilateral Transaction and Collective Transaction.

z Power Exchange(s) will ensure necessary co-ordination with SLDCs for scheduling of the transactions.

Transmission Margin

z NOAR would determine the bid area/control area/group of control area wise margins for STOA.

z Margin calculation for approval of STOA applications will be done automatically by NOAR.

z For regional entities, the system to check for each application whether the sum of total quantum scheduled (Including LT, MT, STOA transactions) and the STOA quantum applied is within the limit of the approved NOC quantum for the applied period.

z For intra state entities, the system should check for each application whether the STOA bilateral quantum applied is within the limit of the approved NOC quantum for the applied period.

Congestion Management in Bilateral Transactions

z Electronic Bidding for Advance Category Bilateral Transactions.

z Pro-rata scheduling in case of FCFS, DAB.

z For contingency transactions:

� Applications received between 15:00 Hrs.- 18:00 Hrs. – pro-rata scheduling.

� Applications received after 1800 Hrs – scheduling FCFS basis.

Revision of Schedules

z Allowed for advance and FCFS after 2 days.

z Not allowed for Day Ahead and Contingency except outage of a unit.

Real Time Congestion Management/Curtailment of Transactions

z RLDC to enter the details of bid area/control area/block of control areas, date, time slots and quantum of congestion through NOAR.

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z The NOAR to initiate the process of curtailment of transactions for all such bid area/control area/block of control areas, date and time slots.

z NOAR would generate revised payment schedules of the applicants whose transactions have been curtailed.

More information: www.posoco.in

HERC determines Transmission Charges for FY 2019-20

Haryana Electricity Regulatory Commission has determined transmission charges at `0.27 per Unit for FY 2019-20 in the Tariff Order for HVPNL for FY 2019-20. The Existing charges were `0.36 per Unit.

More information: www.herc.gov.in

MERC Notifies dSM Regulations - Linked Intra-State dSM Charges with Power Exchange dAM daily Average ACP

Maharashtra Electricity Regulatory Commission notified Deviation Settlement Mechanism and Related Matters Regulations, 2019. The key features of the Regulations are as hereunder:

Applicability

z STOA/MTOA/LTOAs using intra-state transmission system (InSTS) or distribution system of electricity (including inter-state wheeling of power.

z Seller: Generators above 25 MW capacity including RE Generators except Wind and Solar generators.

z Buyer: Distribution licensee(s), deemed distribution licensee(s) located in the state and full open access consumers except partial and embedded OA consumers.

Charges for deviations

z Deviation Charges linked to the CERC (Deviation Settlement Mechanism and related matters Regulations, 2014 and its amendments thereof.

z The DSM rate vector to have a dynamic slope determined by joining the identified price points at 50 Hz. (daily simple average ACP), frequency of 49.85 Hz (`8 per unit) and 50.05 Hz (zero) on a daily basis.

z The maximum ceiling limit applicable for average Daily ACP discovered in the DAM segment of Power Exchange at 50.00 Hz to be 800 Paise/kWh.

z Charges for deviation for each 0.01 Hz step will be equivalent to the slope determined by joining the price at ‘Not below 50.05 Hz’ and ‘identified price at 50.00 Hz’ in the frequency range of 50.05-50.00 Hz, and the

slope determined by joining the ‘price identified at 50.00 Hz’ and price at ‘below 49.85 Hz’ in frequency range ‘below 50 Hz’ to ‘below 49.85 Hz’.

z The daily simple average ACP of the Power Exchange having a market share of 80% or more in energy terms on a daily basis shall be taken into consideration for linking to the DSM price vector. If no single Power Exchange is having a market share of 80% or more, the weighted average day-ahead price will be used for linking to the DSM price.

z Daily simple average ACP in the day-ahead market to be used as the basis for market linked DSM price at 50 Hz.

z The Cap rate for the charges for deviation for generating stations whose tariff is determined by the Commission and for other generating stations whose tariff is not determined by the Commission to be equal to its energy charges of main fuel (imported coal) as determined by the Commission for deviations [394.3] Paise/kWh.

z No retrospective revision of DSM account to be allowed even if the energy charges are revised at a later date.

z In case of non-availability of daily simple average ACP due to no-trade on a given day, daily simple average ACP of the last available day to be considered for determining the DSM charge.

z Deviation price to be rounded off to nearest two decimal places.

z NLDC to act as the Nodal Agency to declare the daily DSM rates and to display all relevant information on its website.

