Page 1
WORLD ALLIANCE FOR DECENTRALIZED ENERGY
In Association With
March - April 2015
CONDITION MONITORING TECHNOLOGIES GET SMARTER n CONVERTING A CHP PLANT FROM COAL TO BIOMASS n HOW
ENCLOSURES IMPACT COGENERATION’S EFFICIENCY n WILL EUROPE’S ENERGY UNION HELP DECENTRALISED ENERGY?
Solar takes off at India’s airports
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Contents
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com2
Volume 16 • Number 2
March - April 2015
8
18 On-site solar takes off at India’s airports Projects are underway in India to install captive solar photovoltaic power systems at the
country’s airports, exploiting innovative funding models and long-term power purchase
agreements.
By Raghavendra Verma
18 Condition monitoring systems get smarter Effective condition monitoring has always been key to plant reliability, but the advances of
the digital age are opening up new horizons and the possibility for feet-wide management
of gas turbines and balance of plant equipment.
By David Appleyard
24 Making the switch from coal to biomass With specifc modifcations, a bituminous coal-fring combined heat and power system can
be converted to operate with wood or other biomass pellets. We fnd out what’s involved in
one such switch at Dong Energy Thermal Power’s Studstrupvaerket plant in Denmark.
By Thomas Krause and Yaqoub Al-Khasawneh
28 Enclosures and effciency Most cogeneration installations are housed in an enclosure, which can be a container or a
special boiler house. Here we show how the setup of an installation’s enclosure can affect
its effciency.
By Dr Jacob Klimstra
Features
WORLD ALLIANCE FOR DECENTRALIZED ENERGY
In Association With
March - April 2015
CONDITION MONITORING TECHNOLOGIES GET SMARTER n CHP FUEL CONVERSION: FROM COAL TO BIOMASS n HOW
ENCLOSURES IMPACT COGENERATION’S EFFICIENCY n WILL EUROPE’S ENERGY UNION HELP DECENTRALISED ENERGY?
Solar takes off at India’s airports
On the cover: On-site solar photovoltaics are increasingly powering India’s airports. See
feature article starting on page 8. COVER ART: Keith Hackett
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www.cospp.com Member, BPA Worldwide
www.cospp.com
ISSN 1469–0349
Chairman: Frank T. Lauinger
President/ Chief Executive Offcer: Robert F. Biolchini
Chief Financial Offcer/
Senior Vice President: Mark C. Wilmoth
Group Publisher: Rich Baker
Publisher: Dr. Heather Johnstone
Managing Editor: Dr. Jacob Klimstra
Associate Editor: Tildy Bayar
Consulting Editor: David Sweet
Contributing Editor: Steve Hodgson
Design: Keith Hackett
Production Coordinator: Kimberlee Smith
Sales Managers: Tom Marler, Natasha Cole
Advertising:
Tom Marler on +44 (0)1992 656 608
or [email protected]
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Published by PennWell International Ltd,
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Gunpowder Mill, Powdermill Lane,
Waltham Abbey, Essex EN9 1BN, UK
Tel: +44 1992 656 600
Fax: +44 1992 656 700
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Web: www.cospp.com
Published in association with the World Alliance for Decentralized Energy (WADE)
© 2015 PennWell International Publications Ltd. All rights reserved.No part of this publication may be reproduced in any form orby any means, whether electronic, mechanical or otherwiseincluding photocopying, recording or any information storage orretrieval system without the prior written consent of the Publishers.While every attempt is made to ensure the accuracy of theinformation contained in this magazine, neither the Publishers,Editors nor the authors accept any liability for errors or omissions.Opinions expressed in this publication are not necessarily those ofthe Publishers or Editor.
Subscriptions: Qualifed professionals may obtain freesubscriptions by visiting our website at www.cospp.com andcompleting an online subscription form. Extra copies of theseforms may be obtained from the publisher. The magazine mayalso be obtained on subscription; the price for one year (sixissues) is US$133 in Europe, US$153 elsewhere, including airmail postage. Digital copies are available at US$60. To start asubscription call COSPP at +1 847 763 9540. Cogeneration andOn-Site Power Production is published six times a year by PennwellCorp., The Water Tower, Gunpowder Mill, Powdermill Lane, WalthamAbbey, Essex EN9 1BN, UK, and distributed in the USA by SPP at 75Aberdeen Road, Emigsville, PA 17318-0437. Periodicals postagepaid at Emigsville, PA. POSTMASTER: send address changes toCogeneration and On-Site Power Production, c/o P.O. Box 437,Emigsville, PA 17318.
Reprints: If you would like to have a recent article reprinted for aconference or for use as marketing tool, please contact Rae LynnCooper. Email: [email protected] .
18
4 Editor’s Letter
6 Insight
7 WADE Comment
34 Genset Focus
36 Diary
36 Advertisers’ Index
Regulars
28
Executive Profle
Opinion
14 Cogenco’s Trevor Atkins Trevor Atkins is Head of Operations at UK utility Veolia’s specialist packaged combined
heat and power subsidiary, Cogenco. We speak with him as he prepares for retirement
after 20 years in the CHP sector.
By Tildy Bayar
13 The case for LPG in the industrial sector When it comes to industrial environments, which could be in rural or off-grid
locations, switching to liquefed petroleum gas (LPG) can deliver both fnancial and
environmental benefts.
By Rob Shuttleworth
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com4
Editor’s Letter
Proven cogeneration technology serving the industry well
In early February this year, I had the privilege
of attending a celebration of one million
successful running hours accumulated
by four cogeneration units at a factory in
Roermond, The Netherlands. It was a very
pleasant event with a happy customer and
a happy supplier.
The cogeneration units have been in
operation since 1983, and I well remember
all the efforts we took in those days to
promote cogeneration. The monopolistic
electricity companies initially tried to block
the connection of local generators to the grid.
They feared voltage and frequency instability,
and were afraid that any generator not
controlled by them would create safety issues.
Fortunately, we could convince the authorities
that increasing the number of generators on
the grid would improve the security of supply
as well as the frequency stability.
The big advantage of cogeneration,
of course, was and is the substantial fuel
savings compared with separate generation.
Nowadays, grid connection for local
generation is generally accepted. The factory
in Roermond expects many years of successful
operation to follow.
The four cogeneration units supply
electricity and heat for a factory that
processes an amazing 600,000 tonnes of
recycled paper per year, turning it into useful
products. The prime movers are modifed
aero-derivative gas turbines running at
14,250 rpm. According to the manufacturer,
many people initially doubted that such light
machines would really show high reliability
and durability. Some engineers might have
thought that a single large industrial unit
would prove a better solution.
However, all doubts have been removed.
The overhaul interval is only once every
45,000 hours. If needed in case of a calamity,
a turbine can be exchanged in one day.
The concept of having four units in parallel
offers high supply reliability. At this factory,
the match between electricity and steam
production on the one hand and demand
on the other is close to perfect. One unit is
equipped with supplementary fring to create
some extra fexibility in steam production. The
factory has received a number of awards for
its environmental friendliness.
A rough calculation reveals that,
compared with separate generation, this
cogeneration plant emits about 15 kilotonnes
less CO2 per year. One might argue that
30 MW in wind turbine capacity can achieve
the same reduction in CO2 emissions.
However, the output from wind turbines is
highly volatile, so the Roermond factory, with
its steady energy demand, could never run
on wind power alone. Yet the owners of wind
turbines receive substantial subsidies, while
the economy of the cogeneration plant
currently suffers from artifcially low electricity
prices and artifcially high gas prices. Soon
we will have a discussion with the responsible
ministry in The Netherlands about this unfair
situation. Hopefully the talks will result in more
favourable conditions for the country’s many
cogeneration plants.
Notwithstanding the low fnancial benefts
of cogeneration in the current climate, the
management of the Roermond factory
is investing in upgrading the installation’s
control systems and counting on many more
happy running hours. Being the energetic
and environmental benchmark for the
European paper industry is highly rewarding
in itself, and is seen as a positive asset by
customers. The cogeneration installation is a
prime example of a reliable technology that
can provide its services for many years.
Cogeneration is still one of the better
options to save primary energy and to
reduce greenhouse gas emissions.
PS: Visit www.cospp.com to see regular news updates, the current issue of
the magazine in full, and an archive of articles from previous issues. It’s the same website address to
sign-up for our fortnightly e-newsletter too.
Dr Jacob Klimstra Managing Editor
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com6
Insight
Stop wasting Europe’s heat
There is much to encourage
Europe’s cogeneration and district
energy industries in the European
Commission’s launch of a strategy to
achieve what it calls a ‘resilient Energy Union
alongside a forward-looking climate change
policy.’
The EC’s vision of an Energy Union is
all about maximising fexibility of energy
systems across the continent in order to cut
primary energy use and thus reduce imports.
This is to be achieved by new rules that
ensure energy users having more choice of
suppliers; the phasing out of poorly designed
subsidies; and energy fowing freely across
national borders. But the EC also points to
a fundamental rethink of energy effciency
– seeing it as a resource in its own right;
and ensuring that locally-produced energy
– including renewables – can be absorbed
into energy grids.
