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Focused Energy Report -
XVIII
Monthly Report-September 2013
Energy Desk
GAIL (India) Ltd.
1
Table of Contents
I. Energy Prices 4
II. Under-Recoveries on Petroleum Products 4
III. Can RLNG Replace High Price Liquid Fuel for Power Generation? 5
A. All India Generating installed capacity (MW) ........................................................................................................................... 5
IV. Natural Gas Hubs in Europe 7
A. CENTRAL EUROPEAN GAS HUB AG ............................................................................................................................................. 7
B. The National Balancing Point .......................................................................................................................................................... 8
C. The Title Transfer Facility .................................................................................................................................................................. 9
D. The ―Transit Hub‖: ZEE ....................................................................................................................................................................... 9
E. The Gaspool Balancing Services hub ........................................................................................................................................ 10
F. NetConnect Germany ..................................................................................................................................................................... 10
G. The Points d‘Echange de Gaz ...................................................................................................................................................... 10
H. The Punto di Scambio Virtuale .................................................................................................................................................... 11
I. Conclusions ......................................................................................................................................................................................... 11
V. LNG import for Non -FTA Countries from USA 12
A. US Trade Agreements ..................................................................................................................................................................... 12
B. US FTA ................................................................................................................................................................................................... 12
C. Non FTA Export Terminals of LNG at USA .............................................................................................................................. 13
1. Sabine Pass LNG Terminal in Cameron Parish Contracts: ........................................................................................... 14
2. Freeport LNG Terminal in Quintana Island, Texas Contracts ..................................................................................... 14
3. Lake Charles Terminal in Lake Charles, Louisiana ........................................................................................................... 15
4. Other Projects in line.................................................................................................................................................................. 15
VI. Geothermal Energy 16
A. Introduction ........................................................................................................................................................................................ 16
B. Geothermal Markets ........................................................................................................................................................................ 17
2
List of Tables:
Table 1: List of Applicants in line for Non- FTA Export Approvals: USA .................................................................................... 15
List of Figures
Figure 1: Natural Gas Hubs- Europe ........................................................................................................................................................... 7
Figure 2: Austria Pipeline Network .............................................................................................................................................................. 8
Figure 3: UK Pipeline Network ....................................................................................................................................................................... 8
Figure 4: Belgium Pipeline Infrastructure .................................................................................................................................................. 9
Figure 5: Germany Pipeline Infrastructure ............................................................................................................................................. 10
Figure 6: France Pipeline Infrastructure .................................................................................................................................................. 10
Figure 7: Italy Natural Gas Infrastructure ............................................................................................................................................... 11
Figure 8: USA Non- FTA Export Permission Granted Ports ............................................................................................................. 14
Figure 9: Geothermal Energy ....................................................................................................................................................................... 17
Figure 10: World Pattern of Plates ............................................................................................................................................................ 17
Figure 11: Average Annual Growth Rates of Renewable energy 2007-2012 ........................................................................... 17
3
Executive Summary
The Focused Energy Report for the month of September 2013 reviews the Energy
Prices taking in consideration the comparison with last month. There‘s an increase of
around 4 % in the WTI oil prices, the prices of natural gas Henry Hub have also increased
by 4.7 % and there‘s an increase of roughly 6.5 % in the crude oil prices of Brent.
Fluctuations are not normalised in comparison to last month especially for Brent and we
see rise in price of all three indices there can be multiple reason but the major concern is
military actions foreseen by US on Syria.
The under recoveries of the petroleum sector pertaining to Diesel, LPG and Kerosene have
also included.
The next discussion in the report is about RLNG‘s market in India and its potential
buyers. A lot has been said and written about potential sources of natural for the country
and their acceptability in the industry. Here an in-depth analysis is carried in regard with its
substitution with other liquid fuels and its feasibility as option is being considered here.
Natural gas market varies from region to region and its trade practices too. European
market which is a more matured one is considered here as centre point and is discussed at
length. All major natural gas hubs across the continent are discussed and their function
country wise are covered in this section of the report.
In the later part we some recent happenings across the western world. A close analysis
of the DoE approvals for non –FTA exporting ports is being carried along with trade
practices of USA with other countries. Towards the end segment of this analysis a list of
projects is there in accordance with their priority with DoE whose approvals are awaited for
non-FTA countries specifically.
A shift in approach towards energy security concerns has been seen across the globe.
There are different sources of energy being explored for above said one such is geothermal
energy. Countries like United States, China, Sweden, Germany, and Japan are forerunner in
this segment in world and have significant usage be it for heating or as electricity
generation.
4
I. Energy Prices
WTI crude oil ($/barrel) BRENT crude oil ($/barrel) Natural Gas ($/mmbtu)
Average International FOB Price & Exchange rate:
II. Under-Recoveries on Petroleum Products
(A) Product-wise Under-recovery of Public Sector Oil Marketing Companies(OMCs):
*additionally, a subsidy of Rs 0.82/Litre on PDS kerosene & Rs 22.58/Cylinder on Domestic LPG is provided by the
Government.