z A change in sign of the deviation will be made once every 6-time blocks, failing which additional charges at 20% of the Deviation Charges applicable will be levied for the duration of continuance of violation.

deviation Limit

z Buyer: Minimum of (12% of schedule, (Peak Demand of Distribution Licensee or Buyer/Non-Coincident Peak Demand) x State Volume Limit)

z Seller: 12% of the scheduled injection or 30 MW, whichever is lower for a Seller.

z Additional Charges for Deviation to be applicable for over-drawal as well as under-injection of electricity for each time block in excess of the volume limit provided that such additional charges are leviable by Regional Pool account in a time block.

z Additional Deviation Charges to be applicable in case Seller/Buyer exceeds its Volume Limit (X) upto six (6) time-blocks within a day.

z The Regulations, and the related provisions regarding Deviation Charges, Additional Charge for Deviation

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and penal actions if any, to come into force from date to be notified separately through Order, which will not be later than 1st April 2020.

z Until notification of such date as referred hereinabove under first proviso, the final Balancing and Settlement Mechanism (FBSM) as approved by Commission.

More information: www.mercind.org.in

MERC Proposes Amendment in dOA and TOA Regulations

Maharashtra Electricity Regulatory Commission proposed 1st Amendment to Distribution Open Access (DOA) Regulations and Transmission Open Access Regulations (TOA). The summary of the proposed Amendments is as hereunder:

Increase in Transmission Charges in Case of Continued Roll Over of STOA Transactions

z In order to discourage repeated roll over of STOA transactions, the applicable STOA transmission charges will be increased by a multiplication factor of 1.25, 1.5 and 2.0 respectively for every 2nd, 3rd and 4th & beyond during a financial year.

Increase in Transmission Charges for Renewable OA

z For RE based MTOA and LTOA transactions the transmission charges will be twice the STOA transaction.

Compulsory Reduction of Contract demand

z It is proposed to compulsorily reduction in the contract demand for STOA/MTOA/LTOA transaction and automatic reinstatement of CD once the open access period is over.

Treatment of Banked Energy for Variable Renewable Energy (VRE)

z Banking: Allowed only for Wind and Solar project.

z Banking Period: Reduced from 1 year to 1 month.

z Surplus unutilized banked power quantum and rate: The buy-back rate for surplus at the end of settlement period (i.e. month) subject to cap of 10%, is proposed to be at the rate discovered under the latest bid process for any RE technology carried out in the State or the Average Power Purchase Cost, whichever is lower.

z Treatment of unutilized banked power treatment: It will be considered towards RPO compliance of the respective Distribution Licensee and Generator could not claim REC on such power.

Eligibility to for Open Access

z Eligible Contract Demand: replaced 1 MVA from 1 MW of load.

z Limitation: For Partial OA Consumer upto its existing Contract Demand and for Full OA consumer upto its sanctioned load. The existing provision of allowing OA based on load flow has been deleted.

z Minimum threshold demand: If the Consumer fails to achieve the Maximum Demand (equal to or more than 70% of the threshold limit at which OAC becomes eligible for Open Access) in any month, the Distribution Licensee will be entitled to a penalty equal to two times the wheeling charges for the financial year or part thereof for which he the Consumer failed to achieve such Maximum Demand.

Priority for Adjustment of Energy Credit

z It is proposed that the priority for adjustment of energy drawl by an OA consumer would be a) RE Generators b) Captive Generating Plant c) Banked Energy d) Long Term Bilateral Purchase e) Medium Term Open Access. f) Short term inter-State open access including power exchange transactions g) Short term intra-State Open Access h) Distribution Licensee.

day-Ahead Open Access

z The application for grant of Day-Ahead Open Access to be made for continuous period of minimum duration of 8 hours.

z The schedule given against the above day ahead open access sought will be uniform at least for a period of eight hours and the minimum schedule during the day would at any time not be less than 75% of the maximum schedule of the day.

More information: www.mercind.org.in

SERC Final Tariff Orders for FY20

Assam

The summary of Tariff Order of APBCL for FY20 is as below:

Annual Revenue Requirement

z Total ARR of the Discom approved is `5,340.71 Cr, reduction of 7% (`379 Cr.) over previous fiscal.

Gross Power Purchase

z Total Power Purchase approved is 10.09 BU, an increase of 3% (2.52 BU) over previous fiscal.

Total Energy Sales

z Total Energy Sales approved is 7.93 BU, growth of 2% over previous fiscal.

