GAS Today / November 2010

Transcripción

Issue 14
November 2010
Construction
contractors
Exporting LNG
CSG fires up at
Condamine
22–24 March 2011,Brisbane
• The magazine for Australia’s natural gas industry •
What we do
Welding
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do no harm . leadership .
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we bring energy to its destination
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November 2010/Issue 14
REGULARS
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64
46
47
48
Editor’s comment
Advertisers’ index, Subscription request, Coming soon
in future editions
NEWS
8
CONSTRUCTION
PROJECTS
Gas Today Update
50
PERSPECTIVE
12
Great
Southern
Press
Great Southern
Press Pty Ltd
A.C.N. 005 716 825
(A.B.N. 28 096 872 004)
GPO Box 4967
Melbourne Vic 3001 Australia
Tel: +61 3 9248 5100
Fax: +61 3 9602 2708
[email protected]
www.gastoday.com.au
Editor: Scott Pearce
Associate Editor: Katherine St Lawrence
Contributing Editor: Lyndsie Mewett
Journalists: Erin Radford, Kim Haworth, Sally Commins,
Melanie Ryan
Sales Manager: Tim Thompson
Sales Representatives: David Marsh, Brett Thompson
Design Manager: Michelle Bottger
Designers: Lela Sablic. Venysia Kurniawan and Ben Lazaro
Event Manager: Elissa Duck
Publisher: Chris Bland
ISSN: 1832-0562
Condamine Power Station.
Image courtesy of AE&E
Issue14
November2010
ExportingLNG
CSGfiresupat
Condamine
22–24March2011,Brisbane
•ThemagazineforAustralia’snaturalgasindustry•
2
CSG fires up at
Condamine Power Station
2010 election: repercussions
for the gas industry
REGION REVIEW – New south wales
Short-term gas trading market
begins operation
Technology
52
54
Gas generating interest in NSW
Coal seam gas: the new Star of NSW
RETAIL
16
LNG
20
26
Negotiating Australia’s first LNG
export contract
LNG high on the agenda in the
Northern Territory
COAL SEAM GAS
28
30
32
34
36
38
Safeguarding the Queensland
CSG industry
The reverse osmosis option
Enerflex open for Brisbane business
Global support for local CSG industry
Safety under pressure: tendering
for major projects
PPI: piping CSG
TRANSMISSION
40
42
52
iGas: break-through application for gas to fuel large highway trucks
AGiT
59
Young ones pipe up at Gas Speak
FutureGAS 2011
60
Get ahead – get to FutureGAS 2011!
EVENTS
62
62
63
63
LNG in focus at SEAAOC
ENA Gas Seminar
New gas opportunities on agenda at
APIA 2010
Calendar of events
Compensating for the
Joule-Thomson effect
APA: expanding pipeline system
capacity across Victoria and
New South Wales
The magazine for Australia's
natural gas industry
Construction
contractors
Gas to the max: Wollert –
Euroa pipeline gets an upgrade
Driving the LNG highway
Pipeline technology ploughs into
the CSG industry
Average Net Distribution 2980
Period ending March 2010
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combination with other material in any publication or format in print or online or howsoever
distributed, whether produced by GSP and its agents and associates or another party to
whom GSP has provided permission.
This magazine is available to interested parties throughout Australia and overseas. The
magazine is also available by subscription. The publisher welcomes editorial contributions
from interested parties, however, the publisher accepts no responsibility for the content
of these contributions and the views contained therein are not necessarily those of the
publisher. The publisher does not accept responsibility for any claims made by advertisers.
3
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22–24 March
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Register now at www.futuregas.com.au
Editor’s comment
A
ustralia decides. Almost. Since our
last edition in August, Australia
went to the polls and delivered
a decisively inconclusive result. After
17 days of negotiations with the cross
benches that covered a wide range of
issues, the Labor Party was successful
in gaining support to be returned to
government.
The Hon Martin Ferguson has retained
his Energy and Resources portfolio
which has been well received by the
industry. Industry stalwart Ollie Clark
has a thought-provoking article in this
edition that looks back at the election
and forward to the issues facing the
Government for the current term.
The Government has since instigated
its Policy Transition Group who will
advise on the transition of existing
petroleum projects to the Petroleum
Resource Rent Tax (PRRT). The Group
has released a PRRT Issues Paper which
sets out its view on the mechanics of how
the PRRT should apply to coal seam gas
(CSG) and LNG projects. From here, draft
PRRT legislation for public comment will
be issued before June 2011, and then the
Government will introduce legislation to
Federal Parliament in late 2011.
With numerous LNG projects at varying
stages of development around Australia,
we look back to the one that started it all.
Gas Today’s Associate Editor Katherine
St Lawrence recently interviewed Shane
McCarthy – who was a lawyer at Shell and
intimately involved during the negotiation
of the original contracts for the NWS
joint venture. His account is a fascinating
insight into the process and no doubt
one that is being replicated, in many
ways, across boardrooms throughout
Asia with respect to current Australian
LNG projects.
Looking towards developing the projects
that this LNG will be contracted from,
Federal Environment Minister Tony Burke
recently gave conditional environmental
approval to the Santos-led GLNG Project
and BG Group’s Queensland Curtis LNG
Project along with approving the dredging
works for Gladstone Port’s western basin
to allow LNG tankers access.
As we know, CSG will be the feedstock
for the various Queensland LNG projects
and in this edition we look at CSG issues
6
including safety and water management
as well as reporting on those who are
servicing and supplying the industry.
Against this backdrop of activity
in
Queensland,
FutureGAS
2011
(22–24 March 2011 in Brisbane) will be
discussing issues including LNG, CSG,
domestic gas needs and supply, the
latest project developments and also
the future of the industry – what are the
new frontiers for the natural gas industry
including new uses and sources.
Two speakers that we are delighted
to have addressing the event are the
recently appointed Queensland Gas
Commissioner Kay Gardiner, as well as
Tony Petersen from the DomGas Alliance
in WA. Their perspectives on where the
industry is headed and the issues that
need to be overcome will be a highlight
of the event. In addition, this year we will
have a one-day technical stream that will
address issues and developments for
engineers and technologists.
You can follow developments in the
program, find out more about the event
and also register to take advantage of the
earlybird rates at www.futuregas.com.au
The Short Term Trading Market (STTM)
commenced operations in Sydney and
Adelaide on 1 September this year, the
result of a lengthy process aimed at
improving transparency and efficiency
of the east coast gas market – we speak
with those active in the market to gain
their impressions on the performance of
the STTM to date.
An issue that we regularly promote in
Gas Today is natural gas as a transport
fuel. In this edition we hear about a
new technology to drive heavy transport
and developments to create a refuelling
network along major routes.
Finally, we take a look at activities in
New South Wales including their growing
coal seam gas industry and gas-fired
generation.
With this our last issue for 2010, we
hope you have had a successful year
and look forward to reporting to you
throughout 2011.
Scott Pearce
Editor
ERHP 1/21
NEWS
Lifting the Curtin on tight gas in WA
In order to further tight gas exploration in Western Australia, researchers
from Curtin University, the University of Western Australia and CSIRO will
work with Whicher Range Energy to study the tight gas sands of the South
Perth Basin.
A review will be taken of the geology, wireline logs, geomechanics and
drilling issues of the Whicher Range field and the tight gas sweet spots will
be mapped. The project is funded by the Western Australian Government’s
Exploration Incentive Scheme.
Government gives green light to GLNG and QCLNG
Federal Environment Minister Tony Burke has granted conditional
environmental approval to Santos’ proposed GLNG Project and BG Group’s
proposed Queensland Curtis LNG (QCLNG) Project, both to be located in
Gladstone.
Mr Burke has established more than 300 new conditions that the
projects’ proponents must adhere to in order to maintain the environmental
approvals, including groundwater protection related to the production of
coal seam gas (CSG), which will be used as feedstock for both projects.
ERHP 2/21
Macedon development gets BHP go-ahead
BHP Billiton has approved the development of the offshore Macedon
gas fields in the Exmouth Sub-basin, Western Australia.
The Macedon Gas Development will commercialise natural gas from
offshore production lease WA-42-L, located 100 km west of Onslow.
The project involves four offshore production wells supplying a
90.5 km, 500 mm diameter wet gas pipeline to an onshore gas
treatment plant. The plant will have a nominal capacity of 200 million
cubic feet per day and will be constructed at Ashburton North. First
production is expected in 2013.
New gas supplies for WA
Santos has announced that it will develop new gas supplies for the
Western Australian domestic market by developing and producing gas
from the Halyard and Spar fields, which it owns with Apache Energy.
The two companies will complete and tie back the Halyard well in
WA 13L and the Spar-2 appraisal well in WA 4R, both located in the offshore
Carnarvon Basin. The area contains expected recoverable resources of
approximately 335 petajoules, which could supply the state with gas until
at least 2025. Halyard is expected to be operational in mid-2011, and Spar
in late 2012.
Continued on page 10 >
Can’t wait for the next edition of Gas Today?
Get the latest news at www.gastoday.com.au/news
8
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Envestra seeks price rise to support capital works
program
Envestra has lodged submissions with the Australian Energy Regulator
(AER) in support of its request for an increase in gas distribution tariffs in
South Australia and Queensland.
The average charge for delivering gas to domestic customers would
rise by approximately $1.40 per week in South Australia and $1.60 per
week in Queensland if the company’s proposal is accepted by the AER.
Envestra Managing Director Ian Little said “Subject to the AER allowing
an acceptable, market-related investment return, we will spend around
$675 million on capital projects over the next five years.”
The requested increase comes as part of the review of the company’s
access arrangements. The revised access arrangements are for the five
years commencing 1 July 2011. It is expected that the AER will issue its
draft determination in early 2011 and the final determination in April 2011.
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the Federal Government’s Policy Transition Group.
They will be taxed at the point where a marketable petroleum commodity has been sold, further
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ERHP 3/21
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proven
Our environmental
2010 election: repercussions
for the gas industry
advantages give you the
confidence you need.
By Ollie Clark, AM
As the dust settles and the Gillard Government gets down to
business, one might well ask whether there are implications
for the gas industry. The top issues are the stances the
new government will adopt with respect to the control of
greenhouse emissions and regulation of the production
sector of the gas industry.
I
t is, I think, significant that the energy
portfolio will continue under the
stewardship of Martin Ferguson, AM,
and that the influence of the Greens has
been strengthened – including a Greens
member of the finely balanced House of
Representatives, and a total of nine Greens
Senators, as of 1 July 2011.
Carbon costings
Happily, there seems to be growing
consensus within the Parliament and
broad acceptance amongst the citizenry, of
the wisdom and inevitability, respectively,
of some form of carbon dioxide emissions
penalty. A simple “$ per tonne” tax
seems likely to eventuate. This path was
pretty much Labor Party policy before
the recent election and is likely to gather
pace per favour of the Greens, and the
reappointment of the Treasurer and the
Minister for Energy.
The rate at which this tax will influence
behaviour will depend on the initial carbon
price ($20 per tonne?) and the rate at
which it is increased. The purpose to
which the potentially huge sums raised are
put, assuming – perhaps naively – they will
be invested to further the cause, will also
influence the rate of uptake.
Given all Australian governments’
reluctance (or perhaps refusal) to even
consider nuclear power generation, and
given the Labor/Greens alliance’s strong
commitment to greenhouse gas reduction,
the focus for growth will clearly be on the
renewable energies and natural gas.
It seems to me that sequestration of
carbon from coal-fired power stations
has a long, long way to go even to abate,
somewhat, the emissions from existing
coal-fired power stations.
Gas and generation
There appears to be a general lack
of understanding in the community of
the significant carbon dioxide emissions
reductions available via the use of natural
gas in combined-cycle (or better still,
cogeneration and trigeneration) power
generation, due to:
(a) the greatly improved
thermal
efficiency it affords; and,
(b) the intrinsic nature of natural gas,
which has the lowest carbon-to-hydrogen
ratio of all the fossil fuels.
The net result is a reduction of
approximately 60 per cent on a
per kilowatt hour basis, compared with
coal-fired generation.
Despite what I read, I cannot for the
life of me see why the capital cost of gasfired generation (nor for that matter the
maintenance costs) is quoted as excessive.
C
ERHP 4/21
onocoPhillips is committed to protecting the environment that we all share.
Employed in LNG facilities around the world for over four decades, the
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has strong environmental advantages, including:
Ollie Clark, AM.
In my view, it should be a fraction of the
cost of coal-fired plants considering the
huge infrastructure required to support
the latter, which are often built in rather
remote areas necessitating the installation
of costly transmission networks.
This raises the point that in this day
and age the opportunity is there to move
away from the traditional model of a small
number of very large generators to a
large number of very small generators –
embedded generation. This concept is
gaining acceptance worldwide, even to the
individual household level. Natural gasfuelled embedded generation facilitates the
use of waste heat for domestic, commercial
and industrial use, with the potential to
raise thermal efficiency to combined-cycle
level and beyond.
• Advanced aeroderivative gas turbines.
• Integrated NGL extraction.
• Integrated waste heat recovery.
• Gas and liquid expanders.
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© ConocoPhillips Company. 2010. All rights reserved. Optimized Cascade is a trademark of ConocoPhillips Company.
Urban renewal and the quest for
improved thermal efficiency in buildings
offers wonderful opportunities for this
application. We would hope that the
development of communities such as the
transport oriented developments proposed
for the Adelaide metropolitan area would
use this proven technology, which is freely
available.
Reforming regulation
Apropos the matter of recent proposals
with respect to regulation, I must admit to
a limited understanding. The point I would
make however is that regardless of the
outcome of the Petroleum Resource Rent
Tax review, it should, in my view, be aimed
entirely at the LNG export component of
production.