(B) The OMCs have reported the following under recovery during 1st quarter 2013-14:
Price on 1st August 2013 Price on 30
th August
2013 Change % Change
Brent crude oil 107.7 115.16 7.46 6.48 %
WTI crude oil 105.03 108.8 3.77 3.47 %
Henry Hub Natural Gas 3.45 3.6 0.17 4.7 %
Particulars Unit 29-Aug-13 Fortnight
(Aug 1-15, 2013)
Crude Oil(Indian Basket)
- In US Dollar
- In Indian Rupees
($/bbl)
(Rs/bbl)
114.07
723.68
106.64
6222.76
Exchange Rate (Rs/$) 67.71 61.13
Product Unit Under-recovery
( eff. 16th Aug 13)
Diesel (Rs/Litre) 10.22
PDS Kerosene* (Rs/litre) 33.54
Domestic LPG* (Rs/Cylinder) 411.99
Product Under-recovery
( eff. 16th Aug 13)
Diesel 10554
PDS Kerosene 6507
Domestic LPG 8518
5
III. Can RLNG Replace High Price Liquid Fuel for Power Generation?
All India region wise generation installed capacity (mw) of power utilities including allocated shared in joint and
central sector utilities.
S.No. REGION THERMAL NUCLEAR HYDRO R.E.S@
TOTAL COAL GAS DSL TOTAL
(Renewable) (MNRE)
1 Northern 33073.50 5031.26 12.99 38117.75 1620 15467.75 5589.25 60794.75
2 Western 50244.51 8988.31 17.48 59250.30 1840 7447.50 8986.93 77524.73
3 Southern 25182.50 4962.78 939.32 31084.60 1320 11353.03 12251.85 56009.48
4 Eastern 23727.88 190.00 17.20 23935.08 0.00 4113.12 454.91 28503.11
5 N.Eastern 60.00 1187.50 142.74 1390.24 0.00 1242.00 252.68 2884.92
6 Islands 0.00 0.00 70.02 70.02 0.00 0.00 6.10 76.12
7 All India 132288.39 20359.85 1199.75 153847.99 4780 39623.40 27541.72 225793.11
@ Renewable Energy Sources (RES) includes Small Hydro Project (SHP), Biomass Power (BP), Urban & industrial
waste power (U & I), Wind Energy and Solar Power.
A. All India Generating installed capacity (MW)
Total diesel based
power generation
capacity is 1199.75
MW & out of this
939.32 MW power
generation capacity
is installed in
Southern region
only. If we can
replace their fuel
with our RLNG, then
they will be
required of 5-10
MMSCMD of RLNG.
If we see Annual Report of CEA on Fuel Supply/Consumption for Gas based power stations in the county then we
find that
Installed
Capacity
( MW)
Gen
(MUs)
Gas
Requirement
at 90% PLF
( MMSCMD)
Gas Allotted
(MMSCMD)
Avg.Gas
Supplied/
Consumed+
(MMSCMD)
Alternate fuel used
(KL)
Gen Loss
due to
short
supply of
gas Naptha HSD
16926.27 92022.77 81.78 67.11 56.37 185288.42 225.60 10855.84
*Normative gas requirement at 90% PLF taking GCV of gas=9000 k.Cal/SCM, station heat rate-2900k.cal/kWh for
open cycle and 2000 K.Cal/kWh for combined cycle
From this we can see that gas supplied to power generation companies was 56.37 MMSCMD in comparison of
gas requirement of 81.78 MMSCMD. They used Naphtha and HSD to compensate of shortfall of natural gas.
6
COMPARISON OF PRICE AND ENERGY OF SPOT LNG WITH LIQUID FUELS
S.No Particulars Unit Spot
RLNG Naptha FO LSHS LDO Propane LPG
1
Gross Calorific of liquid of
fuel
Kcal/Kg
11370 10200 10300 10700 11900 11850
2
Gross Calorific
value spot RLNG
Kcal/SCM 10000
3 Cost of
Liquid fuels Rs/MT - 60970 41450 43290 52789 58500 65251
4 Cost Liquid fuels SU $
$/MT
1016.17 690.83 721.50 879.82 975.00 1087.52
5
One ton of Liquid fuel equivalent
to
MMBTU
45.12 40.48 40.87 42.46 47.22 47.02
6
One MMBTU
equivalent to
Kg
22.16 24.71 24.47 23.55 21.18 21.27
7
One MMBTU
equivalent to
SCM 25.2
8
One ton of Liquid fuel equivalent
to
SCM
1137 1020 1030 1070 1190 1185
9 Cost of
energy in $
$/MMBTU 15 22.52 17.07 17.65 20.72 20.65 23.13
10 Cost of
energy in Rs
Rs/MMBTU 900 1351.31 1024.06 1059.13 1243.25 1238.82 1387.62
11
Benefit of using Spot
RLNG in place of
one ton of Liquid fuel
Rs
20362.86 5021.43 6504.29 14574.71 16000.00 22929.57
conversion rate1$=60 Rs
Presently there has been shortage in availability of APM gas and there is no supply of gas to any power plant
after march-13. This has resulted in loss of generation of power through gas based power plant. In case of gas
based power stations having provision for the use of alternate fuels, such as naphtha, HSD, generation has been
augmented by use of such fuels. The actual generation using liquid fuels is costlier on prevailing high costs of
these fuels resulting in high cost of generation.