Europe is the largest energy importer in the
world, importing around 53% of its energy at
an annual cost of €400 billion ($443 billion),
so any way to reduce these imports is to be
welcomed.
Trade association COGEN Europe has
emphasised the obvious connection
between high-effciency cogeneration
technology, heat, and the need to cut
energy imports. Just a day after the EC
announcement, the association issued its
own manifesto calling for heat to be taken into
account thoroughly in the EC’s work towards
the union. Fundamentally, cogeneration
works by recovering and putting to use what
would otherwise be enormous quantities of
‘waste’ heat discarded at thermal power
plants.
COGEN Europe also refers the EC back to
the results of the recently-completed CODE 2
project, which estimated that cogeneration
could double in size to generate one-ffth
of the EU’s electricity by 2030, employing a
growing proportion of renewable fuels and
delivering substantial primary energy savings.
The amount of Europe’s heat supplied by
cogeneration would grow by half, and CO2
emissions would be cut substantially.
But market barriers to the wider uptake
of cogeneration and district energy remain.
Apart from recent poor spark spreads, the
main challenge for cogeneration remains
overcoming energy market failures which
expose CHP operators to variability of both
electricity and fuel markets. Achieving a
reasonable business proposition for CHP
developers and operators straddling these
two energy markets is still the single biggest
challenge for the sector, concludes the
CODE 2 report.
COGEN Europe’s new heat manifesto calls
for the EC to use an integrated approach
to the energy system, where heating and
cooling are taken into account at the start
of any process towards new legislation. Any
new European heating and cooling strategy
must interact genuinely with the power and
fuel supply sectors in order to overcome the
main barriers to cogeneration.
The manifesto also calls for the tracking of
primary, not just fnal, energy consumption,
and in particular the massive losses
occurring in power systems, by EU member
states. As COSPP readers will already know,
something approaching two-thirds of the
primary energy supplied as fuel to coal-
fred power plants is lost as waste heat or,
put another way, more heat is discarded at
power stations than is used to heat buildings
in many countries.
Integrate heat with power policies, and
take proper note of energy system wastage
– if the EU takes note of this advice from
the industry, its move towards a new Energy
Union will also beneft the decentralised
energy industry.
Steve Hodgson Contributing Editor
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www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 7
Comment
Fifty Shades of CHP
The precipitous drop in
energy prices is having
repercussions throughout
the energy industry,
and nowhere is this felt more
profoundly than in the energy
capital of Houston, Texas. In
the US we have 50 states, each
of which has a distinct market
profle for CHP and distributed
power generation. While the
Texas economy has diversifed in
recent years, it is still very much
an energy town and when prices
fall as far and as fast as they
have, there is going to be some
pain experienced. It is estimated
that there could be 130,000 job
losses in Texas by this summer
as a result of the drop in energy
prices. While energy prices seem
to be slightly rebounding, natural
gas prices remained remarkably
low throughout the winter in the
US, notwithstanding the record
low temperatures and snowfalls
that many parts of the country
experienced.
The fip side of this price
slide is that interest in effciency
measures, such as CHP, is
escalating as companies look for
solutions to increase productivity
and reduce costs. WADE is having
a conference this April that will
focus on CHP for the industrial
sector and the many new
opportunities for CHP in areas
such as oil and gas, chemicals,
processing and others. We will
hear from none other than Pat
Wood, a Texan who served as
Chairman of the Federal Energy
Regulatory Commission in
Washington and who currently
serves as Chairman of the Board
of the power company Dynegy.
In addition, neighbouring
Mexico is undergoing an energy
renaissance as it opens up its
markets to foreign investment,
which is creating a range of
opportunities for energy projects
and infrastructure.
The US energy boom has
created a remarkable industrial
expansion in the Gulf Coast
area. According to the American
Chemistry Council (ACC),
the shale-related chemical
investment has offcially topped
$100 billion which will create
55,000 permanent jobs in the
chemical sector.
While the Obama
administration is giving out mixed
messages on energy policy, with
the recent veto of a bill that
would have allowed the Keystone
Pipeline project to move forward
and announcement of methane
regulations that will impact the
natural gas production and
delivery sectors, the Executive
Order that articulated a goal
to increase the use of CHP in
the United States by 40 GW
by 2020 remains in effect. The
Clean Power Plan announced
by the EPA will also create new
and signifcant opportunities
for CHP, as it can be used as a
mechanism for compliance with
the new emission targets.
While the US is comprised
of 50 unique states and there
are 50 shades of the market for
decentralised energy throughout
the country, we are excited by the
strong opportunities that lie in the
Gulf region and with industrial
customers. We hope that you
can join us in Houston.
David Sweet
Executive Director
World Alliance for
Decentralized Energy
[email protected]
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com8
On-site renewables
The Airports Authority
of India (AAI), which
is owned by the
Indian government,
plans to generate 50 MW
of electric power from solar
plants at 30 airports by the
end of 2015. A communiqué
issued in May 2014 noted
that the plan was designed
to reduce the sector’s
dependence on India’s
unreliable grid power and
eschew supplementary
diesel generators.
At least eight of India’s
130 airports, including those
owned by private companies
such as the Indira Gandhi
International Airport in the
capital, New Delhi, already had
functional solar power systems,
operating smoothly before
the announcement of the
solar expansion plan. Other
Indian airports already ftted
with solar power systems or
currently obtaining such power
sources include Indore city’s
Devi Ahilyabai Holkar Airport,
Raipur’s Swami Vivekananda
Airport, Bhubaneswar’s
Biju Patnaik International
Airport, Bhopal’s Raja Bhoj
Airport, Amritsar’s Sri Guru
Ram Dass Jee International
Airport, Chandigarh
Airport, Ahmedabad’s
Sardar Vallabhbhai Patel
Projects are underway in India to install captive solar photovoltaic (PV) power
systems at the country’s airports, exploiting innovative funding models and long-
term power purchase agreements. However, the country’s grid power operators
are refusing to purchase any excess power, fnds Raghavendra Verma
On-site solar powering India’s airports
Cochin International Airport in Kochi plans to add 12 MW in additional solar power capacity Credit: Cochin International Ltd
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www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 9
On-site renewables
International Airport,
Guwahati’s Lokpriya Gopinath
Bordoloi International Airport,
Hyderabad’s Rajiv Gandhi
International Airport and
Jaisalmer Airport.
Of course, India’s move
towards airport solar power
is far from unprecedented,
with other airport industries
worldwide assessing its beneft.
In November 2010, for instance,
the US Federal Aviation
Administration (FAA) said that
‘airport interest in solar energy
is growing rapidly as a way
to reduce airport operating
costs and to demonstrate a
commitment to sustainable
development’, and issued a
technical guidance paper
promoting the idea.
Generating on-site solar
power is a particularly an
attractive proposition in India,
which receives signifcant
sunshine during most of the
year and suffers from chronic
power shortages, leading to
unreliable grid supplies.
India’s new Bharatiya Janata
Party (BJP)-led government,
elected in 2014, has plans for
expanding solar energy of all
kinds. It has already approved
25 large (non-airport) solar
energy projects, with a note
from its Ministry of New and
Renewable Energy (MNRE)
saying it wants to develop
20,000 MW of solar power
capacity nationwide by 2019.
Each megawatt of solar
power generating capacity
requires 1.8 ha of land and
costs $1.3 million in investment,
Rakesh Kalra, regional
executive director of the AAI,
told COSPP.
In most of the ongoing
solar power projects, the AAI
has not invested up front, but
is making deals with solar
power companies to install
and maintain the plants.
Kalra said it was possible that
airports might invest their own
money, rather than under a
build-own-operate basis, but
with a lifespan of 25 years,
either system should be
“cost-effective.”
The cost of grid power
in India has been rising
continuously. For example,
according to a note from
India’s recently replaced
Planning Commission, power
tariffs for use in commercial
establishments rose by 19%
between 2008 and 2012.
According to Kalra it is
expected to continue to do
so, while the cost of electricity
from existing solar plants
should either remain constant
or even fall.
Airports lead the way
Delhi’s Indira Gandhi
International Airport – which
is owned and operated by
Delhi International Airport
Private Limited (DIAL) – started
operations of its 2.14 MW
solar power plant in January
2014. The plant includes
8736 PV modules of 245 W
each, which have an anti-
refective coating to avoid
distracting landing aircraft
crew. They are mounted on
galvanised iron structures that
can be tilted in three positions
to adjust with the seasonal
changes in the sun’s position.
Spread over 3.64 ha
and running parallel to the
4.43 km runway ‘11/29’, the
solar modules are connected
to 16 combiner boxes, which
use 630 kW inverters to
convert direct current into
alternating current. Installed
by the German company
Enerparc, the average energy
generation of the plant is
10,000 kWh, peaking at
13,050 kWh. After synchronising
with the low tension voltage
received from the grid, the
solar power is fed into two
1600 kVA transformers and
stepped up to 11 kV in
the airport’s high tension
distribution network. It is used
for aeronautical ground
lighting systems installed at
the airport’s three runways,
taxiways and parking stands.
