Australia Coal Seam
Gas Surat Gladstone Pipeline.
2/26/10 arrowenergy.com
The Surat Gladstone Pipeline will connect Arrow Energy’s vast coal seam
gas resources in the Surat Basin with a proposed liquefied natural gas
(LNG) facility at Fisherman’s Landing in Gladstone: a wholly-owned
subsidiary of Arrow Energy Ltd (Arrow), created specifically to deliver
this Project.
The Project involves the planning, construction and commissioning of a
660 mm diameter buried high-pressure steel gas transmission pipeline
which will deliver coal seam gas (CSG) from the Surat Basin near Dalby
in south-eastern Queensland, to a proposed liquefied natural gas (LNG)
plant at Fisherman’s Landing, Gladstone. The proposed LNG plant will be
built by Liquefied Natural Gas (LNG) Ltd, an entity separate to SGP and
Arrow Energy.
The chosen route heads generally north from the Kogan area through the
local government areas of Dalby, Banana, North Burnett and Gladstone.
The route continues to the west of the Barakula State Forest to the
north of Chinchilla and avoids environmentally sensitive areas, such as
essential habitats, endangered and threatened ecosystems and
communities, and remnant (native) vegetation wherever possible.
From a point east of Callide, the route heads north-east and follows
the Queensland natural gas pipeline for the remaining 64 km into
Gladstone. The Premier has announced that the State will be developing
the Callide Infrastructure Corridor (CIC), a 200 m wide common
infrastructure corridor to contain a number of gas pipelines from the
Callide area into Gladstone. The final 23 km of the route is within the
Gladstone State Development Area (GSDA) Infrastructure Corridor.
Construction will require a right-of-way (ROW) width of 30m for clear
and grade, trenching and spoil placement, pipeline stringing, welding
and laying. It is anticipated that construction of the pipeline will
start in 2011, with first gas supplied to the Fisherman’s Landing LNG
Plant in late 2012. Full capacity is expected from the beginning of
2013.
The Project will make a significant contribution to the local,
regional, state and national economies, both in the construction phase
and through its operational life. It will also provide employment,
business and industry opportunities benefiting the wider economy.
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Southern California
LNG Truck Fueling Expansion
Infrastructure to Support Regional Goods Movement
SEAL BEACH, Calif., Feb 23, 2010 (BUSINESS WIRE)
-- Ten-Station Network in Urban Centers and Along Major Truck Routes Is
First Phase of Clean Energy's Planned Southwest LNG Trucking Corridor
-- plans to expand its existing network of liquefied natural gas (LNG)
truck fueling stations in Southern California this year beyond its
current two LNG stations located at the Los Angeles/Long Beach ports
complex. New or upgraded Clean Energy LNG fueling facilities are
planned for strategic points along truck transport routes in the
California cities of Los Angeles, Commerce, Industry, Fontana,
Riverside, Tulare, Barstow, and Otay Mesa/San Diego. This hub of
stations will form the backbone upon which Clean Energy intends to
expand its LNG fueling efforts into the Southwestern region of the
United States.
The Southern California network will enable goods to be transported via
clean-burning natural gas trucks within local urban areas and along
regional goods-movement corridors. Trucks will be able to transport
goods from the Los Angeles and Long Beach ports, deliver them to
distribution centers, and take the goods directly to stores in local
communities.
"This augmented LNG truck fueling capability plays a key role in the
creation of a full-scale Southwest LNG truck-fueling corridor. We plan
to connect this group of LNG fueling stations in Southern California to
Northern California, Arizona, Nevada and Utah," said Andrew Littlefair,
Clean Energy President and CEO. "The development of the new station
infrastructure is a direct response to the increased demand for natural
gas fuel we have observed, as major trucking companies secure and
deploy LNG-powered trucks at the Los Angeles and Long Beach ports and
throughout the region," Littlefair added.
Adjacent to the ports complex, Clean Energy operates the world's
largest public LNG truck fueling station. Located on a 2.7-acre site,
the station is the second that the Company has opened in the area to
serve natural gas-powered port drayage trucks. The first, operational
since December 2007, is located nearby in Carson, CA.
These two LNG stations were specifically designed by Clean Energy to
support the goals of the San Pedro Bay Ports' Clean Air Action Plan and
Clean Truck programs. These programs call for the retirement or
conversion of old diesel trucks entering the ports in favor of new
cleaner-burning and alternative-fueled trucks.
Natural gas vehicle fuel provides lower emissions than gasoline and
diesel, including up to a 23% reduction in greenhouse gases in
medium-and heavy-duty trucking applications. The domestic natural gas
used by the trucks also reduces America's dependence on imported oil.
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Nat Gas and Coal
Production 2002 – 2009 Rky Mtn Region
By DUSTIN BLEIZEFFER - Star-Tribune energy reporter |February 21, 2010
Natural gas production in the Rocky Mountain region doubled to 8
billion cubic feet per day from 2002 to 2009, with Wyoming leading the
way. During the same period, Wyoming annual coal production spiked by
more than 15 percent to nearly 430 million tons.
