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This gives a detailed account of Affordability of Natural Gas for Indian Industries ( Sectorwise) for next 10 years, vis a vis competitive fuels.
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1. Executive Summary
If Coal is the fuel for 19th
Century, Oil is the fuel for the 20th
Century, and then in all
probability Natural Gas will be the fuel for 21st Century. India is facing severe energy shortage
in form of Coal, and Oil prices are stubbornly high for Industries as raw material. Shortage of
Fuel prompted world’s largest blackout in month of July 2012, wherein almost two consecutive
days almost 600 million people of India spent almost 16-20 hours without electricity. This
should ring as an alarm bell for the Indian government to mend its ways and find alternatives to
ever increasing appetite for India to consume energy. In this context, Natural Gas with
abundant supply within and outside India can be alternate energy which can be easily tapped,
ramped up and satisfy the energy appetite of India and unleash the growth which India needs to
bring almost 35-40% of its population above poverty line. But Natural Gas is costlier fuel
compared to Coal but cheaper than oil historically and same parity is to continue. Hence
Natural Gas prices need to study properly to find the affordability factor for Individual
Industries like Fertilizer, Power, Refineries, LPG Extraction Plants, Steel Plants, City Gas
Distribution. Nevertheless Coal is the cheapest form of energy but it has the widest
ramifications as far as environment is concerned and health cost for people in vicinity to Coal
Fired Industries, again which burdens Government, Insurance Companies, local communities
with extra spend on health and environment cleaning. Whereas Natural Gas is the Cleanest
hydrocarbon available in the planet till renewables take over with minimal Carbon footprint,
hence this project will try to develop a model which will factor the Social Cost of using Coal
vis a vis affordability of high cost fuel like Natural Gas and also look into the affordability in
much publicized pooling mechanism as propounded by Natural Gas Industry in India.
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2. Introduction
2.1 Title of the Capstone Project.
The Title of Capstone Project is “Secondary Research on Affordability of Natural Gas
prices for Indian Industries (Sector wise)”
2.2 Company Overview
2.3 Background of project & brief on the title of the project.
Natural Gas being the cleanest hydrocarbon has been the lowest consumed product in India
due to non-uniform pricing across the globe (no single benchmark for Global trade),
Shipping constraints, handling constraints and constraints with end users. Due to different
pricing mechanism Natural Gas is available at 4.2$/mmbtu (domestic gas) to 7.5$/mmbtu
(Imported Term LNG) to 12-13$/mmbtu (imported Spot LNG), hence industries find too
difficult to plan their long term activity with this type of Fuel and hence they prefer long
term planning with either Coal or Liquid fuels. Keeping the situation in mind, I have
developed this title to see whether affordability and uniformity in pricing is possible for
industries which can readily accept Natural Gas in their processes.
2.4 Objectives
To Find the Affordability Natural Gas price levels for Indian Industries
(Sector wise)
To find a model to ascertain Social Cost of using polluting fuels vis-a-vis
Clean Fuels
To merge the above two and form a uniform model for the affordability
To find affordability of Natural Gas for price sensitive sectors by Cross
subsidizing with more polluting Fuels/ costly imported fuels.
2.5 Need and Significance of this project
India is the world’s seventh largest energy producer, accounting for 2.49% of the world’s total
annual energy production. It is the fifth largest energy consumer, accounting for about 3.45%
of total energy consumption in 2004, which has been increasing by an average of 4.8% percent
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a year since 1990. The share of commercial energy in total primary energy consumption
increased from 59.7% in 1980-81 to 79.3% in 2008-09. India’s GDP has grown at more than
8-8.5% during the last few years, and is expected to grow at least at 6.5-7% in the coming few
years. The growth has taken place despite the huge deficit in energy infrastructure. Even
today, half of the country’s population does not have access to electricity or any other form of
commercial energy, and still use non-commercial fuels such as firewood, crop residues and
cow dung cakes as a primary source of energy for cooking in over two thirds of households.
The future growth of the country would demand a move to large scale commercial energy
forms. In particular, natural gas as a clean energy source holds the highest promise for the
country. World’s resources of natural gas, although finite, are enormous. Estimates of its size
continue to grow as a result of innovations in exploration and extraction techniques. Natural
gas resources are widely and plentifully distributed around the globe. It is estimated that a
significant amount of natural gas remains to be discovered. Natural gas has emerged as the
most preferred fuel due to its inherent environmentally benign nature, greater efficiency and
cost effectiveness. The demand of natural gas has sharply increased in the last two decades at
the global level. In India natural gas was first discovered off the west coast in 1970s, and
today, it constitutes 10% of India’s total energy consumption. Over the last decade it has
gained importance as a source of energy and its share is slated to increase to about 25% of the
total energy basket by 2025-2030. Production of natural gas, which was almost negligible at
the time of independence, is at present at the level of around 132.83 million standard cubic
meters per day (MMSCMD). The main producers of natural gas are Oil & Natural Gas
Corporation Ltd. (ONGC), Oil India Limited (OIL), JVs of Tapti, Panna-Mukta and Ravva
and Reliance Industries Limited (RIL) which has discovered gas in the Krishna Godavari
basin at its KG D6 block in the east cost of Andhra Pradesh.
Domestic Supply and Gross Demand Situation
Table 1: Domestic Natural Gas Prodn Estimates ( in MMSCMD)
Block/Field Well Operator 2012-13 2013-14 2014-15 2015-16 2016-17
Existing Fields
ONGC All India ONGC 68 68 68 68 68
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OIL Assam/AP OIL 6.8 6.8 6.8 6.8 6.8
KGD6 MA RIL 6.73 6.92 6.51 4.34 1.25
KGD6 D1 and D3 RIL 20.27 15.74 16.15 18.32 21.41
PSC BLOCKS All India Multiple 19.20 19.20 19.20 19.20 19.20
CBM Blocks Raniganj West GEECL 0.22 1.00 1.50 2.00 3.00
Total Existing Fields 121.22 117.66 118.16 118.66 119.66
New Finds
KGD6 satellite D-2, D-6, D-19, D-22 RIL 0 0 0 0 10
KGD6 satellite D-34 RIL 0 0 0 0 14.68
Deendayal KG Basin D-21 GSPC 0 10 10 10 10
Mahanadi Basin NEC-OSN-97/2 RIL 6 6 8 8
ONGC KG Basin GS 15 ONGC 1.52 1.52 1.52 1.52 1.52
ONGC KG Basin G1 ONGC 0 1.72 1.72 1.72 1.72
ONGC KG Basin KG-DWN-98/2 ONGC 0 0 0 0 25
Tapti B Series ONGC 3.44 3.44 3.44 3.44 3.44
Focus Energy RJ-ON-6 Focus 0.95 0.95 0.95 0.95 0.95
ONGC C Series- Phase III C-23, C-26 and B-12-1 ONGC 0 0 4.6 4.6 4.6
CBM Sohagpur Block CBM RIL 3.5 3.5 3.5
Raniganj East Block CBM Essar 0.50 1.00 2.00 3.00 3.00
Total New Finds 6.41 24.63 33.73 36.73 86.41
Gross Total 127.63 142.29 151.89 155.39 206.07
Table 2: Sectoral Gas Demand ( in MMSCMD) Sector 2012-13 2013-14 2014-15 2015-16 2016-17
Power 112 115 128 151 163
Fertilizer 52 83 84 90 89
City Gas 12 14 18 31 36
Industrial 17 15 16 20 21
Petrochemicals /
Refineries / Internal
Consumption
45 46 50 57 57
Sponge Iron / Steel 6 6 6 6 6
Grand Total Demand 244 279 302 356 373
Data from Planning Commission of India, XIIth Plan Document, 2012
Supply Shortfall
Table 3: Supply/Demand Imbalance (in MMSCMD)
Particulars 2012-13 2013-14 2014-15 2015-16 2016-17
Domestic Supply 128 142 152 155 206
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Total Gross Demand 244 279 302 356 373
Shortfall in Supply 116 137 150 201 167
Power and fertilizer sector will continue to be the main segments consuming natural gas in
coming years. The power and fertilizer sector together will consume around 76-80% of the
total natural gas consumed in the country. There will be huge demand for natural gas on
account of shortage in coal supplies. At present the country largely relies on coal for its
power generation. The coal availability in the country is severely limited on account of the
issues related to environment, mining constraints, rehabilitation issues, etc. As a
consequence of these factors the coal production growth in the country has been
inadequate. The average growth in Coal production is 3.71 percent per annum. As
compared to this in future the country would require a growth in coal supply at about 8 to 9
percent per annum. Even with captive coal mining and increased supply of imported coal,
the gap is very large. Natural gas provides a plausible alternative to coal. Gas as a clean and
flexible fuel is much in demand. It is understood that in the XIIth Plan period the country is
likely to aim for gas based capacity addition of 5000 MW per annum. This would
correspondingly require an additional 100 MMSCMD of supply by the end of the XIIth
Plan period. Demand is also anticipated to grow substantially for fertilizer, industry and for
city gas, all of which prefer gas over the existing options on account of environmental and
economic factors.