We are constantly assured that LNG
exports are vital to our future prosperity
and that the global market will become
immense. Luckily, we have a vast (and
growing) natural gas resource and should
be able to support the local market –
currently around 1,250 petajoules per
annum (PJ/a) – and the growing export
market, which some commentators seem
to think may reach 5,000 PJ/a by 2020.
It is to be hoped that the Government
will acknowledge that the multi-million
dollar liquefaction plants are solely for the
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14
production of LNG for export, and that it
is totally unwarranted to pass any portion
of this cost on to the domestic market.
In addition, the population is supposed
to benefit from the export of Australia’s
resources, not to pay for it!
Fuelling the future
Finally, (and here he goes again, I can
hear some saying!) in a country starved of
oil, and which imports, in net terms, of the
order of 1,000 PJ/a of crude oil and refined
products, costing $15–30 billion annually,
should we not be moving actively towards
the introduction of natural gas as a major
component of the transport fuel mix?
To put the costs into perspective, with
the exception of aviation, all transportation
could be fuelled for around $7.5 billion
using natural gas exclusively, and all
concerns about security of supply would
disappear!
Returning to the subject of the new Labor
Government and what it might mean for
the natural gas industry, let me quote the
Minister for Resources, Energy and Tourism
Martin Ferguson, in his “Foreword” to the
2009 and 2010 Energy in Australia reports:
“The energy sector has a critical role to
play in meeting our nation’s basic social
and economic needs, with energy security
being vitally important. It underpins every
form of our economic activity, powering our
industries, our vehicles, our workplaces
and our homes.
“Against a strengthening global economic
backdrop and increasing demand for
energy exports, Australia must continue
to address the issue of domestic energy
security.”
Paradoxically, in my view, we are
repeatedly told that it is not the role of
the Government to “play favourites” and
we must allow “the market” to sort it out.
I cannot accept this easy escape from a
fundamental responsibility.
There are a number of influential groups
within the energy industry, each with
deep rooted vested interests which do not
necessarily coincide with the best interests
of the nation.
Their views must remain subservient.
Governments are responsible for setting
sound policy. Setting sound policy is
leadership; it is not playing favourites.
Australia desperately needs, and
deserves, a clear, all embracing energy
policy (something it has never had) with
clear environmental, social and governance
imperatives. The nation’s vast natural
gas reserves offer the environmental
and social solutions. Let us hope the
Gillard Government will provide the vital
governance framework.
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ERHP 5/21
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Short-term gas trading
market begins operation
Gas to Energy Solutions.
FP Ad 1/21
Talk to the experts.
Following its official launch by the Australian Energy Market Operator on 1 September 2010,
the short-term trading market is making a significant impact on the way the Australian gas
industry operates. Gas Today spoke to an industrial user and a retailer about the changes
to the market.
T
he short-term trading market (STTM),
is a transparent wholesale spot
market for the trading of natural gas,
which will determine daily market prices
and a timetable for gas deliveries from
pipeline transmission users and hubs. The
market is currently operational in Sydney
and Adelaide, with Brisbane to join in 2011.
Increasing competition,
decreasing costs
Australian Energy Market Operator
(AEMO) Chief Executive Officer and
Managing Director Matt Zema says “The
STTM is a key step in gas market reform
that will improve transparency, efficiency,
and competition across the gas sector in
New South Wales, South Australia, and
Queensland (for 2011). It provides clearer
price signals, incentives for efficient
management of resources, and enhanced
market liquidity.”
Adelaide Brighton is an industrial
end user of gas, and General Manager
Commercial Michael Williams says that
the STTM “provides us with the opportunity
to reduce our annual gas costs by buying
a proportion of our gas from the STTM
when prices are low relative to long-term
contracts.”
Mr Williams says “These low prices are
expected to occur during the mild seasons
of the year when there is a surplus of gas.
Conversely, there will be times of the year
when gas demand is very high and at these
times there is the opportunity to sell gas that
is excess to our operating requirements.
“From an operational perspective, the
STTM places increased importance on our
capability to accurately forecast our gas
consumption one day ahead. The STTM
requires additional management of costs
and risk management processes; however,
the cost of the additional management
processes is recovered quickly through the
cost savings,” Mr Williams says.
From a retail perspective, the new
market, which integrates AEMO’s roles
as both the retail market and wholesale
market operator, offers an opportunity for
a “more integrated interface to deal with
as participants,” says AGL Manager Gas
Market Development George Foley.
Mr Foley says that while the market is
an ex ante market, there is provision for
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minimising the impact of deviation charges
incurred on a trading day through intraday
renominations to the pipeline, — this
particular feature of the design recognises
the linepack capacities of pipes feeding
both the Adelaide and Sydney Hubs.
“This is a useful feature of the market.”
Trading in the new market
AGL has been continuously improving the
accuracy of its demand forecasts, which Mr
Foley says has “certainly been given a boost
by the introduction of the STTM.”
Mr Williams says that “prior to the
commencement of the STTM, our gas
shipments sourced from our long-term gas
supply contract matched our gas usage
exactly and although possible, bilateral
wholesale gas trades with other parties
have been difficult to establish due to
lengthy master contract negotiations. The
STTM enables a mechanism to easily match
sellers who are long term and looking to
sell gas at attractive prices to buyers.
“One benefit of the market is that
large industrial gas users can offset the
increasing gas prices of their long-term
supply arrangements with the ability to
purchase some of their gas requirements
at lower prices when demand is not high.
“Whilst the market prices are unlikely
to be able to be effectively used by large
industrial users when seeking long-term
supply contracts, it does provide the
opportunity for large users to manage their
own gas requirements and seek to reduce
costs by having at least a partial exposure
to the market price.”
Mr Williams remarked that another
strength of the market is that it provides
transparency.
“Historically, the gas industry has tended
to function as a close knit industry with very
little transparency.
“Gas users have not been in a strong
position in terms of information and
options when going into long-term contract
negotiations with major gas suppliers and,
as a result, long-term gas contract prices
have probably been higher and less flexible
than they could have been. The STTM has
created far greater transparency of the gas
market, will encourage new gas entrants,
and will produce more efficient outcomes
than the previous bilateral arrangements.”
Room for improvement?
Mr Foley suggested that “the rigid manner
in which trading rights are registered may
mean a slight loss of portfolio diversity for
the industry as a whole.”
Mr Williams and Mr Foley agreed that
3 Great Companies working
together on a Cure for
the introduction of user-to-user market
schedule variations (MSVs) would help to
contribute towards the STTM’s continued
efficiency.
Mr Williams said that “MSVs – transactions to balance gas between participants
after the gas day has finished – are traded
bilaterally. All parties benefit from undertaking MSVs and we would like to see a
mechanism whereby these can be traded
and settled via the STTM rather than requiring a separate bilateral negotiation and
settlement with each participant on each
gas day.”
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A gas market for the future
The process of changing any of the
key features of the STTM is prescribed by
the National Gas Law and National Gas
Rules. AEMO and participants can propose
changes to the features of the market.
To this end, AEMO established an open
consultative forum (the STTM Consultative
Forum), which is one vehicle to consult with
industry on STTM development issues.
“In this way, progress will be made in a
consultative way, which has been important
in the development and implementation of
the STTM for commencement, and will be
important in the future development of the
market,” says Mr Zema.
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Negotiating Australia’s
first LNG export contract
Australia has been supplying Asia with LNG since 1989. Gas
Today interviewed former Shell lawyer Shane McCarthy,
now retired, about his experience negotiating the contract
that delivered Australia’s first ever LNG exports.
S
hane McCarthy started his career
with Shell in 1971 after completing
his law degree at the University of
Melbourne in 1963. In 1978, Shell posted
Mr McCarthy to London, where he
worked on ship chartering, oil trading,
and natural resource development, in
particular LNG.
It was here that Mr McCarthy gained a
basis of experience in negotiating LNG
sales contracts.
“I worked on the Brunei and Malaysian
projects in 1980. At that stage, the
first Malaysia LNG Project was getting
going and I helped develop a sale and
purchase agreement with the buyers,
getting it in final shape to go to the
board of the Malaysia LNG company.”
In 1979, the sellers from the North
West Shelf Project were starting to
develop a relationship with some
Japanese buyers, who eventually came
up with an eight-buyer consortium:
Tokyo Electric Power, Chubu Electric
Power, Kansai Electric Power, Chugoku
Electric Power, Kyushu Electric Power,
Tokyo Gas, Osaka Gas and Toho Gas.
“I started advising on the Memorandum
of Intent (MoI) from London in that year,
and when I moved back to Australia,
I brought the first draft of the contract
with me,” Mr McCarthy says.
The MoI was signed on Bastille Day,
14 July 1981.
Gas on the North West Shelf
In the 1970s, the North West Shelf Joint
Venture (NWS JV) participants discovered
vast quantities of natural gas and condenContinued on page 22 >
Shane McCarthy, 2010.
The North West Shelf Venture participants today are BHP Billiton
Petroleum (North West Shelf), BP Developments Australia, Chevron
Australian, Japan Australia LNG (MIMI), Shell Development (Australia),
and Woodside Energy as operator
Currently, all participants have an equal one sixth share in the project.
The North West Shelf Gas Project LNG processing facilities. Image courtesy of Woodside Petroleum.
20
FP Ad 3/21
Shipping
Upon Mr McCarthy's retirement in 2004, he
was offered passage to Japan on board an
LNG tanker.
sate on Australia’s northwest continental
shelf. The first development of the NWS
Gas Project began in 1980 with the construction of the Karratha Gas Plant and a
jetty for the loading of LNG and condensate. Domestic gas supply from the project
to Western Australia began in 1984.
In 1985, Woodside began construction
of the first two LNG processing trains
and four LNG storage tanks at the
Karratha plant. The first LNG train
was commissioned in 1989, and four
additional trains have subsequently been
brought online.
Process of negotiation
Mr McCarthy’s visits to Japan during
the negotiations ranged from a few days
to up to six weeks, and were an intense
mix of work and socialising.
He quotes an American colleague who
said, “We work hard, we play hard, and
one justifies the other."
Because there were eight buyers and,
ultimately, six sellers, the Japanese
recognised that having representatives
from every buyer would be unwieldy. The
buyers were jointly represented by just
four companies, called the secretariat
buyers. So meetings consisted of
the secretariat buyers, the sellers,
Mitsubishi & Mitsui as sellers' helpers,
and Nippon Oil as an advisor to Chevron.
Negotiation meetings usually involved a
roomful of 30–35 people. At the buyers’
request, the sellers were represented by
one speaker.
A total of 48 separate contracts were
22
negotiated between the parties, though Mr
McCarthy says they were almost identical
and in practice, they functioned as one.
He says that initially, buyers were
mistrustful of negotiating with sellers
from a joint venture. For contracts on
previous projects, buyers would deal with
a company set up to sell the LNG. The
Malaysia LNG Project set up a separate
company to market the LNG, so the
buyers dealt only with one seller.
“It took until 1985
to sign the contract
because we were
not just drawing
up a contract, we
were developing a
relationship, and we
wanted to make the
document as good as
the relationship.”
The original NWS LNG contracts has
a price clause which looks forward to
negotiation when deliveries would start,
and eventually the sellers developed a
series of rolling five-year price contracts.
The details of the price contracts, Mr
McCarthy said, were too confidential to
talk about with us.
“Mostly, when commercial things
like price were under negotiation, the
number of people in the room diminished
dramatically.
“They said to the lawyers, ‘You can go
and have a holiday.’ So we did! A lawyer
from BP and I went down to Kamakura
for the day.”
The first big point of negotiation,
Mr McCarthy says, was the shipping
arrangements. The MoI had left open who
would do the shipping, and the sellers
recognised that there was a Japanese
interest in shipping.
Mr McCarthy says the main concern
when negotiating the shipping of LNG is
timing.
“In the past, iron ore had been sold on
a free-on-board basis. Buyers send their
ships to the port to load the product. If
they don’t want the iron ore, they don’t
send the ships.
“That would be intolerable in an
LNG project, where everything works
to extremely fine tolerances. So we
wanted to be able to control the
shipping,” he says.
“Our original preference was for CIF
shipping – cost, insurance and freight.”
Under CIF, the seller loads the
product onto a ship, and the ship owner
issues the seller with a bill of lading,
which acknowledges that goods have
been received on board as cargo. The
ship owner acts as custodian of the
product on the voyage, and the transfer
of the bill of lading then transfers
ownership of the cargo from seller to
buyer at some point during or after the
voyage.
“But the buyers said, ‘We don’t have a
relationship with the ship owners, so we
want you to bring the gas to our ports.’
“That kind of a sale is called an exship sale, which means the buyer takes
delivery when the product is discharged
from the ship.”
The buyers’ interest in shipping was
satisfied by a complicated arrangement
for providing ships through charter
parties. Japanese ship owners chartered
two ships into the NWS project and they
became the sellers’ ships, and both the
ships were built in Japan.
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Will you marry us?
Gas liquefaction was a proven
technology by the 1960s, with Malaysia
LNG and other suppliers already
supplying gas to Japan, and further
projects proposed in the Middle East,
Indonesia and Canada.
Mr McCarthy explains that other
projects were not necessarily competitors
to NWS LNG.
“Because of the nature of the MoI and
the commitment it involved, there wasn’t
competition in the sense of people
beating at the door, looking for the same
tranche of business.”
Energy & Infrastructure Specialists
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“Once we’d signed the MoI, we knew
that unless something serious broke
down, we would have a deal.”