The system includes a
weather monitoring system
to check that the energy
produced follows actual solar
radiation, thereby assessing
performance. It also features
SCADA systems, which
raise alarms about poor
performance and generate
reports.
Meanwhile, Devi Ahilyabai
Holkar Airport, Indore, installed
two smaller, 50 kW systems in
October 2013 under the build-
own-operate model, with a
power purchase agreement
for 25 years with Mumbai-
based Chemtrols Solar Pvt
Ltd. It owns and maintains the
plant, charging $0.18/kWh,
falling to $0.11 by the end of
the agreement.
Such tariffs are fxed
through a tender bidding
process as per AAI guidance
and vary according to
location. According to India’s
Central Electricity Regulatory
Commission, the desert state
of Rajasthan and the southern
state of Tamil Nadu have very
high potentials for solar energy
and hence quoted tariffs
are low, while New Delhi, for
instance, has more cloud and
less space and hence bids per
kWh are higher.
In Indore, in the central
Indian state of Madhya
Pradesh, peak power
generation occurs during
summer afternoons, when
systems work at 85% capacity,
whereas this reaches only
10%–15% on a cloudy summer
morning, a senior Indore
airport manager told COSPP.
Despite this useful power
contribution, the Indore airport
plant contributes only a
small fraction of the airport’s
average power requirement
of 1500 kWh and its electricity
is mainly used within the
Devi Ahilyabai Holkar Airport in Indore has installed two 50 kW systems Credit: Airports Authority of India
The cost of grid power in India has been rising continuously Credit: Airports Authority of India
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com10
On-site renewables
terminal building. The plant
draws power from 414 solar
panels of 240 W installed
over 1200 square metres,
800 metres from the main
runway. Made by Mumbai-
based PV Power Tech, the
solar modules are placed at
an 18o incline facing south to
catch the maximum amount
of sunlight. They can withstand
wind speeds of up to 160 km
per hour and are resistant to
lightning. The system uses two
50 kW inverters from German
company KACO.
The plant is equipped with
sensors for solar radiation,
ambient temperature, module
temperature and wind speed.
It can be monitored remotely
through a KACO web portal
that shows various parameters
in real time as well as archived
data.
According to Kalra, AAI solar
power systems are designed
to constantly compare the
energy generated by the
plants with airport power
requirements, drawing only
the required additional power
from the grid.
These solar plants also
can be protected by the
comprehensive security
already in place at airports.
And there is little maintenance
required except for cleaning
the panels. Delhi airport has
a pressurised water washing
system for cleaning and
maintaining the entire plant
area. Delhi airport authorities
have also planted slow-
growing grass to ensure
minimum grounds-keeping
maintenance and to reduce
exposure and damage
caused by birds and reptiles.
The design requirement of
the Delhi project included a
guaranteed life of 25 years,
module effciency exceeding
15% and plant load factor of
more than 20%.
A spokesperson for DIAL
told COSPP that the project
also received customs and
excise duty exemptions on
buying materials used in the
plant. The company also plans
to expand the airport’s solar
power plant capacity.
Restricted subsidies
Indian government policy
provides for a potential 30%
subsidy for any solar power
project to encourage the
generation of renewable
energy. However, subsidies
have not been given to every
solar power project and the
government is trying to restrict
them to only those projects
that would otherwise be
unviable, said Rakesh Kumar,
director of the Solar Energy
Corporation of India (SECI).
Furthermore, according
to Kumar, airports now
commissioning new solar
plants face a key disadvantage
as the government has
decided not to grant the
subsidy to projects (including
those at airports) which do
not install panels on rooftops.
‘The Ministry says that rooftop
is rooftop and not the ground,’
he said. And while that might
sound like fuzzy logic, there is
a reason: solar panels on roofs
are more visible than those on
the ground, and this helps the
government popularise solar
energy, said Kumar.
Explaining why AAI prefers
ground-based over rooftop
solar projects, Kalra said: ‘The
[airport] rooftops are not
big enough or are curved at
many places, and climbing
for the maintenance on the
top of these glass buildings is
not user-friendly.’ On the other
hand, many Indian airports
have a vast amount of unused
land; for example, Hyderabad
Rajiv Gandhi International
Airport is spread over 2200 ha,
while Chennai International
Airport has around 1500 ha.
Kumar believes the
government should continue
to pay subsidies to land-based
projects. ‘This kind of an issue
should better not [be] micro-
managed,’ he said. There are
several pending proposals with
ground-based solar panels,
but now, without the subsidy,
many will remain unviable
or may not be optimised, he
argued.
Raju VR Palanisamy,
president of India’s Solar Energy
Association, said companies
bidding for ground-based
solar power plants have even
started to quote prices without
factoring in the subsidy. But
they are applying for subsidies
nonetheless. ‘If the government
grants that, it would be their
windfall,’ he told COSPP.
Subsidies are distributed
by SECI, which is a state-
owned not-for-proft company
responsible for implementing
and facilitating solar
development. Since its launch
in April 2013, all new Indian
airport projects have been
routed through it. ‘We ensure
quality and remain engaged
for two years in the operation
of the system,’ said Kumar.
Instead of choosing vendors
for each project, SECI chooses
them for each city on the basis
of the best-priced tenders,
taking into account bidders’
technical and fnancial
strengths. Furthermore, to
create competition, it selects
at least two bidders in each
city to encourage a second-
placed bidder to match the
price of the frst, said Kumar.
SECI has already selected
25 solar power vendors and
installers for 37 cities – mostly
state capitals – and it will slowly
expand its approvals to smaller
towns and cities for airport and
other solar energy projects.
The chosen companies
themselves search for solar
power business in a city. In the
case of an airport project, SECI
shares the details of chosen
vendors in the particular
city with AAI and starts the
Many Indian airports have large amounts of unused land that could be used for power generationCredit: Delhi International Airport (P) Ltd
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Page 13
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1503cospp_11 11 3/12/15 5:01 PM
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com12
On-site renewables
bidding process between the
two chosen local competitors,
Kumar explained.
After an initial agreement,
a solar power benefciary
and project installer/operator
bring a detailed project report
to SECI, which sanctions it
for a fee. Upon satisfactory
completion of a project,
two-thirds of the subsidy
amount is released by SECI
directly to the project installing
company. The remaining
subsidy is paid in two equal
instalments after the frst and
second year of successful and
satisfactory performance. ‘So
we remain engaged with them
from allotment to two years of
operations and ensure quality
and performance,’ said Kumar.
However, he said subsidies
will be harder to secure in
future even for rooftop projects,
as the government has a
limited budget. ‘30% subsidy is
going to be reduced to about
15%,’ he added, although it is
not yet known when.
Financing models
SECI does not insist on any
particular fnancial model
for agreements between a
solar power operator and the
land or rooftop owner. Kumar
said the ‘build-own-operate’
model, which is preferred by
AAI, is benefcial because
the installing company is
encouraged to demand better
quality products to avoid future
generation losses. But even
here he foresees potential
problems, which could even
generate court action. ‘If, in
the future, a rooftop owner
doesn’t make payments in
time or starts fnding fault with
the service or decides that
he does not need the system
and tells the vendor to take
it away, it could lead to legal
complications,’ he warned.
Kumar said SECI
recommends installing grid-
connected solar power systems
so that surplus power can be
sold onto the grid. Indeed,
the AAI’s April communiqué
noted that solar power plants
are being set up on a site
‘to meet not only its own
requirements but also to feed
the surplus power generated
to the local grid.’ Likewise,
Kalra stressed that some of the
smaller Indian airports have
little power consumption and
big stretches of empty land to
generate excess solar power.
According to Kumar, one
possible approach is net
metering, where bills are settled
at the end of every month or
year. ‘But [frst] we have to see
all this happening as it is a very
new concept,’ he said. One
potential problem with such
a system is pricing disparity,
with solar power being costlier
than conventional power,
leading grid operators to
refuse to pay the higher price
for excess solar electricity.
‘They do not have any interest
in promoting solar energy and
want separate government
help if forced to purchase solar
power,’ he said. This is especially
likely to be a problem if solar
panel operators become net
exporters onto the grid, he
suggested.
Kumar argued that India
needs new regulation to deal
with solar power. ‘Solar is going
to replace many things and
people will become self-reliant,’
he said. Indeed, solar power
will continue to be attractive to
users with a poor grid supply,
as they have to run costly
diesel generators. ‘Even if you
are able to reduce the running
of generators for a few hours
in the week, you are making a
good saving,’ said Kumar.
Solar power is also
especially attractive to
business customers, as Indian
power tariffs for commercial
units are higher than for the
residential sector. For instance,
the Indore airport pays
$0.13/kWh to the grid supplier,
while local residential tariffs are
$0.08/kWh.
