iex rec market: an overview march 2019 · 2019-05-08 · 2016-17 3,26,848 1,56,934 11,35,332...

IEX REC Market: An Overview March 2019

For Public Use

In this presentation

Introduction to Indian Power Market

Product Portfolio

Trading Mechanism

Market snapshot

Trade @ IEX

Participation Volume Price

Power Supply situation in the Country

Year

Installed Capacity (at the end of FY)

(MW)

Peak Met ( MW )

Energy Available (Excluding RE Gen.)

(MU)

2011-12 1,99,877 1,16,191 8,57,886 2012-13 2,23,344 1,23,294 9,11,209 2013-14 2,43,029 1,29,815 9,59,829 2014-15 2,67,367 1,41,160 10,30,785 2015-16 2,98,060 1,48,463 10,90,713 2016-17 3,26,848 1,56,934 11,35,332

2017-18 3,44,002 1,64,066 12,01,528 2018-19* 3,49,288 1,77,022 11,37,607

• During the last 8 years, capacity has increased at a CAGR of 8 % i.e. from 199 GW to 350 GW, peak demand met increased at a CAGR of only 6%

Source: CEA Till Feb 2019

Installed capacity has grown at a faster pace compared to demand

3

Indian Power Market Development trend

Single buyer/seller

Multi Buyer/Seller

OTC Markets

Spot trading on Exchanges

Improved liquidity and Efficiency

Long Term/Medium Term

Short-Term (upto 1 year)

-Long term - PPA >=25 years - Medium term >1 year

Source: Percentage as per CERC Report on Short Term Power Market (Till December ‘18)

93.86%

6.1%

87.8%

Through traders 3.2% 4.3%

Direct Bilateral 0.5% 1.6%

12.2%

Exchanges 0.4% 4.3%

Unscheduled Interchange 2.1% 2.0%

FY 2009 FY 2019*

Indian Power Sector Snapshot

IEX Market Segments

Day-Ahead Market since June,08

• Delivery for next day • Price discovery: Closed , Double-sided Auction

Term-Ahead Contracts since Sep,09

• For delivery up to 11 days • Daily Contracts, Weekly Contracts

Renewable Energy Certificates since Feb,11

Energy Saving Certificates since 27 Sep’17

Intraday Market & Day-Ahead Contingency Round the clock since Jul’15

• Intraday: For Delivery within the same day • Day Ahead Contingency: Another window for next day • Gate closure : 3 hours

• Green Attributes as Certificates • Sellers : RE generators not under feed in tariffs • Buyers: Obligated entities; 1MWh equivalent to 1 REC

• 1 Ecert= 1 Mtoe( Metric Tonne Oil Equivalent) • Trading Session on every Tuesday of the Week • Trading time 1300 hrs to 1500 hrs

6

Auction

Continuous

Company Snapshot

98% Market Share

6400+ Participants

4000+ Industries 50+ Discoms

500+ Conventional Generators 1650+ RE Participants

Competition

Liquidity Transparency

7

What benefits does the power exchange provide?

Nation-wide voluntary access

E-trading

No counterparty risk

Robust Platform

Delivery Based contracts

IEX Volume Growth : Strong trend line

2,616 6,214

12,712 14,415

22,811

29,270 28,363

34,397

40,576

46,214

52,241

0

10,000

20,000

30,000

40,000

50,000

60,000

FY 09 FY 10 FY 11 FY 12 FY 13 FY 14 FY 15 FY 16 FY 17 FY18 FY 19

Cle

are

d V

olu

me

(M

U)

Electricity Volume

9

Source: IEX Data (DAM+TAM)

Product Portfolio

Intra Day REC

Day Ahead Market (DAM)

Term Ahead Market (TAM)

Renewable Energy Certificates (RECs)

Trade for the following day

Contracts for every 15 min, closed auction

From 3 Hrs ahead to 11 days in advance

4 types of contracts

•Intraday •Day Ahead Contingency •Daily •Weekly

Trade green attributes of electricity

1 REC = 1 MWh of green energy

Product Segments

Contract Characteristic

Delivery

Auction Type

Contracts

Trade Availability

Financial Settlement

Day Ahead Market

Next day

Closed Auction

15 min

All Days

Pay-In- D-1; Pay Out – D+1

Intraday Contracts

0400-2400 Hrs same day

Continuous trading

Hourly

All days

Pay in: T+1

Pay out: T+1

Day Ahead Contingency

For next day

Continuous trading

Hourly

All Days;