Mr McCarthy calls the contract a sort
of marriage, and the MoI was “like an
engagement.” This commitment was
expressed to Mr McCarthy on a number
of occasions during negotiations.
“I rode from the airport with one of our
Mitsubishi advisors, and on the way we
started talking about the process and the
project and where it was at, and so on.
“The Mitsubishi advisor said to me ‘You
know, they’re not really negotiating the
contract with you. They’re negotiating to
get to know you better.’
“After one meeting in the early 1980s, I
was standing outside a lift with one of the
Japanese representatives and I asked him
how the North West Shelf contract was
shaping up compared with the deal they
were working on for Dome Petroleum’s
Western LNG Project in Canada.
“He said, ‘Compared with the Dome
project, we have one divorce, one marriage.’
And I knew which was the marriage!
“It didn’t mean that we didn’t have
a hard negotiation on every word in
the contract. It’s probably the most
comprehensively
and
thoroughly
negotiated contract I’ve ever worked on.
“It took until 1985 to sign the contract
because we were not just drawing
up a contract, we were developing a
relationship, and we wanted to make the
document as good as the relationship,”
Mr McCarthy says.
“The spokesman for the sellers
addressed the group at one point and said,
‘Before we were two teams negotiating
one contract. I can say now that we are
one team.’ And boy, did the Japanese like
that. The relationship was solid.
“It still breaks me up to think about –
the negotiation was a very emotional
process.”
Mr McCarthy uses the Brunei LNG
Project to illustrate the strength of the
seller-buyer relationship with Japanese
clients. Offtake from the Brunei project
was contracted to TEPCO and Osaka Gas
at a fixed price in 1969, as opposed to
the NWS contracts, which had five-year
rolling price contracts.
“In 1973, the first oil shock occurred
and the price of oil went through the roof.
LNG prices are very strongly linked with
oil prices, and so the Brunei project was
left basically stranded because it was on
a fixed LNG price.
“But, the buyers and the seller came
together and the buyers agreed to an
increase. They didn’t have to, but they
did, because the Japanese don’t like
contracts or relationships where there is
one winner and one loser. They like it to
be mutually beneficial – win-win.”
Today
Mr McCarthy says the biggest change
in the LNG market now compared with
the 1980s is the development of a spot
market.
“We had some occasional spot sales of
LNG; the biggest customer was Enagas,
the Spanish company. At one point we
were supplying 10 per cent of Spain’s gas
requirements.”
The NWS project has also supplied
LNG to Louisiana, USA, to Korea Gas
Corporation, to Turkey, and to other
Japanese buyers as well.
Mr McCarthy’s advice to companies
looking to negotiate future LNG supply
contracts is to be honest.
“Honesty is so important if you’re
building a relationship based on trust.
There is even a clause in this contract
referring to trust and understanding.
That is very uncommon in Western
contracts, but it reflects the fact that
we were negotiating a cross-cultural
relationship.”
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Design · Supply · Install
The Darwin LNG Plant.
the right person can
transform a business
LNG high on the agenda in
the Northern Territory
LNG export projects represent a significant commercial opportunity, a fact that the
Northern Territory Government well recognises. Gas Today spoke to the Northern Territory
Government about how it is working to develop the industry.
N
orthern Territory Chief Minister
Paul Henderson has said that
the Ichthys LNG project, together
with the existing Darwin LNG project,
will underpin the Territory’s economy for
decades to come.
But these two projects only represent
the start of an LNG industry in the
Territory. Along with proposed projects like
the Tassie Shoal Methanol Plant and LNG
Project, floating LNG (FLNG) technology
presents a significant opportunity.
Northern Territory Minister for Primary
Industry, Fisheries and Resources
Konstantine Vatskalis has even said that
the Northern Territory could become
“the floating LNG capital of the world”.
“Within ten years...[the Northern
Territory] could have five to seven
FLNG projects under development or in
production,” says Mr Vatskalis.
In order to further LNG investment,
the Territory Government is working to
support the industry on several fronts.
Working with businesses
The Territory operates a wholeof-government taskforce for LNG
developments.
This taskforce approach aims to
identify and resolve issues early, and
to help proponents understand local
requirements and expectations. It
also provides a strong mechanism for
information sharing and accountability.
The Department of the Chief Minister
leads co-ordination of engagement
between proponents and relevant
government agencies.
As an example of this business
engagement, the Department of Business
and Employment and the Department
of Education and Training are working
26
with INPEX to prepare for the training
needs for its Ichthys LNG construction
workforce. This will be followed up on
completion of the development with
engagement in relation to the operations
workforce skills needs.
The Northern Territory Government
also says that it provides a greater level of
regulatory certainty for proponents than
other Australian jurisdictions. Notably,
there is no third-party appeal embedded
in
the
Territory’s
environmental
assessment process.
Onshore infrastructure
The Middle Arm Peninsula of Darwin
Harbour, which hosts the Darwin LNG
Plant, has been reserved for industrial
development. Aside from its proximity
to a deep water harbour, making it wellsuited to accommodate LNG tankers,
the site includes nearby gas pipeline
infrastructure, port infrastructure for
project cargoes, and good road and
rail connectivity. These factors make
it a particularly attractive greenfield
development site, says the Territory
Government.
The first stage of a Common User
Facility has also been established in the
Darwin Business Park, adjacent to the
East Arm Wharf. The facility now enables
local industry to participate in larger
fabrication projects by amalgamating
smaller fabrication modules for load out
over the East Arm Wharf. The Common
User Facility will also cater for a range of
demands, including short-term lay down
for resource projects.
Looking for more offshore
The Northern Territory Government
sees the potential rise of FLNG projects
in the region as an opportunity rather
than a challenge.
There will be a synergy with existing
businesses supporting and servicing
both offshore oil and gas production
and onshore LNG production, the
Government says.
It plans to align existing initiatives to
grow the supply and service industry with
the FLNG industry as it establishes and
expands. It foresees that an increasing
number of FLNG projects and their cooperation with onshore LNG projects
will build a critical mass for an everincreasing number of specialised
support industries.
Meet the market
The Chief Minister, along with other
cabinet members, has made numerous
visits to Japan and China to promote
investment and exploration opportunities
in the Territory’s energy and minerals
sector.
The Territory Government believes
that to attract investment from these
markets, government support is an
essential element for success.
In order to promote the local resources
sector supply and service industries, the
Government has also organised and lead
delegations to overseas markets and
trade expos.
On a recent roadshow promoting
business
and
investment,
Chief
Minister Paul Henderson highlighted
the Territory’s advantages for potential
LNG production and export projects,
noting that “our proximity to Asia is a
key and critical difference to the rest of
the country, as is our size – we are small
enough to make it easy to make things
happen.”
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Safeguarding the
Queensland CSG industry
Wood Group Wagners
Integrated Solutions for CSG
By Stephen Matheson, Chief Inspector Petroleum and Gas Inspectorate, Queensland Government
As industry activity expands significantly to cater for the emerging export LNG industry
in Queensland, issues about the safe operation of CSG wells, facilities and pipelines have
been expressed within the community.
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C
oal seam gas (CSG) activities –
including exploration, appraisal
and development – first began in
Queensland in the 1980s, and CSG has
been safely produced in the Bowen and
Surat Basins for the domestic eastern
seaboard market since 1996.
This increased activity brings its own set
of challenges in the areas of health and
safety to address community concerns.
The CSG industry has grown sharply
in recent years, with more than
2,700 coal seam wells now mostly located
in southwest Queensland.
Keeping Queensland safe
The Queensland Government regulates
health and safety in the petroleum and
gas sector and is working with industry
to address safety concerns raised by the
community.
For example, there has been a full
safety audit of all CSG wells, and
community forums have been held in
relevant regions to talk to landowners
about the industry, and the government
is deploying additional petroleum and
gas inspectors throughout the state.
Wellhead inspection program
Earlier in 2010, the Queensland
Government ordered all CSG producers
to review their operations, to ensure their
gas wells and associated equipment
meet appropriate health and safety
standards.
Under the program, all CSG producers
were required to do a re-inspection and
risk assessment of all existing wellheads
and report back to the Government.
The preliminary report released
in July 2010 found that more than
2,239 individual wells, or 95 per cent,
came back absolutely clear of any safety
issues.
While small leaks were detected in the
remaining 5 per cent of wells, none have
been found to pose any threat to public
health and safety and all are operating
within national health and safety standards.
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The Petroleum and Gas Inspectorate is
currently completing the final wellhead
safety audit report and this is expected to
be released in the near future.
New recruits
The Queensland Government is
investing an additional $14.6 million
over the next four years to substantially
increase the number of Petroleum and
Gas inspectors throughout Queensland.
In 1985, there were a total of 12 inspectors, a number which has increased
only to 15 in 2010.
As of 30 August 2010, six additional
Petroleum and Gas inspectors have
been employed by the Queensland
Government.
Two new recruits are based in
Toowoomba and Bundaberg to increase
the Government’s regional coverage.
The remaining four are stationed in
the Brisbane Southern Regional Office
where they will significantly increase
the Inspectorate’s capacity to service
the whole Southern Region; including
monitor compliance of CSG activities in
the Surat Basin.
The Department is currently recruiting
an additional two inspectors to be based
in the Dalby and Roma districts.
Further, an additional Principal
Inspector position was also advertised
and a dedicated full time investigator is
also being recruited in the second half of
2010 to assist inspectors with significant
compliance investigations.
This recruitment drive will increase the
number of State Government Petroleum
Supply Chain
& Logistics
Engineering
and Gas Inspectors working throughout
Queensland to 24.
This expanded inspectorial service will
enable a higher level of inspection, audit
and investigation activity to work with
industry on compliance issues.
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Safety for the future
Activities in the CSG area are set to
increase as project proponents gear up to
meet commercial supply contracts which,
in some cases, start from 2014.
The Petroleum and Gas Inspectorate
duties include the administration of
petroleum and gas operations from
exploration and production through
transmission, reticulation and all forms
of domestic and commercial use.
The Government is taking action to put
in place additional inspectors to ensure
the safety and health of this expanding
workforce and to have people on ground
in the regions where they are needed.
The Queensland Government is
committed to maintaining the health
and safety of the petroleum and gas
industries and the community as these
industries continue to grow.
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The reverse osmosis option
As coal seam gas developments come under closer scrutiny than ever before, water
management becomes a major concern for developers. However, the produced water
stream can become a revenue stream through reverse osmosis treatment.
C
orporate
social
responsibility,
stakeholder issues and now
Queensland
legislation
mean
that water treatment options are a key
consideration for coal seam gas (CSG)
developers. Desalination of the brackish
water extracted can be achieved through
a number of methods. The most common
processes fall into three categories;
membrane, chemical or thermal.
Reverse osmosis (RO), a membrane
technology, provides the finest level
of filtration available, says RO plant
developer and operator Osmoflo. It
removes 95–99 per cent of dissolved
salts, inorganic molecules and organic
molecules with a molecular weight
of greater than 100. It also removes
98 per cent of residual biological and
colloidal matter from the feed water.
Salinity of CSG water varies greatly,
from drinking quality – less than
500 milligrams per litre (mg/L) – to more
than 10,000 mg/L. Typically, CSG water
contains between 1,500–10,000 mg/L of
dissolved solids.
How does it work?
Osmosis is the tendency of water to
flow from a purer solution through a
semi-permeable membrane into a more
concentrated solution, equalising the
solute concentration on either side of
the membrane. Solute molecules do not
naturally pass through the membrane.
Pressure can be used to reverse the
natural course of osmosis. As such, RO
involves applying pressure to brackish
water to make it pass through a
membrane, removing solutes.
Depending on the quality of the water,
which varies considerably across sites,
pre-filtration by other technologies also
may be used in CSG water desalination
plants. This ensures that larger particles
that could damage the RO membranes
are filtered out.
Considerations
Key issues in the installation of
RO plants relate to water quality and
variability. Water contaminants, which
include silica, iron and hydrocarbons can
all affect the performance of the system,
as can extracted water temperatures. The
30
Above: Diagram of Osmoflo’s RO
plant at Roma.
Left: Osmoflo’s RO plant at Roma.
changing nature of water volumes over
the life of the project – increasing then
decreasing – also needs to be considered.
The remote location of CSG fields
can also pose a challenge. The use of
modularised plants can help minimise
onsite construction and commissioning
activities, says Osmoflo.
Compared to other desalination
technologies, Osmoflo believes that
the disadvantages of RO are negligible,
a result of new innovations in energy
recovery and brine minimisation.
The advantages, aside from the fine
level of filtration, include its ability to
treat very large volumes of water very
effectively, its small footprint and its
cost-effectiveness.
Existing plants
Testament to the flexibility of RO in the
treatment of CSG water is the diversity of
its existing applications in Australia.
Veolia installed water treatment
systems at the Condamine and Braemar
2 CSG power stations in Queensland. The
plants combine a number of purification
processes with RO, including clarification
and microfiltration at Condamine
and ultrafiltration and continuous
deionisation at Braemar 2. The water has
a variety of uses, including cooling tower
basins, potable water, process water and
demineralised water for boiler feed.
Osmoflo built and operates the
5.5 mega litres per day (ML/d) RO plant
at QGC’s Roma CSG fields in Queensland.
The plant uses oxidisation of iron,
microfiltration and RO. The treated water
is used for irrigation.
In August 2009, Impulse Hydro was
awarded a contract to provide RO to
Eastern Star Gas’ Narrabri CSG project in
New South Wales. Previously, produced
water at Narrabri had been disposed
of using evaporation ponds, which was
common in early CSG projects. As such,
the RO system was installed in a way that
would accommodate water from existing
evaporation ponds as well as water
straight from the well.
FP Ad 8/21
Prepared
for anything.