2.6 Scope of the Project
The scope of the project is to the study of Natural Gas Prices against the Solid Fuel
(Thermal Coal and Coking Coal) and Liquid Fuels (like Naphtha, Diesel, Petrol, LPG, SKO
Fuel Oil) and produce a model for Affordability by factoring Social cost(for Coal) and
Subsidy Cost (for Diesel/LPG/SKO).
2.7 Limitations of the Project
The Limitations of the Project are as following
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Commodities Price projections have been done on basis of available past
data and guidance of International Energy Agency and may not be correct in
long run.
This project doesn’t looks into the project development pace in LNG Re-gas
Terminals, which can become a bottleneck for using Natural Gas in big way.
Reliance Industries Limited has requested EGOM (Empowered Group of
Ministers) that Petronet LNG pricing with Ras Gas from 2014 to be made
benchmark for Domestic Gas price. In that case pooling mechanism will
have no validity and such grand scale usage and affordability of Natural Gas
cannot be achieved.
3.0 Research Methodology
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The Research Methodology is Secondary Research; Primary Data for this research has been
collected from following sources
International Energy Association for Crude Price Projections
Platts.com for historical Crack spreads for Petroleum products
Term LNG Price Formula between Gorgon LNG and Petronet LNG for Long term
Imported LNG prices
Domestic Natural Gas prices based on RIL formula for KG D6 Gas with suitable Caps
escalation on 5 years basis (Assumption of Upper Cap from present 60$ for Crude price
to 100$ for 2014-19 and 120$ for 2019-2024) .
Platts Metal Report for Crude Steel Prices
XIIth and XIII th Plan Document of Planning Commission of India
Historical Saudi CP Prices for LPG crack spreads over Crude Price
Regression Analysis for Thermal Coal, Coking Coal and Urea Prices with respect to
Brent Crude Prices.
Energy is measured in mmbtu which makes economics calculation against alternate fuel
easy. Same concept is used to find the economics for alternate fuel i.e. For Fertilizer
Industry, Naphtha can be replaced with Natural Gas, For Power Plants though Thermal
Coal plants cannot be physically converted to Natural Gas based, but economics worked
out against Thermal Coal separately, again Natural Gas can replace those power plants
which run on Naphtha or Diesel, For Steel Plant Natural Gas can replace Coking Coal
requirement, For LPG Extraction , Natural Gas can replace LPG substitution directly in
home usage and also Propane and Butane Extraction from Domestic Natural Gas
economics worked upon, For CGD, affordability for transport fuel worked against Motor
Spirit/Gasoline and Diesel.
After finding the Affordability levels, a model prepared to ascertain the social cost of using
Coal and the Subsidy cost of using liquid fuels factored to arrive at the correct affordable
rates for each industry.
4.0 Natural Gas Industry and Pricing
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Natural gas is a scarce resource in India and Govt. of India plays an important role in its
allocation. Historically, gas has been allocated in priority to end-users such as fertilizer
producers and power plants. In 2007, the Govt. of India started working on a new Gas
Utilization Policy. This was mostly a consequence of the dispute between the Ambani
brothers and the related issues on gas pricing and utilization, which created a very hot
debate in India. In 2007, a price was agreed between RIL and the government under the
PSC so that RIL was to sell gas at USD 4.2/ Million British thermal units for the first five
years of production. This price level, often reported, reflects the calculation under a formula
linking the price of gas to the price of oil:
GP = 2.5 + (OP – 25) ^0.15
Where, OP is the annual average Brent crude price for the previous FY, with a cap of USD
60/bbl and a floor of USD 25/bbl. Since 2007, the annual Brent price has always been
above USD 60. This and the large gap between demand and available supplies prompted
the government to develop a Gas Utilization Policy and to go back to administrative control
over prices (Govt. of India introduced a price formula for all discoveries under the first six
NELP rounds) and over volumes to be allocated to end-consumers. Therefore, in 2008, the
government introduced Natural Gas in India new guidelines called the Gas Utilization
Policy, which effectively took away gas producers' rights to sell the gas they discover on
the open market. These guidelines would be applicable for the next five years and be
reviewed afterwards. The recent ruling of the Supreme Court in May 2010 regarding the
dispute between RIL (Reliance Industries Ltd.) and RNRL (Reliance Natural Resources
Ltd.), reaffirms the role of the government in the allocation and pricing of gas. Currently,
the rules of the General Policy for the gas market imply that gas will be allocated according
to industry-wise priorities set up by the government. This does not imply that the gas is
“reserved”: if one customer is not in a position to take the gas, the next one on the list
becomes eligible. Existing users have priority over Greenfield users. The gas is allocated as
follows:
For Existing customers:
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Fertilizer producers
LPG and petrochemicals
Power plants
City Gas Distribution (CGD)
Refineries
Others
For Greenfield users:
Fertilizer producers
Petrochemicals
City Gas Distribution (CGD)
Refineries
Power plants
The above lists clearly show the preference for fertilizer producers, petrochemicals and
power plants as first category customers. CGD usually comes in second position. Govt. of
India gave priority to power generators and fertilizer producers, making them the major
customers supplied at the lowest rate (Administered Pricing Mechanism prices decided by
the government) by the state-owned oil and gas companies. Industrial users, which are
interested in switching to gas, do not have access to low-priced gas resources and have to
pay higher prices to private companies and LNG importers. This makes sense when gas is
more economical than the fuel they use (for example naphtha). This situation has changed
with the increase of APM (Administered Pricing Mechanism) prices to USD 4.2/ Million
British thermal units in May 2010.
Regulations for Pricing Downstream Gas
Historically, gas markets were entirely serviced by PSU with prices determined by the
central government. From 1987 to 2005, production and transport prices were fixed by the
Empowered Group of Ministers (EGOM). The APM mechanism for oil was formally
phased out in 2002, but most of the gas produced by ONGC and OIL and distributed by
GAIL continues to be sold at APM prices. In 2006, the regulator PNGRB was created to set
up the bases for a competitive market and has been developing regulations since then. In
the transmission sector, Govt. of India wishes to develop a policy concerning the approval
of pipeline construction that would be consistent, market-friendly, and would help avoid
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duplication of gas transport routes. In December 2006, the monopoly on transmission
networks for GAIL was abolished enabling other companies to build and operate networks.
The regulator PNGRB set up the Access Code requiring third-party access for one third of
the capacity and setting the tariffs of transportation for third parties. PNGRB has therefore
to determine tariffs for existing pipelines as well as for pipelines authorised by the
government (before PNGRB was created). Typically, transport along the Hazira-Bijaipur-
Jagdishpur pipeline costs USD 0.58/Million British thermal units; GAIL proposed to charge
USD 0.88/MBtu for its 572 km-long Dahej-Uran-Panvel pipeline. For its 1400 km-long
East-West pipeline (EWPL), RGTIL (Reliance Gas Transportation Infrastructure Ltd.)
opted for a two-zone tariff and wanted to charge USD 0.3-0.4/MBtu for the first zone and
USD 1.25/MBtu for the second zone.
