The Union Minister for Power and New & Renewable Energy has given an explanation of the government’s policy regarding use of imported coal in thermal power plants, as given below.

The concern of Ministry of Power is to ensure sufficient availability of coal at Thermal Power Plants (TPPs) so that the demand for electricity may be met. Coal, whether domestic or imported, is procured by Thermal Power Plants [Domestic Coal Based (DCBs) plants or Imported Coal Based Plants (ICBs)] separately and as per their requirements. As Coal is under open general licence (OGL) since 1993, thermal power plants / generators have been regularly importing coal as per their preference (imported coal has high Gross Calorific Value and therefore is of better quality) and need, based on their commercial prudence. There are a number of Power Plants based exclusively on imported coal. In addition, the Domestic Coal Based (DCBs) plants have been importing coal for blending purpose since 2009. The imports for blending varied between a peak of 47.6 MT in 2015-16 to 23.8 MT in 2019-20. In 2020, Ministry of Power advised States to reduce imports for blending; as a result, the imports declined to 8.1 MT in the year 2021-22. Information regarding coal imports by DCBs and ICBs is regularly collected and monitored by Central Electricity Authority.

The import of coal by thermal Power Plants during last 14 years and in the current year (up to October 2023) is as follows:

Import of coal by power sector
Figure in Million Tonnes
Year	For Blending	By Imported Coal Based plants	Total Import
2009-10	18.8	4.4	23.2
2010-11	21.1	9.4	30.5
2011-12	27.3	17.6	44.9
2012-13	31.1	31.6	62.7
2013-14	38.6	40.9	79.5
2014-15	47.6	42.5	90.1
2015-16	37.1	44.0	81.1
2016-17	19.8	46.3	66.1
2017-18	17.0	39.4	56.4
2018-19	21.4	40.3	61.7
2019-20	23.8	45.5	69.3
2020-21	10.4	35.1	45.5
2021-22	8.1	18.9	27.0
2022-23	35.1	20.5	55.6
2023-24 (Apr-Oct)	13.6	21.7	35.3

The above table clearly shows that Import of coal for DCBs was on decline since 2019-20 primarily due to increased availability of domestic coal on account of various policy measures taken to increase domestic coal production. Accordingly, the Ministry of Power, in FY 2020-21, gave advisory to GENCOS to reduce their imports as Ministry of Coal informed that sufficient domestic coal was available. However, from July ’21 onwards the consumption of coal in Thermal Power Plants increased because of increased demand and the supply of domestic coal on a daily basis was less than consumption which resulted in depletion of coal stock and stocks at plants’ end came down from 28.7 Million Tonnes (MT) as on 30.06.2021 to about 8.1 Million Tonnes (MT) as on 30.09.2021. Therefore, in December 2021, Ministry of Power advised State GENCOs and Independent Power Producers to import @4% and Central GENCOs @10% of their requirements during 2022-23. During the month of April, 2022, the Power Demand and the coal consumption in power plants grew by about 12% as compared to April 2021. In view of the high demand for power and receipt of coal being less than consumption leading to depletion of coal stock, Ministry of Power on 28.04.2022 advised States and IPPs to import coal @ 10% of their requirement in order to maintain sufficient coal stock during the monsoon season. The gap between receipt of domestic coal and consumption continued and shortages partially met through Imported Coal.

During April-Sep 2022 (QI, Q2 of FY 2022-23) the receipt of domestic coal was about 355 MT against the consumption of 385 MT (Dom: 359 MT + Imp: 1.4 x 18.9 MT). The gap between supply of domestic coal and consumption of coal was about 1.6 lakh tonnes / day during this period. On the improvement of the situation, Ministry of Power advised GENCOs on 01.08.2022 to take decision regarding blending at their level taking into account the domestic coal supply and stock position (need based blending) with continuous monitoring of stock levels.

The gap between daily coal consumption and daily arrival of domestic coal ranged between 2.65 Lakh Tonnes to 0.5 Lakh Tonnes between the months of September 2022 and January 2023. If the imports for blending had not been made, the coal stocks in thermal power plants would have reduced to ZERO in September 2022 and would have continued so, leading to widespread power cuts and blackouts. Therefore, Ministry of Power advised Central, State Gencos and Independent Power Producers (IPPs) on 09.01.2023 to import coal @ 6% by weight through a transparent competitive procurement for blending so as to have sufficient coal stocks at their power plants for smooth operations till September 2023.

In the current Financial Year, Power Supply position has been regularly reviewed by the Ministry of Power and it has been observed that there is consistent rising trend in the power demand in the country coupled with inadequate supply of domestic coal which has resulted in rapid depletion of coal stocks at Domestic Coal Based (DCB) Plants across the country. During April-October 2023, the average growth in coal-based generation, with respect to corresponding period of FY 23, was 8.6% and the depletion in DCB plants stocks was 15.3 MT (Month-wise position is shown in table).