From the above comparison this is clear that use of RLNG is cheaper than the use of other liquid fuel even at 17
$/mmbtu. We should target these power generation companies and make them convenience for using RLNG
instead of other costlier fuel which they are using in present.
7
IV. Natural Gas Hubs in Europe
Natural gas is priced and traded at different locations throughout the country. These locations, referred to as
'market hubs', exist across the country and are located at the intersection of major pipeline systems.
Major hubs in Europe are as follow:
UK NBP 1996
Belgium Zeebrugge 2000,
Denmark TTF 2 0 0 3
Italy PSV 2003
France PEGs 2004
Austria CEGH 2005
Germany EGT 2006, HubCo 2002
German Gaspool and NCG in 2009.
Figure 1: Natural Gas Hubs- Europe
A. CENTRAL EUROPEAN GAS HUB AG
Central European Gas Hub (CEGH) located in Vienna, Austria, is the one of the leading hub for trading gas from
the Eastern to Western Europe. It was established in the year 2005. As an operator of Virtual Trading Point, CEGH
opens international gas traders a gateway for trading in the newly developed exit/entry zone of Austrian market.
Austria‘s role as a gas transit country linking East with West will increase significantly with the go ahead of South
Stream and Nabucco West projects.
8
It actually comprises 6
tradable locations across
Austria of which
Baumgarten is by far the
most important and the
one that registers the
most trades.
Baumgarten is situated
in the east of the
country on its border
with Slovakia. The
import terminal itself is
vast and is owned and
operated by Gas
Connect Austria.
Approximately one third
of all Russian gas supplies to Western Europe come through Baumgarten for onward transportation to Germany,
Italy, Slovenia and Hungary, as well as for supplying the national market. Austria is probably the most complex
country in Europe in terms of its gas network. It is actually 3 separate networks, known as Control Areas; the main
one in the east containing the transit pipelines, a high pressure transmission grid and a high and low pressure
distribution grid.
There are two further, much smaller networks in the west central and west of the country: Tyrol and Voralberg.
These two Control Areas are not physically connected to the Eastern Area, nor to each other but have direct
pipeline connections to Germany and so can be considered as separate distribution grids off the German NCG
system. A further complication is that the Austrian gas industry works to three different gas days: starting at 8am
for transit gas from Russia; at 6am for Austrian transmission; and midnight for Austrian distribution.The Exchange
offers different types of contracts. It started a Spot market in December 2009 and added a Futures market a
year later in December 2010.
B. The National Balancing Point
The National Balancing Point, referred as the NBP, is a virtual trading location
for the sale and purchase and exchange of UK natural gas. It is the pricing and
delivery point for the ICE (Inter-continental Exchange) natural gas futures
contract. It is the most liquid gas trading point in Europe[citation needed] and
is a major influence on the price that domestic consumers pay for their gas at
home[citation needed]. Gas at the NBP trades in pence per therm. The NBP
market has been a ‗mature‘ market for over 10 years now and therefore its
potential for further growth might be expected to be more limited.
Figure 2: Austria Pipeline Network
Figure 3: UK Pipeline Network
9
C. The Title Transfer Facility
The Title Transfer Facility (TTF) is a virtual market place enabling national and international parties in the gas
sector to transfer ownership of gas that is already in the transport network to another party, effectively the whole
of the Dutch gas grid. The TTF, operated by Gas Transport Services B.V. (GTS), experienced substantial growth in
2008.The growth figures demonstrate that the Netherlands is becoming a European market place and is
increasingly attractive to gas traders and suppliers. This is crucial position as a gas interchange.
It offers market parties the opportunity to transfer gas that is already present in the system (‗entry-paid gas‘) to
another party. Using the TTF, it is straightforward for gas that is brought into the national grid via an entry point
to change ownership before it leaves the national grid at an exit point.
The TTF serves to promote gas trading. The TTF serves as a virtual entry point in the portfolio of a shipper or
trader who buys gas on the TTF or as a virtual exit point in the portfolio of a shipper or trader who sells gas on
the TTF.