Current Pricing Mechanism in India
The natural gas pricing scenario in India is complex and heterogeneous in nature. There are
wide varieties of gas price in the country. At present, there are broadly two pricing regimes
for gas in the country - gas priced under APM and non-APM or free market gas. The price
of APM gas is set by the Government. As regards non-APM/free market gas, this could
also be broadly divided into two categories, namely, domestically produced gas from JV
fields and imported LNG. The pricing of JV gas is governed in terms of the PSC
(Production Sharing Contract) provisions. It is expected that substantial gas production
would commence from the gas fields awarded by the Government under the New
Exploration Licensing Policy (NELP). As regards LNG, while the price of LNG imported
under term contracts is governed by the SPA (Special Purchase Agreement) between the
LNG seller and the buyer, the spot cargoes are purchased on mutually agreeable
commercial terms.
APM (Administered Pricing Mechanism) Gas Pricing
APM gas refers to gas produced by entities awarded gas fields prior to the PSC regime.
The prices of gas from these fields are administered by Govt. of India. In 2005, the price
of APM gas of ONGC and OIL was revised. Based on recommendations of the Tariff
Commission, the Cabinet Committee on Economic Affairs decided that APM gas
prices would be increased. All available APM gas would be dedicated to power
generators, fertilizers as well as specific end users covered by Court orders and small-
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scale consumers having allocations up to 0.05 MCM/day. At that time, ONGC and OIL
produced about 55 MCM/day APM gas from nominated fields. The Government
raised the consumer price be revised from Rs. 2,800/MMSCM to Rs. 3,200/MMSCM
with effective from July 1st 2005 for the following categories of consumers. It was also
decided that all the APM gas will be supplied to only these categories.
Power sector
Fertilizers sector
Cons covered under court order
Consumers Allocation less than 0.05 MMSCMD
This increase was on an ad hoc basis and it was decided that the Tariff Commission would
examine the issue of producer price of natural gas. The Tariff Commission (TC) has
since submitted its report and has recommended Producer price of Rs.3710/MSCM and
Rs.4150/MMSCM for ONGC and OIL respectively. TC has also recommended that the
consumer price should be somewhat higher than the producer price, considering the
substantial difference between the recommended producer price and the price of market
gas/alternative fuels. Govt. of India also decided that the price of gas supplied to small
consumers and transport sector (CNG) would be increased over the next 3 to 5 years to the
level of the market price. With effect from May 6th 2005, the APM gas price to small
consumers and CNG sector has been increased by 20% to bring it to Rs.3840 / MSCM.
The price of natural gas for customers in the North-East has been kept at 60% of the price
in the rest of the country. Accordingly, the price for power and fertilizers sector in the
North- East is Rs.1920/MMSCM and that for court-mandated and small scale consumers
in the region is Rs.2304/MMSCM. APM gas prices for the transport sector (CNG), small
industries and consumers would be progressively increased from INR 3 200/1 000m3
(USD 1.79/MMBtu) over the following years to reflect the market price. As they
became the second category after fertilisers and power producers, small users/CNG saw
prices increasing from INR 3 200/1000m3
(USD 1.79/MMBtu) to INR 3 840/1 000m3
(USD 2.15/MMBtu) in 2006 (INR 2 304/1 000m3 in the North East).
Pricing of Gas under Pre-NELP Production Sharing Contracts (PSC)
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Production Sharing Contracts (PSCs) were executed by GOI with Ravva consortium and
PMT (Panna Mukta Tapti) consortium on October 28, 1994 and December 12, 1994
respectively. The price of natural gas is determined by the provisions of PSC signed by the
consortium with GOI. Around 17.3 MMSCMD, 1 MMSCMD and 0.9 MMSCMD
are supplied from PMT fields, Ravva fields and Ravva Satellite fields respectively under
the pre- NELP PSCs. Out of this, GAIL supplies 5 MMSCMD from PMT fields and the
production (1 MMSCMD) from Ravva fields at APM rate to APM consumers; the
difference between PSC price and APM price is being made up through the gas pool
account mechanism.
Pricing of Gas with reference to NELP Provisions
As regards the gas from NELP fields, the Government constituted an Empowered Group of
Ministers to consider inter alia issues relating to pricing of natural gas, produced under the
NELP regime. It has been decided therein that the provisions of the NELP PSC should be
honoured. The following price basis/formula for the purpose of valuation of natural gas has
been approved by the Government in case of KG-D6 Block of RIL/Niko.
Selling price (in US $/MMBTU) = 2.5 + (CP-25) ^0.15 (in US$/MMBTU),
where CP=crude price in US$/barrel, with cap of CP=US $60/barrel. The price
basis/formula comes to US$4.2/MMBTU for crude price greater or equal to US $60/barrel.
It was decided that price discovery process on arm's length basis will be adopted in the
future NELP contracts, only after the approval of the price basis/formula by the
Government.
Import Gas (LNG) Pricing
A contract was signed with RasGas, Qatar for supply of 5 MMTPA LNG (equivalent to
about 18 MMSCMD) by Petronet LNG Limited (PLL) and supplies commenced from April
2004. This quantity has subsequently increased to 7.5 MMTPA effective from January
2010. The price for LNG has been linked to JCC crude oil under an agreed formula.
However, the FOB price for the period up to December 2008 has been agreed at a
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constant price of $2.53/MMBTU. This price translates to RLNG price of $3.63/MMBTU
ex-Dahej terminal. The price would vary on monthly basis from January 2009. Further, in
July 2007, PLL has signed another contract with RasGas, Qatar for supply of 1.25 MMTPA
LNG from July 2007 to September 2009 to meet the requirement of Ratnagiri Power
Project in Maharashtra. In order to make the price of spot RLNG affordable, EGoM has
decided in the meeting held on January 11th 2007 for pooling of prices of spot cargoes with
LNG being imported on term contract basis. This Ministry accordingly issued orders on
March 6th 2007 in compliance with the decision of EGoM. In addition to the above term
contracts, LNG is also being sourced from spot market by PLL and Hazira LNG Pvt. Ltd.
During 2011-02, an average quantity of about 5.7 MMTPA was brought into the country as
spot cargoes.
MoPNG also allowed ONGC and OIL to market gas produced by them at market rates.
ONGC was given permission to sell gas from its C-series fields in Mumbai offshore at
USD 5.25/MBtu, even higher than KG-D6. These fields are expected to produce 1 BCM/y.
On top of gas produced domestically, LNG has become an increasing part of the supply
mix of India. The current LNG prices for the two operating terminals are the following:
Long-term contract with Gorgon LNG Project
For twenty years, Petronet LNG signed an agreement with Gorgon LNG at the following
levels for 1.44 MMTPA FOB price
Per MMBTU FOB Price = 14.85 X JCC Price
Add Transportation @ Approx 2$/mmbtu from Australia to Kochi. This Agreement has
been the Costliest imported LNG agreement signed by India till date and hence all Imported
LNG and Pooled Gas price Imported LNG Components is based on this formula.
Pricing Issues
The pricing issue in India has always been quite complex. Firstly, APM gas supplies
have been declining while non-APM gas saw a dramatic increase in volume
and share but they also started falling with KG D6 supplies dwindling. Furthermore,
APM and Non APM gas has been allocated in priority to power producers and
fertilizers, two sectors expected to see their demand increasing over the coming decade.
While the Ministry of Petroleum and Natural Gas has been pushing for higher prices
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to limit losses from the PSU, this has met with strong resistance from the Ministry of
Power and Ministry of Chemicals and Fertilizers. The subsidies to fertilizers have
already multiplied by five over the last five years to reach INR 900 Billion (USD 18.0
billion) in 20011/12.