Summary of Growth in Coal Based Generation, Receipt of Domestic Coal and Consumption in DCB Plants during 2023-24 (up to October 2023) is as under:

Summary of Growth in Coal based generation, receipt of Domestic Coal and consumption in DCB Plants
Month		% Growth coal-based generation w.r.t FY23		Receipt of domestic coal (MT)	Consumption of Domestic Coal (MT)		Consumption of Imported coal for blending (MT)		Total Consumption (Dom + 1.4 x Imp) (MT)		Gap (Receipt – Consumption) (MT)		Total Stock at DCB plant Level (MT)
Apr-23		0%		65.4	66.4		2.2		69.5		-4.1		34.6
May-23		2%		67.5	66.3		2.2		69.4		-1.9		33.8
Jun-23		3%		63.9	64.7		2.2		67.7		-3.9		35.0
Jul-23		8%		63.0	63.2		1.6		65.4		-2.4		33.6
Aug-23		14%		61.8	66.1		2.0		68.9		-7.1		33.1
Sep-23		12%		59.9	65.5		1.9		68.1		-8.3		28.2
Oct-23		25%		65.5	68.8		2.3		72.0		-6.5		21.8
2023-24 (Till Oct 2023)		8.6%		447.0	460.9		14.4		481.1		-34.2		19.3
On Per-day basis
Summary Growth in coal-based generation, receipt of domestic coal and consumption in DCB Plants
Month	% Growth in coal-based generation w.r.t FY23		Receipt of domestic coal (MT/day)			Consumption of Domestic Coal (MT/day)		Consumption of Imported coal for blending (MT/day)		Total Consumption (Dom + 1.4 x Imp) (MT/day)		Gap (Receipt - Consumption) (MT/day)
Apr-23	0%		2.18			2.21		0.07		2.32		-0.14
May-23	2%		2.18			2.14		0.07		2.24		-0.06
Jun-23	3%		2.13			2.16		0.07		2.26		-0.13
Jul-23	8%		2.03			2.04		0.05		2.11		-0.08
Aug-23	14%		1.99			2.13		0.06		2.22		-0.23
Sep-23	12%		2.00			2.18		0.06		2.27		-0.28
Oct-23	25%		2.11			2.22		0.07		2.32		-0.21
	8.6%

 

About 14% fall of Hydro Generation has been recorded in H1 of FY24 compared to the corresponding period of FY 23 due to variable monsoon rainfall. Approximately 2 GW of hydro capacity is out because of recent floods in Sikkim. The Reservoir levels in Northern, Eastern and Southern regions are less compared to the previous year as on 09^th Oct’ 2023, which has resulted in lower reservoir energy content at pan India level. This has put additional burden on Coal Based Thermal Generation.

Therefore, in order to ensure un-interrupted power supply across the country, after careful consideration, Ministry of Power vide letter dated 25.10.2023 directed all GENCOs (Central, State and IPPs) to continue to import coal for blending at 6% (by weight) minimum for the rest period of FY 2023-24 till March 2024.

The price of the imported coal is not comparable with the price of domestic coal due to difference in calorific value. The pricing of imported coal is linked with international indices for import coal, source of origin, other factors like ocean freight, insurance, etc. which is purely dynamic and vary with international demand supply scenario. Every generating company imports coal as per its requirements. Further, the cost of generation of electricity is dependent upon the quantity of imported coal used and the price of imported coal.

DISCOMS procure power from generators on tariff fixed by the SERCs/CERC under section 62 of the Electricity Act. The Regulator fixes the tariff after examining all input costs – fuel / transport / O&M costs / administrative costs etc according to norms. If any cost which is claimed by the generator is found by the SERCs/CERC to be excessive, they do not allow it to be passed through in tariff. Therefore, if any generator inflates the fuel cost, the Regulator – SERCs/CERC – will not pass it in tariff. The Regulator also lays down norms for various costs – and do not allow costs in excess of the norms to be passed through. The issue of the fuel costs and the resultant tariff is between the GENCO and the Regulator – the Government has no role to play. If a DISCOM or GENCO is aggrieved by the order of a Regulator, they can appeal to the APTEL – Appellate Tribunal.

The other methodology for procurement of power by DISCOMs from GENCOs is under Section 63 – by an open competitive bid. The Regulator will adopt the tariff if the bid has been competitive and transparent. The DISCOMs can sign the Power Purchase Agreement only after the tariff has been concurred in and adopted by the Regulator.

The third option for the Generator is sale through the exchange – which functions on the basis of open competition. In case of open competition input costs are irrelevant – if some generator’s power cost is high it will not sell.

This information has been given by the Union Minister for Power and New & Renewable Energy Shri R. K. Singh, in a written reply to a question, in Rajya Sabha on December 5, 2023.

***

PIB DELHI | Alok Mishra / Dheep Joy Mampilly

(Release ID: 1983084) Visitor Counter : 1159