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Alaska In-state gas demand may overtake contract
February
18, 2010 By Tim Bradner Morris News Service-alaska, Alaska
Journal of Commerce
Natural gas demand for space heating and power generation over the next
decade or so appear to fit comfortably within a 500 million cubic
feet-per-day limit the state of Alaska has accepted for gas for Alaska
communities from a gas pipeline built by TransCanada Corp., according
to a study of in-state gas demand commissioned by TransCaanda.
The wild card, however, is potential future industrial demand for
natural gas from plants that would most likely built in Southcentral
Alaska. There is strong interest in industry using gas because jobs are
created that pay high wages and the plants provide significant tax base
for local governments.
Any significant new development of natural gas-based industry, such as
if the liquefied natural gas plant near Kenai, is expanded or a new
development occurs, such as a gas-to-liquids plant, it could push the
in-state demand up to 1 billion cubic feet per day, which exceeds the
limit in the contract with TransCanada. The state agreed to the limit
as part of its Alaska Gasline Inducement
Act contract with TransCanada, in which the pipeline company accepted a
number of state conditions for a pipeline in return for a $500 million
state subsidy and the limit to gas taken off for use within
Alaska. If there are good prospects for industrial development
that would
exceed the limit the state will be presented with a thorny problems in
having to negotiate a change in the contract with TransCanada.
The pipeline company wants to limit the gas "off-take" in Alaska to
keep as much gas volume as possible flowing the entire length of the
pipeline. That is important to the economic viability of the pipeline
and TransCanada's ability to finance its construction.
It's also likely that new gas reserves will be found on the North Slope
that will allow the pipeline to be expanded and making more gas
available for in-state use, state officials point out.
The in-state gas study assumes a continuation of gas production from
gas fields in the Cook Inlet region at an average of about 150 million
cubic feet per day. Northern Economics Inc., an
Anchorage-based consulting
company, led the team doing the in-state gas demand analysis for
TransCanada. Science Applications International Corp. and the
University of Alaska Anchorage's Institute of Social and Economic
Research were also part of the team.
TransCanada is required to do the in-state demand study as part of its
application to the Federal Energy Regulatory Commission to conduct an
open season for its pipeline project this summer. The Denali pipeline
group, which is developing a competing pipeline
project to TransCanada's proposal, has said that it will use the
Northern Economics study as a part of its open season application to
FERC later this spring. The study is a public document. Denali is not
bound by the limits on local gas deliveries because the
company has not signed an AGIA contract and is receiving no state
funds.
The study led by Northern Economics estimated future gas demand with a
series of probabilities. For example, residential and commercial space
heating is estimated to require 100 million to 150 million cubic feet
of gas daily with a high degree of certainty over the next 10 to 15
years but that could also reach 175 million to 200 million cubic feet
per day under certain circumstances.
Similarly, gas demand for power generation is estimated at 90 million
cubic feet per day with some certainty in the five- to 10-year
timeframe, but the amount could drop in the years beyond if a large
hydroelectric project is built, such as a project on the upper Susitna
River north of Anchorage or one at Lake Chakachmna, on the west side of
Cook Inlet.
Industrial demand could stay essentially at current levels if no new
gas-based industry is developed, but if two or three projects are built
that demand could reach 1 billion cubic feet per year in 15 years, the
study shows. The industrial demand estimates do not include gas needed
for a large
liquefied natural gas (LNG) plant at Valdez which would "anchor" a
pipeline to Valdez, an option which TransCanada will offer in its open
season this summer along with a pipeline to Alberta.
If the Valdez pipeline is built the development of the LNG plant at
that city is a given because that pipeline would be built only to serve
such a plant.
Mainly, the industrial demand possibilities considered in the study are
mainly in the Matanuska-Susitna Borough and Kenai Peninsula Boroughs
that would be served by a spur pipeline from the big pipe, whether to
Alberta of Valdez.
Possible projects include the continuation, or an expansion, of the LNG
plant now operating near Kenai, a possible restart of the Agrium
fertilizer plant also near Kenai (the plant is now closed) and a
gas-to-liquids plant that would use the Fischer-Tropsch chemical
process to convert natural gas to high-value liquid fuels for sale on
the U.S. west coast or in export markets.
Tim Bradner can be reached at tim.bradner@alaskajournal.com.
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Navistar a 400-mile range on natural gas engine
By Jill Dunn 2/20/10 www.etrucker.com
Navistar has entered an agreement with Clean Air Power to develop a
Navistar 2010 MaxxForce 13 big bore engine to run on natural gas and
diesel for the North American market. Clean Air Power developed
Dual-Fuel combustion technology, allowing heavy-duty diesel engines to
operate on a combination of diesel and natural gas. The new product
initially will be aimed at the regional haul truck market with a goal
of achieving a 400-mile range. Clean Air Power will invest $1.5
million to develop the concept over the next 10 months. During this
time, in preparation for production and the next development stage,
Navistar and Clean Air Power will seek federal grants for full
production.
More information is available at www.navistar.com and
www.cleanairpower.com.