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5.0 Natural Gas Affordability levels for Fertilizer Industry
India is net importer of Fertilizer due to skewed policy in India, the local capacity built
up hindered due to subsidy issues and no clear road map, but India is forced to import
Fertilizer from International market at almost 700$/MT ( at peak in Sep 2008 before
Global recession ) to present levels of 432$/MT ( FOB July 2012). These costlier imports
are drain to exchequer and increasing the fiscal deficit. The Alternate fuel for Fertilizer
industry is Fuel Oil or Naphtha. Also one more issue of Fertilizer Industry is controlled
price of its main output i.e. Urea and subsidy to manufacturer to sell Urea below the
manufacturing cost. A chart for the Alternate Competitive Fuels, which is as below
Chart 1: Long Term Price Projections of Competing Fuel ($/mmbtu)
It is evident from the chart above that due to shortage of Domestic Natural Gas
Availability in India; the best alternate fuel will be Pooled Natural Gas (i.e. Bundling of
Domestic and Imported RLNG and thereby finding Weighted Average price). The Cost
of Urea on FOB basis in India is roughly Rs 5841/- per MT which translates into $106
per MT. The Affordability rate of Natural Gas for this price is as below in the table
0.0
5.0
10.0
15.0
20.0
25.0
30.0
35.0
2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Naphtha Imp RLNG Fuel Oil Pooled Nat Gas Dom Nat Gas
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Table 4: Urea Price with Pooled Gas and subsidy projection Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
International Urea Prices (CFR India) $/MT 462 483 504 525 533 541 549 557 565 570 575
Domestic Sales Price of Urea $/MT 106 117 128 141 155 171 188 207 227 250 275
Fixed Cost of Urea Plant $/MT 41 45 50 54 60 66 72 80 88 96 106
Cost towards Fuel Price $/MT 65 72 79 87 95 105 115 127 140 153 169
Heating Norm of Urea Plants for 1 MT Gcal 6.0 5.9 5.7 5.6 5.5 5.4 5.3 5.2 5.1 5.0 4.9
Gas Required for 1 MT Kg 514 503 493 483 474 464 455 446 437 428 420
Energy Required for 1 MT mmbtu 24 23 23 22 22 21 21 21 20 20 19
Cost of Energy with Domestic Gas $/MT 100 98 100 98 96 94 93 92 90 88 87
Cost of Energy with Imported RLNG $/MT 458 470 481 491 489 487 486 484 482 477 473
Cost of Energy with Pooled Price $/MT 335 344 353 372 350 356 354 352 350 347 344
Subsidy Requirement with Domestic Gas $/MT 35 26 22 12 1 -10 -23 -35 -49 -65 -82
Subsidy Requirement with Imported RLNG $/MT 393 398 402 405 394 383 370 357 342 324 304
Subsidy Requirement with Pooled Gas $/MT 270 273 275 286 254 251 239 225 211 193 175
Lsss to India in Imports $/MT 152 166 180 185 219 224 238 252 266 280 294
Considering the above table, to keep on importing from international market compared to
produce the same in India with Pooled Gas is comparatively cheaper, moreover with more
manufacturing units India can have more add on social benefits like Job Creation etc. If India
doesn’t add Urea Plants due to shortage of Domestic Natural Gas, then it will have to shell out
almost cumulatively 17.8 billion $ extra to import Fertilizer from outside India and subsidize for
its usage for next 10 years.
Table 5: Imported Urea vis a vis Domestic Production
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Demand of Urea Mton 30.1 31.3 32.6 33.8 34.8 35.9 37.0 38.1 39.2 40.3 41.4
Domestic Supply(if no extra Prod) Mton 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0
Import Requirement Mton 8.1 9.3 10.6 11.8 12.8 13.9 15.0 16.1 17.2 18.3 19.4
Cost of Imports Billion$ 3.7 4.5 5.3 6.2 6.8 7.5 8.2 9.0 9.7 10.4 11.2
Cost for Total Production in India Billion$ 11.3 12.2 13.1 14.4 14.3 15.1 15.8 16.5 17.2 17.9 18.6
Sale Price in India for total Production Billion$ 3.2 3.6 4.2 4.8 5.4 6.1 6.9 7.9 8.9 10.1 11.4
Overall Subsidy Requirement Billion$ 8.1 8.5 9.0 9.7 8.8 9.0 8.8 8.6 8.3 7.8 7.2
Cost of Production for Import substitute Billion$ 3.0 3.6 4.3 5.0 5.2 5.9 6.4 7.0 7.5 8.1 8.7
Difference between Dom Prod & Import Billion$ 0.7 0.9 1.1 1.2 1.6 1.7 1.8 2.0 2.2 2.3 2.4
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6.0 Natural Gas Affordability levels for Power Industry
Indian power sector is very much dependent on Coal and almost 65% of generation is
now is Coal based, but even though Coal India Ltd, the world’s largest Coal miner is
unable to maintain the pace of Coal requirement for India. Demand Elasticity is generally
1.1 times of the GDP growth, the present base Capacity of power plants is roughly 180
GW, which translates into almost 8GW of power addition per year to maintain a GDP
growth of 7-7.5% year on year. Though Coal is the cheapest fuel available in the planet
but it has lot of environmental issues and specific handling issues in India due to lot of
imports will require very high investment in Port infrastructure and Rail infrastructure, in
place of that Natural Gas partially will be better alternatives. There have been few power
plants using liquid fuel also like Naphtha, Diesel, and Fuel Oil (FO) etc. A chart for the
competing fuels is enclosed below
Chart 2: Long Term Price Projections of Competing Fuel ($/mmbtu)
It is evident from the chart that Domestic Coal is cheapest (though availability is an
issue), Imported Coal is the next best (infrastructure issues to handle the same), followed
0.0
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2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Naphtha Diesel Imp RLNG Fuel Oil
Pooled Nat Gas Imported Coal Dom Nat Gas Domestic Coal
18 | P a g e
by Domestic Gas (But availability is an issue), hence the next best alternative is the
Pooled Gas. We will now study the affordability of Pooled Gas Price
Table 6: Power Tariff with Pooled Gas and subsidy projection
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Pooled Gas Price $/mmbtu 14.1 14.8 15.5 16.7 16 16.6 16.9 17.1 17.4 17.6 17.7
Station Heat Rate Kcal/Kwh 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800
Fixed Cost of Operations $/Kwh 0.018 0.019 0.019 0.020 0.020 0.021 0.022 0.022 0.023 0.024 0.024
Fuel Cost $/Kwh 0.101 0.106 0.111 0.119 0.114 0.119 0.121 0.122 0.124 0.126 0.126
Total Breakeven Cost $/Kwh 0.119 0.124 0.130 0.139 0.135 0.140 0.142 0.144 0.147 0.149 0.151
Levelized Tariff $/Kwh 0.045 0.048 0.050 0.053 0.055 0.058 0.061 0.064 0.067 0.071 0.074
Subsidy Required $/Kwh 0.073 0.077 0.080 0.087 0.079 0.082 0.082 0.081 0.080 0.079 0.077
Subsidy Required Rs/KWh 4.04 4.22 4.39 4.76 4.37 4.49 4.48 4.43 4.41 4.34 4.22
Now to foot this subsidy there can be two options, put a small Coal Cess on the Coal
power generated so that both Coal and Gas generation remains viable and increase the
Tariff suitably. To Calculate the Coal Cess/Tax we need to see the attractiveness of Coal
Power generation which is shown below
Table 7: Power Tariff with Domestic and International Coal projections
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Domestic Coal Prices $/mmbtu 1.72 1.89 2.08 2.29 2.52 2.77 3.04 3.35 3.68 4.05 4.46
International Coal Prices $/mmbtu 5.80 6.03 6.26 6.53 6.61 6.69 6.81 6.89 6.97 7.05 7.10
Station Heat Rate Kcal/Kwh 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500
Fixed Cost of Operations $/Kwh 0.02 0.02 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03
Domestic Fuel Cost/unit $/Kwh 0.01 0.01 0.01 0.02 0.02 0.02 0.02 0.02 0.03 0.03 0.03
Imp Coal Cost/unit $/Kwh 0.04 0.04 0.04 0.04 0.04 0.05 0.05 0.05 0.06 0.06 0.06
Levelized Tariff $/Kwh 0.04 0.04 0.05 0.05 0.05 0.05 0.06 0.06 0.06 0.06 0.07
Dom Coal- Breakeven $/Kwh 0.04 0.04 0.04 0.04 0.04 0.05 0.05 0.05 0.06 0.06 0.06
Imp Coal - Breakeven $/Kwh 0.06 0.06 0.07 0.07 0.07 0.07 0.08 0.08 0.09 0.09 0.10
Gain/(loss) with Dom Coal $/Kwh 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.005 0.005
Gain/(loss) with Intl Coal $/Kwh (0.02) (0.02) (0.02) (0.02) (0.02) (0.02) (0.02) (0.02) (0.02) (0.03) (0.03)
It is evident from Table 7, that though Domestic Coal is marginally profitable, but
imported Coal operations is not profitable at present tariff levels and also future tariff
19 | P a g e
levels which generally increases at 5% level year on year. Hence the attractiveness is for
Domestic Coal Generation only, though availability of the same is not certain. To
incentivize industry to go for Gas based generation, a Coal Cess or Coal Tax can be
levied considering the Social harm it does to the environment. The Coal Cess should not
make Coal Cost more than International prices.
