THE 33RD CLEAN COAL DAY INTERNATIONALSYMPOSIUM

B. C. Mallick, Principal Chief Engineer,
Central Electricity Authority, Ministry Of PowerSTRATEGIC ENERGY TRANSITION•••••

Policies and Programme
Recognisation of sourcesRegulations
Promoting Markets and Competition
Priority Research Areas

POLICIES AND PROGRAMMEa) Ambitious targets for Solar and Wind: solar and wind capacity addition by 2030b) ‘Must-run’ priority dispatch status for renewables: Preference is given to RE power in the merit order dispatchc) Renewable Purchase Obligations (RPO): These are obligations for the purchase of renewable power, specified by State Electricity
Regulatory Commissions for distribution companies, open access consumers and captive plants.
d) Promotion of Hydro Power: This is being undertaken through several policy measures to tap hydro power potential in the country,
including the introduction of Hydro Purchase Obligation.
e) Energy Storage Obligations: These are being progressively introduced. According to the policy document, there is a stipulated annual
increase in ESO for all obligated entities, beginning at 1% in FY 2023–24 and reaching 4% in FY 2029–30.
f)Green energy corridors: These are being developed to strengthen transmission networks in RE rich States.

g) Policy and financial incentives: These include solar park development, accelerated depreciation on investment, waiver on transmission
charges, and capital subsidy for residential solar roof-top.
h) Thrust to increase nuclear installed capacity: Capacity shall be increasedi) Agricultural solar pumps are being promoted . The consumption of energy (18%)in the agriculture sector is an important aspect toensure the food security aspect of the country and the globe, as large energy consumption is required for irrigation pumps.

POLICIES AND PROGRAMMEj)

Manufacturing support such as production-linked incentives for solar, electric vehicles and battery storage systems.

k) Establishment of a ‘Renewable Energy Management Centre’ for supervision, monitoring and control of RE.
l)

Policy and financial assistance for promotion of waste to energy measures.

m) Enabling bundling of thermal and hydro power with RE to enhance flexibility.
n) Policies to support biomass use for power generation.
o) PAT Scheme: This will enable alignment with the goals of the NDC, mainly through energy efficiency and conservation
activities included under standards and labelling programme for appliances, building efficiency programme, industrial
efficiency improvement under Perform, Achieve and Trade (PAT) scheme.
p) National Green Hydrogen Mission: The Mission will lead to significant de-carbonisation of the economy, Greenhydrogen has great potential for the decarbonization of hard-to-abate sectors.
q) Support to R&D in carbon capture and utilization.
r) Developing storage systems (Pumped Storage Plants, Battery Energy Storage Systems etc.)

RECOGNISATION
Recognize all sources, options and commercially viable technologies, along with new innovations that can help
in a time-bound manner in achieving a clean energy transition.
••
•
•
••

Expansion of solar, hydro and wind capacities
More nuclear power capacities addition
Flexibilisation of coal based plants
Energy storage system- PSP, BESS
Increase share of energy from waste and biomass
Carbon capture utilization and storage (CCUS) technologies in coal based plants

Green hydrogen is likely to play a significant role in decarbonizing energy use in many of the emission
intensive industries.

Zero Emission Vehicles (ZEVs) and biofuels also offer a promising potential to transition the sector away fromfossil fuels.

PRESENT AND FUTURE GENERATIONPRESENT INSTALLED CAPACITY AND GENERATION

Year,2023-24
Fuel Type

Installed capacity

Generation

GW

(%)

MU

(%)

Coal and lignite

217.5949.36

1,294,072

74.31

Hydro

46.93

10.65

134,054

7.70

Small Hydro and Biomass

15.36

3.48

12,9020.74

Nuclear

8.18

1.86

47,817

2.75

Solar and Wind

127.7028.97

199,360

11.45

Gas

25.04

5.68

31,302

1.80

Total

441

100.00Non-fossil:

198

GW45(%)

Non-fossil:

394134MU

23(%)

1,741,481

100.00PRESENT AND ANTICIPATED INSTALLED CAPACITY

Fuel Type

ActualTargetAs on 31.03.2024

As on 31.03.2030

GW

GW(%)

(%)

Coal and lignite

217.59

48.57

252

33.20

Hydro

46.93

10.47

54

7.11

Small Hydro and Biomass

16.00

3.57

20

2.64

Nuclear

8.18

1.83

15

1.98

Solar and Wind

134.28

29.97

393

51.78

Gas

25.04

5.59

25

3.29

Non-fossil (2024):

205 GW

46 (%)

Non-fossil (2030):

482 GW

64 (%)ANTICIPATED GENERATION CAPACITY (GW)
Fuel Type2029-30

2031-322046-472049-50

Fossil Fuel

277

285

250

240

Nuclear15205454

Hydro#546292

109

PSP

1927116

117

Small Hydro

5566Solar

293

365

1191

1409

Wind100

122

436

474

Biomass

15162325

Total Non-Fossil

501

616

1918

2194

Total Installed Capacity

777

900

2168

2434

42/20847/ 2,36364/2006

484/2755

BESS (MW/MWh)9

GRID BALANCING IN YEAR, 2029-30

SOLAR & WING GENERATION (GW) in 2029-30
132316
181426225444239590246327
247664228978183511
137981Max. Solar Day, May,2030