D. The “Transit Hub”: ZEE
The ―transit‖ hubs are hubs that are
actual transit locations, or physical
points, at which market participants
can choose to trade gas; however,
their primary role is to facilitate the
transit of large quantities of gas for
onward transportation. Indeed, the
two transit gas hubs of North West
Europe, Zeebrugge in Belgium and
Baumgarten in Austria have the
capacity between them to handle
some 130bcma, or around 45% of the
demand in the downstream countries
they provide gas to32. This makes
these two locations very important in
the physical context of gas deliveries
to Western Europe; however, the
nature of their formation means that trading
has not developed as much as in
neighboring hubs.
ZEE is a physical hub centered on the actual location of the gas installations and meter points outside of the
town of Zeebrugge in north western Belgium. Trading at ZEE was lackluster for many years; saw a marked
increase in 2009, as did all the gas hubs, continuing to rise slowly since then. In absolute terms though, the
traded volumes at ZEE lag a long way behind the British NBP and its immediate neighbor, TTF, and are currently
similar to the traded volumes of the German NCG hub. Nevertheless, the number of participants has continued
to grow, reaching 78 member companies in 2011.
The purely physical set up has its advantages for the transportation of large quantities of gas and ZEE is indeed
ideally placed geographically to take advantage of gas flows to and from France, Britain, Norway, the
Netherlands, Germany and the adjacent LNG terminal and Belgian gas grid37. However, the fact that it is not a
virtual hub, covering all of the Belgian grid and that trading and the balancing regime at the Zeebrugge hub is
subject to shortfalls and pro-ration of volumes, has left this hub trailing behind as other Continental European
hubs advance in respect to their trading activities.
Figure 4: Belgium Pipeline Infrastructure
10
E. The Gaspool Balancing Services hub
GPL is operated as a
physical hub rather than a
virtual one and that the hub
operator uses "balancing
services" in its title is
indicative of the physical
nature of this hub. Although
it does cover a large
geographical area, it is
mainly used by traders to
adjust their storage
portfolios and in relation to
the other German hub, NCG.
Nevertheless, traded volumes
which had remained more
modest than the main NWE
hubs, have seen a burst of
activity in the first quarter of
2012, rising 119%
over the
same period last year and in
so doing, overtaking in
absolute terms the volumes traded at the French PEGs.
F. NetConnect Germany
The ‗new‘ NCG was formed on 1st October 2011 by the merger of the Thyssengas H-Cal zone and the NCG H-Cal
zone; the new company has 6 TSO shareholders57, each holding an equal 1/6th share. NCG had been considered
until only recently as the ‗most promising‘ of the NWE gas hubs and indeed, total traded volumes have increased
significantly.
G. The Points d’Echange de Gaz
In France, the PEGs are quietly trading without
creating much of a ‗stir‗. Volumes have slowly
improved since this hub was started but are still
relatively low compared to their neighbouring
markets. Despite some unification on 1st January
2009 from the original model to the present three
zones, there are also high and low calorific contracts
tradable in PEG Nord. PEG Nord H (high cal) is the
most traded market, followed by PEG Sud and finally
PEG Nord B (low cal) and TIGF in the south west.
There are two TSOs, GRTgaz covering PEGs Nord and
Sud, as well as Total for PEG TIGF.
Figure 5: Germany Pipeline Infrastructure
Figure 6: France Pipeline Infrastructure
11
H. The Punto di Scambio Virtuale
When Italy announced the formation of
the PSV, there was great hope amongst
the gas trading fraternity that this could
be the beginning of truly pan-European
trading. The Italian Network Code for
gas is almost identical to the British
one, although entry capacity is not as
flexible. However storage is on an open
access basis and in fact all gas entering
the system goes through the PSV.
However, only a very small percentage
of all that gas is actually traded at the
hub and the National incumbent, ENI,
does not trade at the PSV at all.
I. Conclusions
European gas market developments had a transition from long term oil-indexed contracts to hub based
contracts. The past ten years or so have seen much development in the European traded gas markets
culminating in some significant changes since about 2009. However, not all the hubs have developed in the same
way or at the same pace.
The British and the Dutch are, and historically have been, trading nations and it is therefore no real surprise that
these are the two countries in Europe that have mature trading hubs. In future we too see development of more
hubs but contrary to previous situations its more favoring for non-physical ones.
In 2012 we observe that Britain‘s NBP is at the forefront, with a liberalised, fully mature traded market, offering
reliable marker prices. In Continental Europe TTF has emerged as the pre-eminent hub. Britain‘s gas supplies are
by and large all market priced whereas Continental Europe has lagged behind with most of its supplies still on
LTCs which have oil indexation formulae as their pricing mechanism.
This analysis is being carried out with a view of understanding European Hub and viz a viz Asian context.
