Coal Threat for Power Generation in India - My Article in the Mining India Magazine
Demand and supply gap for thermal coal of
nearly 100 million tonnes in 2012 is likely to reach about 200 million tonnes
in 2017. CIL plans to increase its production by about 180 million tonnes in
the same period through public-private partnerships which may enhance the
production by 60-70 MTPA, through expansion existing opencast and underground
mines to expand capacities which may enhance the production by 30-40 MTPA, and
through opening new projects in relatively unexploited coalfields – North
Karanpura, Ib Valley and Mand-Raigarh – which may enhance the production by
60-80 MTPA. However, challenges exist in the production increase in the form of
delays in clearances and approvals, land acquisition and development of
infrastructure to evacuate coal.
Regulatory
uncertainties in India indicate that growth in imports is likely to continue. Investment
climate has worsened. Land acquisition and rehabilitation & resettlement of
project affected people have become challenging and procedures for approvals
and clearances are labyrinthine and unpredictable.
Demand for
imported thermal coal crossed 100 million tonnes in 2011-12 although the final
off-take was lower at about 80 million tonnes due to concerns about
affordability of imported coal based power. Indonesia and South Africa have
been major sources of coal imports for Indian thermal coal. While Indonesia
coal exports have been growing at brisk pace, South African exports have nearly
been stagnant. Other sources are likely to emerge – Mozambique, Australia and
USA – have been considered. Challenges have been the price of imported coal and
infrastructure to transport coal.
Coal imports from Indonesia
While Indonesia
is clearly the favorite for thermal coal imports and acquisition of mining
assets, coal sector there has been in regulatory flux. Indonesia's Law No. 4 of 2009 on Minerals and
Coal Mining (the 'New Mining Law') replaced Law No. 11 of 1967 (the 'Old Mining
Law'). The Law through
Implementing Regulations regulates the following:
– Mining Area Determination;
– Mineral and Coal Mining Business
Activities;
– Mining Services for Minerals and
Coal (i.e. who may provide mining services and their licensing requirements);
– Post-Mining and Reclamation
Activities;
– Prioritization of Coal and Mineral
Supply for Domestic Interest;
– Investment changes pursuant to the
old 'Contracts of Work' and 'Coal Contracts of Work';
– Transparency of state and regional
income generated from extractive industries; and
– Administrative sanctions in the
event of non-compliance.
For those
who acquired or desired to acquire mines, there is now divestment obligation - after 5 years of production, the holder of
an IUP (Izin Usaha Pertambangan – coal
mining permit) to divest its foreign shareholding so that at the end of 10
years of production a minimum of 51% of the shares are locally owned. An IUP holder
is obliged to carry out processing and refining activities related to the
mining products produced by it in Indonesia. There is imposed Domestic Market Obligation (DMO).
IUP holders who export coal are required to
refer to the benchmark price set by the minister in charge of minerals and coal
mining affairs. A Standard Price is fixed monthly
by reference to a number of indices. Exporters even those to their own power
plants in India are to sell at the standard price only except for low grade
coal. For those, who own
stakes in mines, the Indonesian rule will force such companies to transact at
market prices, which may be seen as raising the cost of delivered coal in
India. This is true but is not fatal. Taking a holistic view, however, the cash
flows in an integrated Indonesian coal mining and Indian power generation unit
after this regulation will continue to be similar (albeit a little lower,
obviously), except that royalty and income taxes will be paid in Indonesia, and
the cash flows will need to be brought on the books on Indian power project
after paying taxes in Indonesia through appropriate and innovative business
structuring.
Export
duties have been contemplated though it has not been imposed yet. The proposal
that has been muted is to keep the duties at a high of 20 to 30%. This could
make exports less lucrative for domestic producers in Indonesia which may
impact the future investments. The same could make imports into India expensive
if the export duties are passed on even partially to consumers in India.
From the
mine acquisition perspectives, there are significant geological risks in
Indonesian acquisition. Often the resource estimate data and calculations are
not reliable. The acquirers must insist on JORC compliant reports or conduct
drilling – greater geological risks exist now since low-hanging fruits have
gone and several prospects are exploration IUPs which are in the market for
quick sell off without any investments to prove the asset. Regulatory
uncertainties can have significant impact on coal asset valuations. Infrastructure
challenges require greater quantum of investments than pure mining license
acquisition
Coal imports from South Africa
South
Africa’s thermal coal exports have been in the range of 65 to 70 million tonnes
since 2009-10. The stagnation in exports is partly attributable to limitations
in infrastructure to support exports, and weather related disruptions in the
first-half of 2011. Thermal coal exports from South Africa are expected to
increase by 3 per cent and 4 per cent. The
growth in exports will be supported by gradual improvements to the efficiency
of the infrastructure network, including increased capacity of the rail line to
the Richards Bay Coal Terminal.