Pressing ahead
These benefts are
encouraging airports to
press ahead with their on-site
solar power projects despite
the recent diffculties over
subsidies. Cochin International
Airport, in the southwestern
state of Kerala, is pushing
ahead with a plan to sell
excess power from its solar units
to the grid. It has negotiated
a power banking contract
with local power company
the Kerala State Electricity
Board Limited (KSEB), under
which any excess solar power
supplied to the grid could only
be adjusted against future
power bills. ‘We have given
in-principle approval’ for the
airport’s proposal, a senior
offcial of KSEB told COSPP.
Cochin airport plans to add
12 MW in solar PV capacity on
22 ha of land before the end
of this year. It already has a
1 MW system installed at three
locations, including a 320 kW
plant on a hangar roof.
One potential way out of
grid supply deals for Indian
airports would be to install
power storage systems – but
such developments are
unlikely in the short term.
‘Storage is a very costly affair
and not very environmentally
friendly,’ said Kalra. ‘The
batteries have a limited
life; it takes lot of energy to
manufacture them, and bulk
power cannot be stored.’
Meanwhile, diesel
generators will continue to
operate on standby mode at
India’s airports whether they
have solar power systems or not.
Raghavendra Verma is a
New Delhi-based journalist.
This article is available
on-line.
Please visit www.cospp.com
Delhi Airport’s 8376 photovolatic modules have an anti-refective coating to avoid distracting aircraft landing crews Credit: Delhi International Airport (P) Ltd
1503cospp_12 12 3/12/15 5:01 PM
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www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 13
Opinion
Switching to liquefed petroleum gas (LPG) can deliver both fnancial and
environmental benefts in industrial environments, argues Rob Shuttleworth
Rob Shuttleworth
The case for LPGin the industrial sector
With the energy
l a n d s c a p e
c h a n g i n g
so rapidly,
industrial organisations
could be forgiven for feeling
bombarded with messages
about the most effective
power solution.Across much
of Europe, different markets
are trialling a variety of
technologies to deliver
on their energy needs.
Of course, concerns over
fossil fuels are directing
the energy spotlight onto
renewables; however, these
do not suit all environments.
Indeed, while governments
are concerned with meeting
global targets, for the majority
of businesses and industrial
units the challenge is on a more
local level. Most organisations
are focused towards delivering
cost savings, ensuring process
effciencies and removing the
risk of unplanned downtime.
The opportunity for LPG
When weighing up the options
for powering the industrial
sector, specifers should
not overlook the potential
advantages of affordable
and available conventional
energies, such as liquefed
petroleum gas (LPG), a
low-carbon fuel that is portable,
widely available, easy to install
and competitively priced.
A mixture of propane (C3H
8)
and butane (C4H
10), LPG is
derived during the exploration
of natural gas felds and is
also produced during the oil
refning process. Its combustion
emits 33% less CO2 than coal
and 17% less than heating oil.
In addition, LPG emits almost
no black carbon, which is the
second largest contributor to
global warming after CO2 and
a signifcant contributor to
poor air quality. LPG’s low levels
of particle and NOx emissions
also make it ideal for both
indoor and outdoor use.
The lowest-carbon fuel
available in non-mains gas
areas, LPG has been used within
commercial applications
for the past 40 years. It is a
particularly attractive option
for larger organisations that
have to report on their carbon
emissions. And the fact that
LPG will be in plentiful supply
for many years to come adds
security for any commercial
building energy managers.
Case study: UK site
The benefts that LPG can bring
to a commercial property
were highlighted recently with
an installation carried out at
a packaging manufacturer
to reduce its carbon footprint
and energy costs.
One of the key company
sites is located in an off-mains
area and had previously relied
on an oil-powered fuel system,
which had not only begun
to prove expensive, but had
also heavily increased the
CO2 output. By switching to
LPG, the company was able
to reduce its fuel costs by
around 15%–20% per year and
reduce the associated CO2
emissions by up to 29%. In just
two months, fuel costs were
lowered by £42,000 ($64,000).
The time is right for LPG
The industrial sector has a
large role to play in helping
Europe and the wider
developing world to meet
ambitious carbon reduction
and renewable deployment
targets. However, as a
complement to renewable
energy and energy effciency
measures, it is apparent that
certain conventional fuels like
LPG still have a distinct area
of responsibility as part of
the development of a more
sustainable energy future.
Indeed, market conditions
are currently favourable for the
type of on-site gas-powered
cogeneration to which LPG is
particularly suited. With LPG
production forecast to increase
over the coming decades,
stability of supply is clearly a
selling point. As technology
develops and the effciency of
engines and pumps increases,
the arguments for introducing
LPG into the industrial sector
continue to stack up.
Rob Shuttleworth is chief
executive of the UK
Liquefed Petroleum Gas
Association (UKLPG)
This article is available
on-line.
Please visit www.cospp.com
1503cospp_13 13 3/12/15 5:01 PM
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Executive profle
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com14
In his 20 years of service
in the combined heat
and power (CHP)
sector, Trevor Atkins
has acquired a wealth of
experience across control
engineering, EPS systems
and CHP engines for a
breadth of applications,
and a deep knowledge
of their operation and
maintenance. During his
long career Trevor has
worked with almost every
aspect of CHP. He spoke with
COSPP as he was winding
up his work at UK packaged
CHP frm Cogenco.
After leaving school at 16,
Trevor joined the Royal Navy
where he served for 24 years
as a controls electrical artifcer,
maintaining weapons systems
– missiles, gunnery systems,
sonar systems and ship
electrics – as well as working
for 10 years in mine warfare. On
his discharge he was awarded
a British Empire Medal by the
Queen for services to the Navy.
Newly discharged in 1988,
he joined power solutions
frm Holec, now called Hitec
Power Protection Ltd, where
he carried out service and
commissioning on CHP and
rotary UPS systems. When Holec
split, forming a new company
between Eastern Elecricity
and newly-created Nedalo,
Trevor moved across to Nedalo
where he worked as project
manager for fve years. He
recalls installing CHP systems
for hotels, leisure centres and
industrial and agricultural
sites, and in the late 1990s
he worked on the UK’s frst
combined heat and power
system for greenhouses.
This was Nedalo’s frst
big project, at Tangmere
Nurseries in Chichester. It was a
£6.5 million ($9.9 million)
contract, which Trevor project
managed and helped design.
It featured nine Cat 3516
engines with heat recovery
and CO2 scrubbing systems,
feeding exhaust gases back
into the greenhouses to
enhance crop growth. The
frm went on to install similar
systems at another 13 sites.
Around 2000, Trevor became
an embedded manager
with Nedalo. He managed
14 embedded generation
sites, from 1 MW to 10 MW,
plus a feet of maintenance
engineers, and was fnancially
responsible for the sites and
their maintenance.
Both Eastern Electricity, now
known as TXU Europe, and
Nedalo were owned by US frm
Texas Utilities. Around the time
that energy and commodities
frm Enron declared
bankruptcy, the power market
price collapsed and Texas
Utilities in Europe entered
administration. In 2003 part
of the business was acquired
by npower, and some 12
months post-administration
Nedalo was bought by its
management team, making
Trevor a minority shareholder
in the business.
The four majority and
six minority shareholders
renamed the frm Cogenco
and proceeded to rebuild it
to manufacture and produce
its own CHP systems. The
company grew quickly and
further funding was required,
so it was sold to Dalkia in 2007.
It is now owned by Veolia.
At the time of the TXU Europe
administration, Nedalo sold off
all but one of its embedded
generation sites. Trevor took
over as Operations Manager
for the whole of Cogenco,
which involved managing
some 35 service engineers,
seven to eight commissioning
engineers/product specialists,
and a budget of £10–11 million
per year. This was his job until
May of last year, when he was
slated to retire. However, he
was asked to stay on to wind
up the frm’s 1999 contract with
Tangmere Nurseries. Then, set
to retire again, he was asked to
stay on as a general advisor to
management until Christmas,
when he was asked to set up
training programmes on new
technology, control systems,
air-to-fuel ratio controllers
on engines, software system
controls and a bespoke
remote monitoring and control
system.
Change and challenge
When asked about the
biggest change he’s seen in
the industry, Trevor said: ‘The
biggest change is in engine
technology, with the contrast
between the very lean burn,
very high effciency engines
which we have today and the
old stoichiometric engines
which weren’t too clean for the
environment.
‘The biggest change
engine-wise is effciency and
increased demand for lean
burn/clean burn engines to
come under the new emissions
standards,’ he added. As to the
biggest overall technology
change, he cites how engine
controls and electronics have
shifted to digital controls.
‘Now it’s impossible to set the
engine up without use of a
laptop! A huge V20 engine is
controlled from a laptop; all
emissions, controls, closed-
loop air-fuel ratio controllers
are software-based.
‘Before, you had a gas
supply, you put the gas supply
in the engine, there was a
butterfy valve and a mixer,
Trevor Atkins is Head of Operations at UK utility Veolia’s specialist packaged combined heat and power
subsidiary, Cogenco. After 20 years in the industry, he is set to retire this year.
Trevor Atkins: a life in CHP
Executive Profle
1503cospp_14 14 3/12/15 5:01 PM
Page 17
Executive profle:
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 15
and you just set the engine up
like a car throttle, turned a few
screws, got the mixture right
and the engine would run,’ he
explains. ‘It’s like the difference
between running an old Morris
8 car and a new high-tech
car on the road today. It’s a
constant battle adapting to
new software – one of the
training programmes I’m
setting up now is about this.