Although European market had its own peculiarities but its maturation time period was less. There are some
areas for us to replicate in our continent too in terms of the course of development of natural gas market. The
fundamental difference lies in terms of physical trading of gas via pipelines, which is not so rampant in our
continent. Europeans could mature earlier owning to nearby natural gas availabilities. Asian too needs to think
about itself as an entity and integrate itself in terms of energy transportation infrastructure.
Figure 7: Italy Natural Gas Infrastructure
12
V. LNG import for Non -FTA Countries from USA
Fundamentals
Trade agreement, is any contractual arrangement between states concerning their trade relationships. Trade
agreements may be bilateral or multilateral—that is, between two states or more than two states. For most
countries international trade is regulated by unilateral barriers of several types, including tariffs, nontariff barriers,
and outright prohibitions. Trade agreements are one way to reduce these barriers, thereby opening all parties to
the benefits of increased trade.
In most modern economies the possible coalitions of interested groups are numerous, and the variety of
possible unilateral barriers is great. Further, some trade barriers are created for other, noneconomic reasons, such
as national security or the desire to preserve or insulate local culture from foreign influences. Thus, it is not
surprising that successful trade agreements are very complicated. Some common features of trade agreements
are:
(1) reciprocity,
(2) a most-favoured-nation (MFN) clause, and
(3) national treatment of non-tariff barriers.
Reciprocity is a necessary feature of any agreement. If each required party does not gain by the agreement as a
whole, there is no incentive to agree to it. If agreement takes place, it may be assumed that each party to the
agreement expects to gain at least as much as it loses. The most-favoured-nation clause prevents one of the
parties to the current agreement from further lowering barriers to another country. A ―national treatment of
nontariff restrictions‖ clause is necessary because most of the properties of tariffs can be easily duplicated with
an appropriately designed set of nontariff restrictions. These can include discriminatory regulations, selective
excise or sales taxes, special ―health‖ requirements, quotas, ―voluntary‖ restraints on importing, special licensing
requirements, etc., not to mention outright prohibitions. Instead of trying to list and disallow all of the possible
types of nontariff restrictions, signatories to an agreement demand treatment similar to that given to
domestically produced goods of the same type (for example, steel).
A. US Trade Agreements
Now from generic to specific below is an example of United States of America with their list of prevailing trade
agreements:
WTO & Multilateral Affairs
Free Trade Agreements
Trade & Investment Framework Agreements
Bilateral Investment Treaties
WTO & Multilateral Affairs: Overall responsibility for trade negotiations and policy coordination regarding
matters before the World Trade Organization (WTO), including the Doha Development Agenda negotiations. The
U.S. bilateral investment treaty (BIT) program helps to protect private investment, to develop market-oriented
policies in partner countries, and to promote U.S. exports. In addition to pursuing U.S. trade policy objectives
through the World Trade Organization, USTR, together with other agencies, works with various regional fora.
Among these are the Asia Pacific Economic Cooperation (APEC) forum and the Association of South East Asian
Nations (ASEAN), which has a Trade and Investment Framework Arrangement with the United States.
B. US FTA
A FTA is an agreement between two or more countries where the countries agree on certain obligations that
affect trade in goods and services, and protections for investors and intellectual property rights, among other
topics. For the United States, the main goal of trade agreements is to reduce barriers to U.S. exports, protect U.S.
13
interests competing abroad, and enhance the rule of law in the FTA partner country or countries. The reduction
of trade barriers and the creation of a more stable and transparent trading and investment environment make it
easier and cheaper for U.S. companies to export their products and services to trading partner markets.
The United States has 14 FTAs in force with 20 countries. The United States is also in the process of negotiating a
regional FTA, the Trans-Pacific Partnership, with Australia, Brunei Darussalam, Canada, Chile, Malaysia, Mexico,
New Zealand, Peru, Singapore and Vietnam. Following is the list of currently having FTA with USA:
1. Israel 2. Australia
3. Jordan 4. Bahrain
5. South Korea 6. Canada
7. Mexico 8. Chile
9. Morocco 10. Colombia
11. Nicaragua 12. Costa Rica
13. Oman 14. Dominican Republic
15. Panama 16. El Salvador
17. Peru 18. Guatemala
19. Singapore 20. Honduras
C. Non FTA Export Terminals of LNG at USA
The development of U.S. natural gas resources is having a transformative impact on the U.S. energy landscape,
helping to improve energy security while spurring economic development and job creation around the country.
This increase in domestic natural gas production is expected to continue, with the Energy Information
Administration forecasting a record production rate of 69.96 Bcf/d in 2013.