Table 8: Calculation of Coal Cess/Tax to incentivize Gas Power Generation
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Subsidy (For Pooled Gas) $/Kwh 0.07 0.08 0.08 0.09 0.08 0.08 0.08 0.08 0.08 0.08 0.08
25% of subsidy from Tariff
Increase $/Kwh 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02
Power Capacity GW 180 194 209 225 242 261 281 303 326 351 378
Coal Power % 65 64 63 62 61 60 59 58 57 56 55
Gas Power % 10 11 12 13 14 15 16 17 18 19 20
Domestic Coal Price $/MT 34 38 41 45 50 55 60 66 73 80 88
Gas Power Generation TWH 145 171 201 235 273 315 361 414 472 536 608
Coal Power Generation TWH 941 998 1058 1121 1188 1258 1333 1411 1493 1580 1671
Coal Required for Gen MMT 470 499 529 560 594 629 666 705 747 790 836
Gas Subsidy Bill $ 8.0 9.9 12.1 15.3 16.3 19.3 22.1 25.0 28.3 31.7 35.0
Coal Cess on Dom Coal $/MT 16.9 19.8 22.8 27.2 27.4 30.6 33.2 35.4 38.0 40.2 41.9
Gross Dom Coal Price $/MT 51.0 57.3 64.1 72.6 77.3 85.5 93.5 101.8 111.0 120.5 130.3
Imported Coal Price ( CFR) $/MT 153.5 159.6 165.7 172.8 174.9 177.0 180.1 182.2 184.3 186.6 187.8
Savings Bill $ 48.2 51.0 53.7 56.1 58.0 57.5 57.7 56.7 54.7 52.2 48.1
The basis of above table is that, there is a widening Gap between Domestic Coal prices
and International Coal prices, hence due to immense shortage of Domestic Coal, the
Capacity Mix for Coal Power needs to be progressively brought down from 65% at
present to 55% by next decade and increase the Gas Power in the Capacity mix from 10%
at present to 20% by next decade. If we don’t do the same, as it is we have to
progressively rely upon imported Coal, but again Coal plants on a lifecycle pollutes
almost 2.5 times compared to Gas based plants, hence why not use this gap between
international Coal prices and domestic Coal prices to fund the use of imported LNG (
after pooling it with domestic Gas). , This operations will be win-win situation for Gas
based Industry, General Consumer and the environment at large. The savings accrued by
not using Imported Coal cumulative is 594 billion $ (Notional Value) over the domestic
20 | P a g e
coal with Coal Cess on top of it. 25% Subsidy for Gas Based plants can be achieved by
increasing the Tariff for Gas based plants suitably and 75% of subsidy can be provided
by putting a Coal Tax ( CT) or Coal Cess in $/MT for all Domestic Coal Sold in India ( to
de-incentivize usage of Coal). The Below Table finds the Breakeven Tariff for such
arrangement
Table 9: Breakeven Tariff Calculation for Domestic Coal Generation (including Coal Tax)
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Doms. Coal Prices (incl CT) $/MT 51 57 64 73 77 86 94 102 111 121 130
Doms. Coal Prices (incl CT) $/mmbtu 2.6 2.9 3.2 3.7 3.9 4.3 4.7 5.1 5.6 6.1 6.6
Station Heat Rate Kcal/Kwh 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500
Fixed Cost of Operations $/Kwh 0.02 0.02 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03
Domestic Fuel Cost/unit $/Kwh 0.02 0.02 0.02 0.03 0.03 0.03 0.03 0.04 0.04 0.04 0.05
Breakeven Tariff $/Kwh 0.04 0.04 0.05 0.05 0.05 0.06 0.06 0.07 0.07 0.07 0.08
Tariff at 5% esclat. $/Kwh 0.04 0.04 0.05 0.05 0.05 0.05 0.06 0.06 0.06 0.06 0.07
Difference between Tariff $/Kwh (0.00) (0.00) (0.00) (0.00) (0.00) (0.00) (0.01) (0.01) (0.01) (0.01) (0.01)
Difference between Tariff Rs/Kwh (0.01) (0.06) (0.11) (0.20) (0.20) (0.26) (0.32) (0.38) (0.45) (0.51) (0.58)
Incremental tariff incr. Rs/Kwh (0.01) (0.05) (0.05) (0.08) (0.00) (0.07) (0.06) (0.06) (0.07) (0.07) (0.07)
As evident from above, meager 1 paise to 58 paise Increase in Tariff over a period of 10
years, will ensure that Breakeven Cost is achievable even with Coal Tax/Cess.
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7.0 Natural Gas Affordability levels for LPG Extraction
LPG is extracted generally from Domestic rich gas with has Propane and Butane
fractions in fractionators, GAIL India Ltd, usually extracts around 1 MMTPA of LPG
through this process, Indian LPG demand is ever increasing, but India is also importing
LNG, hence if we are able to import rich LNG, we can further extract LPG from it and
save precious foreign exchange. The competing fuels for LPG extraction is as below
Chart 3: Long Term Price Projections of Competing Fuel ($/mmbtu)
It is evident from the chart, that domestic Gas is most competitive source for LPG
extraction followed by Pooled Natural Gas. LPG extraction ratio from Natural gas
depends upon the availability of Propane and Butane ends in the Natural Gas. 80-85%
LPG consumed for Kitchen use in India, Natural Gas can directly substitute LPG, but that
requires huge investment in Pipelines, Local Grid and other facilities. PNGRB has come
up with ambitious project of putting CGD networks for 300 cities and towns of India,
which will drastically reduce the LPG consumption in India in long run,.
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2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Imp RLNG LPG Pooled Nat. Gas Dom Nat. Gas
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8.0 Natural Gas Affordability levels for Oil Refineries
Oil Refineries generally refines Crude Oil and produces different types of Petroleum
products, each having unique usage and pricing patterns due to Supply/ Demand and
Quality. Refineries generally use 10% of their inputs as energy cost for running the
Refinery Captive Power Plants, Process heating, and Boilers etc. Hence it is very
important for them to select the right fuel mix to minimize the cost and maximize the
profit. As Refinery has access to all types of Liquid fuels because they are producing in
the complex, the decision to use a particular fuel stems from usability of such fuel and
revenue it can earn from selling out to customers, as Gasoline/Petrol is one of the
premium product in market and getting maximum realization, you will seldom see
refineries using Gasoline as their fuel Source. A chart has been prepared for all the
competing fuels
Chart 4: Long Term Price Projections of Competing Fuel ($/mmbtu)
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2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Naphtha SKO Petrol
Diesel Imp RLNG LPG
Fuel Oil Pooled Nat Gas Dom Nat Gas
23 | P a g e
As evident from the Chart, Domestic Natural Gas and Pooled Natural Gas price is way
above economical for refinery to use as fuel for their Refineries. Though in India, this
realization is gaining strength with refineries as Refining Margin are hurling down from
10-12$/bbl to nowadays 5-6$/bbl. Also the difference between the Sweet Crude (i.e.
Brent) and Sour Crude ( like Maya Crude) is narrowing down, which will further bring
down the refining margin for complex refineries which are processing cheap crude
(discount to sweet Crudes) and able to manage healthy Refining Margins.
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9.0 Natural Gas Affordability levels for Steel Plants
In India, Steel Plants have range of Options starting from Coking Coal (Different from
thermal Coal in Power Industry), Natural Gas, Propane (LPG) and Liquid Fuels. Steel
Plants concentrated on Western part of India, have access to Natural Gas, but Steel plants
in Central, Southern and Eastern part of India is devoid of Natural Gas access. The Steel
Industry in India consumes almost 10% of electricity generated and 27% of Coal used by
Indian Industry. The Price of Steel is not controlled by Govt of India, but being a
commodity, goes up and down as per International market. The price fluctuations in last 5
years have been at peak 1000$/MT to present 370 $/MT. Also there is also scope of
Value addition which again follows a different market compared to other commodities.