89 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

50000

Most Critical day, July,2029

2

345667873

68610

69600

68896

73379

70872

75439

73363

71093

69192

86852876595367127657226062905

47164962709

36415570995

270062

70406

1

67689

73971

50000

19915392804

145680222457210792230155226859228663

Solar+Wind

67873
68610
69600
68896
70872
74314
109130100000111352
64769
64156
67689
70062
70995
70406
73971

1500009 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

WIND

74701

2000008SOLAR

1629542020002081352238402209232240612135791975221679322500007194737

1715211042411027117737497641767

5

Solar+Wind

43675

4WIND

53928

3SOLAR

51372

247494

1

10000039459

0150000

38768

50000

200000

13347
14409
16106
14948
15629
12239
51887

58204
8407
10264
10026
10419
10957
13135
15233

10000025000043325

150000

Solar+ Wind

40828

200000Max. Demand day Solar and Wind Gen., May,2029

WIND

44996

250000

SOLAR

47630

3000000
9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24Recommended Battery Storage capacity: 42 GW

MOST CRITICAL DAY BALANCING IN 2029-30

180000

40000
35000

162954167932200000Hydro-Nuclear-Gas Generation

202000208135220923223840197522220000213579240000224061

Solar and Wind Generation

30000
25000

160000120000

15000
10000
5000

67873

68610

69600

68896

70872

74314

64769

64156

67689

70062

70995

70406

80000

73971

10000020000

10913011135214000001 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

60000

HYDRO (MW)

40000
12345678

NUCLEAR (MW)GAS (MW)9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

PSP Generation and Load

Coal Power plants Generation

20000

14000015000

120000

10000

1000005000
080000

-5000
60000

12345678

9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24-10000-1500040000-2000020000-2500000

510
COAL (MW)15CFBC (MW)202-shift (MW)2530

PSP Generation (MW)Pump Load (MW)COAL POWER PLANTS ON MOST CRITICAL DAY
The balancing of most critical day by operating flexible coal plants, CFBC and old TPP at 40% MTL, 55% MTL and 2shift needs Battery storage capacity of 22679 MW.
GasGen.
(MW)

Hydro Gen.
(MW)

Nuclear Gen. Solar & Wind
(MW)
(MW)

4616
36657
9474
224061Max. Coal Gen. (flexible plants+CFBC+Old TPPs in MW)
Min.

1847

21682

9474

MTL(%)
Max. Coal Gen. (flexible plants+CFBC+Old TPPs in MW)
Synchronished coal capacity (MW)Coal Capcity needed (MW)

64156

PSP
Gen.
(MW)

Pump Load Coal Gen.
(MW)
(MW)

CFBC
Gen.
(MW)

Old plants
Gen.
(MW)

BatteryGen./Load(MW)Demand(MW)17985

0107110

4200

20000

20240

2891780-1883642884

23100-22679

250177

40.04

55.00
131310143137168397

Ramp up rate (MW/Min.)

479

Ramp down rate (MW/Min.)

531

BSS Power (MW)

22679

0.00

REGULATION ON TECHNICAL MINIMUM LOAD

CEA has also notified a Regulation regarding Flexible operation of coal based Thermal Power Generating Units on
30.1.2023.
1.

The 55% minimum load and 2% ramp rate operating requirement shall have to be implemented by all thermal
generating units (Central/State/Pvt) within one year of the notification of the regulation.

2.

Power plants shall implement measures, if required, as per the phasing plans by the respective power plants owners tooperate thermal unit at 40% minimum load with following ramp rate:
1% per minute - 40% to 55% and 55% to 40% load
2% per minute - 55% to 70% and 70% to 55% load
3% per minute - 70% to 100% and 100% to 70% load

PHASING PLAN
PILOT PHASE

PHASE I
July,2024-Jun,2026

(40%)

(40%)

5PHASE II

PHASE III

July,2026-Jun,2028

July,2028-Dec,2029(40%)

PHASE IV(40%)

Total

Jan,2030-Dec,2030(40%)

2-shifting(age>40 yrs)

CENTRAL CAPACITY(MW)24902817510

UNITS

42760

27159102310480

34105904511810499915

18261465

1600

412096065
31035

3612055

146420

4862

161
71932

1058509654380

11553365

8127375

10235080

8920687493
196737

UNITS

STATE

CAPACITY(MW)UNITSPRIVATECAPACITY(MW)TOTAL (UNITS)TOTAL

Capacity (MW)BALL & TUBE

UNITSCAPACITY(MW)

CFBC

UNITS
CAPACITY(MW)2 - SHIFTINGUNITSCAPACITY(MW)

GRAND TOTALUNITSCAPACITY(MW)2711850

1147304316850

36991015063340

3489505460016378
587
212066

ROADMAP FOR RENEWABLE INTEGRATION IN YEAR, 2030
⮚ CEA (Flexible operation of coal based thermal power generating units) Regulations, 2023 notified

on 30th January, 2023.
⮚ A report on Flexiblization of coal fired Thermal Power Plants – A Roadmap for achieving
40%Technical Minimum Load has been prepared, published and widely circulated in 2023.