Federal law generally requires approval of natural gas exports to countries that have an FTA with the United
States. For countries that do not have an FTA with the United States, the Natural Gas Act directs the Department
of Energy to grant export authorizations unless the Department finds that the proposed exports ―will not be
consistent with the public interest.‖
In particular USA Section 3 of the Natural Gas Act (NGA) (15 U.S.C. § 717b) prohibits the import or export of
natural gas, including liquefied natural gas (LNG) from or to a foreign country without prior approval from the
Department of Energy (DOE). Parties who want to enter into natural gas transactions with foreign sellers and
buyers must file for an import and/or export authorization under the rules and procedures found in (10 CFR Part
590) of DOE's regulations.
The Natural Gas Act of the United States, as amended has deemed exports to countries having a Free Trade
Agreement (FTA) to be in public interest and hence applications are authorized without any major delay.
However, non-FTA applications require the Department of Energy (DoE) to post a notice of application in the
federal register for comments, protests and motions to intervene, and to evaluate the applications to make a
"public interest consistency determination".
The authorized terminals are:
1. Sabine Pass LNG Terminal in Cameron Parish May 2011
(at a rate of up to 2.2 Bcf/d)
2. Freeport LNG Terminal in Quintana Island, Texas May 2013
(at a rate of up to 1.4 Bcf/d- 20-year approval to export up to 511 billion cubic feet (BCF) per year)
3. Lake Charles Terminal in Lake Charles, Louisiana August 2013
(2.0 billion cubic feet of natural gas a day (Bcf/d) for a period of 20 years)
14
1. Sabine Pass LNG Terminal in Cameron Parish Contracts:
Cheniere Partners owns 100 percent of the Sabine Pass LNG receiving terminal located on the Sabine Pass
Channel in western Cameron Parish, Louisiana. The Sabine Pass terminal has regasification and send-out capacity
of 4.0 billion cubic feet per day (Bcf/d) and storage capacity of 16.9 billion cubic feet equivalent (Bcfe).
Cheniere Partners is developing a project to add liquefaction and export capabilities to the existing infrastructure
at the Sabine Pass LNG terminal. As currently contemplated, the liquefaction project is being designed and
permitted for up to four modular LNG trains, each with a nominal capacity of approximately 4.5 mtpa.
The customers include
BG Gulf Coast LNG, LLC ("BG") for 5.5 mmtpa,
Gas Natural A provision amientos SDG S.A. ("Gas Natural Fenosa") for 3.5 mmtpa,
Korea Gas Corporation ("KOGAS") for 3.5 mmtpa,
GAIL (India) Ltd. ("GAIL") for 3.5 mmtpa,
Total Gas & Power North America, Inc. ("Total") for 2.0 mmtpa and
Centrica plc ("Centrica") for 1.75 mmtpa.
GAIL has recently signed long term agreements for 3.5 MMTPA with US based Sabin Pass Liquefaction Company
at a price benchmarked to Henry Hub gas price in USA and supply is expected to start from 2017/18.
2. Freeport LNG Terminal in Quintana Island, Texas Contracts
Michael Smith and ConocoPhillips (COP) each own 50% of the general partner of Freeport LNG Development,
L.P. (FLNG), Freeport LNG-GP, Inc. (FLNG-GP). LNG currently has four limited partners that, collectively, own all of
the economic interests in FLNG: (1) Freeport LNG Investments, LLLP, an entity owned by Michael S. Smith; (2)
ZHA FLNG Purchaser, LLC, a Delaware limited liability company; (3) Texas LNG Holdings, LLC, a wholly owned
subsidiary of The Dow Chemical Company; and (4) Turbo LNG, LLC, a wholly owned subsidiary of Osaka Gas Co.,
Figure 8: USA Non- FTA Export Permission Granted Ports
15
Ltd. Freeport LNG is proposing to add liquefaction infrastructure at the existing terminal to provide export
capacity of approximately 13.2 million metric tonnes per annum (mtpa) of LNG, which equates to processing
approximately 2.0 Bcf/d of pipeline-quality natural gas (feed gas).
The customers include
BP signed an agreement for 4.4 mtpa of liquefaction tolling capacity
Japan‘s Osaka Gas Co., Ltd. and Chubu Electric Power Co. Liquefaction Tolling Agreement (LTA) for a
total of 4.4 million tons per annum (mtpa)
3. Lake Charles Terminal in Lake Charles, Louisiana
Lake Charles Exports LLC, a venture between U.K.-based BG Group BG.LN - PLC and Texas-based Energy Transfer
Equity LP ETE that plans to ship up to two billion cubic feet a day from Lake Charles, La. The approval lasts for 20
years and permits sales to countries that lack free-trade agreements with the U.S., including some in Europe and
Japan.
The Energy Department announced that it has conditionally authorized Lake Charles Exports to export
domestically produced liquefied natural gas (LNG) to countries that do not have a Free Trade Agreement (FTA)
with the United States from the Lake Charles Terminal in Lake Charles, Louisiana. Lake Charles previously received
approval to export LNG from this facility to FTA countries on July 22, 2011. Subject to environmental review and
final regulatory approval, the facility is conditionally authorized to export at a rate of up to 2.0 billion cubic feet
of natural gas a day (Bcf/d) for a period of 20 years.