1500-2300

Pay in: T+1

Pay out: T+2

Daily Contracts

From 4th day to next 7 days

Continuous trading

Block of Hours (Fixed)

All Days;

1200-1500


Weekly Contracts

For next week

Open Auction

Block of Hours (Fixed)

Wed & Thurs;

1200-1600


TERM AHEAD MARKET

Contract Characteristics

T = Trade D = Delivery

DAM and TAM Trading Timeline

Trading Mechanism

Features of Day Ahead Market

A closed double-sided anonymous auction for each 15-min time block for the following day

The intersection between the aggregated sale and purchase curves defines the market clearing price (MCP)

13 Bid area defined

Congestion Management through market splitting and determining Area Clearing Price (ACP) specific to an area

Bid types: Portfolio Orders or Block Orders

Minimum bid=Re.1 for 0.1MWh

Minimum Price & Volume Step = 0.1p * 0.1 MWh

13 Bid Areas

N1

N2

A2

A1

W3

E2

E1

N3

W2

W1

N2

S2

S1

S2

S3

Congestion Management

Risk Management

Bidding and Matching

Understanding exchange mechanism

Treatment of losses

and charges

DAM trading process

Bidding Matching Review corridor

and funds availability

Result Confirmation Scheduling

Bids for 15- min each or

block bids can be placed

MCP &MCV

calculated

Corridor availability and funds

verified

Collective transaction

confirmation by NLDC

Final Schedule sent

to RLDC for incorporation

Final ACV and ACP

calculated. Market

splitting if congestion

10:00 am to 12:00 pm

12:00 pm to 1:00 pm

1:00 pm to 2:00 pm

3:00 pm 5:30 pm 6:00 pm

Bid Types

• Bids for each 15 min can be entered

• Varying price and quantum pairs

• Allow partial execution

Single/Portfolio Bid

• Relational Block Bid for any 15 min

• Mother or child bid

• No circular links

• No partial execution

Block Bid

DAM-Single Bid

DAM-Block Bid

Rules for bid linking : •A bid (bid B) can only be linked to one other bid (bid A) •Both bid A and bid B must be of same type, i.e. sale-sale or purchase-purchase. •Bid A and bid B can span any set of hours independently of each other •Bid A and bid B can have any bid price independently of each other.

Price Tick 0 1 1.1 2 2.1 2.5 3 3.1 3.5 3.8 4 4.1 5 7 9 12 14 17 19 20

Portfolio A 20 20 20 20 20 20 20 10 7 4 0 0 0 0 0 0 0 0 0 0

Portfolio B 60 60 60 60 50 40 40 40 40 40 40 40 20 20 20 20 20 20 20 20 Portfolio C 70 70 70 70 70 60 50 50 50 50 50 50 50 10 10 10 10 10 10 10

Portfolio D 40 20 0 0 -40 -60 -80 -81 -85 -100 -120 -120 -120 -120 -120 -120 -120 -120 -120 -120 Portfolio E 0 0 0 0 0 -40 -50 -50 -50 -50 -60 -60 -90 -90 -90 -90 -90 -90 -90 -90 Portfolio F 0 0 0 0 0 -20 -20 -20 -20 -20 -20 -30 -40 -40 -40 -40 -40 -40 -40 -40

190 170 150 150 140 120 110 100 97 94 90 90 70 30 30 30 30 30 30 30

0 0 0 0 -40 -120 -150 -151 -155 -170 -200 -210 -250 -250 -250 -250 -250 -250 -250 -250

Total Buy, MW

Total Sell, MW

190 170 150 150 100 0 -40 -51 -58 -76 -110 -120 -180 -220 -220 -220 -220 -220 -220 -220 Net Transaction, MW

Matching: Model Price Calculation algorithm (Example for a sample 15-min)

0

2

4

6

8

10

12

14

16

18

20

0 50 100 150 200 250 300

Demand (Buy) Supply (Sell)