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Navistar's Natural
Gas for MaxxForce 13 Truck Engines
Hybrid Energy Holdings Reports Demand Increasing
February 18, 2010
Hybrid Energy Holdings, Inc. expects additional demand for Natural Gas
based on the recent announcement by Navistar, Inc. that it is
developing a Natural Gas model for is popular MaxxForce 13 Engines.
Navistar's announcement was reported to be necessary to meet increased
customer demand for flexible few options. Navistar, Inc. is a holding
company whose subsidiaries and affiliates produce International brand
commercial and military trucks, MaxxForce brand diesel engines, IC Bus
brand school and commercial buses, Monaco RV brands of recreational
vehicles, and Workhorse brand chassis for motor homes and step vans. It
also is a private-label designer and manufacturer of diesel engines for
the pickup truck, van and SUV markets.
Natural gas burns more cleanly than other fossil fuels. It has fewer
emissions of sulfur, carbon, and nitrogen when it is burned; it leaves
almost no ash particles. Being a cleaner fuel and available
domestically, without the need for importing foreign oil, are
considered the main reasons that the use of Natural Gas has grown so
much.
This customer demand in the trucking industry comes on the heels of
recent Ford and Honda's natural gas passenger and taxi cab
announcements; and validates the Company's aggressive Natural Gas
portfolio. To meet these growing demands, Hybrid Energy recently
announced its latest acquisition of 9 properties that consistently
deliver profitably with strong recurring current and historical
cash-flows. This important expansion of the company's portfolio results
in 35,000,000 BCF of known reserves and delivers an estimated
$30,000,000 of shareholder value in active reserves and an additional
estimated $145,000,000 in yet untapped reserves of current properties.
The Company will provide timely updates as to the progress of this and
other Natural Gas acquisition initiatives.
About Hybrid Energy Holdings
Hybrid Energy Holdings (HEH) acquires and operates profitable energy
companies with strong historical cash-flow and sustainable
profitability. HEH may acquire promising nascent energy technology or
technology rights as portfolio enhancing assets. HEH's acquisitions are
focused primarily on traditional and proven fuel production and the
latest in energy conservation and power co-generation technologies.
HEH's fuel production acquisitions provide expertise in the recovery of
oil and gas reserves in both mature and marginal fields. The company's
operational teams deliver production improvements and developmental and
low risk exploration as part of its acquisition strategy for it fuel
producing subsidiaries. HEH's primary business strategy is the
acquisition of diverse, profitable energy related assets that provide
synergistic profits and revenue enhancements across all portfolio
companies. HEH believes its combination of acquisition profitability
and mitigated-risk funding structures provides ongoing portfolio
viability and long-term shareholder equity appreciation.
The company maintains its web site at: www.HybridEnergyHoldings.com
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Marcellus Shale Anadarko, Mitsui agree to venture
By MARC LEVY 2/18/10 HARRISBURG, Pa.
The production of natural gas from tightly compacted shale in the U.S.
is attracting more capital from around the world.
Japanese conglomerate giant Mitsui & Co. said that it will take a
$1.4 billion stake, or 32.5 percent, in Anadarko Petroleum Corp.'s
assets in the Marcellus Shale gas field that stretches from
Pennsylvania into New York. Mitsui said Tuesday that it expects
to invest up to $4 billion in a venture, which it hopes will produce as
much as 460 million cubic feet of natural gas per day. "This just
validates that everybody around the world is interested in this play,"
Anadarko CEO Jim Hackett said Tuesday on CNBC.
Last month, Chesapeake Energy Corp., based in Oklahoma City, and a
subsidiary of France's Total SA formed a $2.25 billion joint venture
that gives Total access to the Barnett Shale natural gas field in north
Texas.
Manuj Nikhanj, vice president of the Calgary-based investment research
firm Ross Smith Energy Group, said the sheer size of the shale fields
appeals to the world's largest companies. Plus, international and
foreign energy companies also can learn how to exploit shale and bring
that knowledge to other basins around the world where development
hasn't started yet, Nikhanj said.
Geologists and energy companies have known about the gas trapped in
shales for decades, but the cost to tap them was prohibitive until
recently when new exploration techniques became available. "The
U.S. gas market has never seen such a sharp turnaround in expectations
as happened with the emergence of shale gas," said Richard Nehring,
president of Nehring Associations in Colorado Springs, Colo., which
provides information on oil and gas field production to the exploration
industry. "It is a big thing and it is something that emerged very
quickly. It upset a lot of investment apple carts."
Mitsui invests in and owns companies in a range of industries around
the world, including power plants, freight and textiles, as well as
liquefied natural gas and natural gas exploration. It previously
partnered with Anadarko in Mozambique and Indonesia.
Anadarko, based in Houston, has gas interests in more than 700,000
acres in northern Pennsylvania, and is the largest leaseholder in
Pennsylvania's state forests. Anadarko expects to drill more than
4,500 wells in the coming years. To date, there are about 1,100
Marcellus Shale wells drilled in Pennsylvania. About half of them are
producing, according the Marcellus Shale Coalition, an industry group.
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