The Department granted the first authorization to export LNG to non-FTA countries in May 2011 from the Sabine
Pass LNG Terminal in Cameron Parish, Louisiana at a rate of up to 2.2 Bcf/d, and the second authorization in May
2013 from the Freeport LNG Terminal in Quintana Island, Texas at a rate of up to 1.4 Bcf/d.
4. Other Projects in line
Following is the list of applications received by DOE/FE to Export Domestically Produced LNG to Non – FTA
countries from the Lower-48 States (as of August 7, 2013):
Table 1: List of Applicants in line for Non- FTA Export Approvals: USA
Company Quantity FTA Applications
(Docket Number) Non-FTA Applications
(Docket Number)
Carib Energy (USA) LLC 0.03 Bcf/d: FTA
0.01 Bcf/d: non-FTA Approved (11-71-LNG)
Under DOE Review (11-141-LNG)
Dominion Cove Point LNG, LP
1.0 Bcf/d Approved (11-115-LNG) Under DOE Review (11-128-LNG)
Jordan Cove Energy Project, L.P.
1.2 Bcf/d: FTA 0.8 Bcf/d: non-FTA
Approved (11-127-LNG) Under DOE Review (12-32-LNG)
Cameron LNG, LLC 1.7 Bcf/d Approved (11-145-LNG) Under DOE Review (11-162-LNG)
Freeport LNG Expansion, L.P. and FLNG Liquefaction, LLC
1.4 Bcf/d Approved (12-06-LNG) Under DOE Review (11-161-LNG)
Gulf Coast LNG Export, LLC
2.8 Bcf/d Approved (12-05-LNG) Under DOE Review (12-05-LNG)
Gulf LNG Liquefaction Company, LLC
1.5 Bcf/d Approved (12-47-LNG) Under DOE Review (12-101-LNG)
LNG Development Company, LLC (d/b/a
1.25 Bcf/d Approved (12-48-LNG) Under DOE Review (12-77-LNG)
16
Oregon LNG)
Southern LNG Company, L.L.C.
0.5 Bcf/d Approved (12-54-LNG) Under DOE Review (12-100-LNG)
Excelerate Liquefaction Solutions I, LLC
1.38 Bcf/d Approved (12-61-LNG) Under DOE Review (12-146-LNG)
Golden Pass Products LLC 2.6 Bcf/d Approved (12-88 -LNG) Under DOE Review (12-156-LNG)
Cheniere Marketing, LLC 2.1 Bcf/d Approved (12-99-LNG) Under DOE Review (12-97-LNG)
CE FLNG, LLC 1.07 Bcf/d Approved (12-123-LNG) Under DOE Review (12-123-LNG)
Waller LNG Services, LLC 0.16 Bcf/d Approved (12-152-LNG) n/a
Pangea LNG (North America) Holdings, LLC
1.09 Bcf/d Approved (12-174-LNG) Under DOE Review (12-184-LNG)
Magnolia LNG, LLC 0.54 Bcf/d Approved (12-183-LNG) n/a
Gasfin Development USA, LLC
0.2 Bcf/d Approved (13-06-LNG) n/a
Sabine Pass Liquefaction, LLC
0.28 Bcf/d Approved (13-30-LNG) Under DOE Review (13-30-LNG)
Sabine Pass Liquefaction, LLC
0.24 Bcf/d Approved (13-42-LNG) Under DOE Review (13-42-LNG)
Venture Global LNG, LLC 0.67 Bcf/d Pending Approval (13-69-LNG)
Under DOE Review (13-69-LNG)
Advanced Energy Solutions, L.L.C.
0.02 Bcf/d Pending Approval (13-82-LNG)
n/a
Total of all Applications Received for Non -FTA
20.31 Bcf/d
The market for LNG sourcing seems to be very promising on account of projects pending for approval with DoE.
Approximately 20.31 Bcf/d quantities are lined up for Non FTA as a futuristic source for LNG.
VI. Geothermal Energy
A. Introduction
Geothermal energy is the heat from the Earth. It is the thermal energy contained in the rock and fluid (that fills
the fractures and pores within the rock) in the earth's crust. Heat is a form of energy and geothermal energy is,
literally, the heat contained within the Earth that generates geological phenomena on a planetary scale.
'Geothermal energy' is often used nowadays, however, to indicate that part of the Earth's heat that can, or could,
be recovered and exploited by man, and it is in this sense that we will use the term from now on.