MCP: Rs 2.5

MCV: 120 MW


SR WR

S1 50 MW RS 8000

B1 50 MW RS 8500

S1 50 MW Rs 8/u

B1 50 MW

RS 8.5/u

B2 150 MW RS 9000

B2 160 MW Rs 9/u

S2 40 MW RS 8500

S2 40 MW Rs 8.5/u

S3 50 MW RS 7500

S3 50 MW Rs 7.5/u

B1 100 MW Rs 6/u

S1 80 MW Rs 9.5

B3 30 MW Rs 7/u

B3 30 MW RS 7000

Deficit 100 MW

S1 80 MW RS 9500

B1 100 MW RS 6000

S2 120 MW RS 8000

S2 20 MW Rs 8/u

S3 100 MW RS 5500

S2 100 MW Rs 5.5/u

Surplus 100 MW

Required Flow

100 MW


SR WR

S1 50 MW RS 8000

B1 50 MW RS 8500

B2 160 MW RS 9000

S2 40 MW RS 8500

S3 50 MW RS 7500

B1 100 MW RS 6000

S1 80 MW RS 9500

B3 30 MW RS 7000

Deficit 100 MW

S2 20 MW RS 8000

S2 100 MW RS 5500

Surplus 100 MW

Allowed Flow

20 MW

Surplus 20 MW

Highest Seller getting rejected Lowest Buyers getting rejected

Deficit 20 MW

Term Ahead Market

24

TAM Market Segments

Open Auction Continuous

Continuous Continuous

25

Types of Contracts

• Weekly and Daily

– FBA -- Firm Base – 24 Hrs

– FNT -- Firm Night – 8 Hrs (0-7 & 23-24)

– FDY -- Firm Day – 11Hrs (7-18)

– FPK -- Firm Peak – 5 Hrs (18-23)

• Day Ahead Contingency and Intra-Day

– Hourly ( DAC-24 hrs & Intraday-04-24)

Region Specific Contracts

26

Trading of Intra-day Contracts

1-2 2-3 3-4 4-5 5-6 0:30-1 6-7

4-5 5-6 6-7 7-8 9-10 8-9 10-11 11-12 12-13 13-14

Trading Hours:19.5 (00:30-20:00)

Delivery Hours:20 (04-24)

14-15 15-16 16-17 17-18 18-19 19-20

21-22 22-23 23-24 20-21

7-8 9-10 8-9 10-11 11-12 12-13 13-14 14-15 15-16

16-17 17-18 18-19 19-20

Contracts available for delivery on the same day

Trading Hour

27

Intra-day & DAC contracts with current

trading system Trading Date Trading Time Intra-Day contracts DAC contracts

17-04-2016 00:30- 01 H5 to 24 (of 17-04)

17-04-2016 01 - 02 H6 to 24 (of 17-04)

17-04-2016 02 - 03 H7 to 24 (of 17-04)

17-04-2016 03 - 04 H8 to 24 (of 17-04)

17-04-2016 04 - 05 H9 to 24 (of 17-04)

17-04-2016 05 - 06 H10 to 24 (of 17-04)

17-04-2016 06 - 07 H11 to 24 (of 17-04)

17-04-2016 07 - 08 H12 to 24 (of 17-04)

17-04-2016 08 - 09 H13 to 24 (of 17-04)

17-04-2016 09 - 10 H14 to 24 (of 17-04)

17-04-2016 10 - 11 H15 to 24 (of 17-04)

17-04-2016 11 - 12 H16 to 24 (of 17-04)

17-04-2016 12 - 13 H17 to 24 (of 17-04)

17-04-2016 13 - 14 H18 to 24 (of 17-04)

17-04-2016 14 - 15 H19 to 24 (of 17-04)

17-04-2016 15 - 16 H20 to 24 (of 17-04) H1 to 24 (of 18-04)

17-04-2016 16 - 17 H21 to 24 (of 17-04) H1 to 24 (of 18-04)

17-04-2016 17 - 18 H22 to 24 (of 17-04) H1 to 24 (of 18-04)

17-04-2016 18 - 19 H23 to 24 (of 17-04) H1 to 24 (of 18-04)

17-04-2016 19 - 20 H24 to 24 (of 17-04) H1 to 24 (of 18-04)

17-04-2016 20 – 21 H1 to 24 (of 18-04)

17-04-2016 21 – 22 H2 to 24 (of 18-04)

17-04-2016 22 - 23 H3 to 24 (of 18-04)

17/18-04-2016 23.00 - 00:30*

Trading of Weekly & Daily Contracts

SUNDAY MONDAY TUESDAY WEDNESDAY THURSDAY FRIDAY SATURDAY

1 2 3 4 5 6

7 8 9 10 11 12 13

14 15 16 17 18 19 20

21 22 23 24 25 26 27

28 29 30

Weekly

Daily

29

Market Place Functionality (TAM)

30

BID MATCHING

Open/Closed Auction

Orders accumulated during call phase (no matching)

Orders matched after call period

Orders are used for calculation common price

i.e. Equilibrium Price.