Resource
base is about 55 billion tonnes of largely thermal grade coal. Coal seams are
relatively thick and close to the surface, which allows for low-cost mining; a
quarter of South Africa’s bituminous coal is between 15-50 meters below the
surface and much of the remainder between 50-200 meters.
Resource
deals with innovative payment structures provide good investment opportunity in
South African coal mining. Expansion of RBCT sets the scene for growth of the
country’s large position as a supplier of thermal coal into the international
markets.
About 77
per cent of South Africa's primary energy needs are provided by coal, a fact
unlikely to change in the next two decades owing to the relative lack of
suitable alternatives to coal as an energy source. The South African power
sector has been facing capacity constraints and the economy has faced severe
outages recently. This may make exports difficult given that the domestic
markets needs will be given priority over exports.
Coal imports from Australia
Australia
faces stiff competition from Indonesia in serving the Asian Market, Indonesia
having a clear advantage in terms of logistics. In 2011, Australia’s thermal coal exports grew
by four per cent, relative to 2010, to total 148 million tonnes. Projections are
for growth at an average annual rate of 11 per cent between 2013 and 2017, to
total 271 million tonnes by the end of the period. Business environment in Australia is relatively
stable and the country has a robust mining legislation with minimal political
and regulatory risks.
Responding
to demand, coal producers in Australia are investing heavily in new coal mine,
rail and port infrastructure. Export coal industry in Australia is serviced by
nine coal loading terminals located in Queensland and New South Wales. Number
of rail projects under construction in South Wales, Queensland that would lead
to increase in supply chain capacity. Governments are supporting expansion in export infrastructure with the
Australian Rail Track Corporation forecast to invest $1.4 billion over five
years in the Hunter Valley, and the Queensland Government recently completing
69 km of the Northern Missing Link.
Cost of coal
mining in Australia is higher than Indonesia due to labour constraints, which
make human resources expensive, and regulatory compliances which require
investments in environmental management whose standards are higher. Cost of
coal transportation is higher than Indonesia due to longer distance between the
coal basins and ports, also congestions on the railway network has begun to
hamper dispatches. Shipping cost from Australian ports to India is almost
double of the shipping cost from Indonesia, voyage days and fuel costs are
higher.
Coal imports and Blending
Quality of
domestic coal has been deteriorating – ash content has been observed to be
close to 50% in several cases. This also necessitates imports, apart from
shortages in supplies, to make power generation less environmentally
threatening. However, blending is technically challenging and all types of
coals may not be amenable to blending for power generation plants in India. Imports
therefore also present technical challenges of blending with Indian coals. Compatibility
of coals used for blending needs to be ensured to avoid problems in boiler
operation due to large variations in aggregate/individual coal quality from
acceptable design limits. Large proportion of blending of imported coal of very
low ash content, in boilers designed for high ash coal, could affect the heat
transfer profile between the radiative and convective sections of the boiler
and may lead to difficulty in attaining rated main steam and reheat steam
temperatures.
It has been observed from the operations of several power
plants that even if the blended coal in the laboratory testing environment
closely resembles the design coal for the boiler, power plant performance does
not meet the expectations. This is
mainly due to petrographic characteristics of coal which are reflected by the
transformation of inorganic particles during combustion and the manner in which
the organics are dispersed in coal.
The main characteristics of coal that affect boiler design
are ash content, volatile matter, moisture content, fixed carbon, gross
calorific value (GCV), Hardgrove
Grindability Index (HGI), coal reactivity and ash fusion
characteristics. High ash content in coal influences furnace sizing. Indian
coal contains high quantum of abrasive ash necessitating lower flue gas
velocities and larger spacing of pressure parts to minimize the flue gas
erosion. Further, heat is retained in the ash and released slowly in the
super-heater, re-heater and economiser zone.
Coal with very high moisture content de-rates the capacity
of mills and requires higher quantum of heat for coal drying in the mill thus
necessitating higher hot air temperature at mill inlet and thus impacting
sizing of economizer and air pre-heater. Fixed carbon and Volatile Matter provide
an insight into the reactivity of coal. FC/VM ratio which is called as fuel
ratio indicates the combustion characteristics of the coal. When the ratio is
more than 1.5, combustion would be difficult and if the ratio is less than 1.5,
it is easy to burn. Hardgrove Grindability Index (HGI) is important from
grinding considerations and large variation in HGI poses problem of selective
grinding of one coal over another and difficulty in achieving desired coal
fineness for proper combustion.
The boilers designed with Indian coal parameters are likely
to perform well with up to 15% blending. The new design guidelines prescribe
that target should range from 100% domestic coal consumption to 30% blending. This
design flexibility will have capital cost implications. This range is likely to
be implemented by new power plants in view of shortages expected from domestic
coal sources.
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