We’re trying to broaden the
experience of our service
engineers in the feld to give
them, for example, a better
understanding of remapping
engine fuel maps.’
From a business
perspective, Trevor said
his biggest challenge has
been that consultants are
increasingly aware of CHP
and its capabilities, so tender
specifcations today are
much tighter than they used
to be. Additionally, the level of
effciency sought by today’s
industry ‘wasn’t even dreamed
of 15 years ago,’ he said. ‘It’s
not unusual now to be asked
for 94% availability on projects,
which is very high. In reality
this is too high an expectation,
particularly when you consider
that service and overhauls
have to be accounted for
within the 6% allowed for
downtime.’
Cost is also a growing issue,
he added: ‘People are much
more aware of the bottom line
now. In the past our customers
may have gone for, say, a Rolls
Royce CHP unit, while now they
and consultants are looking
at price more than anything
else, and the market is very
competitive price-wise.’
Trevor believes this trend will
continue into the future. He
says: ‘Looking at any major
project now, any developer
now has got to put, within his
remit, some sort of energy-
saving technology, and CHP
fts quite nicely with that. We’re
fnding now that a lot more
CHP units are being ftted to
blocks of fats, district heating
schemes, and things like that.’
And requirements are
changing. Like engine
manufacturers, Trevor says his
frm is now increasingly looking
into alternative fuels. Cogenco
deals primarily with natural
gas, biogas from anaerobic
digestion or sewage gas, as
well as red diesel and biodiesel.
‘It’s an up-and-down
market,’ Trevor says. ‘When I
frst came into the industry it
wasn’t unusual to see a spark
gap of 6–1 or even 7–1, while
over recent years we’re lucky to
get 3–1 or 4–1 because of the
difference between gas and
electricity prices. This makes
savings not quite as good, but
there are still savings to be had
for the end customer.
An evolving industry
The basic principle behind
CHP systems is ‘the same as
it’s always been,’ Trevor says,
although today’s margins
are tighter and demands on
suppliers are higher.
‘When I frst joined Nedalo,’
he says, ‘I helped project-
manage and install 30 CHP
units in Hilton hotels. Those
engines have now run their
course, many with over 120,000
operating hours on them.’
Cogenco is currently in the
process of decommissioning
old plant at Hilton and Marriot
sites as well as at a Land Rover
manufacturing facility, and
installing new plant, including
two new MTU CHP units. ‘We’ve
now run through a complete
cycle with those engines,’
Trevor says. ‘Those contracts
have run their course and the
customer is renewing.
‘We tend to fnd that
hospitals and universities are
now required by European
law to have open tenders,’ he
adds. ‘In the majority of cases
we do tend to win our old
contracts back. The deciding
factor is either price or a bad
experience with the previous
supplier – we win others’
contracts too. But taking on
other people’s kit can be a
challenge. We prefer to ft our
own bespoke monitoring and
control systems.’
Asked about his most
challenging project, Trevor
cites the Tangmere Nurseries
installation – Nedalo’s frst
contract, ‘so it was all new to
us. We had a sister company
in Holland so I spent a fair
amount of time there looking
at how other projects were
done and best practices,’
he says. ‘Then I had to put
a package together in the
UK along with a horticultural
engineer from Holland. We had
to build, from scratch, three
big engine rooms with three
3516 Cats in each engine
room, and incorporate the
mechanical, electrical and
HV connections which we had
to sort out, although we had
consultants for the HV.
‘Then we had to go to the
Continent and look at COdi
NOx’s huge catalytic converters
which scrub exhaust gases,
as well as interface water
systems, exhaust sytems and
HV systems, and then deal
with the grid connections with
Southern Electric – so that
project, over the course of 18
months, involved £6.5 million
worth of kit.’
On a previous project
with Holec, undertaken right
after his retirement from the
Navy, Trevor was service and
commissioning engineer on
a data centre installation in
the UK. ‘We were dealing with
putting in a 500 kVA rotary UPS
system,’ he recalls. ‘It was going
to be a combined booking
centre for several airlines. We
put it all in, and 18 months later
the Americans bought it and
moved the whole database
back to the US. The rotary UPS
system was very interesting
because we couldn’t afford to
make mistakes. The UPS systems
supported all their computer
networks: one mistake and you
put the whole place down!
‘Systems today are very
similar, they just use much
larger engines now,’ he adds.
‘They were moving from
500 kVA MTU engines to
2 MW Cummins engines when
I left: from single-unit supply to
multiple-unit supply.’
When asked what advice
he would give to new industry
entrants, Trevor says: ‘To be
a CHP engineer these days
you’ve got to be an electrician,
a mechanical engineer, a
plumber and a gas engineer!
You have to have a gas
qualifcation to work on CHPs,
you have to know the ins and
outs of engines, you have to be
competent and safe working
with electricity, and you have
to be open to training because
very few people who come into
the business are competent in
all of those aspects.
‘That then applies to project
managers as well,’ he adds.
’You need a good all-round
general grounding in the
basic principles of engineering
and electricity. You need to
also be able to be fnancially
responsible.’
Trevor is uncertain about
how well retirement will suit him
– as we can perhaps tell from
the fact that he’s still working!
But whatever he does in future,
we wish him all the best.
This article is available
on-line.
Please visit www.cospp.com
‘People are much more aware of
the bottom line now’
1503cospp_15 15 3/12/15 5:01 PM
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DistribuGen 2015
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com16
The market for CHP is
changing and many
now have a better
understanding about
power generation. Aiding
this understanding is the
constant drumbeat of news
suggesting that abundant
natural gas supplies are
expected to keep the price
of the fuel at multi-year
lows for the foreseeable
future. As a result, the
economics supporting
CHP development are
becoming increasingly
attractive, thereby driving
more adopters to seek CHP
for both its economic value
proposition and for power
reliability.
This is evident in America’s
chemical processing and
refning industry. These
operations need heat, lots
of heat, and where these
or other concentrations of
manufacturing facilities are
located are typically the same
locations where CHP facilities
can best provide heat and
power. Last year the American
Chemical Council gathered a
list of 148 proposed chemical
plant investments between
now and 2023, and found
that chemical companies
are planning to spend
$100.2 billion in the US. The vast
majority of new projects are
in the Gulf Coast area and
will involve the expansion of
existing CHP systems or new
systems altogether as part of
their investment.
But more deployment of
CHP won’t stop there. CHP
and waste heat-to-power
(WHP) technologies can and
will play an increasing role in
the nation’s manufacturing
renaissance beyond just
chemical processing and
refning. Industrial demand
for electricity is growing in
every region and all industries
are sure to examine, and
ultimately implement, CHP as
an economic, effcient and
reliable on-site energy option.
This also holds true for many
other CHP end-user candidates
such as hotels, hospitals, data
centres, residential towers and
even single-family homes.
Additionally, policymakers
concerned about grid
inadequacies are beginning
to better understand the
emission benefts. Plus,
many now know that more
distributed energy using CHP
saves vast quantities of water,
making water shortages in
many regions an important
driver for additional CHP. Just
last year the Texas legislature
changed the state’s utility
code to allow CHP facilities
to sell electricity to multiple
customers in microgrid-type
arrangements.
Before the change, CHP
facilities could only sell
electricity to one customer,
and this restriction may have
kept otherwise good energy
projects from moving forward.
This change was deemed
important in the ongoing
discussion about how Texas will
power its industrial expansion
and vibrant population growth
while, at the same time, reduce
the amount of water used by
traditional power generation.
Policy initiatives like these in
many states, combined with
equipment and technology
advances, innovative project
fnancing mechanisms and
power price dynamics are
all driving decisions to install
new CHP and WHP systems.
Currently, 82 GW of installed
CHP capacity (9% of US
energy-generation capacity)
are in use at more than 4100
sites across every state. But at
least 50 GW, and up to almost
200 GW, of additional potential
remains. The potential for WHP
projects is equally impressive,
with more than 11,000 MW
available at industrial sites
as well as gas compressor
stations, landflls and locations
where gas faring is occurring.
In April, the World Alliance
for Decentralized Energy
(WADE) will bring together
business and energy leaders,
engineering consultants,
project developers, policy
specialists and end users
to Houston, Texas for the
DistribuGen Conference and
Trade Show for Cogeneration/
CHP 2015. There attendees
will explore new market
drivers, discuss emerging
technologies, examine policy
changes and survey the
growing demand for the
energy security and resiliency
offered by CHP and WHP
systems for the industrial,
commercial and institutional
sectors.
This is the ffth year that this
important energy conference
has been held, and more
about the event can be found
at www.distribugen.org.
Paul Cauduro is Director
of WADE’s Cogeneration
Industries Council
An upcoming conference will discuss new power market dynamics, new
technologies and new policies that are changing the game for the many
cogeneration systems that experts agree are on the horizon, writes Paul Cauduro
CogenerationDiscuss among yourselves
1503cospp_16 16 3/12/15 5:02 PM
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Operations and maintenance
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com18
Co n d i t i o n
m o n i t o r i n g
allows operators
to switch from
a preventive maintenance
programme – in which key
components are inspected
and replaced on a regular
schedule – to one based on
actual physical conditions.