The Competing Fuels are shown in the chart below
Chart 5: Long Term Price Projections of Competing Fuel ($/mmbtu)
Coking Coal prices are more than Thermal Coal, hence they are costlier than Domestic
Gas as alternatively. As Steel Plants are very low in priority in Allocation of Domestic
Gas (as their Output price i.e. Price of Crude Steel) is not regulated, hence they will
always find difficult to get allocation of Domestic Gas. Also India itself is importing
almost 75% requirement of Coking Coal (at present total requirement at 40 MMTPA)
from International market and with Steel production to double in next 10years from
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2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Imp RLNG LPG Coking Coal Pooled Nat Gas Dom Nat Gas
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present 100 MMTPA to 220 MMTPA, more and more Coking Coal needs to be imported
and %age of Imports will also increase as recoverable reserves in India for Coking Coal
is very limited. It is assumed that if 85% of the requirement of Coking Coal has to be
imported in 2022, then the Quantity will be almost 126 Million Ton; this Quantity will be
on top of Thermal Coal Imports. The Better Alternative is to use Pooled Natural Gas over
a period of time to mitigate the situation of huge and unmanageable imports, the
following table looks into a model to make usage of 75% Coking Coal with 25% Pooled
Gas as one option
Table 10: Steel Price Projection and Energy Cost
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Crude Steel Price ( Billet) $/MT 400 420 441 463 486 511 536 563 591 621 652
Specific Energy of Crude Steel Prodn. Gcal/tcs 6.1 5.9 5.7 5.5 5.3 5.1 4.9 4.6 4.5 4.5 4.5
Coking Coal Price ( CFR India) $/MT 210 217 225 234 236 239 245 247 250 254 256
Gas Required for 1 tcs Kg 526 508 489 471 453 435 417 399 387 387 387
Energy Required for 1 tcs mmbtu 24 23 23 22 21 20 19 18 18 18 18
Coking Coal Required for 1 tcs Kg 916 885 853 822 790 759 727 696 675 675 675
Cost of Energy with Coking Coal $/tcs 181 181 180 181 176 171 167 162 158 161 162
Cost of Energy with Domestic Gas $/tcs 102 98 100 96 92 89 85 82 80 80 80
Cost of Energy with Pooled Price $/tcs 343 347 351 363 335 334 325 315 310 314 317
Cost of Energy with Imported RLNG $/tcs 469 474 477 479 468 457 445 433 427 431 436
Energy Cost % of Steel Price-Coking Coal % 45 43 41 39 36 33 31 29 27 26 25
Energy Cost % of Steel Price- Dom Gas % 25 23 23 21 19 17 16 15 14 13 12
Energy Cost % of Steel Price- Pooled Gas % 86 83 80 78 69 65 61 56 53 51 49
Energy Cost % of Steel Price- Imported LNG % 117 113 108 103 96 90 83 77 72 70 67
Crude Steel production Mton 100 112 124 136 148 160 172 184 196 208 220
Coking Coal Qty Requirement (if used 100%) Mton 92 99 106 112 117 121 125 128 132 140 148
Natural Gas Required ( if used 100%) MMTPA 53 57 61 64 67 70 72 73 76 81 85
Cost of Energy with All Coking Coal Bill$ 23 27 32 37 43 49 56 64 71 77 83
Cost of Energy with All Pooled Gas Bill$ 34 39 43 49 50 53 56 58 61 65 70
Cost of Energy with 75% CC + 25% PG Bill$ 26 30 35 40 44 50 56 62 69 74 80
Net Savings over Using 100% Coal Bill$ (3) (3) (3) (3) (2) (1) 0 1 3 3 3
Both the Import requirements of Natural Gas and Coking Coal is at Staggering 148
MMTPA and 85 Million ton if used exclusively as fuel for Steel Plants, but the option of
using both the Fuel sources, will mitigate the handling of any one Commodity to its
fullest, the Net Savings will progressively become positive and these intermediate years
Govt to Subsidize the Pooled Natural Gas price. As the domestic availability of Coking
26 | P a g e
Coal is very limited, we cannot put Coal Tax unlike for Power Sector and fund the
subsidy for Natural Gas in this case.
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10.0 Natural Gas Affordability levels for CGD
CGD or City Gas Distribution is the low pressure Natural Gas distribution in Cities.
Generally Cities have two grids; one is very low pressure at 4-6 Kg/cm2 for domestic
Kitchen use and other at 18-19 kg/cm2 for SME’s (Small and Medium Enterprises) like
Hotels, Restaurants, Small Factories, and CNG Pumps etc. As the name suggest, there is
no competing fuels for CGD other than Natural Gas itself and different sources, like
Domestic Natural Gas, Imported RLNG and Pooled Natural Gas. However the same
when used as transportation fuel do replace Gasoline/Motor Spirit/Petrol or
Diesel/Gasoil. Hence the below chart shows the competing fuels for Transportation Use.
Chart 6: Long Term Price Projections of Competing Fuel ($/mmbtu)
It is evident from the chart that most affordable option for CGD (Transportation Fuel) is
domestic Gas, but again availability is an issue and next best option is Subsidized Diesel,
at present 38% subsidy of Rs 15.66 per litre is there in Diesel, the “Subsidized Diesel” is
projected for 10 years based on 38% subsidy to international Diesel Prices. The Third
best option is Pooled Natural Gas in CGD for transportation Use. A study also done,
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2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Petrol Diesel Imp RLNG
Pooled Nat Gas Dom Nat Gas Reducing Diesel Subsidy
Subsidised Diesel
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based on Govt of India plan to progressively reduce diesel subsidy and merge the same
with international prices, same has been shown against “Reducing Diesel subsidy”.
Hence if the plan of reducing subsidy becomes a reality, then Pooled Natural Gas will be
the most economical for CGD as transportation fuel.
The other option of CGD is fuel for domestic use like Kitchens. The competing fuels for
the same is shown in a chart below
Chart 7: Long Term Price Projections of Competing Fuel ($/mmbtu)
It is evident from the chart that most affordable option for CGD (Domestic Fuel) is
domestic Gas, but again availability is an issue and next best option is Subsidized SKO,
at present 41% subsidy of Rs 29.77 per litre is there in SKO, the “Subsidized SKO” is
projected for 10 years based on 41% subsidy to international SKO Prices. The Third best
option is Subsidized LPG, at present 35% subsidy of Rs 16.26 per Kg is there in LPG, the
“Subsidized SKO” is projected for 10 years based on 35% subsidy to international LPG
Prices. A study also done, based on Govt of India plan to progressively reduce SKO and
LPG subsidy and merge the same with international prices, same has been shown against
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2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Imp RLNG Pooled Nat Gas Reducing LPG Subsidy
Subsidised SKO Reducing SKO Subsidy Subsidised LPG
Dom Nat Gas
29 | P a g e
“Reducing SKO subsidy” and “Reducing LPG Subsidy”. Hence if the plan of reducing
subsidy becomes a reality, then Pooled Natural Gas will be the most economical for CGD
as Domestic fuel. Even Imported LNG will gain parity over LPG and SKO after 2017 if
the assumption of 5% reduction envisaged for subsidy on year on year basis.
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11.0 Conclusion
The conclusion can be drawn as following to the above study:
The Demand of Sectors like Fertilizer. Power and Steel can be ascertained properly
on basis on the available production projections, this type of demand is price sensitive
demand, The combine Gas required as per the above plan for the three sectors is
enumerated below.
The Demand of Sectors like CGD, Refineries and LPG extraction is difficult to
measure as, CGD depends upon the number of cities under Distribution Network,
Refineries demand depends upon conformity to Gas as fuel in Refinery process and
LPG Extraction depends upon availability of rich gas. This type of demand is Price (
Insensitive Demand) .Though an assumption has been made and following analysis
done , which is physically possible to achieve
Table 11: Gas Demand as per above study (Sector Wise)
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Price Sensitive Demand as per this study
Fertz. Gas Demand MMTPA 15 16 16 16 16 17 17 17 17 17 17
Power Gas Demand MMTPA 20 24 28 33 39 45 51 59 67 76 86
Steel Gas Demand MMTPA 13 14 15 16 17 17 18 18 19 20 21
Price Insensitive ( to some extent) Demand as per this study
Rich Domestic Gas MMTPA 16 18 19 19 26 27 28 30 31 33 35
Extractable LPG MMTPA 1 1 1 1 2 2 2 2 2 2 2
Refin. Gas Demand MMTPA 4 4 4 4 4 5 5 5 5 5 5
CGD Gas Demand MMTPA 3 4 5 8 9 11 12 13 15 16 17
Total Gas Demand MMTPA 55 61 67 76 84 93 101 110 121 132 145
Domestic Gas MMTPA 32 36 38 39 52 54 57 60 63 66 69
Imported LNG MMTPA 23 25 29 37 32 39 44 50 58 67 76
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12.0 References and Bibliography
Steelmart.com for Historical US FOB Coking Coal Prices
Indexmundi.com for historical Dated Brent Crude Price, Urea prices, Australian Thermal
Coal FOB prices
Pooling Document by Mercados EMI, for GAIL India Ltd.