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Renewable Purchase Obligation

Solar % 6.00%Non-Solar % 7.00%Total Solar MU 475.8Total Non-Solar MU 555.1Solar Energy Purchase MU 228.8Non-Solar Energy Purchase MU 495.1Balance Solar to be procured MU 247Balance Non-solar to be procured MU 60

Average power purchase cost (including transmission) 4.68 `/kWh

Average Cost of Supply (ACoS) 7.05 `/kWh

Tariff HT Average: 4% reduction

unit Fy19 Fy20 Increase (+)/Decrease (-)

Option I (Without TOd) Fixed charge (`/kVA/Month) All 180 200 11%Energy Charge (`/kWh) HT-II 7.2 6.90 -4%

Option II (With TOd) Fixed charge (`/kVA/Month) All 300 300 0%Energy Charge (`/kWh) HT-II 6.5 6.45 -1%

Open Access Charges & Losses: Open Access charges have been reduced

unit Fy19 Fy20 Increase (+)/Decrease (-)

Wheeling Charges 33 kV `/kWh 0.27 0.26 -0.01Wheeling Losses 33 kV % 5 5 011 kV % 11 11 0Transmission Charges `/kWh 0.65 0.37 -0.28Transmission Losses % 3.44 3.39 -0.05Cross Subsidy Surcharge `/kWh 1.37 1.62 0Additional Surcharge `/kWh 0 0 0

More information: www.aerc.nic.in

Andhra Pradesh

The summary of Tariff Order of SPDCL and EPDCL for FY20 is as below:

Annual Revenue Requirement z Total ARR of both the Discoms approved is `35,857 Cr, an increase of 12% (`3874.5 Cr.) over previous fiscal.

Gross Power Purchase z Total Power Purchase approved is 65.7 BU, an increase of 8% (4.91 BU) over previous fiscal.

Total Energy Sales z Total Energy Sales approved is 59.16 BU, growth of 9% over previous fiscal.

RPO z The licensees proposed to sell RECs for the excess energy over and above the obligation.

Average Power Purchase Cost (APPC) z Approved at `4.02/kWh, reduction of 2 paisa/Unit w.r.t previous fiscal.

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Average Cost of Supply (ACoS) z The ACoS has been approved at `6.02/kWh, increase of 14 paisa/Unit w.r.t previous fiscal.

Average Realization (ABR) z ABR is `4.88/kWh, increase of 4 paisa/unit compared to previous fiscal.

Tariff HT

H-I(a): (i) INDuStRy geNeRal Fy19 Fy20 Increase (+)/Decrease (-)

Fixed Charge `/kVA/Month 475 475 0

Energy Charge

11 kV

Normal `/kWh 6.33 6.3 -0.03

TOD peak (6 AM to 10 AM & 6 PM to 10 PM) `/kWh 7.38 7.30 -0.08

TOD off peak (10 PM to 6 AM) `/kWh 5.33 5.30 -0.03

33 kV

Normal `/kWh 5.87 5.85 -0.02

TOD peak (6 AM to 10 AM & 6 PM to 10 PM) `/kWh 6.92 6.85 -0.07

TOD off peak (10 PM to 6 AM) `/kWh 4.87 4.85 -0.02

132 kV & Above

Normal `/kWh 5.44 5.4 -0.04

TOD peak (6 AM to 10 AM & 6 PM to 10 PM) `/kWh 6.49 6.40 -0.09

TOD off peak (10 PM to 6 AM) `/kWh 4.44 4.40 -0.04

Open Access Charges & Losses

DiscomFy19 Fy20 Increase (+)/

Decrease (-)SPDCl ePDCl SPDCl ePDCl SPDCl ePDCl

Wheeling Charges (`/kWh)11 kV 0.41 0.33 0.40 0.40 -0.01 0.0733 kV 0.02 0.02 0.02 0.22 0.00 0.20

Wheeling Losses11 kV 7.98% 7.25% 3.27% 3.20% -5% -4%33 kV 4.00% 3.39% 3.20% 2.79% -1% -1%

Transmission Charges (`/kWh) 0.13 0.12 -0.01Transmission Losses 3.95% 3.10% -0.85%

Cross Subsidy Surcharge (`/kWh)11 kV 1.77 1.61 1.83 1.83 0.06 0.2233 kV 1.42 1.44 1.47 1.47 0.05 0.03132 kV & Above 1.35 1.41 1.33 1.33 -0.02 -0.08

Additional Surcharge (`/kWh) 0 0 0 0

More information: www.aperc.gov.in

Bihar

The summary of Tariff Order of NBPDCL and SBPDCL for FY20 is as below:

Annual Revenue Requirement

z Total ARR of both the Discomsis `18,137.6 Cr, an increase of 12% (`1,888.65 Cr.) over previous fiscal.