⮚ Phasing plan for achieving 40% upto year 2030 for Technical Minimum Load has been notified inGazette in Dec,2023⮚ 40% low load study- successfully completed at Ukai, Sagardighi, Dadri, Mauda, Maithon , DSTPS ,Raichur and Ramagundem.
⮚ 10 units have been selected for 40% compliance by December, 2024 under pilot phase

COST OF FLEXING
I.

Capital Expenditure (CAPEX): One-time expenditure to be incurred in retrofitting of various measures to make the plantcapable of low load operation.

II. Operational Expenditure (OPEX):i.

Cost due to increase in Net Heat Rateii.

Cost due to Increased Life Consumption (damage costs)

iii. Cost due to additional oil consumption for additional EFOR

III. Compensation methodology for below 55% low load operation upto 40% - Methodology has been approved by
MOP and sent to CERC.

17COMPENSATION
1. Capital Expenditure: One-time expenditure to be incurred for retrofitting ofvarious measures to make the plant capable of low load operation. An estimated capital
investment of Rs 10 crores to 30 crores for each unit shall be required depending on
unit’s age, size, existing plant’s control & instrumentation system etc.
Increase in tariff (paisa/kWh)Unit size (MW)Loading(%)

Min. capex (10 cr.)Max. capex (30 cr.)

20040%

2.56

7.68

500

40%

1.02

3.07

660

40%

0.85

2.56800

40%

0.64

1.92

3. Cost due to increase in Net Heat Rate: After analyzing the HBD report ofmajor OEMs (BHEL/GE/Siemens) and actual test report of low load operation unit
size wise Net Heat Rate increase including it’s tariff impacts has been prepared

2. O&M cost due to increased Life Consumption (damage costs): Flexible
operation leads to a higher rate of deterioration of plant’s components. This is observedin increased failure rate and more frequent replacement of components.

Capacity (MW)Loading(%)

O&M cost
Increase(%)

Increase in
O&M cost (RsCr.)

Increase in
O&M cost(Paisa/kWh)200
500660800

40%40%40%40%

20.00
20.00
20.00
20.00

14.62
24.97
29.66
32.35

14.88
10.16
9.14
8.23

Loading(%)

Pit head unit

Non-pit headunit

Unit Size (MW)Net HeatRateincrease(%)

Variable Tariffincrease(Paisa/kWh)

Variable Tariffincrease(Paisa/kWh)

200

40%

16.00

21.89

36.11

500

40%

16.00

21.53

35.52

Increase in tariff (paisa/kWh)
Capex =10 crores

Capex = 30 crores

Unit size (MW)Pit headNon-pithead200

40.3354.55

45.45

59.67

500

33.71

47.70

35.76

49.75

660

29.73

41.91

31.44

43.62

800

28.45

40.52

29.73

41.80

Pit headNon-pit head

660

40%

14.60

18.74

30.92

800

40%

15.00

18.58

30.65

4. EFOR: The additional EFOR due to regular low load operation of thermal
generating units may increase specific oil consumption from 0.5 ml/kWh to 0.7ml/kWh. Therefore 1.0 paisa per kWh may increase due to EFOR.

PROMOTING MARKETS AND COMPETITIONS

1) Increasing electrolyser manufacturing capacity several fold by 2030 to become a global leader.
2) India envisages becoming a leading exporter of Green Hydrogen (GH) and Green Ammonia (GA) by 2030.
3) Encourage adoption of green hydrogen and green ammonia in hard to abate sectors, and ensuring
availability of low-cost green electricity for green hydrogen.
4) Promote co-firing of green ammonia in thermal power plants (TPPs).
5) Green Ammonia/hydrogen firing in exiting GT which will run during non-solar period for grid balancing

PRIORITY RESEARCH AREA

▪ Alternative to Lithium-Ion batteries storage▪ Modifying electric cookers/ pans to suit Indian cooking methods.
▪ Green hydrogen for mobility (High Efficiency Fuel Cell)▪ Development of Carbon Dioxide Removal Technologies /CCUS▪ Geo-thermal energy▪ Hydrogen/ammonia firing at existing Gas turbine in the countryPROMOTION OF E-MOBILITY• Guidelines for EV charging infrastructure : CEA facilitates drafting of theguidelines and standards for EV charging infrastructure (EVCI) issued byMoP.
•Ministry of Power is prescribing technical standards/ type of chargers
to be used in the country by issuing the “Charging Infrastructure forElectric Vehicles - Guidelines and Standards”.

•

Monthly Report of electricity consumption by EVs taking data frompublic charging stations being published.

21

Thank you