All successful orders matched at Equilibrium

Price.

Continuous Trading

Price-time priority based continuous matching

The highest Buy order & lowest Sell order gets the

priority

If the prices are same then priority is given to the time

of the order received.

UNIFORM AUCTION The Sellers

S1 S2 S3

S4 S5

S6

B1 B2

B3 B4

B6 B5

B7

The Buyers Trade Matched Selected Sellers : S1,S2,S3,S4 (partial) Selected Buyers : B1,B2,B3,B4 MCP :Rs 8000/MWh Volume: 125 MW

125

50 MW @ Rs 5,500

40 MW @ Rs 7,000

50 MW @ Rs 8,000

50 MW @ Rs 9,000

50 MW @ Rs 10,000

10 MW @ Rs 6,000

10 MW @ Rs 10,000

40 MW @ Rs 9,000 50 MW @ Rs

8,000

25 MW @ Rs

8,000

25 MW @ Rs

7,000

50 MW @ Rs 6,000

50 MW @ Rs 5,500

CONTINUOUS TRADING PROCESS TWS Screen

Pending Buy Order Pending Sell Order

Buy 10 MW @ Rs 4500/MWh Sell 15 MW @ Rs 5500/MWh

Sell 15 MW @ RS 5500/MWh Buy 10 MW @ Rs 4500/MWh

Sell 15 MWh @ 4500

Trading Engine

Buy 10 MW @ RS 4500/MWh Sell 15 MW @ RS 5500/MWh

TWS Screen


Buy 10 MW @ 5000/MWh

Sell 15 MW @ Rs 5500/MWh Buy 10 MW @ 4500

Sell 15 MWh @ 4500

Trading Engine

Buy 10 MW @ RS 5000/MWh



Sell 15 MWh @ 5500

TWS Screen


Sell 15 MW @ RS 5000/MWh

Sell 15 MW @ 5500

Sell 15 MWh @ 4500

Trading Engine

Sell 15 MW @ Rs 5000/MWh

Buy 10 MW @ 5000

Buy 10 MW @ 4500

Sell 15 MW @ 5500 Sell 5 MW @ Rs 5000/MWh

Trade 10 MW @ RS 5000/MWh

Buy 10 MW @ RS 4500/MWH

Bid Modified

Risk Management in DAM/TAM Proprietary/Trading Licensee

Members Professional Members

Initial Margin Basis/Additional Margin

Initial Margin Basis/Additional Margin

Day-Ahead Market

Margin equal to Last 7 Days Average of Buy turnover

As per Bank Balance including Hair Cut Factor

TAM-Intraday 105% of order - 105% of order Value -

TAM-DAC 100% of order Value

- 100% of order Value -

TAM-Daily 5% of order Value 50% of Trade Value

5% of order Value 50% of Trade Value

TAM-Weekly 5% of order Value 50% of Trade Value

5% of order Value 50% of Trade Value

REC 100% of order Value

- 100% of order Value -

Member Client RMS

Credit facility can be provided by Trader Member to their clients

No credit or funding facility by Professional Members to their clients

Timelines for payment of Charges: DAM/TAM

NLDC

Charges

• Application Fees is paid in advance = T

• NLDC Scheduling & Operational Charges is paid on T+1

• Transmission Charges CTU is paid on T+1

SLDC

Charges

• SLDC Scheduling & Operational Charges is paid on T+1

• Transmission Charges STU is paid on T+1

• Area Transmission Charges (ATU) is paid on T+1

• Area Load Dispatch Centre (ALDC) is paid on T+1

RLDC

Charges

• Application Fees/PoC/SLDC/RLDC charges is paid on Within 3 working days of Acceptance

T = Trade Date

• Both Buyers and Sellers to absorb losses

• Average Transmission Losses of the Region where the Entity is geographically located.