Gross Power Purchase

z Total Power Purchase approved for FY 2019-20 is 34 BU, an increase of 16% (4.6 BU) over previous fiscal.

Total Energy Sales

z Total Energy Sales approved for FY 2019-20 is 25.24 BU, an increase of 14% over previous fiscal.

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Renewable Purchase Obligation

Solar % 4.75%Non-Solar % 6.75%Total Solar MU 1199.28Total Non-Solar MU 1704.24Solar Energy Purchase MU 198.28Non-Solar Energy Purchase MU 1535.44Balance Solar to be procured MU 1001.00Balance Non-solar to be procured MU 169.00

Average power purchase cost (including transmission) 4.09 `/kWhAverage Cost of Supply (ACoS) 6.84 `/kWhAverage Tariff hike 0%

Tariff HT

unit Fy19 Fy20 Increase (+)/Decrease (-)

Fixed Charge (`/kVA/Month) All 300 300 0Energy Charge (`/kWh) HTS-I 6.65 6.65 0

HTS-II 6.6 6.6 0HTS-III 6.55 6.55 0HTS-IV 6.5 6.5 0

Open Access Charges & Losses: Overall OA charges have been reduced

unit Fy19 Fy20 Increase (+)/Decrease (-)

Wheeling Charges 33 kV `/kWh 0.27 0.47 0.2011 kV `/kWh 0.31 0.51 0.20Wheeling Losses 33 kV % 5% 4% -1%11 kV % 6% 5% -1%Transmission Charges `/kWh 0.51 0.23 -0.28Transmission Losses % 3.92% 3.92% 0.00

Cross Subsidy Surcharge 132 kV `/kWh 1.71 1.81 0.1033 kV `/kWh 1.85 1.82 -0.0311 kV `/kWh 1.87 1.85 -0.02Additional Surcharge `/kWh 0 0 0.00

More information: www.berc.co.in

Chhattishgarh

The summary of Tariff Order of CSPDCL for FY20 is as below:

Annual Revenue Requirement

z Total ARR approved is `13,294.94 Cr.

Tariff HT z 6 Paisa decrease in Energy Charges of HT consumers. No change in Demand charges.

www.iexindia.com 11

Fy19 Fy20 Increase (+)/Decrease (-)

tariff Ht

Demand charge

energy Charge

Demand charge

energy Charge

Demand charge

energy Charge

`/kVa/Month `/kVah `/kVa/

Month `/kVah `/kVa/Month `/kVah

HV-3: Other Industrial and General Purpose Non-Industrial220 kV 375 5.85 350 5.91 -25 0.06132 kV 375 5.95 350 6.01 -25 0.0633 kV 375 6.3 350 6.36 -25 0.06HV-4: Steel Industries220 kV 375 5.3 365 5.30 -10 0132 kV 375 5.45 365 5.45 -10 033 kV 375 5.85 365 5.85 -10 0

Open Access Charges & Losses

open access Charges unit Fy19 Fy20 Increase(+)/Decrease (-)Wheeling charges (33 kV) `/kWh 0.25 0.24 -0.01Wheeling Losses (33 kV) % 6% 6% 0.00Transmission Charge `/kWh 0.35 0.30 -0.05Transmission Losses % 3.22% 3% -0.22%Cross Subsidy Surcharge220 kV/132 kV `/kWh 1.23 1.70 0.4733 kV `/kWh 1.49 1.38 -0.11Additional Surcharge `/kWh 0 0 0.00

More information: www.cserc.nic.in

Jharkhand

The summary of Tariff Order of JBVNL for FY20 is as below:

Annual Revenue Requirement

z Total ARR of the Disoms approved is `7,164.22 Cr, an increase of 20% (`1,190.76 Cr.) over previous fiscal.

Gross Power Purchase z Total Power Purchase approved is 13.44 BU, an increase of 3% (3.5 BU) over previous year.

Total Energy Sales z Total Energy Sales approved for Fiscal 2019-20 is 11.01 BU, growth of 8% compared to previous fiscal.