A clear understanding of
these conditions thus allows
systems to be maintained
more effectively, improving
overall availability and
reliability and reducing
unplanned outages.
Furthermore, by making
such a transition, owners and
operators not only typically
reduce both the frequency
and duration of shutdowns
for maintenance, but also
maximise the lifespan of
such machinery whilst saving
money on other associated
areas of the maintenance
programme, for instance
minimising inventory.
Principal parameters for
Effective condition monitoring has always been key to plant reliability, but
the advances of the digital age are opening up new horizons and the
possibility for feet-wide management of gas turbines and balance of plant
equipment, fnds David Appleyard.
Making condition monitoring smarter
SKF’s Machine Condition Indicator is a vibration sensor and indicator for monitoring non-critcal machines Credit: SKF
1503cospp_18 18 3/12/15 5:02 PM
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Operations and maintenance
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com20
monitoring gas turbines in
on-site and combined heat
and power (CHP) applications
include temperature and
pressure – both dynamic and
static – as well as vibration.
Other methods of investigation
include oil analysis and
thermography. Temperature
and pressure readings, for
example, allow operators to
control combustion more
precisely, enabling advanced
warning of potential failure
modes or unstable and
potentially hazardous
combustion conditions.
Similarly, vibration monitoring
can reveal the vast majority
of machine faults which arise
from shaft misalignment,
imbalance or bearing and
gear wear.
Indeed, the importance of
effective condition monitoring
in power generation and
CHP assets cannot be over-
emphasised. As Derek Griffths,
Sales Director, Western Europe
for GE Measurement & Control’s
Bently Nevada product line,
explains: ‘Excessive vibration
can lead to catastrophic
mechanical failure and the
associated environmental
health and safety risk to
plant personnel. Analysis of
the signals obtained from a
correctly selected vibration
transducer can provide insight
into the machinery condition
and the possible cause of a
malfunction. More importantly,
continuous monitoring of
machine vibration can provide
early detection of deterioration
of the machine condition
and enable proactive
management of the asset and
its maintenance.’
And this is the crux of
condition monitoring, as
Griffths notes: ‘The operating
condition of a gas turbine
can only be assessed by
use of a comprehensive
online monitoring system that
provides an indication of both
the mechanical integrity and
thermodynamic performance
of the machine’.
New requirements,
changing demands
The need for fexible and
effcient operations is central to
achieving economic viability,
even for captive power plants
where the presence of on-site
renewables is increasingly
introducing an element of
greater variability. As Griffths
notes: ‘The current market,
where machines need to
operate under variable load
conditions, increases the need
for detailed information about
machine availability and
reliability. Therefore, the need
for an online monitoring system
that provides plant operations
with a clear indication of
whether it is safe to operate
the machine has never been
greater’.
Henry Reinmann, Vice
President (Energy) for Strategy,
Sales & Marketing at Meggitt
Sensing Systems, echoes
this theme of increasingly
demanding operational
requirements, saying:
‘Operational costs have to
be low, emissions have to be
low for SOx and NOx; it’s now
also CO2. Effciency needs to
be increased and availability
and fexibility of the machines
needs to be high, and
these are all contradictory
requirements’.
Reinmann continues: ‘If you
want to increase effciency
and lower emissions you have
to operate the machine in a
very lean manner. You have
to go close to the stall limits of
the machine, which is when,
for example, a gas turbine
starts pumping. That could
potentially be dangerous
and you need to monitor it to
see whether, if such an event
is coming up, you have to
move away from that critical
stage with the machine. The
chemical composition of the
fuel affects the combustion
dynamics, so a change in the
gas supply on the grid may
have a signifcant effect. You
can only do that with active
monitoring’.
In late August 2013, Meggitt
signed an agreement to
acquire Piezotech LLC for
$41.2 million, bolstering its
access to high-performance
piezo-ceramic technology
for extreme temperature gas
turbine sensors.
Adopting new
approaches
Faced with growing
operational complexities,
asset owners and operators
are increasingly turning to
more sophisticated condition
monitoring techniques as
they attempt to maintain a
competitive edge. As Griffths
says: ‘There is an increasing
acceptance of condition
monitoring in a range of
industries, with vibration
monitoring being one of the
technologies used in these
programmes’.
Dr Geraint Jones, Technical
Manager for SKF’s Traditional
Energy business, picks up on
another change too. ‘Perhaps
what’s slightly different now,’
he says, ‘is that the process
data is incorporated within the
vibration data, your analysis
data and which instrument
you’ve used to collect your
data. That allows you, with the
condition monitoring software
we have now, to incorporate
the process parameters that
tell you how the gas turbine
is operating.’ However, Jones
also notes: ‘These installations
are not just a gas turbine on
their own. You might have
something on a skid with oil
pumps and other ancillary
equipment, and all those extra
machines are important. The
task of condition monitoring
is to treat the whole machine
as a complete system, not just
focus on the gas turbine.’
Reinmann also notes an
increasingly holistic approach
to condition monitoring, saying:
‘We see a combination of
monitoring tasks, with vibration
and combustion monitoring,
Meggitt Sensing Systems’ rack-mounted VibroMeter VM600 monitoring system is designed for power plants where measurement data is accessed
from a central area Credit: Meggitt Sensing Systems
1503cospp_20 20 3/12/15 5:02 PM
Page 23
Operations and maintenance
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 21
for example. A trend we
are seeing is that the large
machines usually monitor the
traditional rack-mount systems,
and we now see combinations
with balance of plant and
the smaller machines with
modular distributed systems.
With distributed monitoring
there is certainly an advantage
of reducing cabling and
installation cost and increasing
fexibility.’ He adds: ‘Many
machine manufacturers want
to have monitoring systems on
the smaller machines so they
can swap out the machine,
including all the monitoring
around it. They take it out and
put a new machine in and
everything is on there already.’
Such modular ancillaries
are connected to the control
and monitoring system via an
ethernet cable. As Rienmann
notes, ‘You don’t have to
worry about transporting
pico coulomb signals a long
distance. These signals from
piezoelectric transducers are
quite critical, but you cannot
easily transport them over
large distances.’
Mark Carrigan, Senior Vice-
President of Global Operations
for PAS Inc, also highlights
the growing complexity
of condition monitoring
systems in process plants.
He says: ‘For many in the oil
and gas community and
petrochemical industry, there
has been a focus over the
last couple of years on better
managing operating windows.
The issue that processing
industries have is managing
across the literally thousands
of measurements and their
associated operating limits.
The problem is exacerbated
by the fact that the storage
of all those different operating
windows is typically scattered
across various locations,
including documentation,
OEM specifcations and
control systems.’
Carrigan continues:
‘An original equipment
manufacturer, for instance,
will have established reliability
limits. The plant will have
optimisation limits that it wants
to keep within the reliability
limits of the equipment. In
this case, a plant that pushes
production must understand
the resulting long-term impact
on equipment performance.
This requires a co-ordinating
element that is best handled
through automation.’
Explaining how such a
system works, Carrigan points
to a hierarchy of operability
limits, such as an optimisation
limit, which should be lower
than an alarm limit, and
correspondingly should
be lower than the value at
which long-term reliability of
the equipment is affected.
‘The main value PAS provides
is bringing together all of
these limits that live in many
different data sources,’ he
says. ‘Consolidating and
normalising this data ensures
that the operational limits
stay in sync. It also provides
additional capabilities such
as varying the alarm in the
distributed control system
(DCS) so that the alarm always
enunciates at the right time,
allowing the operator to take
the proper action.’
In February of this year, PAS
announced a new multi-year
contract with BP Downstream
to help manage critical
operational limits in refneries
and petrochemicals assets.
The product, PlantState Suite
inBound, captures, analyses
and alerts operators on
boundary data within plant
operations. Boundary data
includes process alarms, safety
instruments and environmental
trip points, mechanical design
For more information, enter 7 at COSPP.hotims.com
1503cospp_21 21 3/12/15 5:02 PM
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Operations and maintenance
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com22
limits, normal operating zones,
and safe operating envelopes.
Carrigan says: ‘Companies
have realised the diffculty in
managing all these systems
they’ve put in place. No one
plant has one control system
vendor that does it all, so
it’s hard to try and get these
systems working together.’
He concludes: ‘Automating
boundary management
with software within a plant is
considered an industry best
practice today. Most of the
majors have an initiative in
place to get a handle on their
operating windows.’
PAS is not alone in adopting
a more holistic approach to
condition monitoring, covering
not just the gas turbine but also
critical ancillary equipment
and balance of system.