Platts.com for Crack spreads historical
Argus.com for reference
MOPNG Website (www.mopng.gov.in)
PNGRB Website ( www.pngrb.gov.in)
The International Crude Oil Market , Handbook, Energy Intelligence Research
Coal India ltd Website
IEA Website ( www.iea.org)
EIA Website (www.eia.gov)
Fertilizer Association of India ( www.fai.org)
Central Electricity Authority ( www.cea.org)
GAIL Website (www.gailonline.com)
SAIL Website ( www.sail.co.in)
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13.0 List of Charts
The list of Charts from No1 to 7 is based on $/mmbtu for the competing fuels, the data
for such charts is tabulated below
Product 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 NCV(Kcal/kg)
Naphtha 23.4 24.6 25.8 27.0 27.4 27.8 28.2 28.6 29.1 29.3 29.6 10500
SKO 22.4 23.5 24.6 25.7 26.1 26.5 26.8 27.2 27.6 27.8 28.1 10270
Petrol 21.9 23.0 24.0 25.1 25.4 25.8 26.2 26.5 26.9 27.1 27.3 11464
Diesel 21.1 22.1 23.1 24.1 24.5 24.8 25.2 25.5 25.9 26.1 26.3 10366
Imp RLNG 19.3 20.2 21.1 22.0 22.4 22.8 23.1 23.5 23.9 24.2 24.4 11750
LPG 18.3 19.1 20.0 20.9 21.2 21.5 21.8 22.1 22.4 22.6 22.8 11840
Fuel Oil 18.2 19.3 20.3 21.3 21.6 22.0 22.3 22.7 23.0 23.2 23.4 9300
Pooled Nat Gas 14.1 14.8 15.5 16.7 16.0 16.6 16.9 17.1 17.4 17.6 17.7 11750
Reducing LPG Subsidy 13.8 15.6 17.4 19.4 20.9 22.4 24.0 25.5 25.8 26.1 26.3 11840
Subsidized SKO 13.1 13.8 14.4 15.1 15.3 15.5 15.8 16.0 16.2 16.3 16.5 10270
Reducing SKO Subsidy 13.1 15.0 16.9 18.9 20.5 22.1 23.8 25.5 27.3 27.8 28.1 10270
Reducing Subs Diesel 13.0 14.8 16.6 18.6 20.1 21.6 23.2 24.8 25.9 26.1 26.3 10366
Subsidized Diesel 13.0 13.7 14.3 15.0 15.2 15.4 15.6 15.8 16.0 16.2 16.3 10366
Subsidized LPG 12.0 12.5 13.1 13.7 13.9 14.1 14.3 14.5 14.7 14.8 14.9 11840
Coking Coal 7.5 7.7 8.0 8.3 8.4 8.5 8.7 8.8 8.9 9.0 9.1 7091
Imp Thermal Coal 5.8 6.0 6.3 6.5 6.6 6.7 6.8 6.9 7.0 7.1 7.1 6667
Dom Natural Gas 4.2 4.2 4.4 4.4 4.4 4.4 4.4 4.5 4.5 4.5 4.5 11500
Domestic Coal 1.7 1.9 2.1 2.3 2.5 2.8 3.0 3.3 3.7 4.1 4.5 5000
Assumptions:
Brent Crude Projections from IEA ( International Energy Agency, 2011 review
document)
$/bbl 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Brent 110.0 115.6 121.3 126.9 128.9 130.8 132.8 134.7 136.7 137.9 139.0
33 | P a g e
Crack Spreads over Dated Brent , average of last 10 years as per table below
Cracks Spread( $/bbl)
Petrol 7.122
Naphtha -0.597
SKO 3.982
Diesel 6.984
Fuel Oil -7.962
For LPG , Avg of last 5 years Saudi CP price over Dated Brent at 51.223$/MT
LPG defined as 40% Propane and 60% Butane. Monthly Saudi CP prices checked for last
5 years for Propane and Butane and Dated Brent and ratio as per above considered for
Crack Spread.
Energy Calculations based on the following conversions
1 Kcal/Kg = 1.799989 btu/lb = 3.968297 btu/kg
Domestic Gas Price based on RIL formula
Price = 2.5+ (CP- 25) ^0.15, CP = Crude Price
CP has cap of 60$ for 2009-2014, assumed 100$ cap for 2014-19 and 120$ cap for 2019-
24
Imported LNG Price on Petronet LNG and Gorgon LNG Formula
FOB Australia Price of LNG = 14.85% of Crude Price
Add , 2$ for Transportation for 2012 with 1% escalation, 1 $ for Regas for 2012 with 5%
escalation to CFR RLNG Prices.
Pooled Gas Price on ratio of Domestic and RLNG prices year on year as per demand.
Domestic Coal Prices based on present Coal India prices with 34 $ /MT with 5%
escalation year on Year
Imported Thermal Coal prices based on Australian Thermal Coal CFR India historical
prices in tandem with Brent Crude Prices., through Linear Regression analysis.
Imported Coking Coal prices based on US Coking Coal CFR India historical prices in
tandem with Brent Crude Prices., through Linear Regression analysis.
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14.0 List of Tables
The Assumptions/Source for the above table is as below:
1. Table 1: Domestic Natural Gas Production Estimates ( in MMSCMD)
Data Sourced from MoPNG, DGH Websites and Press Briefs
2. Table 2: Sectoral Gas Demand ( in MMSCMD)
Data sourced from XII th Plan Report on Energy by Planning Commission of India
3. Table 3: Supply/Demand Imbalance (in MMSCMD)
Difference between Table 1 and Table 2.
4. Table 4: Urea Price with Pooled Gas and subsidy projection
Assumptions
International Urea Prices ( 21 years linear regression analysis of historical Brent
Crude Prices and historical International Urea Prices and projecting the same for
future Brent Prices for 2012-22)
Domestic Sales Price: Current Price of 106$/MT (1$= Rs 55), with 10% escalation
each year.
Fixed Cost of Urea Plant = As per present Benchmark of FAI ( Fertilizer Association
of India ) at 41$/MT followed by 10% escalation each year
Heating Norm of Urea Plant: 5.97 Gcal per MT of Urea for 2012, with 2% de-
escalation year on year till 2022.
Calorific Value of Natural Gas = 43161 btu/kg
5. Table 5: Imported Urea vis a vis Domestic Production
Urea demand for 2012-22, based on IIM Ahmedabad and Planning commission
document.
Other as per Table 4.
6. Table 6: Power Tariff with Pooled Gas and subsidy projection
Assumptions
Station Heat Rate: 1800 Kcal/Kwh or 1800 Kcal/Unit, as per CEA (Central
Electricity Authority) Guidelines for Heat Rate for Gas based power plants.
Fixed Cost of Operations: Rs 1 per MW as per CEA Guidelines for Gas Based Power
Plants with 3% escalation each year.
35 | P a g e
7. Table 7: Power Tariff with Domestic and International Coal projections
Assumptions
Station Heat Rate: 2500 Kcal/Kwh or 2500 Kcal/Unit, as per CEA (Central
Electricity Authority) Guidelines for Heat Rate for Thermal Coal based power plants.
Fixed Cost of Operations: Rs 1.3 per MW as per CEA Guidelines for Thermal Coal
Based Power Plants with 3$ escalation each year
8. Table 8: Calculation of Coal Cess/Tax to incentivize Gas Power Generation
Assumptions & Data Source
Power Capacity: 180 GW for 2012 as per CEA Website, with 7.7% escalation each
year to sustain 7% GDP Growth.