Renewable Purchase Obligation

Solar % 6.55%Non-Solar % 5.00%Total Solar MU 814.89Total Non-Solar MU 622.05Solar Energy Purchase MU 45.85Non-Solar Energy Purchase MU 104.59Balance Solar to be procured MU 769.04Balance Non-solar to be procured MU 517.46

Average Power Purchase Cost (APPC) 4.10 `/kWh

Average Cost of Supply (ACoS) 6.32 `/kWh

Average Tariff hike 6%

www.iexindia.com 12

Tariff HT

unit Fy19 Fy20 Increase (+)/Decrease (-)

Fixed charge (`/kVA/Month) All 300 350 50

Energy Charge (`/kWh) HTS-11/33/132 kV 5.75 5.50 -0.25

Open Access Charges & Losses: Overall OA charges have been reduced

unit Fy19 Fy20 Increase(+)/Decrease (-)

Wheeling charges

33 kV `/kWh 0.17 0.16 -0.01

11 kV `/kWh 0.45 0.41 -0.04

Wheeling Losses

33 kV % 3.43% 3.10% -0.33%

11 kV % 8.31% 8.00% -0.31%

Transmission Charge `/kWh 0.25 0.25 0

Transmission Losses % 2.23% 2.23% 0%

Cross Subsidy Surcharge

132 kV `/kWh 1.23 1.03 -0.20

33 kV `/kWh 1.62 1.03 -0.59

11 kV `/kWh 1.67 1.19 -0.48

Additional Surcharge `/kWh 0 0 0

More information: www.jserc.org.in

Uttrakhand

The summary of Tariff Order of UPCL for FY20 is as below:

Annual Revenue Requirement

z Total ARR of both the Discoms approved is `6549.39 Cr, an increase of 9% over previous fiscal.

Gross Power Purchase

z Total Power Purchase approved is 14.42 BU, an increase of 2% over previous fiscal.

Total Energy Sales

z Total Energy Sales approved is 12.36 BU, growth of 4% over previous fiscal.

www.iexindia.com 13

Renewable Purchase Obligation

Solar % 7.25%

Non-Solar % 10.25%

Total Solar MU 611

Total Non-Solar MU 863.83

Solar Energy Purchase MU 471.19

Non-Solar Energy Purchase MU 712.18

Balance Solar to be procured MU 139.81

Balance Non-solar to be procured MU 151.65

Average Power Purchase Cost (APPC) 3.53 `/kWh

Average Cost of Supply (ACoS) 5.28 `/kWh

Average Realization (ABR) 5.15 `/kWh

Average Tariff hike 2.89%

Tariff HT: 20-15 paisa/kwh increase in Energy Charges and 5 `/kVA/Month in fixed charges of HT consumers

unit Fy19 Fy20 Increase (+)/Decrease (-)

CD up to 1000 kVA (LF < = 40%) Fixed charge `/kVA/Month 295 300 5.00

Energy Charge `/kWh 3.85 3.95 0.10

CD up to 1000 kVA (LF > 40%) Fixed charge `/kVA/Month 295 300 5.00

Energy Charge `/kWh 4.2 4.35 0.15

CD More than 1000 kVA (LF < = 40%) Fixed charge `/kVA/Month 355 360 5.00

Energy Charge `/kWh 3.85 3.95 0.10

CD More than 1000 kVA (LF > 40%) Fixed charge `/kVA/Month 355 360 5.00

Energy Charge `/kWh 4.2 4.35 0.15

Open Access Charges & Losses

Fy 19 Fy 20 Increase/Decrease (-)

Wheeling charges

CD up to 1000 kVA `/MW/day 1040 3088 2048

CD More than 1000 kVA `/MW/day 0 1411 1411

Wheeling Losses % 14.50% 14.25% -0.25%

Transmission Charge `/MW/day 2453.7 3152.80 699.1

Transmission Losses % 1.60% 1.40% -0.20%

Cross Subsidy Surcharge `/kWh 0.49 0.51 0.02

Additional Surcharge `/kWh 0 0 0

More information: www.uerc.gov.in

14 www.iexindia.com

PoWeR SeCtoR at a glaNCe (data sourced from : www.pososco.in and www.cea.nic.in)

z The all India installed capacity grew by 5% YoY from 3,34,147 MW to 3,50,162 MW as on 28th February’19 with thermal capacity at 2,22,927 MW; renewable capacity at 75,056 MW; hydro capacity at 45,399 MW and nuclear capacity at 6,780 MW.

z The installed capacity increased by 2% for thermal, 19% for renewables, 1% for hydro, and remained same for nuclear over the same period.

z The all India peak demand in fiscal 2019 increased by 8% from 1,64,066 MW to 1,77,022 MW over last fiscal. The all India Energy Met also increased by 5% for the same period from 1,204,697 MU in fiscal 2018 to 1,269,343 MU in fiscal 2019 according to NLDC.