Water reuse
When constructing RO plants, it is
the desired end use for the water that
determines the level of filtration. Water
treatment can be tailored to client needs,
be they municipal or industrial.
Treated CSG water can be used for a
range of purposes, depending on the
purity of water the client specifies.
Given the often remote location of
CSG projects, one of the key issues is
the cost and infrastructure needed to
transport water for use other than at the
immediate location, says Osmoflo. As
such, water produced at CSG sites will
tend to be used for irrigation, for general
use onsite, or fed into local streams.
Dräger X-zone 5000: reacts to up to six gases.
State-of-the-art area monitoring - the Dräger X-zone® 5000, in combination with
the Dräger X-am® 5000 or X-am 5600 gas detection instruments, can be used
for the measurement of up to six gases. This easily transportable, robust and
water-proof unit extends mobile gas detection technology to a unique system
with many applications.
Call 1800 67 77 87 or visit www.draeger.com for more details.
Enerflex open for
Brisbane business
In July 2010, Enerflex launched a new Brisbane manufacturing facility, located at Trade
Coast Central, Eagle Farm, Queensland. The new facility will become the company’s first
dedicated re-packaging and reassembly facility outside of North America.
E
nerflex General Manager Chris
Lewis, President and Chief Executive
Officer Blair Geortzen, Managing
Director AustralAsia Steve Dropulich,
President International Bill Moore,
Executive Director AustralAsia Kelvin
Andrijich, and Queensland Minister for
Natural Resources, Mines and Energy
Stephen Robertson were present to
celebrate the facility’s opening.
Mr Robertson gave a keynote address
and congratulated the company on its
success. In particular, he acknowledged
Enerflex’s involvement in the development of the coal seam gas (CSG) industry
in the east coast of Australia.
On the back of the huge market
opportunity driven by the burgeoning
CSG-fed LNG industry in Queensland, the
differing regions of Enerflex collectively
and collaboratively designed the facility
to suit the expected quantity and
specification of the compressor packages
to be delivered to their customers.
32
Furthermore, the size and configuration
of the facility allows Enerflex to leverage
off this core competency and further
supply triethylene glycol and process
equipment
packages,
undertake
revamps and compressor optimisation
and execute fabrication and assembly
works as part of turnkey and integrated
projects.
The new facility features 2,000 square
metres (sq m) of office area with an option
to expand a further 1,000 sq m to house
their teams. The office has been designed
keeping in mind the dynamic nature of
Queensland’s work styles and workforce.
The workshop has a floor area of
3,650 sq m to support the range of
services and workshop functions required
by Enerflex. This includes overhead
cranage,
welding
and
fabrication
capabilities, vehicle access, stores and
associated support infrastructure.
As part of the company’s ongoing
commitment to pioneering best practice,
Enerflex is the first company in Australia
to be awarded a 4.5 GreenStar rating by
the Green Building Council of Australia
using a pilot tool developed specifically
for the industrial sector. The GreenStar
system evaluates the environmental
attributes of the built space and allows
for benchmarking across the sector.
Some of the sustainable initiatives
included the use of recycled rubber
(including that from used tires) in lieu
of carpet, an operable louver system to
manage radiant heat whilst maintaining
views, recycled water for sanitary use
and irrigation, minimal use of PVC and
materials with a low volatile organic
compound content, as well as energy
efficient lighting and air conditioning
systems.
“Enerflex’s continued, demonstrated
leadership in design and construction
will set the standard for Australia’s
natural gas industry going forward,” says
Mr Andrijich.
enerflex
9/21
Global support for
local CSG industry
Global Oilfield Services subsidiary Global Artificial Lift is a leading electric submersible
pump supplier for the coal seam gas market in the United States of America with an install
base of over 5,000 systems. The company recently opened a Brisbane office to service
Australia’s burgeoning CSG industry.
Proven Technology for Australia’s CSG Challenges
Global Artificial Lift now has sales, service and technical
support personnel located in Australia to provide tangible
solutions to the challenges of our customers’ coal seam
gas wells. In the past 25 years, Global Artificial Lift has
worked on more than 5,000 wells in support of the
Wyoming Powder River basin coal seam gas business.
Now, our experienced personnel bring their innovative
solutions and industry focus to meet similar challenges
in Australia.
M
embers of Global Artificial Lift’s
unconventional
gas
division
have been actively involved in
coal seam gas (CSG) since 1982. This
vast experience base covers dewatering
vertical and horizontal wells and
the company has developed unique
processes and procedures to deal with
the challenges of these applications.
Challenges of CSG
Since 1982, there has been a very steep
learning curve with dewatering CSG
wells. Most of the expertise initially came
from the oil industry. It became apparent
early on that the same technology that
had been proven in the oil industry was
not applicable to CSG challenges.
The mechanical differences and associated challenges of CSG production –
including dealing with solids, turbulent
flow conditions, gas locking, pulling the
water down below the bend of a horizontal well, and others – demanded products and service changes to meet these
differences.
It was also apparent that the economics
of CSG were very different from the oil
industry and therefore using the same
products were cost prohibitive. Global has
met the mechanical and the economic
challenges by developing specific costeffective products and developing new
processes and procedures for this industry.
A new product for a new
industry
For many years electric submersible
pumps (ESPs) had been viewed as
products best suited for high volume
wells, and are still excellent pumping
platforms to accomplish that. Due to
years of experience and development,
Global has developed CSG systems
that are also capable at low levels of
production – down to 50 barrels per day.
This product development has led to
industry-changing solids control both
at the time of drilling and in existing
Applications
• Coal seam gas wells
Global Artificial Lift
10/21
• Disposal water reinjection
Benefits
• Downtime minimized with fast service
and efficient, reliable operation
• Fine solids plugging effectively
controlled
• Gas locking eliminated by enhanced
gas separation
Global Artificial Lift's electric submersible pumps.
wells. Products have been developed and
patented for unique gas bypass systems
that considerably reduce the risk of gas
locking and increase gas production
by drastically reducing the amount of
free gas lost with the water during the
dewatering cycle.
Reinjection of the produced water has
become a paramount environmental
issue and systems have been developed
that include being able to reinject water
without ever bringing it to surface or
creating a closed loop so as not to allow
oxygen back into the system.
Supporting CSG
One of the most important things that
has been learned since 1982 is that
every basin can be different, every field
can exhibit its own set of challenges,
and we are going to learn something
new that can be applied to applications
somewhere else.
The
CSG
industry
appears
straightforward on the surface but has
at times baffled the most experienced.
We have also learned that bringing high
cost oil field equipment to CSG has
proven ineffective and too costly for the
economic structure of CSG. A substantial
amount of time and money has been
invested in the development of products
that specifically address the common
mechanical and economical challenges
faced by artificial lift.
Global is excited about bringing
proven and economical dewatering and
reinjection products along with years of
practical experience to the Australian
CSG market.
• Anti-corrosion and anti-abrasion
options
• Longer run times and reduced
operations costs
Features
• Global Linear Lift Systems require no
large cement pad, are air-transportable to remote sites, and are
suitable for all kinds of wells—from
conventional oil wells to gas-well
dewatering.
• Patented fines filtration accessories
• Unique gas lock bypass option
• Remote monitoring by phone, radio
or data modem
© 2010 Global Oilfield Services, Inc. All rights reserved.
34
Artificial lift is our focus. From proven ESP technology
to the Global Linear Lift System, we have the equipment
and accessories to deal with the top challenges facing
coal seam gas producers—solids plugging, gas locking
and corrosion—that cause downtime and rob you of
profits. Our experienced engineers and technicians
can help you choose the right system for your specific
situation—all from our Brisbane location. Our goal is to
work with our customers to design the best possible
solutions for the Australian coal seam gas industry
with proven technology, deep experience and
unparalleled service.
Level 24 AMP Place
10 Eagle Street
Brisbane, QLD 4000 Australia
Phone: +61 (0) 7 3303 8617 | Fax: +61 (0) 7 3303 8618
Mobile: +61 (0) 450123 699
www.globaloilfieldservices.com
Value delivered, guaranteed!
MERCER VALVES
SAFETY RELIEF VALVES
for CSM APPLICATIONS
•
•
•
•
Compressors
Separators
Scrubbers&Dehydrators
GasProductionPlants
andTransmissionLines
• Air,Gas&LiquidRelief
ASME VIII Division 1 certified
Field Proven Soft Seating
Threaded½”-3”,CtoKorifice
Flanged½”-4”,CtoMorifice
Modulating & Snap Pilots
Inletsizes1”-8”,DtoTorifice
and1½”-8”FullBorerange
Pressure and Safety Systems
Melbourne(03)96997355
[email protected]
Perth(08)92278744
[email protected]
36
Safety under
pressure: tendering
for major projects
As proving safety credentials becomes increasingly
important in being awarded major project service contracts,
Pressure and Safety Systems has adopted a ‘no harm’ policy.
In the competitive world of tenders for large-scale pipeline
project service contracts, proving your safety credentials is
becoming increasingly important.
L
arge-scale pipeline projects carry
with them significant risks to
workers, contractors, equipment
and assets as well as the environment.
Minimising these risks through a
coherent safety policy is critical to the
success of these projects.
In awarding contracts for the provision
of services on these projects, big
companies are increasingly looking to
the safety credentials of its potential
contractors and equipment suppliers.
Pressure and Safety Systems, an
Australian service partner which provides
Mercer Safety Relief Valves, has adopted
a ‘no harm’ policy to increase its chances
of winning contracts on major projects.
Engineering
Manager
Malcolm
Reeve says “We are passionate about
contributing to a ‘no harm’ environment
on Australian projects when supplying
our Mercer Safety Relief Valves.”
Mr Reeve says that Mercer Flanged
Safety Relief Valves are between 27 and
64 per cent lighter and are considerably
smaller than other conventional spring
operated valves, guaranteeing less
physical strain on all workers involved
in the fabrication of the wellhead skids,
onsite commissioning of skid valves
and long-term in-field maintenance of
the valves.
“Easier to handle valves ensure a
reduced risk of injury for employees and
contractors, and greater occupational
health and safety compliance,” says
Mr Reeve.
The valves also protect equipment and
assets as they are designed with a unique
Pressure and Safety Systems supplies
Mercer valves.
spherical seat which incorporates a soft
seat seal. Mercer valves are capable of
surviving rough in-field handling without
damage to the sealing capability of the
valve and, unlike other valves, are not
required to be transported vertically.
Equipment downtime is also minimised
with Mercer valves as they require no seat
lapping when an overhaul is undertaken.
Instead, a new seat is easily fitted in a
very short time and the valve can be
re-set and back in service extremely
quickly and all to manufacturers’ original
specifications.
Pressure and Safety Systems also
has a ‘no harm’ policy regarding the
environment. As Mr Reeve notes “It is
vital that as little gas as possible escapes
to the environment.”
Mercer valves are tested for zero
leakage at 95 per cent of set pressure.
Where old style metal-seated valves tend
to trap particles between the disc and
seat after blow-off, causing significant
leakage, the unique ‘lip seal style soft
seat’, ensures no loss of gas to the
atmosphere even after the valve has
operated many times.
Pressure and Safety Systems has offices in Melbourne, Perth and Brisbane.
For more information call 03 9699 7355 or visit
www.pressureandsafetysystems.com.au
FP Ad 11/21
Jemena is a leading national gas, water and
electricity infrastructure company. We not only
own major gas assets but we design, construct,
maintain and operate gas transmission and
distribution pipelines across Australia.
Jemena – we know the difference the best
solution makes.
www.jemena.com.au
orange is good
PPI: piping CSG
Hobson Stud Bolt Kits:
Combining experience, expertise and strategically located manufacturing facilities, PPI
knows how to service the coal seam gas industry; providing a wide range of polyethylene,
pipe and affiliated products.
W
ith the emergence of the coal
seam gas (CSG) sector as one
of Australia’s fastest-growing
industrial markets, polyethylene (PE)
pipe manufacturer PPI Corporation is
continuing to grow.
PPI has supplied PE pipe to numerous
CSG projects throughout Queensland and
New South Wales. Among these projects
is a QGC development near Chinchilla,
Queensland, for which PPI supplied over
300 km of PE pipe.
PPI has also supplied Delco Australia
(now known as WDS Oil & Gas) with
PE pipe for their contracts with Arrow
Energy. Delco Australia constructed the
gathering pipeline systems at Arrow
Energy’s Moranbah and Dalby CSG sites
in Queensland.
In New South Wales, PPI has supplied
PE pipe to AGL for use in the Camden area.
PPI has been manufacturing PE pipes
for nearly 30 years, providing pipe for
water, gas, slurry, drainage, irrigation, electrical and communications
purposes.
The company’s PE pipe range includes:
• Multiple pipe extrusion lines up to
800 mm in diameter;
• Manufacturing efficiency with high
quality extrusion equipment;
• A full range of electrofusion and welded
fittings up to 800 mm and SDR 7.4;
• Specialist products like Schedule 80
PE to steel transition fittings;
• Project management, production and
delivery scheduling;
• PE recycling capability; and,
• Full quality assurance/quality control
testing capability.
PPI also offers a range of fittings for
the expanding PE pipe market.
The company’s largest production
facility in Brisbane is able to efficiently
service key CSG areas in Queensland
as well as in the northern parts of New
South Wales.
As the only manufacturer of large bore
PE pipe in Adelaide, PPI’s upgraded
facility in South Australia is able to
service the needs of the local mining
industry. This site also enables PPI to
competitively service Victoria and the
Northern Territory.