Calculations show that the earth, originating from a completely molten state, would have cooled and become
completely solid many thousands of years ago without an energy input in addition to that of the sun. It is
believed that the ultimate source of geothermal energy is radioactive decay occurring deep within the earth
The earth‘s centre is a distance of approximately 4000 miles and is so hot that it is molten. Temperatures are
understood to be at least 5000 degrees centigrade. Heat from the centre of the earth conducts outwards and
heats up the outer layers of rock called the mantle. When this type of rock melts and becomes molten it is called
magma. Magma can reach just below the earth‘s surface. Rain water sometimes seeps down through geological
fault lines and cracks becoming super-heated by the hot rocks below. Some of this super-heated water rises back
to the surface of the earth where it emerges as hot springs or even geysers. Sometimes the hot water becomes
trapped below the surface as a geothermal reservoir.
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Figure 9: Geothermal Energy
One way of producing electricity from geothermal energy is by drilling wells into the geothermal reservoirs. The
hot water that rises emerges at the surface as steam. The steam is used to drive turbines producing electricity. If
the water is not hot enough to produce steam, it can still be used to heat homes and businesses, saving
gas/electricity.
World pattern of plates,
oceanic ridges, oceanic
trenches, subduction zones,
and geothermal fields. Arrows
show the direction of
movement of the plates
towards the subduction
zones. (1) Geothermal fields
producing electricity; (2) mid-
oceanic ridges crossed by
transform faults (long
transversal fractures); (3)
subduction zones, where the
subducting plate bends
downwards and melts in the
asthenosphere.
B. Geothermal Markets
Geothermal resources
provided an estimated
805 PJ (223 TWh) of
renewable energy in 2012,
delivering two-thirds as
direct heat and the
remainder as electricity.
The use of ground-source
heat pumps is growing
rapidly and reached an
estimated 50 GW of
capacity in 2012. At least
Figure 10: World Pattern of Plates
Figure 11: Average Annual Growth Rates of Renewable energy 2007-2012
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78 countries tap geothermal resources for direct heat, while two-thirds of global capacity is located in the United
States, China, Sweden, Germany, and Japan. Geothermal electric generating capacity grew by an estimated 300
MW during 2012, bringing the global total to 11.7 GW and generating at least 72 TWh.
Geothermal energy is used for direct heating purposes, including district heat systems, bathing and swimming
applications, industrial purposes, agricultural drying, and other uses.65 Ground-source heat pumps can both heat
and cool space and represent the largest and historically fastest-growing segment of geothermal direct use.
Geothermal direct use continued to increase globally during 2012. Direct use refers to direct thermal extraction
for heating and cooling. A sub-category of direct use is the application of ground-source heat pumps (GHP),
which use electricity to extract several units of thermal energy from the ground for every unit of electrical energy
spent. Although there are limited data available on recent growth in direct use of geothermal energy, output is
known to have grown by an average of 10% annually from 2005 through 2010; much of that growth was
attributed to ground-source heat pumps, which experienced an average annual growth of 20%. Assuming that
these growth rates have persisted in the last two years, global geothermal heat capacity reached an estimated 66
GW in 2012, delivering as much as 548 PJ of heat. GHP represents the largest and historically fastest-growing
segment of geothermal direct use. In 2012, it reached an estimated 50 GW of capacity; this amounts to about
three-quarters of estimated total geothermal heat capacity, and more than half of heat output (>300 PJ). Of the
remaining direct heat use (nearly half), the largest share goes to bathing and swimming applications, with smaller
amounts for heating (primarily district heating), industrial purposes, aquaculture pond heating, agricultural
drying, snow melting, and other uses.
China remains the presumptive leader in direct geothermal energy use (21 TWh in 2010), followed by the United
States (18.8 TWh in 2012), Sweden (13.8 TWh in 2010), Turkey (10.2 TWh in 2010), Iceland (7.2 TWh in 2012), and
Japan (7.1 TWh in 2010).5Iceland, Sweden, Norway, New Zealand, and Denmark lead for average annual
geothermal energy use per person. About 90% of Iceland‘s total heating demand is derived from geothermal
resources.
Geothermal electricity generation, which occurs through kinetic conversion of high- or medium-temperature
steam, is estimated to have reached at least 72 TWh in 2012. Global geothermal electric generating capacity grew
by an estimated 300 MW during 2012—with new capacity coming on line in the United States (147 MW),
Indonesia (110 MW), Nicaragua (36 MW), and Kenya (7.5 MW)—bringing total global capacity to an estimated
11.7 GW.
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The countries with the largest amounts of geothermal electric generating capacity are as follows:
the United States (3.4 GW),
the Philippines (1.9 GW),
Indonesia (1.3 GW), Mexico (1.0 GW),
Italy (0.9 GW),
New Zealand (0.8 GW),
Iceland (0.7 GW), and
Japan (0.5 GW).15
Note:
The data and information in the report is sourced from websites and documents available in public
domain and doesn’t purport to be official view of government or any organization. Sincere efforts have
been made to present correct data; however, errors and omissions, if any, are regretted and the same may
please be brought to the notice of Energy Desk for necessary corrective action.