Peak demand Comparison of key States (MW)

The comparison of the peak demand in the key states during FY18 and FY19 is as hereunder:

Energy Met Comparison of key States (MU)

The comparison of the energy met in the key states during FY18 and FY19 is as hereunder:

Demand and Supply Position

2%

19%1%

5%

All India Installed Capacity

5%

FY 18 FY 19

2,19

,557

62,8

47

44,9

63

6,78

0

3,34

,147

75,0

56

45,3

99

6,78

0

Thermal Renewable Hydro Nuclear All India

February 2018 (MW) February 2019 (MW)

Peak Demand (MW) Energy Met (MU)

3,50

,162

2,22

,927

8%

1,64,

066

1,77

,022

12,0

4,69

7

12,6

7,20

9

State Fy18 Fy19 % Change

Karnataka 10,857 12,841 18%

Odisha 4,652 5,357 15%

Rajasthan 11,722 13,276 13%

Bihar 4,521 5,115 13%

Jammu & Kashmir 2,899 3,277 13%

West Bengal 8,137 9,130 12%

Madhya Pradesh 12,338 13,815 12%

Kerala 3,892 4,264 10%

Punjab 11,705 12,638 8%

Delhi 6,553 7,016 7%

Chhattisgarh 4,169 4,444 7%

Haryana 9,671 10,270 6%

State Fy18 Fy19 % Change

Rajasthan 70,603 79,637 13%

Bihar 26,603 29,827 12%

Odisha 28,706 31,781 11%

Telangana 60,235 66,635 11%

Andhra Pradesh 58,288 63,677 9%

Madhya Pradesh 69,925 75,665 8%

Gujarat 1,09,973 1,16,572 6%

Karnataka 67,701 71,690 6%

Maharashtra 1,49,531 1,58,148 6%

Haryana 50,775 53,665 6%

Jammu & Kashmir 15,050 15,868 5%

Assam 8,779 9,204 5%

15www.iexindia.com

POWER MARkET: MARCH 2019

The electricity market at IEX –Day Ahead- Market (DAM) and Term Ahead-Market (TAM) combined traded 3,602 MU in March’19 registering 25% increase over 2,879 traded in Feb’19 and 12% decline over 4,093 MU traded in March’18.

In financial Year 2018-19, IEX Electricity Market traded 52,168 MUs, 13% increase over 46,215 MUs traded in fiscal year 2017-18.

day-Ahead Market (dAM)

Traded volume in DAM at 3,356 MU registered 20% increase over 2,794 MU in February’19.

On a daily average basis 108 MU were traded in March’19.

The average Market Clearing Price (MCP) at ̀ 3.12 per unit registered 22% decline over `4.02 per unit in March’18 and at par with `3.08 per unit in Feb’19. The average MCP during different time-periods of the month was:

� Morning (07:00 to 10:00 Hrs): `3.35 per unit

� Day (11:00 to 17:00 Hrs): `2.99 per unit

� Evening peak (18:00 to 23:00 Hrs): `3.53 per unit

� Night (01-06 Hrs and 24 Hrs): `2.76 per unit

� Daily Average `3.12 per unit

The day-ahead market experienced transmission congestion mainly towards import of power by Southern States which led to volume loss of 120 MU representing 3% of the total traded volume on the exchange. The percentage time congestion occurred was 35.6%.

One Nation, One Price was realized only for 3 days during the month.

On daily average basis 735 participants traded in the market during the month.

In fiscal 2018-19, DAM cumulatively traded 50,063 MU over 44,842 traded in the previous fiscal registering 12% increase.

Term-Ahead Market (TAM)

The Term-Ahead Market traded 246.34 MUs in March’19 registering an increase of 78% over 138 MUs traded in March’18.

`/U

nit

MCP for March' 18 & March' 19

March'18

March'18

March'19

March'19

0.00

1.00

2.00

3.00

4.00

5.00

6.00

01-3

-201

9

02-3

-201

9

03-3

-201

9

04-3

-201

9

05-3

-201

9

07-3

-201

9

08-3

-201

9

09-3

-201

9

10-3

-201

9

11-3

-201

9

12-3

-201

9

13-3

-201

9

14-3

-201

9

15-3

-201

9

16-3

-201

9

17-3

-201

9

18-3

-201

9

20-3

-201

9

21-3

-201

9

22-3

-201

9

23-3

-201

9

24-3

-201

9

25-3

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9

26-3

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9

27-3

-201

9

28-3

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9

29-3

-201

9

30-3

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9

31-3

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9

06-3

-201

9

19-3

-201

9

MaRKet NeWS

16 www.iexindia.com

ReC MaRKetIn the concluding REC trading session for fiscal year 2018-19 held on 27th March’19, IEX saw a total trade of 9,34,160 RECs comprising of 7,16,929 Non-Solar RECs and 2,17,231 Solar RECs.