For further information contact the
PPI Mining, Industrial, Civil sales
office on 07 3860 0388 or
email [email protected]
PE Pipe: Carrying the Future’s Water & Energy
PPI Metric poly pipe & fittings to 800 mm
P
StudBolts and Hex Bolts manufactured to ASTM A193/A193M and
A320/A320M. Heavy Hex Nuts manufactured to ASTM A194/A194M.
P
Tested in Australia by an independent NATA approved laboratory.
NATA Certificates available on request.
P
Accredited to ISO9001.
P
Material grades B7 | L7 | B16 | B5 | B6 | B8 | B8M | B8T
held ex-stock for fast delivery.
P
Fast reliable delivery on coated items (including Mechanical Plating,
Inorganic Zinc Silicate (ESSO Spec.), 1PX1 (Moly), Xylan 1424 Series
- Blue & Green, Cadmium plated, Zinc Plated and Hot Dip Galvanised).
FP Ad 12/21
Hobson Engineering is a leading supplier of the 3000lb and 6000lb High Pressure Fittings range
to the resource and commercial industries. Hobson supply M.E.G.A quality fittings.
Hobson High Pressure Pipe Fittings:
P
P
P
P
P
P
P
P
P
PPI Polyethylene
Strength and flexibility
38
PPI Corporation Pty Ltd -– Mining, Industrial & Civil
Sales Phone:
Sales Fax:
Email:
(07) 3860 0388
(07) 3860 0392
[email protected]
Manufactured from ASTM A105N steel.
Shell / Mobil / Caltex / Exxon approved product.
Swage Nipples manufactured to ASTM A234WPB MSS-SP95-86.
Seamless Pipe Nipples manufactured to ASTM A106B B36.10-95
Stainless Fittings manufactured to ASTM A182.
Threads according to ANSI/ASME B1.20.1.
Material according to NACE MR0175 / 2003
Lot trace number on each Fitting.
Test Certificates are available on line at www.hobson.com.au.
www.hobson.com.au
AS/NZS 4130
Lic21212
No.9000117
quality matters
The National Association of Testing Authorities ( NATA ) is Australia’s national laboratory accreditation authority. NATA accreditation
recognises and promotes facilities competent in specific types of testing, measurement, inspection and calibration.
Compensating for the
Joule-Thomson effect
By Brian Walkington, Grimwood Heating Managing Director
When choosing a direct electric heater, it is important to take many factors into consideration,
including the Joule-Thomson (J-T) effect. Grimwood Heating can analyse your process
conditions to accurately confirm the true J-T effect based on the gas composition.
What is the J-T effect?
Typically, the J-T effect refers to the
drop in temperature that occurs when
gas pressure is reduced.
The magnitude of the temperature
drop depends on the starting pressure,
the pressure change and the composition
of the gas. The J-T coefficient, or the
change in temperature per unit change
in pressure, is not a constant and is
highly variable for any particular gas
mixture depending on the starting and
ending conditions.
Heat tracing
Heat tracing involves wrapping a
heating cable around a length of pipe to
heat the pipe and its contents.
Heat tracing is simple to install,
requires no ongoing maintenance, and
can be retrofitted to an existing pipeline.
Disadvantages of this method are that it
can be difficult to get fine control with
variable flow, and it requires a reliable
power supply onsite.
Water bath heaters
Under large pressure changes, the
temperature of the gas or gas mixture
can fall to a point where the gas or a
component of the mixture starts to
condense into a liquid, or in extreme
cases to solidify (such as ice formation
where traces of moisture exist). This can
cause equipment to malfunction with
catastrophic consequences.
The way to prevent this is to preheat
the gas before the pressure reduction
so that the temperature after expansion
is above the saturation temperature of
components of the gas mixture.
A water bath heater is typically a
horizontal, cylindrical, water-filled tank
with a fire tube in the bottom and a gas
pipe serpentine through the water to
raise the gas temperature. Water bath
heaters may also be heated with hot oil.
While fine control is also difficult with
water bath heaters, they can operate in
remote sites with no electricity supply
and can use waste heat from other
processes. On the other hand, they can
be high maintenance, requiring repair
and replacement parts. The water must
be treated, and there can be issues of
corrosion. All these lead to planned and
unplanned downtime.
Gas heating options
Direct electric heating
Compensation
There are three main methods of
heating gas flows: heat tracing the
pipeline, a water bath heater, and direct
electric heating.
Finally, direct electric heating involves
electric elements in the gas stream to
heat the gas as it flows over the elements.
The benefits of direct electric heating are
Reliability? High.
its compact size, and therefore small
footprint. While this method does require
a reliable source of power onsite, fine
and accurate control is possible, which
maximises energy efficiency, especially
under fluctuating flow rates.
This method also requires no ongoing
maintenance, and therefore it has low
levels of downtime. Minimal heat is lost
during this process, and the method
is flexible in location – the unit can
be positioned at any angle, and can be
indoors and immediately adjacent to the
point of consumption to minimise ‘cold
slug’ on start up.
Total cost of ownership? Low.
Accurate? Without a doubt.
Why choose a Grimwood direct
electric heater?
FP Ad 13/21
Grimwood has the proven capability to
design and build direct electric heaters
to the highest and most stringent
standards in the world. It was the first
heater manufacturer in the world to
obtain an International Electrotechnical
Commission Explosive Certificate of
Conformity for these products.
Grimwood can design and build
the control system to heat gas to the
temperature required depending on the
flow rates, and inlet temperatures and
pressures without unnecessary and
wasteful overheating. The company can
deliver the heater with a short lead time,
reducing overall project lead time and
working capital investment.
the most reliable, easy to maintain and
cost-effective gas monitors in the world.
Why? Because our innovative gas detectors and DrägerSensors are designed and manufactured
by us for optimal performance. For the lowest cost of ownership of any single gas monitor, choose
our long-life Dräger Pac® 5500. The new Dräger Pac® 3500 provides 2-year maintenance-free
warning of H2S, CO, and O2 levels. Our reliable and easy-to-use bump test station provides workers with
confidence and protection they can trust.
Quality
ISO 9001
ContaCt us to reCeive 1 free Dräger PaC® 3500 or Dräger PaC® 5500 for every 2 you buy.*
*Limited time offer until 31st December 2010. Call 1 800-677-787 or visit www.draeger.com/gasdetectionoffer
pdf2146
40
Wollert Compressor Station.
APA: expanding pipeline system
capacity across Victoria and
New South Wales
From Young to Wagga Wagga, Wollert to Euroa, keeping regional Australia connected
to natural gas supplies is serious business for APA Group. The company is undertaking
expansion projects across its Victorian and New South Wales pipeline systems.
I
n 2008, construction of the Uranquinty
Power Station was completed. Located
on the Moomba to Sydney Gas Pipeline
southern lateral near Wagga Wagga, the
power station has significantly increased
gas demand on this section of the New
South Wales transmission system, and
required expansion pipeline infrastructure
to meet the increasing demand.
Since then, gas usage for the power
station has continued to increase and
a decision to further increase to the
capacity of the Young to Wagga Pipeline
was made in October 2009. This will
remove capacity constraints on the
Moomba to Sydney southern lateral, and
provide additional gas storage capacity
for the Uranquinty Power Station.
The existing Young to Wagga Pipeline,
constructed in 1981, provides gas supply
to towns in central south New South
Wales including Griffith, Cootamundra,
Young and Wagga Wagga. In 1998, the
18 inch Interconnect was built connecting
Bomen (Wagga Wagga) and Barnawatha
in Victoria, which enabled gas to flow
between the two states. The Young to
Wagga Looping project is designed to
additional provide flexibility of supply,
security of supply and gas storage.
Stage 1 of APA Group’s Young to Wagga
Looping project involves the construction of
61 km of 18 inch diameter gas
transmission pipeline from Bomen north
to Bethungra. The looping pipeline will be
positioned 7 m away from the operating
Young to Wagga Pipeline, with line valves
at Wantiool and Bethungra, and cross tieins at Bethungra and Bomen.
Construction contractor WDS Ltd has
mobilised approximately 115 people to
work towards the project’s completion,
expected by mid-November 2010.
42
Construction commenced on 25 May 2010
and has been affected by weeks of rainfall.
APA has also commenced the formal
approvals process for Stage 2 of the
looping project, which entails looping of
the Bethungra to Young section of the
Young to Wagga Pipeline, and will be in
a position to commence construction in
approximately October 2011 if necessary.
Navigating new project approval
regulations
The Young to Wagga Looping is the first
APA pipeline project to go through the
new NSW major projects approval Part
3A regulations under the Environmental
Planning and Assessment Act 1979.
“APA has gone through a very
detailed approval process including the
approval process for the Construction
Environmental Management Plan (CEMP).
We have also had to appoint an independent
Environmental Representative for the
project,” said Manager Projects New
South Wales, Australian Capital Territory
and Western Australia Prakash Mehta.
The Part 3A approval process required
preparation and submission of the
Environmental
Assessment
Report
(EAR). The EAR was placed on public
exhibition, and the submissions received
from the New South Wales Department
of Planning were responded to in the
Submissions Report.
The project was approved with conditions
of approval which were incorporated into a
CEMP, and are being implemented during
construction of the project.
Construction underway
Construction
crews
targeted
a
production rate in the order of 2 km of
pipeline per day.
Temporary facilities for the project
include site office and work areas for
material and equipment, workshop for
equipment maintenance, a dam to store
water for hydrostatic testing and borrow
pits to source additional fill material if
required.
Access tracks and additional gates have
been constructed to access the pipeline
easement and work areas and existing
roads, access tracks and disturbed areas
have been used to minimise disturbance
to the surrounding areas.
Installing compressors
in Victoria: the Wollert
Compressor Station upgrade
APA is also undertaking an upgrade of
the Wollert Compressor Station, designed
to expand capacity on the Wollert to Euroa
Pipeline on the northern section of the
Victorian Transmission System.
The Wollert Compressor Station
upgrade involves the installation of two
Solar Centaur 50 Low NOX emission gas
turbine driven compressors, fin fan after
coolers, gas filters and all associated
services and piping. Construction
commenced with earthworks in December
2009, with completion of the upgrade
scheduled for early November 2010.
The two Centaur 50 compressors will
supersede the existing three Saturn
compressors.
With
each Centaur
machine having more than five times
the capacity – 6,102 horsepower each –
of the older units, the station’s overall
capacity will be increased by over three
times. Provision has also been made for
further compressors in the future.
Following completion of the Wollert
Continued on page 44>
FP Ad 14/21
Compression project and the maximum
allowable operating pressure pipeline
upgrade project, the pipeline’s pressure
limit will be 8,800 kilopascals (kPa). The
new Wollert station has been designed for
10,200 kPa for potential future pressure
requirements.
3D modelling software was used to
virtually assemble the project before
construction. APA Manager Projects
Victoria Tom Carroll said “The use of 3D
modelling software has allowed for the
entire project to be assembled in the
virtual world before any construction
began.”
“The benefits of this technology
were apparent from early in the design
phase – allowing the end users to review
the entire project easily and have their
input – through to construction, with the
minimisation of site work as a result of
highly accurate design drawings,” he said.
The design of the Wollert Compressor
Station was influenced by APA Asset
Management and Engineering’s strategy
to standardise designs nationally across
all of APA’s future installations. Under the
new strategy all compressor stations will
be standardised across key deliverables,
site layout, diverging plant configuration
and equipment purchase.
Process Plant Solutions
• LNG Plants
• CO2 Capture
• Clean Fuel Technology
• Scrubbers
• Natural Gas Dehydration and
Fuel Gas Conditioning
Engineered Products
• Demisters
• Internals
Vessel Internals
• Mist Eliminators
• Ejectors and Eductors
Process Materials
Overall the project will involve the
installation of ten major equipment
items, 20 km of instrument and electrical
cable, 2.5 km of piping and 40 tonnes
of structural steel. Approximately
10,000 tonnes of reclaimed soil and
12,000 tonnes of imported select fill were
used to complete site levelling.
Keeping safe
Part of the design concept was to locate
the new station in a greenfield site, outside
the existing Wollert Compressor Station’s
operating assets, thereby minimising the
risk of construction personnel working
in the vicinity of live plant. This had
the combined benefit of allowing APA
operations personnel to continue with
their activities with minimal impact from
construction personnel.
APA’s permit-to-work system was
incorporated into the project, which
included completing a job safety analysis
for each job task prior to any work
commencing. Weekly toolbox meetings
are held with the contractors, co-ordinated
by the project specific safety officer, to
ensure any site issues are addressed
promptly and allowing a direct line of
communication between the work crews
and APA supervision.
 Design
 Consult
 Construct
 Install
 Commission
Using local labour
For all construction activities, local
labour was utilised and the majority of
plant, materials and equipment has been
procured from local suppliers. However,
the specialised nature of some equipment
meant that some items and raw materials
were sourced from outside Australia.
The main piping contractor, Skinner
Engineering, is located in Epping, approximately 15 km from Wollert, allowing for a
greater degree of connectivity to the site.
Hanson also supplied the imported
crushed rock from a local quarry, which
meant deliveries were timely and transport
costs were reduced.
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Avoiding the hot tap challenge
Although tie-in works were planned
carefully to avoid any hot tap works, a
station shutdown proved unavoidable. The
shutdown plan required approval from
multiple stakeholders prior to any work
commencing on site.
Gas needed to be sourced from New
South Wales to maintain the gas supply
commitments and the opening of valves to
ensure security of supply to the distribution
companies. The works were completed
early in 2010 before the higher demand for
gas brought on by the colder months.
www.gastoday.com.au
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Gas to the max: Wollert –
Euroa Pipeline gets an upgrade
Comdain Infrastructure has completed works on an APA Group upgrade of the pipeline
between the Wollert Compressor Station and the Euroa city gate in Victoria.