Treatment of Losses

Draw less than contracted power

(Contracted Power – losses)

Inject more than contracted power

(Contracted Power + Losses)

Buyer

Seller

Treatment of Losses… for buyer

• POC Loss: 1.5 %

• S1 (State) loss: 4.85 %

• Buyer X bids for 100 MW at its respective regional periphery

100 MW

at NR periphery

POC

Loss

1.5%

98.5 MW

at State periphery

State

Loss

4.85%

93.72 MW at Buyer End

X

(Buyer)

Bid Volume Scheduled Drawal <= SLDC Clearance

Maximum Bid= Volume in standing clearance + Regional & State losses

Treatment of Losses… for seller

• POC Loss: 1.5%

• State loss: 4.85%

• Seller Y bids for 100 MW at its respective regional periphery

POC

Loss

1.5%

106.69MW

Injected by seller

State

Loss

4.85%

Y (Seller)

101.52MW at state

periphery

100 MW at regional periphery

Bid Volume Scheduled Generation

<= SLDC Clearance

Maximum Bid= Volume in standing clearance – Regional & State losses

Market Snapshot

Participation Volume Prices

Key Statistics: Electricity & REC Market

Market Share (Apr-March’19)

State Utilities

Generators

Industrial Consumers

Volume

(FY19)

71%

17 States I5 UTs

660+

>90 lacs RECs

Highest: 32,39,142 RECs (Dec’17)

ELECTRICITY REC

98%

29 States I5 UTs

500+

52,168 MU Highest :306 MU (29 Sep’18)

2,930+ 4,000+

IEX Data as on March’19

Increasing Participation Participation

26 8

0 6

343 10

489 32

123 2

537 21

58 18

32 0

0 3 0 48

37 20

1 0

0 1

824 20

249 63

0 1

25 27

476 4

Consumer: 4000+

Generator: 500+

Participation at IEX

430 7

5 0

14 0

35 1

0 1

7 0

224 12

0 3

Open Access Status across Indian States

States Generator Consumer

Haryana Punjab Rajasthan HP J&K Uttaranchal Delhi UP


M.P

DNH & DD

Gujarat

Chhattisgarh

Maharashtra


Assam Bihar Manipur/Mizo Tripura/Sikkim Jharkhand A.P. Meghalaya Orissa West Bengal


A.P

Karnataka

Tamil Nadu

Kerala

Northern Region

Southern Region

Western Region

East & North Eastern Region

Allowed Not Allowed

Industrial segments with IEX

Textile 29%

Manufacturer 15%

Metal 24%

Chemical 9%

Auto Components

6%

Cement 4%

Paper 3%

Cotton 1%

Others 9%

CERC MMC Report for FY 2017-18

Prices

*Average Price of Collective Transactions

IEX monthly Average MCP in DAM

3.03

3.88

4.17

3.21

2.82

2.56

3.68

2.56

2.61 2.31 2.43

2.31 2.56

2.59

4.09

3.00

4.02

3.73

4.69

3.30

3.11

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

4.50

5.00

Ave

rage

Pri

ce (

Rs/

Kw

h)

Month

Monthly Avg Price (Rs/kWh)

IEX Monthly Prices (FY 17-18)

Prices for various time block March 2019

5.5

9

5.5

9

5.5

9

5.5

9

5.5

9

5.5

9

10

.17

10

.17

10

.17

3.0

6

3.0

6

3.0

6

3.0

6

3.0

6

3.0

6

3.4

9

3.4

9

3.4

9

3.3

7

3.3

7

3.3

7

3.3

7

3.3

7

3.3

7

4.3

8

4.3

8

4.3

8

2.9

5

2.9

5

2.9

5

2.9

5

2.9

5

2.9

5

3.2

0

3.2

0

3.2

0

2.7

3

2.7

3

2.7

3

2.7

3

2.7

3

2.7

3

3.1

1

3.1

1

3.1

1

-1.00

2.00

5.00

8.00

11.00

East North East North(N1+N2) North(N3) West(W1+W2)

West (W3) South(S1) South(S2) South(S3)

Are

a P

rice

(R

s./K

Wh

)

Min Max RTC*(0-24 hr)

Peak*(18-23 hr)

Non Peak*(1-17 & 24 hr)

Night*(1-6 & 24 hr)