In fiscal 2018-19 IEX cumulatively traded 89,55,572 over 93,29,253 traded in the previous fiscal registering decline of about 4% largely due to the lower REC inventory.

Non-Solar REC (Issued After 1.4.17) z A total of 7,16,929 Non-Solar RECs were traded with

sell bid at 7,57,242 and buy bid at 10,39,447. The clearing price discovered was ` 1,500 per REC.

Solar REC z A total of 2,17,231 Solar RECs were traded with sell

bid at 3,05,049 and buy bid at 6,86,784. The clearing price discovered was ` 2,000 per REC.

Both Non-Solar and Solar REC continued to see low supply situation with buy bids exceeding the sell bids.

The price for both Non Solar RECs (Issued after 1.4.17) and Solar RECs saw an increase of 8% and 33% respectively on MoM basis.

The distribution companies were the major buyers in March’19 REC trading session followed by Captive Users and Open Access Consumers.

Participants z A total of 1,163 participants participated in the

trading session. Overall 3,463 participants are registered in the REC segment at IEX out of which 664 are Eligible Entities (RE Generators); 2,778 are Obligated Entities (DISCOMs, Open Access Consumers & Captive Generators) and 21 are registered as Voluntary Entities.

Captive UserDistribution LicenseeOpen Access Consumer

Non-Solar Buyer Mix

130,424 (60%)

Captive UserDistribution LicenseeOpen Access Consumer

Solar Buyer Mix

43,024 (20%)

43,783 (20%)

159,226(22%)

397,559(56%)

160,144(22%)

total number of registered participants 3,460+

Obligated Entity 2,770+

DISCOMs 34

Open Access consumers 2550+

Captive Consumer 180

Voluntary 21

Eligible Entity (Private Generators) 669

Solar ReCs Non-Solar ReCs (Issued after 1.4.17)

Buy Bids 6,86,784 10,39,447

Sell Bids 3,05,049 7,57,242

Cleared Volume 2,17,231 7,16,929

Price (`/REC) 2,000 1,500

Participants 1,163

key Highlights

www.iexindia.com 17

MARkET PERFORMANCE REVIEW: FISCAL 2018-19

Overall IEX achieved 94% market share in fiscal year 2018-19, with the following key milestones:

z 306 MU, highest volume traded in DAM on 29th September, 2018.

z 52,168 MU of electricity (DAM+TAM) traded on the Exchange, 13% increase over 46,215 MU traded in the previous fiscal.

z 89.56 lac RECs traded.

z One Nation, One Grid, One price realized on 214 days.

z 23 Solar projects with total installed capacity of 1,072 MW sold solar energy through the DAM.

day Ahead Market (dAM)

A total of 50,063 MU were traded in DAM over 44,842 MU traded in previous fiscal accounting a growth of 12%. The average daily volume was 137 MU, 12% more than 123 MU in the previous fiscal. The Key highlights are as below:

z Purchase bids for 65,585 MU were received, 15% more than 57,133 MU in previous fiscal.

z Sell bids for 86,841 MU were received, 19% more than 72,956 MU in previous fiscal.

z Final cleared volume was 50,063 MU, 12% more than the previous fiscal.

z The average MCP was `3.86/unit, 19% more than `3.26/unit in previous fiscal.

z ACP is the price at which settlement takes place. In South, ACP varied from `1.5 to `20.00 per unit while for the Rest of India, ACP was to `1.25 to `18.29 per unit. The graph below compares average ACP in this fiscal with the previous fiscal.

z Participation Trend: Total registered participants increased to 6,429 from 6,238 in the previous fiscal, seeing a growth of ~3%. The Open Access consumer base increased to 4,075 an increase of 2% from 3,990 in the previous fiscal. On a daily average basis, 670 participants traded in the DAM, as compared to 887 participants in the previous fiscal. The highest ever participation was observed on 13 April, 2018 when 786 participants traded in DAM.

z Congestion: Inter-state transmission congestions led to loss of 538 MU in this fiscal representing about 1.1% of the total volume cleared in DAM. The loss in volume almost doubled from 279 MU in the fiscal year 2017-18 representing 0.6% of the total volume traded. Southern and Northern States were affected due to congestion in the Inter-State transmission corridors.