T
he upgrade has increased the
pipeline’s
maximum
allowable
operational
pressure
from
7.4 megapascals (MPa) to 8.8 MPa, and
has
therefore
increased
its
gas
transportation capacity into New South
Wales.
The upgrade project was initiated by the
installation of two new compressors at
the existing Wollert Compressor Station.
Comdain was responsible for the supply
and installation of mechanical, electrical
and instrumentation works completed
at the Euroa site, for future compressor
installation.
The
company
provided
labour,
materials, supervision, consumables, risk
assessments and work procedures for
main works including the fabrication and
installation of all main process gas piping,
valves and fittings. Comdain ensured
delivery of all pipe work, piping skids, piping
supports and all structural steelwork.
Comdain also led the inspection and
testing efforts, welding and testing
recording and environmental management
plans.
Comdain has said that the greatest
challenge faced during the works was
ensuring that there was no disruption to
the gas supply for the north. In order to
maintain supply, a bypass was constructed
at the Euroa site to enable continuous
supply while civil works were undertaken
onsite.
Another challenge was the fabrication
of a sizeable valve assembly, completed in
a Comdain workshop and then delivered
onsite.
Victoria’s cold weather during the
winter months of 2010 resulted in a
greater demand for gas, and increased the
potential risks associated with gas works.
The key risk is the potential for gas supply
to be interrupted. This is increased during
the cold weather because the increased
46
Driving the LNG highway
LNG is not only for export, as shown by BOC’s proposed
new ‘LNG highway’, to be constructed along Australia’s east
coast. Plant designer and builder Gas Liquid Processing
spoke to Gas Today about the first plant to be built and what
it could mean for other domestic LNG applications.
G
as Liquid Processing (GLP) is
currently constructing the microLNG plant in Westbury, Tasmania,
for BOC. Construction of the Tasmanian
plant is nearing completion. GLP
constructed the plant, along with the gas
supply pipeline infrastructure connecting
it to Tas Gas Networks’ Tasmanian Gas
Pipeline.
Mechanical,
instrumentation
and
electrical handover of the plant from GLP
to BOC is currently underway, with the
pipeline completed and ready to supply
gas to the plant.
Pre-commissioning
works
have
started with natural gas due into the
plant in November 2010, a delay on the
original timetable due to poor weather
and general ground conditions.
The micro-LNG plant has been
designed and built by GLP in modular
form. Plant modularisation helps speed
up the construction process and ensures
that site engineering and installation
hours are reduced.
Experience counts
Construction at the site of the upgrade project.
consumption of gas for heating increases
the potential for loss if a failure of supply
occurs.
Comdain said that risks were contained
by a risk assessment with APA Gasnet and
the Australian Energy Market Operator.
Comdain performed the job without
incident, within budget and on time,
according to APA Group Project Manager
David Thek.
“The timing of works at Euroa was
impacted by regulatory and operational
requirements,” Mr Thek said.
“The co-operative approach between
Comdain and APA on the project allowed
the impacts to be minimised, with
Comdain being able to react to changes
and reschedule works in consultation with
APA.
“This co-operative approach ensured that
APA had the ability to deal with operators
and regulators with confidence, and helped
to mitigate the impact of operational delays
to the project,” Comdain said.
Following on from the Westbury plant,
BOC has approached GLP to start the
engineering and procurement for the
new micro-LNG plant to be built near
Chinchilla, Queensland.
Earlier in the year QGC and BOC
announced that QGC would supply gas
from its coal seam gas (CSG) fields to
BOC starting from July 2011. This would
mean that the plant would become
the first in Australia to produce LNG
from CSG.
The GLP-designed plant will be the
first plant built on mainland Australia
dedicated to help provide an ‘LNG
highway’ along the east coast. This LNG
highway will involve a series of LNG
refuelling stations between Melbourne
and Brisbane. BOC is also currently
modifying its existing LNG plant at
Dandenong in Victoria to help service the
new refuelling stations.
As the Queensland plant is a copy
of the Westbury plant, modular skid
manufacturing time is reduced because
fabricators are simply replicating past
work. This results in a relatively small
front-end purification capital cost penalty
which is covered by the engineering and
fabrication efficiencies.
Developing domestic LNG
applications
Developing an LNG transport industry
can be difficult. Motor companies are
unwilling to produce LNG-powered
vehicles without a supporting LNG
supply network.
On the other side, refuelling station
developers are unwilling to finance and
operate LNG plants without a customer
base.
In committing to construct the LNG
plant, BOC is showing commitment to
the industry. Furthermore, each LNG
production site is sized to allow a further
train of the same size or larger to be
built, supporting future expansion needs.
The development also supports a new
area that is being investigated within
the industry, the ‘virtual pipeline’. This
concept involves LNG being trucked
to remote locations for use in onsite
power generation, or placement of the
LNG plant on a stranded pipeline before
trucking LNG to the end user.
The technology utilised and the
hazards involved in this process are well
known to companies like BOC and GLP
who have extensive experience in the
cryogenic and gas industries.
Half of the gas clean up process: the
absorber and stripper.
LNG storage tanks at the Westbury plant.
GLP is a wholly-owned private Australian engineering company. For more information on the
company and its projects, visit www.glp.com.au
BOC Limited is a member of the Linde Group
47
Pipeline technology ploughs
into the CSG industry
Pipe and Civil is introducing technology to Australia’s pipeline construction industry to
increase cost-efficiency and safety on projects while reducing environmental impacts.
P
loughing technology traditionally
used in the rollout of fibre optics
has been scaled up to provide a new
method of installing gathering pipelines.
The ploughing technology uses a unique
ripper and chute design to displace the
soil, and the guidance system then pulls
the pipe into the trench. Unlike open
trenching systems, the furrow in the earth
created by the plough closes quickly under
its own weight and is easily compacted.
A specially designed all-terrain, allweather mobile winch vehicle (FWF 80 and
FWF 82) pulls the plough vehicle (FSP 220
and 22) using a cable. The winch vehicle
is anchored into the ground, avoiding
the churning and mixing together of top
soils so often associated with tracked or
wheeled vehicles and trenching.
The plough vehicle’s every leg operates
independently, allowing the equipment
to work easily in undulating terrain. The
tip of the plough blade forms and clears
the laying bed at specific depths. Then,
using a patented guidance system, a pipe
insertion unit is dragged along the bed
and the pipe is inserted into the cavity
with minimal risk of damage.
Australia’s coal seam gas (CSG)
sector saw the arrival of the first
FSP 220 Fockersperger from Germany in
July 2010.
The plough is suitable for cable and
pipe from 315–600 mm in diameter, and
48
can bury the pipe at depths up to 2.5 m.
According to Director Brenton Euler,
Pipe and Civil is the first to bring this
new ploughing technology to Australia,
and in doing so will become the largest
pipeline and cable ploughing contractor in
the country.
“Pipe and Civil is always looking for
better ways to deliver our service, now by
applying this technology and customising
it to the local requirements we have once
again set ourselves apart from the pack
and are positioned as a leader in CSG
upstream gathering innovation,” said
Mr Euler.
“This new pipeline system will be more
cost-efficient in Australia because of
the increase in production capability. It’s
also safer due to the lack of open trench
and reduces the environmental impact
when compared to current pipeline
burial methods.
“A reduced construction easement
combined with lower levels of soil
disturbance is a win for the environment
and landowners,” Mr Euler said.
For more information contact
Pipe and Civil on 07 3262 4600
or visit the company website at
www.pipeandcivil.com.au
PIPE & CIVIL
FP 16/21
Image courtesy of AE&E Australia.
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fuel source, Condamine Power Station uses proven combined cycle technology to generate electricity more efficiently
than a coal-fired power station and produces significantly less greenhouse gas emissions.
Siemens have supplied two SGT-800 gas turbines and one SST-400 steam turbine for the power station. Whatever the
application, Siemens gas and steam turbines set the benchmark for efficiency, reliability and environmental compatibility,
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Innovation for generations.
CSG fires up at
Condamine Power Station
Situated 8 km east of Miles in the Murilla Shire in southern
Queensland, QGC’s Condamine Power Station is a smooth
amalgamation of green efficiency.
T
he
chief
attribute
of
the
140 megawatt (MW) Condamine
Power Station is that it operates in
combined-cycle power mode. The power
station has the capacity and capability
to generate electricity more efficiently
than a coal-fired power station, whilst
producing significantly less greenhouse
gas emissions.
Constructed by power plant specialists
AE&E Australia, Condamine Power
Station was Australia’s first combinedcycle power station to run entirely on
coal seam gas (CSG).
The plant comprises two Siemens
SGT-800 gas turbines, two AE&E heat
recovery steam generators and one
Siemens SST-400 steam turbine.
Hot exhaust gases are captured from
the gas turbines in order to generate
steam. The steam then powers a steam
turbine generator, producing additional
electricity without the need for additional
fuel. The power station also includes
a cooling water system and a water
treatment plant.
Civil & Allied Technical Construction
50
(CATCON) was contracted to supply inground structures and services for the
turbines.
Condamine Power Station operates
24 hours a day and produces a nominal
140 MW of electricity to the grid. The
location of the power site also optimises
fiscal and environmental efficiency by
allowing the easy supply of CSG and
water from neighbouring gas fields. This
significantly reduces the environmental
impact and carbon footprint that can be
left by conventional coal-fired power
stations.
The power station has the capability of
providing very efficient gas-fired electricity
to the National Electricity Market.
In 2010, Condamine Power Station has
reached several significant milestones
including the first synchronisation of
the Siemens SST-400 steam turbine
Turbo-Gen set to the National Grid
in February. In addition, R2 testing
of the SGT-800 units was completed,
with approval by the Australian Energy
Market Operator for connection to the
National Grid.
Construction of the oil retention facility.
Image courtesy of CATCON.
How do I generate electricity more
efficiently, while emitting fewer
harmful greenhouse gases?
Siemens
17/21
Gas
generating
interest in
NSW
and investment in greener energy
sources could soon become significantly
more attractive. These factors add up
to considerable potential for gas-fired
generation in the state.
Gas-fired power generation
in New South Wales could
grow significantly in the nottoo-distant future. Gas Today
looks at the state’s current
and potential gas generation
assets.
Current capacity
There are six operating large-scale
gas-fired power stations in New South
Wales with a combined capacity of
2,103.6 megawatts (MW).
The largest at 724 MW is Delta
Electricity’s Colongra Gas Turbine, which
opened in December 2009. This runs in
open-cycle configuration, as does the
next biggest station, Origin Energy’s
Uranquinty Power Station, which has a
capacity of 664 MW.
TRUenergy’s combined-cycle 460 MW
Tallawarra Power Station is located in
Yallah. Marubeni Australia operates
the 160 MW Smithfield Power Facility, a
steam turbine that runs on a combination
of natural gas and waste heat.
Energy Developments owns and
operates the two smallest turbines in
the state, the Appin Mine and Tower
Mine Power stations, at 55.6 and 40 MW
respectively.
I
t’s an eventful time for gas-fired power
generation in New South Wales.
The State Government is in the
process of partially privatising its energy
sector. Although it will maintain public
ownership of existing power stations and
electricity transmission and distribution
networks, electricity trading rights and
state-owned power station development
sites will be privatised. Bids for these
trading rights are due by 15 November
2010.
At the same time, activity is ramping up
in New South Wales’ coal seam gas (CSG)
industry. These new CSG developments
could mean that New South Wales
becomes self-sufficient in natural
gas supply or even becomes a net gas
exporter.
A report published in August 2010 by
Access Economics for the New South
Wales Innovation Council states “Gasfired generation, potentially fuelled by
CSG, will be crucial to meet base load
electricity requirements to 2020.”
Competition in the New South Wales
electricity market is set to increase,
domestic gas supplies are increasing,
electricity supplies need to be amplified
52
Next generation
Tallawarra Power Station emissions stack.
These six stations could grow to twenty
if all publicly-announced proposals for
gas-fired power stations go ahead. Along
with private developments, a total of seven
power station development sites are being
sold as part of New South Wales’ energy
reform process.
The sites are being sold individually,
concurrently to the sale of trading rights
for existing power generation assets,
which are being sold in bundles.
The largest proposed new developments are Macquarie Generation’s
Bayswater B Power Station and the
installation of two new units at Delta
Electricity’s Mount Piper Power Station.
Both developments are proposed to have
a capacity of 2,000 MW. Development approval for both stations is being sought
for either black coal or gas-fired power
generation. This would allow parties
acquiring the assets under the privatisation process to develop the stations using whichever fuel is preferred.
The next largest station is AGL’s Dalton
Power Station, an open-cycle power
station that could eventually have a
capacity of up to 1,160 MW. Although it
does not have development approval as
yet, AGL is progressing permit options. The
station is expected to be commissioned in
the last quarter of 2013.
Eastern Star Gas’ Wilga Park ‘A’ and
Wilga Park ‘B’ Power Stations, at 3 MW
and 29.4 MW respectively, are the nearest
to commissioning, which will take place
from the second quarter of 2011 through
to the fourth.
Conclusion
With the energy reform transactions
intended to be executed before the end
of 2010, the New South Wales energy
sector is under close scrutiny. Gas-fired
generation has emerged as an attractive
option as the state’s generation mix
changes and expands.