For example, in July 2014,
GE’s Measurement & Control
business invested in asset
performance management
(APM) software company
Meridium, Inc to integrate
Meridium’s suite of enterprise
performance management
and asset strategy software
with GE’s System 1 condition
monitoring and diagnostic
solution. The new integrated
solution, Production Asset
Reliability (PAR), aggregates
data from System 1 and other
plant maintenance systems to
provide plant engineers with a
dashboard of reliability metrics,
the company says. According
to a statement, this new
industrial internet offering can
result in an estimated 10%–30%
reduction in maintenance
costs.
‘The way we do business
is being dramatically altered
in the era of the industrial
internet. We are realising the
increased productivity and
effciency gains from big data
and analytics delivered in real
time,’ says Art Eunson, General
Manager of GE’s Bently
Nevada product line.
More recently, in January
Meggitt released its VibroSight
software for turbines, critical
machinery and balance-
of-plant equipment. The
company says its software
suite fags critical events
and monitors machinery
health, enabling the use of
predictive methodologies
which help operators make
informed decisions about
asset management and
maintenance.
A further focus of
development in condition
monitoring has seen
considerable energies
expended on improving the
interface between the various
monitoring systems and the
decision-making user.
As Carrigan explains: ‘The
frst thing you want to do is make
it available to the operator,
visualise it and see real-time
data against these limits and
make sure we’re operating
within them. The second is that
you want to provide a score
card to management.’ For
example, in mid-December SKF
announced further investment
in ‘smartifying’ its maintenance
service offering, production
and sales processes. As
part of the investment, feld
maintenance engineers
and others are equipped
with smart devices using
tailor-made software apps.
‘Integrating SKF’s condition
monitoring technologies into
mobile devices supports the
group’s focus on asset lifecycle
management. By providing
access to real-time machine
performance data in a user-
friendly format, customers
and maintenance engineers
are better able to take
informed decisions regarding
maintenance activities and
increase machine effciency,’ a
statement says.
Building relationships
with the OEMs
While condition monitoring
equipment is growing in
sophistication, there are
nonetheless signifcant
opportunities for further
improvement. Some sensor
and diagnostics companies
already work with turbine and
balance-of-system original
equipment manufacturers in
order to more effectively place
or embed sensor equipment
within machines during the
manufacturing process, as
well as enable condition
monitoring systems to establish
a clear performance baseline.
However, Jones argues
that more could be achieved,
saying: ‘Normally, in that
situation, we would want
to work in partnership with
the client, but we would like
to really get in touch with
OEMs at an earlier stage
and do condition monitoring
at the point at which the
equipment is commissioned
and tested. The way we would
see that working would be
to encourage our clients to
specify this to their OEM as a
pre-requisite when ordering
new equipment.’
Jones also calls for turbine
manufacturers to work
with such companies to
design condition monitoring
machines into the equipment
at the outset, as well as earlier
engagement with their clients
on condition monitoring.
He notes that owners and
operators will often provide
detailed specifcations for
the turbine, but the issue of
condition monitoring will only
be raised at the shipping
point, when customers may
belatedly realise that there
is no condition monitoring
equipment included in the
package as specifed.
‘One development we
are really interested in at the
moment, in terms of our varying
research, is embedding the
accelerometer in the bearing
itself. If we could do that,
we would save a lot more
bearings than we currently
do. The condition monitoring
becomes more robust,’ says
Jones. He adds: ‘Advanced
processing techniques
Metso’s wireless Maintenance Pad is a portable data collection and analysis tool that includes the Metso
Machine Analyzer vibration analysis softwareCredit: Metso
1503cospp_22 22 3/12/15 5:02 PM
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Operations and maintenance
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 23
give you a better understanding of the
rolling element bearing. Although those
techniques are not new, they are still very
useful. Simply embedding the sensor in the
bearing makes them even more effective.’
There is also a continued push
towards simplifed modular systems.
For example, SKF has launched remote
wireless technology sensor systems –
machine condition indicators – which
include a traffc light system that
activates depending on the vibration
limit programmed into it. ‘This can remove
some of the burden for data collection,’
says Jones.
The future of condition
monitoring
A natural consequence of a more holistic
and online approach to condition
monitoring is the potential beneft for feet-
wide operations. As Griffths says: ‘Remote
condition monitoring via the internet
allows entire feets of gas turbines to be
managed from a central location. This
allows feet data to be gathered, common
faults to be identifed, and engineered
solutions developed to improve the overall
reliability of the feet.’
This is a theme also picked up by
Reinmann: ‘In the early days you had
machine specialists in every power plant,
and that is just not economical anymore.
Large utilities concentrate resources, they
have remote monitoring centres, and
some of the large OEMs do that also. They
want to get a central location where the
specialists sit, and it can then act or react
remotely, if they have a feet of machines
of the same type. If there’s an event
happening on a machine, they look at the
data to see if there are other machines of
the same type showing similar indications
- a feet-wide approach.’
Jones also points out the development
of remote diagnostic centres, saying:
‘As a condition monitoring tool, you can
actually monitor your machines online
and you don’t need someone walking
around. As you move to an online system,
you can possibly move towards remote
diagnostic centres; those have been
developed in the past decade.’ However,
he also sounds a warning: ‘The other side
of the coin is that cybersecurity is an issue.
That has to be considered.’
Looking ahead, Griffths says: ‘I
believe power generation operators will
continue to improve the effciency of their
operations, which will require some form of
condition monitoring to provide them with
an indication of where they need to focus
their maintenance efforts and improve
the overall availability of their plant, whilst
keeping control of their operational costs.
Think of this as enabling condition-based
maintenance.’
And, as Reinmann says: ‘Thus, it will
require more condition monitoring, data
management, more knowledge and
understanding of what the machine
is doing, and also to be able to plan
changes, upgrades etc. I think there is a
long way to go for condition monitoring.’
David Appleyard is a freelance
journalist specialising in the energy,
technology and process sectors.
This article is available
on-line.
Please visit www.cospp.com
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1503cospp_23 23 3/12/15 5:02 PM
Page 26
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com24
Biomass case study
The Studstrupvaerket
power station in
Studstrup, Denmark
features two units, 3
and 4, which are designed
for combined heat and
power (CHP) production.
The maximum net power
output is 350 MW and the
maximum district heating
output is 455 MJ/s per unit.
Dong Energy Thermal Power
is planning a fuel conversion
at unit 3 (SSV3) to 100 per
cent wood pellet fring, while
as far as possible keeping
the maximum thermal heat
output at 930 MWth with the
option of using the present
fuel qualities (coal, straw and
oil) alternatively to the pellets.
The complete conversion
of unit 3 comprises mainly
new unloading and feeding
systems, wood pellet storage,
feeders and modifcation of
existing mills and burners. The
existing coal feeding system
remains ready-to-operate to
allow a fuel switch between
hard coal fring and wood
pellet fring.
In summer 2013 one of the
upper mills (mill No 40) and
the respective burners were
upgraded at SSV3 to allow
wood pellet operation as well
as coal combustion. After the
modifcations, the transition
from coal to biomass operation
(and reverse) should be
possible within a period of
30 minutes or less for each mill
while the unit keeps running
continuously.
Four different trial runs were
conducted from October
2013 to February 2014 using
bituminous coal and different
kinds of wood pellets for testing
under different load conditions,
variable load ramps and
fuel switching between coal
and biomass at the modifed
mill. From December 2013 to
March 2014, a total of about
70,000 tonnes of wood pellets
were ground and burned with
the upgraded combustion
equipment.
Mill modifcations
The boiler at SSV3 is equipped
with four bowl and roller mills
type MPS 190. Inside the mill
(see Figure 1) the grinding
process of the fed raw coal
is initialised by rolling off
stationary, rotating grinding
rollers upon a turning grinding
bowl.
The fuel is fed via a coal-
chute centrally into the mill
to the rotating grinding bowl,
and afterwards is transported
by centrifugal force to the
grinding rollers. The grinding
rollers are pressed on the
grinding bowl due to their
own weight and an additional
external force, generated by
a spring-loaded rope pull
system.
The fuel gets crushed
through pressure and shearing
inside the milling gap between
grinding rollers and grinding
bowl. The primary air required
for drying and pneumatic
transport of the ground fuel is
provided by a separate fan.
The required primary air fow
depends on the inserted mass
fow rate of the fuel. The desired
primary air temperature is
achieved by mixing hot and
With specifc modifcations, a bituminous coal-fring CHP system can be
converted to operate with wood or other biomass pellets, write
Thomas Krause and Yaqoub Al-Khasawneh
Making the switchfrom coal to biomass
1503cospp_24 24 3/12/15 5:02 PM
Page 27
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 25
Biomass case study
cold primary air. The primary
air is fowing into the grinding
chamber through a nozzle ring,
with a defned temperature,
velocity and fow direction.
The mills at Studstrup unit
3 are equipped with dynamic
classifers of type HEP 33H6.
This classifer uses adjustable,
stationary blades and a speed-
controlled rotor for fneness
adjustment. Increasing the
rotor speed leads to an
improvement in the grinding
fneness. The dynamic classifer
is designed for coal operation
with a grinding fneness of R_90
µm = 5%–25% (about 10%–30%
residue on a sieve 75 µm).