Coal Power Capacity: 65% of 180 MW as per CEA Website in 2012
Gas Power Capacity: 10% of 180 MW as per CEA Website in 2012
9. Table 9: Breakeven Tariff Calculation for Domestic Coal Generation (incl. CT)
Assumptions
As Above
10. Table 10: Steel Price Projection and Energy Cost
Crude Steel Prices : 400 $/MT as per Platts Steel data with 5% escalation on year on
year basis
Specific Energy of Crude Steel Plant: As per present SAIL data at 6.1 Gcal/tcs, to be
de-escalated as per govt directive to reach 4.5 Gcal/tcs by 2020.
11. Table 11: Gas Demand as per above study (Sector Wise)
All the assumptions as above
4 MMSCMD of RLNG = 1 MMTPA of LNG
220 GW power Generation with 1 MMSCMD gas
Domestic Gas Supply
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Domestic Gas Supply MMTPA 32 36 38 39 52 54 57 60 63 66 69
Assumed rich gas from Domestic Supply @ 50% of above
LPG Extraction from Domestic Gas efficiency @ 6%
Crude/Oil Refining Capacity in India
36 | P a g e
Particulars Unit 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Crude Ref. Cap MMTPA 217 238 239 240 256 275 279 282 289 308 323
Gas Demand for Refineries assumed at 0.14 MMSCMD for 1 MMTPA of refining
Again Gas consuming facilities assumed to be available in 70% of Refining Capacity.
CGD Gas demand as per GOI , XIIth and XIII th Plan Document.
Total Gas Demand = Gas Demand ( Fertilizer + Power + Steel+ Refinery+ CGD-
LPG Extracted)
LNG Import Demand = Total Gas Demand – Domestic Supply
37 | P a g e
15.0 Abbreviations
$ US Dollar
$/MT US Dollar per Metric Ton
% Percentage
APM Administered Pricing Mechanism
bbl US Barrel
BCM/y Billion Cubic Meter per year
Billion $ Billion US Dollar
CGD City Gas Distribution
CNG Compressed Natural Gas
CP Crude Price
CT Coal Tax /Coal Cess
EGOM Empowered Group of Ministers
FO Fuel Oil
FOB Free On Board
FY Financial Year
GAIL Gas Authority of India Ltd.
Gcal Giga Calories
GDP Gross Domestic Product
GP Gas Price
GW Giga Watt
IEA International Energy Association
JCC Japan Crude Cocktail
JV Joint Venture
Kcal/KWh Kilo Calories per Kilo Watt hour
Kg Kilogram
Kwh Kilo Watt Hour
LNG Liquefied Natural Gas
LPG Liquefied Petroleum Gas
mmbtu Million British thermal Unit
MMSCM Million Standard Cubic Meter
MMSCMD Million Standard Cubic Meter per Day
MMTPA Million Metric Ton Per Annum
MoPNG Ministry of Petroleum & Natural Gas
MSCM Million Standard Cubic Meter
MT Metric Ton
Mton Metric Ton
NELP New Exploration Licensing Policy
ONGC Oil and Natural Gas Corp. Ltd
38 | P a g e
PLL Petronet LNG Ltd.
PNGRB Petroleum and Natural Gas Regulatory Board
PSC Production Sharing Contract
PSU Public Sector Undertaking
RLNG Re-gasified LNG
SKO Superior Kerosene Oil
SME Small and Medium Enterprises
SPA Special Purchase Agreement
tcs ton Crude Steel
TWH Tera Watt Hours
USD US Dollar
39 | P a g e
16.0 Annexure -1
Urea price Regression Analysis wrt Crude Prices
Data from Jan 1991 to July 2012 month wise plotted as below for Brent Crude in $/bbl
and Urea FOB prices in $/MT.
We got the following Linear Regression equation
Where Y= Urea FOB Price, X= Brent Crude Price
Y= 42.3786 + 3.5434* X
When Future Brent Crude Prices were plotted against this equation, we got,
0
100
200
300
400
500
600
700
800
900
Jan
-91
No
v-9
1
Sep
-92
Jul-
93
May
-94
Mar
-95
Jan
-96
No
v-9
6
Sep
-97
Jul-
98
May
-99
Mar
-00
Jan
-01
No
v-0
1
Sep
-02
Jul-
03
May
-04
Mar
-05
Jan
-06
No
v-0
6
Sep
-07
Jul-
08
May
-09
Mar
-10
Jan
-11
No
v-1
1
Urea Brent Crude
40 | P a g e
Year Brent Crude FOB Urea Prices Freight to India Urea CFR Price
$/bbl $/MT $/MT $/MT
2012 110 432 30 462
2013 116 452 31 483
2014 121 472 32 504
2015 127 492 33 525
2016 129 499 34 533
2017 131 506 35 541
2018 133 513 36 549
2019 135 520 37 557
2020 137 527 38 565
2021 138 531 39 570
2022 139 535 40 575
41 | P a g e
Annexure-2
Australian FOB Thermal Coal Price Regression Analysis wrt Crude Prices
Data from Jul 1997 to July 2012 month wise plotted as below for Brent Crude in $/bbl
and Australian FOB Thermal Coal prices in $/MT.
We got the following Linear Regression equation
Where Y= Australian Thermal Coal FOB Price, X= Brent Crude Price
Y= 4.885693 + 1.078506* X
When Future Brent Crude Prices were plotted against this equation, we got,
0
50
100
150
200
250
Jul-
97
Feb
-98
Sep
-98
Ap
r-9
9
No
v-9
9
Jun
-00
Jan
-01
Au
g-0
1
Mar
-02
Oct
-02
May
-03
De
c-0
3
Jul-
04
Feb
-05
Sep
-05
Ap
r-0
6
No
v-0
6
Jun
-07
Jan
-08
Au
g-0
8
Mar
-09
Oct
-09
May
-10
De
c-1
0
Jul-
11
Feb
-12
Thermal Coal Crude
42 | P a g e
Year Brent Crude FOB Coal Prices Freight to India Coal CFR Price
$/bbl $/MT $/MT $/MT
2012 110 124 30 153.5
2013 116 130 30 159.6
2014 121 136 30 165.7
2015 127 142 31 172.8
2016 129 144 31 174.9
2017 131 146 31 177.0
2018 133 148 32 180.1
2019 135 150 32 182.2
2020 137 152 32 184.3
2021 138 154 33 186.6
2022 139 155 33 187.8
43 | P a g e
Annexure-3
USA FOB Coking Coal Price Regression Analysis wrt Crude Prices
Data from Third Quarter 1997 to July 2012 Quarterly Wise plotted as below for Brent
Crude in $/bbl and USA FOB Coking Coal prices in $/MT.
We got the following Linear Regression equation
Where Y= USA Coking Coal FOB Price, X= Brent Crude Price
Y= 16.67165 + 1.302348* X
When Future Brent Crude Prices were plotted against this equation, we got
0
50
100
150
200
250
19
97
Q3
19
98
Q1
19
98
Q3
19
99
Q1
19
99
Q3
20
00
Q1
20
00
Q3
20
01
Q1
20
01
Q3
20
02
Q1
20
02
Q3
20
03
Q1
20
03
Q3
20
04
Q1
20
04
Q3
20
05
Q1
20
05
Q3
20
06
Q1
20
06
Q3
20
07
Q1
20
07
Q3
20
08
Q1
20
08
Q3
20
09
Q1
20
09
Q3
20
10
Q1
20
10
Q3
20
11
Q1
20
11
Q3
20
12
Q1
Coking Coal Brent Crude
44 | P a g e
Year Brent Crude FOB Coal Prices Freight to India Coal CFR Price
$/bbl $/MT $/MT $/MT
2012 110.0 159.9 50.0 210
2013 115.6 167.3 50.0 217
2014 121.3 174.6 50.0 225
2015 126.9 182.0 52.0 234
2016 128.9 184.5 52.0 236
2017 130.8 187.0 52.0 239
2018 132.8 189.6 55.0 245
2019 134.7 192.1 55.0 247
2020 136.7 194.7 55.0 250
2021 137.9 196.2 58.0 254
2022 139.0 197.7 58.0 256