Fourteen new gas-fired power stations have been proposed for New South
Wales. The table below provides a brief overview of the proposals:
Proponent
Project
Capacity
Commissioning
date
AGL Energy
Dalton
1,160 MW
Q4, 2013
AGL Energy
Leafs Gully
360 MW
TBA
Delta Electricity
Bamarang
300 or 400 MW
2014
Delta Electricity
Marulan
350 or 450 MW
2014
Delta Electricity
Mount Piper units 3 & 4
2,000 MW
2014 or 2016
Delta Electricity
Munmorah Rehabilitation
700 MW
2014
ERM Power
Wellington
640 MW
Q3, 2013
International Power
Buronga
120-150 MW
TBA
International Power
Parkes Peaking Power Plant
150 MW
TBA
Macquarie Generation
Bayswater B
2,000 MW
2014
Macquarie Generation
Tomago GT
TBA
TBA
TRUenergy
Tallawarra B
450 MW
TBA
Eastern Star Gas
Wilga Park ‘A’
3 MW
Q2, 2011
Eastern Star Gas
Wilga Park ‘B’
29.4 MW
Q3–Q4 2011
Source: Australian Energy Market Operator 2010 Electricity Statement of Opportunities.
53
Coal seam gas:
the new Star of NSW
Eastern Star Gas has positioned itself as a key player in New South Wales’ burgeoning coal
seam gas industry as operator of the one of the most advanced CSG project in the state,
the Narrabri CSG Project.
N
ew South Wales has long been
seen as the state between two
major gas producers, but Eastern
Star Gas (ESG) is looking to change this
reputation. The state may even become
a net gas exporter, says ESG, if reserves
and resource upgrades continue at the
Narrabri coal seam gas (CSG) Project.
The project is located in PEL 238,
adjacent to the town of Narrabri. It is
located in close proximity to a number
of ESG’ other permits – PELs 6, 427,
428, 433 and 434, all situated within the
lightly-explored Gunnedah Basin. ESG
holds a 65 per cent interest in the project,
while joint venture partner Santos holds
the remaining 35 per cent.
Drilling in NSW
A key feature of the permit is the
vertically fractured architecture of
the target coals. While vertical wells
could not produce gas in the expected
volumes, ESG found that lateral wells
could realise the potential of the
coal seams. Following a number of
successful lateral pilots, the company
is looking forward to trialling a new
‘stacked multi-lateral pilot’ well design.
This design involves two or more lateral
wells targeting different seams being
drilled from the one location, allowing
very high gas recovery rates.
The permit’s location also protects
it from one of the key issues facing
Queensland’s CSG sector – water
management.
In
response
to
environmental concerns, the Queensland
Government recently passed legislation
on the management of CSG water, as well
as establishing landholder committees
in affected areas. Luckily, ESG’s primary
targets are completely surrounded by
layers of rock, which means that they are
isolated from regional aquifers. This also
means that CSG drilling for the project
will not affect the Great Artesian Basin
or the surface area.
“This development
schedule could see
LNG leaving the Port
of Newcastle as early
as 2014.”
ESG Managing Director David Casey.
Commercialising CSG
ESG is looking to commercialise the
Narrabri project in multiple stages.
ESG's Narrabri CSG Project.
Schematic of a stacked multi-lateral pilot well.
The first stage involves gas supply
to the 7 megawatt (MW) Wilga Park
Power Station, located in PEL 238. The
station is owned by the Narrabri joint
venture partners and supplies electricity
to Country Energy. A further 9 MW of
capacity will be installed at the station
in the first quarter of 2011. Although
conventional gas from PPL 3 provides
the majority of feedstock for the station,
pilot production gas from Narrabri is
also used, providing early monetisation
of the resource. Opportunities also exist
for further expansion of the station.
Approvals processes are underway
for commercialising gas under stages
2 and 3 of the Narrabri CSG development.
These stages would involve connecting
the project to existing pipeline
54
infrastructure, allowing gas to feed the
east coast market as well as other power
stations. Under stage 2, the Narrabri
development would be connected to
existing markets via a lateral to APA
Group’s Central Ranges Gas Pipeline.
Stage 3 would involve expanding this
domestic supply with pipeline extensions
from the Central Ranges Pipeline to
Bayswater, Tamworth and Wellington.
Underpinning this stage, ESG has three
Memorandums of Understanding (MoUs)
in place for the supply of a total of
1,700 petajoules of gas for power
generation, commencing from 2013.
ESG has signed an MoU with ERM for
the supply of 20 petajoules per annum
(PJ/a) of gas from 2013 to the 660 MW
Wellington Power Station. The company
has also signed an MoU with National
Power for supply of gas to a proposed
new gas-fired power station in northern
New South Wales. The proposed station
would require new connecting pipeline
infrastructure.
The final Narrabri development stage
involves looking at other ‘value-adding
opportunities’. ESG has entered into
an MoU with Hitachi Limited and Toyo
Engineering to investigate the feasibility
of an LNG plant in Newcastle. The
company has looked at alternatives,
including piping the gas to Gladstone
for use in CSG-to-LNG projects or
developing a gas-to-liquids or methanol
project.
However,
ESG
Managing
Director David Casey says, a Newcastle
LNG development is at present the most
attractive. APA Group will construct an
approximately 400 km CSG pipeline from
Narrabri to Newcastle.
Speeding towards trains
Although the results of the feasibility
study are not expected until the end of
2010, the company is rapidly progressing
the Newcastle option. An agreement has
been signed to acquire 24 hectares of
land on Kooragang Island, Newcastle,
and the company has raised $100 million
to progress the development. Following
the feasibility study, the development
partners are looking to progress frontend engineering and design work in 2011
to allow a firm commitment in 2012. This
development schedule could see LNG
leaving the Port of Newcastle as early as
2014.
Current gas reserves support a
one million tonne per annum (MMt/a)
LNG development, however the site has
the potential to expand to at least 4 MMt/a
of LNG. Having spent considerable effort
on exploration activities, Mr Casey says
that ESG is a company ready to transition
to development and production. In 2011,
the company will be completing gas
sales and LNG project agreements,
along
with
progressing
project
approvals and upgrading reserves to
support its ambitious plans for CSG in
New South Wales.
55
iGas: break-through
application for gas to fuel large
highway trucks
By Paul Whiteman, iGas Energy Holdings founder and Chief Executive Officer
The new, patented iGas system could drive a new generation of CNG-fuelled interstate
highway trucks, says Chief Executive Officer Paul Whiteman. He tells Gas Today all about
the technology and its application.
The science
How does the system work?
The key to the iGas process is to
maintain pressure in the CNG cylinder
as the gas is consumed by the engine.
This is achieved by displacing the gas
with a liquid in one CNG cylinder at a
time; this keeps the CNG at a pressure
that allows gas to be directly injected
into the engine.
Once all of the gas in a cylinder has
been used the liquid injection stops, the
valves are shut and the liquid is returned
to a low pressure tank. The process is
then repeated for the subsequent CNG
storage cylinders.
CNG is also a safe fuel and is
significantly lighter than air: unlike
LPG or liquid fuels, any leaks dissipate
quickly. CNG is a well established and
well understood fuel in Australia in buses
and small trucks, and is extensively
used overseas for these applications as
well as in cars.
There are four subsystems: the
hydraulic pack, the fuel pack, the liquid
tanks and the gas drying assembly.
• The hydraulic pack is fitted inside a
second battery box on the prototype
truck and it comprises a high
pressure metering pump which is
used to pump liquid into the CNG
cylinders. It is powered by a hydraulic
motor which in turn is powered by a
hydraulic pump fitted in tandem with
the truck’s power steering pump.
• The fuel pack comprises four CNG
cylinders, three air actuated valves
per cylinder plus two header valves
and a number of manual isolation and
re-filling valves. The fuel pack gives a
truck the same range as a 450 L tank
of diesel in a conventional engine.
• The liquid tanks holds approximately
What is the range of the fuel pack on
the prototype truck?
The prototype has four CNG cylinders
with a storage capacity of approximately
1,200 L of natural gas at 350 bar gauge
(barg). On an energy equivalent basis
this equals approximately 420 L of diesel
(105 L per cylinder) or approximately
450 L when the diesel pilot fuel is added;
so a typical semi trailer would get
approximately 900–1,000 km range and
a B double around a 600–700 km range.
We have layouts for up to seven
cylinders in configurations that will still
pull a maximum length B Double and up
to ten cylinders if we stretch the chassis
half a metre. Range is not really an
issue; it is more about weight and length
of the prime mover.
There are a number of refilling options
for the fuel pack, depending on the
application. The conventional method is
to connect the cylinders to a high pressure
gas compressor and let the gas flow into
the cylinders until the pressure reaches
the desired level. This will take around
30 minutes, subject to compressor
sizing.
We have also developed a nonconventional method that uses the liquid
displacement approach of the iGas
How much mass does the iGas
system add to a truck?
The prototype truck has a four cylinder
fuel pack which weighs approximately
1,200 kg when full of CNG. There is
another 100 kg in the hydraulic pack
and fuel conditioning system, and the
additional liquid for displacing gas weighs
approximately 400 kg. The total figure of
1,700 kg is offset by the reduction in diesel
fuel load and tanks, so approximately
1.35
tonnes
extra
weights
for
this configuration. An eight pack,
giving a range of
more than
1,300 km for a B Double would add
about 2.2 tonnes of extra weight.
Is the prototype running on the road?
The prototype is now registered for
road use, and has successfully towed
loaded trailers at highway speeds. The
CNG cylinders are registered for service
in Australia (they are made in the USA)
and an independent engineer has
certified the system as compliant and
suitable for use.
What happens if the truck runs out
of gas?
The HPDI injector contains both diesel
and high-pressure gas injection circuits.
On a typical HPDI truck operating cycle
diesel fuel consumption is approximately
5 per cent of the fuel energy, while the
rest is gas. To make this work properly
the diesel injection circuit is by necessity
very small and while it can run without
gas, the engine will only deliver about 10
per cent of its rated power for a short
time (ten minutes) on diesel alone. So
it can run on diesel in a limited manner
but cannot pull a load or operate for an
extended period of time.
If the truck runs out of natural gas,
the engine switches to diesel-only mode
and if the truck is on the road the driver
will need to pull over and stop. From
there, there are a number of options
including in-place refuelling or towing
the prime mover.
Continued on page 58>
The iGas Energy Truck with fuel pack.
350 L of a water-based solution that
is pumped into the CNG tanks at high
pressure to maintain the gas at the
required pressure for direct injection
into the engine.
• The gas drying assembly contains
two filters that remove water vapour
from the gas stream and a collection
arrangement to return any condensed
liquids back to the tank.
Paul Whiteman, former Chief Executive Officer and Managing
Director of EDL, is now founder and Chief Executive Officer
of iGas Energy Holdings Limited, a new company developing
a patented compressed natural gas (CNG) fuel storage and
delivery system to enable large high pressure direct injection
(HPDI) engined trucks to run on CNG.
He has been joined in the enterprise by Jim McDonald, former
Chief Executive Officer and Managing Director of the Australian
Pipeline Trust (now APA Group), and Derek Fekete, previously a
senior engineer with EDL. The iGas team has been working with
Westport to enable CNG to be used as fuel for the Westport GX
engine that uses HPDI technology.
EMICO_ad_HPH.indd 1
56
process that will allow faster refuelling.
In addition, we have developed the
concept of a changeover fuel pack; that
is where a truck pulls into the refuelling
terminal and the empty fuel pack is
removed and replaced with a full one.
This could reduce the time it takes to
refuel a truck to less than five minutes.
20/04/10 10:25 AM
57
Will the iGas system work in this
application?
Firstly, the Westport engine is proven
using LNG as a fuel. In this configuration,
the LNG is pumped up to high pressure
by a pump submerged in the LNG and
then piped to an evaporator where it
becomes CNG. It is then pumped to the
engine, so the Westport engine is really a
CNG engine, as it already runs on CNG in
LNG trucks.
Secondly, we have already proven
that the injection of liquid into the CNG
storage cylinder to maintain gas pressure
works. We initially undertook small-scale
testing to confirm the concept, and in
addition identified examples overseas
where the principle has been used in gas
compression going back several decades.
We are now focused on working through
the components and the process to refine
everything for absolute reliability and
commercial application.
Finally, it has in the past been a
challenge to get sufficient CNG storage
on a truck because of its relatively low
energy density. The iGas system operates
at 350 barg (5,076 pounds-force per
square inch gauge) which increases the
energy density over previous systems by
around 40 per cent. We intend that iGas
trucks will carry sufficient fuel onboard
to travel 1,000 km, and this prototype
demonstrates that capability.
Westport’s involvement
compress the air fuel mixture in the
cylinder. When diesel is injected near
the top, dead centre on the compression
stroke, it spontaneously combusts,
igniting the air/gas mixture.
While this works well if the engine is
not heavily loaded and at low percentages
of gas relative to diesel, the more gas
that is introduced the greater the risk of
spontaneous ignition before the diesel is
injected due to the heat of compression –
something that can have catastrophic
consequences for the engine. The more
gas that is introduced the greater the
potential for detonation.
The other problem with gas fogging
is over-fuelling. It is quite difficult to
limit the fuel required to meet the rated
horsepower of an engine when using gas
to supplement diesel in this manner. The
sophistication required to do this is often
not contained in gas fogging installations.
Bad experiences with gas-fogged
engine failures in the industry five to ten
years ago have affected the take up of gas
to replace or supplement diesel.
Gas fogging does provide greater fuel
flexibility. Trucks fitted with a gas fogging
system can still run on 100 per cent
diesel, however the whole point of the
iGas business case is to replace diesel
with gas to reduce the cost of fuel for
large trucks.
Advantages
Import replacement
As the engine supplier for the truck,
Westport has modified its control system
to allow the iGas system to operate without
the LNG tanks, pumps and vaporiser.
We have had extensive communications
with Westport over the past two years to
ensure that we understand the Westport
HPDI engine and controls fully, and that
they understand iGas.