MaRKet INSIgHtS

135 159 166 130 128 191 210 113 99 106 100 108

3.98

4.67

3.733.46 3.34

4.69

5.94

3.593.30 3.33

3.08 3.12

0.00

1.00

2.00

3.00

4.00

5.00

6.00

0

50

100

150

200

250

300

Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar

Pri

ce (`

/kW

h)

Volu

me

(MU

)

Cleared Volume (MU) MCP (`/kWh)

Monthly Average Cleared Volume and MCP FY18-19

www.iexindia.com 18

Term-Ahead Market (TAM)

A total of 2,105 MUs were scheduled through TAM, 53% increase from 1,373 MU scheduled in previous fiscal. The highest volume was in October 2018 when close to 617 MUs were traded.

REC Market

IEX cumulatively traded 89,55,572 RECs over 93,29,253 RECs in the previous fiscal, registering decline of about 4% largely due to the lower REC inventory. Through this fiscal year, both Non-Solar and Solar markets continued to see low supply situation with buy bids exceeding the sell bids consequently the clearing price increased for both the markets. While in the previous fiscal year, the REC market was in contrary situation with sell bids exceeding the buy bids and consequently market traded at the floor price.

A total of 3,469 participants are registered in the REC segment. Of this, 669 are Eligible Entities (RE Generators) 2,772 are Obligated Entities (DISCOMs, Open Access Consumers & Captive Generators) and 21 are registered as Voluntary Entities.

Global Forum on World Energy Transition was organized by Florence School of Regulation from 25-28 March at Florence, Italy. About 100 experts from all over world were invited to debate on issues related to Energy Transition. Mr. Rajesh K Mediratta, Director BD attended and chaired a session on ‘Role of Power Exchanges in Flexibility Platforms’.

Mr. Rajesh K Mediratta Director BD, IEX participated as panelist in session ‘Power Market Design’ chaired by Mr. P.K Pujari, Chairperson, CERC at the EU-India Workshop during India Smart Utility Week (ISUW) 2019 held on 14th March, 2019 at New Delhi

PHOTO GALLERY

www.iexindia.com 19

TRAdE dATA: dAY-AHEAd MARkET, MARCH’19

PRICe

Minimum MCP Maximum MCP Average MCP

` 3.12/kWh` 5.90/kWh` 2.00/kWh

VoluMe 1 Mu = 1 Million kWh = 1 gWh

Unconstrained Volume

3,476

112

Cleared Volume

3,356

108

PurchaseBids

4,444

250

Sell Bids

7,765

143

VOLUME

Average Daily (MU)

TotalVolume (MU)

PaRtICIPatIoN

Total Registered Participants

Open Access Consumers

Private Generators

Highest Participation

6,400+ 4,000+ 500+1,410

22nd June '13

Total Volume (MU)

Max Price (`/kWh)

Min Price (`/kWh)

Contracts

45.70 5.35 2.07Day-Ahead Contingency

171.36 4.15 4.15Weekly

5.95 1.50Intraday 29.28

- - -Daily

teRM aHeaD MaRKet - MaRCH’19

www.iexindia.com 020

Pri

ce `

/kW

h

Volu

me

(MU

)

01-3

-201

9

02-3

-201

9

03-3

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9

04-3

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9

05-3

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9

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9

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9

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9

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9

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9

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9

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9

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9

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9

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9

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9

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9

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9

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9

020406080100120140160

0.000.501.001.502.002.503.003.504.004.50 Price and Volume Trend

Cleared Volume (MU) MCP S ROI

Average Hourly Market Clearing Volume and Price

Pri

ce (`

/kW

h)

HoursHourly MCV (MU) Hourly MCP (`/kWh)

Volu

me

(MU

)

0

1

2

3

4

5

6

7

0.000.501.001.502.002.503.003.504.004.50

21 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Pri

ce (`

/kW

h)

March, 2018 March, 2019

3.06

4.02 4.03 4.02 4.023.49

3.06 3.12

0.000.501.001.502.002.503.003.504.004.50

North South ROI MCP

Price for the Month : March'18 vs March'19

01-3

-201

9

02-3

-201

9

03-3

-201

9

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9

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9

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Pri

ce (`

/kW

h)

Volu

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(MU

)

Day-Ahead Market - Trade Details

Buy Sell CV2019 Avg Price

1

2

3

4

5

6

7

8

9

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400

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