DAM Cleared Volume v/s MCP Volume

2,616

6,171

11,801 13,799

22,330

28,925 28,141

34,066

39,831

44,925

50,136 7.31

5.19

3.56 3.54 3.49

2.8 3.51

2.73 2.41

3.26 3.86

0

1

2

3

4

5

6

7

8

0

10000

20000

30000

40000

50000

60000

FY 0

8-0

9

FY 0

9-1

0

FY 1

0-1

1

FY 1

1-1

2

FY 1

2-1

3

FY 1

3-1

4

FY 1

4-1

5

FY 1

5-1

6

FY1

6-1

7

FY1

7-1

8

FY1

8-1

9

MC

P (

Rs/

kWh

)

Cle

are

d V

olu

me

(M

Us)

Cleared Volume MCP

IEX Monthly Cleared Volume

2281 2616 2536

2173 2276 2447

3188 2987 3078 3146

3630

3101 3364

3920 4086

3107

3955

4965

5725

3066 3356

0

1000

2000

3000

4000

5000

6000

7000

Cle

ared

Vo

lum

e (

Mu

s)

Month

Total Monthly Volume (MUs) Total Monthly Volume (MUs)

TAM: Performance so far

Weekly Day-ahead Contingency

Intraday Daily

3,189,452 MWh 24,89,817 MWh

16,87,578 MWh 9,35,656 MWh

Total Volume traded

8,302 MUs

TAM Monthly Snapshot - March’19

Contracts

Weekly

Intraday

Day-Ahead Contingency

Daily

Total Volume (MWh)

21,869

36,079

Max Price (Rs./kWh)

6.00

5.22

Min Price

(Rs./kWh)

2.50

2.24

Trade @ IEX

Entities eligible for Membership:

Inter-State Generating Stations (ISGS)

Distribution Licensees

State Generating Stations

IPPs

CPPs and IPPs

(with consent from SLDC)

Open Access Customers

(with consent from SLDC)

Electricity Traders / Brokers

Who Can become Members of IEX ?

IEX Membership Types

Proprietary Member

Right to trade and clear on its

own account

Generator- Distribution

licensees- IPPs - CPP- MPPs –O A

consumers

Professional Member

Trade and clear on behalf of its

Clients

NO CREDIT /FINANCING

Electricity Traders

Trade and clear on behalf of its

Clients

CREDIT /FINANCING

Clients Grid Connected

Generator, Distribution licensees, IPPs, CPP, MPP, OA consumers

Trader Client With valid PPA

Financial Requirements

Membership Category: Proprietary / Professional Member The financial criteria for payment options available on IEX are:

Fees

Professional & Proprietary & Electricity Trader

(Full Payment Option)

Proprietary member (Light Payment

Option) Admission fee Rs. 35,00,000 Rs. 10,00,000

Interest Free Security Deposit

Rs. 25,00,000 Rs. 10,00,000

Annual Subscription Fees

Rs. 5,00,000 Rs. 2,50,000

Processing Fees Rs. 10,000 Rs. 10,000

TOTAL Rs. 65,10,000 Rs. 22,60,000

Exchange Transaction 2p/kWh 3p/kWh

How to Move Ahead…

Become Member or Client (of a Member)…options

• Rs 22.6 Lacs +3p/kWh transaction fee

• Rs 65.1 lacs + 2p/kWh transaction fee

• Client @ 1Lakh

Technical Requirements

• Standing Clearance from UTs/State SLDC

• ABT Meters

• Sufficient transmission capacity

Connectivity with exchange can be done in two ways

• Internet Immediate

• Leased Line

Start Buying from IEX or Sell surpluses to IEX

Registration P

RE

-TR

AD

ING

SELECTION OF MEMBER 1 week

METERING (unless already done) Special Energy Meter

0.5-3

Months

SLDC Clearance/NOC NOC from respective SLDC 1 Month

Registration at IEX Client registration for each point of drawal Unique id created in Exchange system

0.15 Month

Member Related Activities

Exchange Related Activities

Register for IEX Monthly Bulletin

Register for Daily SMS alerts

Use IEX Mobile Application to track prices

Follow us @IEXLtd

Thank You www.iexindia.com

iex rec market: an overview march 2019 · 2019-05-08 · 2016-17 3,26,848 1,56,934 11,35,332...

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