From our research we believe vehicles
in the initial target market for iGas
burn around 4 billion L of diesel fuel
annually: almost all of this is either
imported refined or produced from
imported crude oil. Replacement of this
imported fuel with local natural gas has
the potential to reduce imports by over
$2 billion per year at current oil prices.
How do Westport HPDI engines
compare with other options?
Cost and availability
There is another option known as 'gas
fogging'. The Westport engine displaces
approximately 95 per cent of the diesel
with gas whereas gas fogging systems
generally achieve 50–60 per cent.
Gas fogging systems inject gas at
low pressure with the combustion
air, generally into the turbo inlet, and
Liquid natural gas is difficult to manage
and handle being held at temperatures
down to about minus 160 °Celsius. LNG
production requires an LNG plant, which
is expensive and needs to be of a large
scale to be cost effective. LNG also
requires insulated transport, as well as
expensive insulated storage vessels at
refuelling stations.
Young ones pipe up at Gas Speak
The Australian Gas Industry Trust (AGIT) welcomed 29 young members of the gas industry
to take part in the Gas Speak Colloquium, a three-day forum designed to encourage
awareness and knowledge of the gas industry in Australia.
CNG can be more attractive than
LNG in both availability and price. For
CNG all you need is a gas supply and a
compressor. There are numerous proven
products available from a range of
manufacturers at only a fraction of the
cost of an LNG plant. A CNG refuelling
point can be set up almost anywhere
there is gas supply.
We envisage a number of re-fuelling
stations will be established along the
national highway network where gas
pipelines and highways intersect. We aim
to lower the cost of interstate transport.
Held at Old Parliament House in
Canberra, Gas Speak provides a forum for
young professionals in the gas industry to
develop their presentation and sessionchairing skills. Each delegate presented
a paper on the topic of their choice, and
received feedback from a panel of mentors.
As Gas Speak was held concurrently with
the one-day Energy Networks Association
(ENA) Gas Seminar, the event was opened
by ENA Chief Executive Andrew Blyth.
Delegates spent Day One learning the
art of effective presentations, in sessions
designed to enhance and develop the
presenting skills of the delegates,
and enjoyed a tour of Old Parliament
House, in the afternoon. Following the
morning’s training, delegates were keen
to get back to their computers and make
some last-minute edits to improve their
presentations.
Mentors provided their time and
expertise to these very talented people
Santos' Ying Luo, winner of Best
Presentation.
and offered useful advice and tips on
presentation and communication skills, as
well as providing further insights into the
gas community.
The Gas Speak 2010 mentors included:
• Barbara Jinks – GHD
• Andrew Creek – Australian Gas Industry
Trust
• Steve Davies – Australian Pipeline
Industry Association
• Chris Blogg – Rinnai
• Shelley Reed – Australian Power and
Gas.
Among the high calibre presentations,
the following individuals took home the
Gas Speak 2010 awards:
• Ying Luo, Graduate Field Engineer with
Santos, won Best Presentation with
a talk on life at remote coal seam gas
sites.
• Michael Fox, Mechanical Engineer with
APA Group, won the Encouragement
Award.
• Jared Brown, HSE Adviser with DrillTec
Australia, took out Best Impromptu
Speech.
Environmental benefits
The Westport GX engine is currently
certified to Australian Design Rules (ADR)
80/02 standards and has approximately
50 per cent less particulate matter
emissions and 25–29 per cent less
greenhouse gas (GHG) emissions relative
to an equivalent diesel engine.
While everyone understands GHG
emission reduction as a key government
objective, the reduction in particulate
emissions (soot) from the exhaust stack is
also important. This is a major emission
and health issue that has been tackled
so far by upgrading the diesel refining
process to reduce sulphur content in fuel.
Westport has recently certified the
GX 15 L engine to ADR 80/03 standards,
which comes into force in January 2011.
How, when, where?
• iGas expects to have two trucks up and running by Christmas 2010.
• Trucks will likely be offered as tow-operator vehicles before the fuel system is available to
other parties.
• Patent is approved in Australia, pending for North America and European Union.
58
Gas Speak delegates and mentors.
59
2010 FutureGAS Gala Dinner.
A new, larger exhibition space will allow for
over 50 booths.
Get ahead – get to
FutureGAS 2011!
The business program will be expanded in 2011 to include a technical stream.
Australia’s whole-of-industry gas conference and exhibition, FutureGAS 2011, is returning
to Brisbane in March with an expanded program, larger exhibition and the ever-popular
networking events.
F
utureGAS, Australia’s premier gas
industry event, is returning in 2011
from 22–24 March, bigger and better
than ever before.
Following on from the success of the
2010 event, FutureGAS 2011 is moving to
the Brisbane Convention and Exhibition
Centre to accommodate the rapidly
growing number of exhibitors, delegates
and trade visitors.
Event Partner MWM Energy, a leading
provider of high-efficiency gas engines in
Australia, is returning for the third year as
Event Partner.
Being involved in multiple segments
of the gas industry in Australia, and as
one of the largest independent engine
manufacturers in the world, MWM well
recognises the need to share knowledge
across sectors.
MWM’s continued support demonstrates
the benefits reaped from sponsorship and
attendance at FutureGAS.
The event brings together all sectors of
the industry, from exploration, production,
transmission,
power
generation,
distribution, and end users.
It’s an exciting time for every sector of
the industry. Interest in unconventional
gas is heating up, while a number of
major LNG developments are entering the
final approval stages, and construction
on major gas projects pushes ahead.
The short-term trading market has been
launched in Sydney and Adelaide, with
Brisbane to join in 2011.
All of this adds up to a need to keep
informed about issues and developments
in the industry. FutureGAS provides this
unparalleled opportunity.
Expanded program
In addition to the two-day business
stream, this year’s event will feature
a one-day technical stream. While the
business stream will feature key industry
figures from government, business and
industry associations, the new technical
stream is tailored to the specific
needs and interests of engineering
professionals.
Special registrations will be available
for delegates wishing to attend the
technical stream.
The business stream features speakers
providing invaluable experience and
insight, including the recently-appointed
Queensland Gas Commissioner, Kay
Gardiner, and DomGas Chairman and
Western Australian Director for ERM
Power Tony Peterson.
The technical stream will hear from
–among others – CSIRO Theme Leader
Gas and Geothermal Research Dr Jim
Underschultz on research in coal seam
gas.
The full program is soon to be
released – keep an eye on Gas Today and
www.futuregas.com.au for all the details.
Delegates from the 2010 event
particularly noted the opportunities
these events provided to expand their
professional networks. With even more
attendees anticipated for the 2011
events, this is a networking opportunity
not to be missed.
Having moved to accommodate
a greater number of exhibitors, the
exhibition hall will host over 50 booths,
allowing even greater opportunities for
engineers, procurement leaders and
other industry members to speak directly
with suppliers.
In addition, the free-to-attend exhibition
will be open until 7 pm on one of the
conference days to allow trade visitors to
drop by after work to meet the industry.
As the industry pushes forward,
FutureGAS grows with it, an unmissable
forum for members of every sector of the
Australian gas industry.
Opportunities are still
available for interested
exhibitors and sponsors –
for more information
or to book a booth,
call 03 9248 5100 or visit
www.futuregas.com.au
Earlybird special
registrations will be
available until 21 January
2011, offering exceptional
value for money. Visit
www.futuregas.com.au for
more information or
to register.
Meet the industry
Networking at the Opening Cocktails.
60
Returning this year are the extremely
popular networking functions, which
include the Opening Cocktails and the
industry highlight networking event of
the year, the Gala Dinner.
61
LNG in focus at SEAAOC
Australia’s offshore industry gathered in Darwin for the South East Asia and
Australia Offshore Conference, held from 22–24 September 2010.
INPEX Darwin General Manager Sean
Kildare.
D
elegates descended on Darwin to
attend the two-day South East Asia
and Australia Offshore Conference
(SEAAOC), held for the offshore petroleum
sector.
In the opening session of the
conference
Federal
Minister
for
Resources and Energy Martin Ferguson
noted the significance of LNG projects
in the Northern Territory and across
Australia.
“Australia exported nearly 15.5 million
tonnes of LNG in 2008–09. By 2029–30,
LNG exports are projected to increase to
109 million tonnes [per annum], or about
700 per cent.”
Talk of LNG continued throughout
Day One, with presentations from major
LNG project proponents including
ConocoPhillips, INPEX, Shell, Santos,
QGC and ExxonMobil.
Other presentations covered a range
of topics including project case studies,
market and economic outlook for
offshore projects, and a brief insight into
unconventional gas projects in Australia.
Australian conventional and non-conventional gas
opportunities look bright, delegates heard at the Australian
Pipeline Industry Association’s Annual Conference
and Exhibition in Darwin, Northern Territory, from
11–14 September 2010.
H
Federal Minister for Resources and Energy
Martin Ferguson at SEAAOC.
ENA Gas Seminar
By Dale Weber, ENA Director, Gas and Energy Market Developments
The Energy Networks Association Gas Seminar 2010 was held in Canberra on
12 October 2010 at Old Parliament House. ENA Director Gas and Energy Market
Developments Dale Weber reflects on the event.
O
ur intention was to run a thought
provoking seminar that examined
the key question: Is natural gas the
next big thing, or has its time come and
gone?
In a joint opening session with the Gas
Speak Colloquium, the keynote address
was delivered by the Minister for Energy
and Resources Hon. Martin Ferguson.
The Minister recognised that gas has
a significant role to play in Australia’s
future, in both domestic and export
markets, particularly in light of the focus
on reducing greenhouse gas emissions.
It was also acknowledged that industry
has an important role to play in issues
such as establishing a price on carbon
and in working with government in
identifying the barriers to increasing the
62
uptake of natural gas for road transport.
The industry keynote address, Natural
gas now and into the future, was delivered
by Ian Little, Managing Director of
Envestra. Mr Little’s speech included
important insights into some of the
key issues facing Envestra including
regulatory barriers to investment, and
workforce skills and planning.
Mark McKenzie from Rare Consulting
presented the draft strategy for
Australia’s
natural
gas
industry
commissioned by the Energy Networks
Association (ENA). The strategy – helping
to secure Australia’s energy future in a
carbon constrained economy – is built
around three strategic opportunities: to
improve Australia’s energy security; to
reduce greenhouse gas emissions; and
New gas opportunities
on agenda at APIA 2010
to fast track renewables and distributed
generation.
Both Ben Wheaton (WheatonBeer
Consulting)
and
Karen
Masnata
(PricewaterhouseCoopers)
discussed
natural gas’ role in the energy mix with
respect to renewable energy sources.
After lunch, sessions were held on
bringing new products to market, policy
and regulatory issues, and upstream gas
market perspectives.
In conclusion, natural gas will play a
significant role in Australia’s energy future,
but there is a lot of work to do, not the least
in terms of working with government in
shaping appropriate policy settings and
working with key industry and non-industry
stakeholders to implement the strategy for
Australia’s natural gas industry.
eld at the Darwin Convention
Centre, the conference – whose
host sponsors included APA Group,
BlueScope Steel, Bredero Shaw, CNC
Project Management, Sargent and Vermeer
– included an opening address from
Territory Chief Minister Paul Henderson
and a keynote speech from 2005 Young
Australian of the Year, Khoa Do.
Australian
Pipeline
Industry
Association (APIA) President Peter
Cox welcomed delegates on Monday
morning, noting that the industry
is facing unprecedented challenges
and opportunities. Dampier Bunbury
Pipeline’s Mark Cooper continued the
theme, discussing how natural gas needs
to be recognised as an industry in itself,
rather than as an industry segment.
The opportunities presented by coal
seam gas (CSG) were the key topic
of Monday afternoon, during which
time delegates heard from speakers
including OSD's Paul Beukelman and
AJ Lucas’ Ben Cooper, who discussed
the Wallumbilla to Gladstone pipeline
looping in Queensland, and the potential
impact of the state’s four proposed
42 inch diameter pipeline projects for
extraction of CSG.
Tuesday’s program was jam-packed,
featuring sessions on research and
training, pipeline operations issues,
construction
and
innovation,
and
environment and safety.
The exhibition featured 68 companies
from all areas relating to the industry,
including
recruitment,
equipment
suppliers,
service
providers
and
trenchless technology specialists.
The conference also provided plenty
of opportunities for delegates to
network and explore Darwin. Saturday
was dedicated to golf and a Welcome
Dinner, while Sunday featured an outing
to Crocodylus Park and the conference
Opening Dinner. In a tribute to Darwin’s
namesake, guests dressed as their
favourite ‘Charlie’ at Monday’s Fancy
Dress Dinner, while Tuesday’s APIA
Annual Dinner concluded the conference
with smiles all around.
APIA Chief Executive Cheryl Cartwright
welcomes guests to the Convention
Opening Dinner.
Senator Mathias Cormann opened the
Exhibition.
Calendar of events
DATE / VENUE
EVENT
CONTACT
22–24 March 2011
Brisbane Convention and Exhibition Centre, QLD
FutureGAS
www.futuregas.com.au
10–13 April 2011
Perth Convention and Exhibition Centre, WA
Australian Petroleum Production &
Exploration Association Conference
and Exhibition
www.appeaconference.com.au
4–7 September 2011
EcoGen 2011
www.ecogen2011.com
22–25 October 2011
Sydney Convention and Exhibition Centre
APIA Convention 2011
www.apia.net.au
3–6 October 2011
No-Dig Down Under 2011
www.nodigdownunder.com
12–14 September 2011 (TBC)
Gas Speak Collquium 2011
www.agit.org.au
63
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GAS Today / November 2010

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