Because of the differences
in grinding, drying, pneumatic
transport and the fneness
requirements for combustion
of pulverised coal and wood
pellets, it is not possible to grind
both fuels simultaneously.
The parameters of the
grinding system regarding the
requirements of pulverised
fuel drying, as well as fre and
explosion protection, are set
either for coal or for wood
pellets. After the correct setting,
the mill operates economically
and reliably with the chosen
material.
Necessary changes for
adjusting the grinding system
to the new fuel, besides the
adapted control technology,
are mechanical modifcations
to the mill and classifer
regarding grinding, pneumatic
transport of the pulverised
fuel, and classifcation. The
following modifcations were
made to adapt the grinding
system:
• Grinding bowl rotational
speed increase;
• Dam ring installation at the
grinding table edge;
• Coal-downpipe extension;
• Modifcation of the classifer:
installation of variable drive
for louver blade angle
adjustment, return hopper
modifcation, change of the
fan at the classifer motor;
• Double wall installation
(cylindrical airfow defector)
inside the grinding chamber
and upstream classifer.
These mechanical
modifcations allow mill
operation with both fuels. The
classifer, for example, can
be controlled by the angle
adjustment of the louver
blades and by adjusting the
classifer’s rotational speed
to fulfl the different fneness
requirements for bituminous
coal and biomass combustion.
The grinding system is
equipped with additional
temperature measuring points
and an explosion suppression
system.
Besides mechanical
modifcations, some
adaptations to the control
system had to be arranged.
Mill operation with bituminous
coal or wood pellets is realised
individually by an independent
operation programme
which contains the required
parameters and limit values for
mill operation.
Burner modifcations
The 24 burners were originally
designed for the use of
pulverised bituminous coal.
Six burners are arranged in
four elevations, located on
the boiler front and rear walls.
Each burner is connected to
the combustion air supply
system by a secondary air
duct, including the necessary
damper and fow measuring
devices for individual
combustion air control.
The target for the
modifcation was to operate
the swirl burners either in
100 per cent bituminous coal
mode or 100 per cent biomass
mode on a wood pellet
basis.
For the realisation of coal/
biomass combustion the six
burners of the upper level
40 were upgraded with the
essential DS Burner elements.
Concentric setup and
swirling of all burner fows are
essential features of this burner
type. The DS Burner design is
determined by the ignition, the
fame start and the subsequent
low-oxygen primary reaction
phase. Further, the burner has
been designed to handle the
fuel particles in the pyrolysis
process as well as their
subsequent oxidation.
In general, the DS Burner
consists of the following main
components:
• Ignition device;
• Core air tube;
• Primary air tube with
integrated fuel nozzle,
primary air swirl device and
inlet elbow linked to the
pulverized fuel line;
• Secondary air pipe with
swirl blades and tertiary air
defecting cone;
• Tertiary air nozzle with swirl
blades;
• Burner wind-box.
The prerequisites for the
process are created through
the interaction between swirl
devices and fuel nozzle, as well
as the resulting heat transfer
in the nearby burner zone.
Early oxidation of the pyrolysis
products with a defned oxygen
volume is the precondition for
stable low-NOx combustion in
the core fame.
The core fame is surrounded
by spatially staged fows of
secondary and tertiary air,
while the combustion process
is supplied with the necessary
oxygen by a continuous
delayed supply from the
peripheral burner fow.
For the burner modifcation,
new primary air tubes with
Raw coal
Hot air
Louver blades adjustment
Dynamic classifer
Rotating cage
Louver blades
Sealing air circle line
Grinding rollers
Rod
Dam ring
Nozzle ring
Grinding track
Hot air annular channel
Mill gearbox
Coal dust outlet
Coal down pipe
Return hopper
Loading frame
Spring
Guide frame
Inner housing(Double wall)
Hot air inlet duct
Motor
Figure 1. MPS mill for coal and biomass operation
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com26
Biomass case study
integrated fuel nozzles and inlet
elbows, linked to the pulverised-
fuel tubes, were installed. The
fuel nozzles, fabricated as
single component of spun-
casting heat-resistant alloy, are
welded to the pulverised-fuel
tubes. With exception of the
fuel nozzles, the pulverised-
fuel tubes are fabricated of
composite material, including
an inside erosion-protective
lining on a chromium-carbide
base.
On the circumference of
the core air tube, primary swirl
blades with angle position of
35° to the fow direction are
welded at a certain distance
to the burner tip. In addition,
the existing core air nozzle was
replaced by a new one made
of heat-resistant material, with
length of about 650 mm.
Due to the new design of
the pulverised-fuel tubes, new
secondary air swirl inserts
must be installed. With the
exception of the SA nozzle with
TA defector, all burner parts
on the combustion air side
remained unchanged.
Process parameter and
safety considerations
Coal and wood pellets have
a clearly different grinding
and combustion behaviour
than coal. Thus the operating
parameters of the fring system
have to be adjusted to the
individual fuel properties to
comply with the following
tasks: grinding and classifying,
drying, pneumatic transport
and distribution of the fuel dust
into the individual pulverised
fuel lines. Furthermore, stable
ignition at the burners and
the combustion process in the
furnace has to be ensured. Mill
operation with coal or wood
pellets is realised individually
by an independent operation
programme.
Due to the highly volatile
content, the reactivity of
pulverised biomass is much
higher compared to pulverised
bituminous coal.
Special attention was paid to
a suffcient distance between
carrier gas temperature and
self-ignition temperature of the
pulverised biomass in a hot air
atmosphere, and to preventing
biomass ignition at hot surfaces
in the grinding system.
During coal operation
the required primary air
temperature and, partly,
the grinding system surface
temperature during coal
operation could lead to wood
pellet ignition. Before switching
from biomass to coal operation
the grinding system must
be emptied of biomass – in
particular, the hot air annular
channel below the mill’s
nozzle ring, and the reject box.
The primary air temperature
may only be increased to the
required values after this step.
Before switching from coal
to biomass operation it must
be ensured that the hot zones
inside the mill are cooled down
suffciently to prevent self-
ignition of the fuel during any
operating mode or shutdown
procedure. Therefore,
additional temperature
measuring points inside the
mill housing were installed.
While switching fuel types,
dust samples were taken from
the PF lines at certain times to
determine the duration of the
fuel discharge.
Figure 3 shows parameters
and temperatures of the
primary air upstream mill and
of the carrier gas at mill outlet
as well as fuel parameters to
reach the boiler peak load
of 930 MWth in four-mills
operating mode.
Operational results
In delivery state, the mill MPS
190 was equipped with a
static classifer of type SLK,
and designed for grinding
a coal fow of 12.78 kg/s
with a grinding fneness of
R_0.09 = 20% (residue on a
screen 90 µm) related to the
coal parameters HGI = 55°H,
moisture = 9% and ash content
= 13.5%. Later the mill was
equipped with a dynamic
classifer of type HEP 33H6 for
fneness improvement. Today,
the average grinding fneness
is about R_0.09 = 14% Related
to the design fuel and the
higher fneness degree, the
coal mass fow for the same
mill load is 11.65 kg/s.
The pulverised coal mass
fow, the accessible grinding
fneness and the dynamic
behaviour of the mill should
not be limited by the mill
modifcations. These are
the requirements given by
EnergiNet DK Grid Code: load
changes at 50%–90% plant
load not less than 4% per
minute; below and above this
range plant load changes
not less than 2% per minute.
Furthermore, the functionality
of the modifed burner must
be demonstrated. The burners
should have a stable ignition
and fully satisfying coal
combustion behaviour.
The performance of the
modifed mill 40 and the
function of the dedicated
burners were proven in a trial
run in February 2014. The mill
was operated safely with a
coal mass fow of 12.5 kg/s
and measurements were
taken at the mill, as well as coal
sampling at the pulverised
fuel lines. Burner functionality
was monitored by the fame
scanners and checked by
video recordings of the wing
burners from the side wall
inspection holes.
The dynamic behaviour of
the modifed mill had already
been tested in January 2014.
Load change behaviour of
the modifed mill has not
deteriorated compared with
unmodifed mills. The required
grid code parameters have
been achieved.
A deterioration of part load
behaviour appears while in
coal operation mode. The
modifcations have led to an
increased grinding capacity,
while also increasing the
achievable minimum load.
The aim of a minimum load of
5.2 kg/s leads to a disturbed
smoothness, so that the
obtainable minimum load
was increased to 6–6.5 kg/s.
The desirable minimum load
could be realised through
adjustment of the grinding
force during operation (state-
of-the-art, but not implanted
in SSV3) or by a moderate
decrease of the modifed mill’s
grinding capacity.
With the exception of
the temporary limitation of
minimum load behaviour
during coal operation, the
performance of the modifed
grinding system as well as
the burners turned out to be
comparable to the capacity
of the unmodifed units. Thus,
high expectations for biomass
operation could be fulflled
and even exceeded.
Secondary Air SwirlerFuel Nozzle
TA Defector
Primary Air SwirlerPF Tube
Core Air TubeFigure 2. DS Burner components
1503cospp_26 26 3/12/15 5:02 PM
Page 29
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 27
Biomass case study
Switching modes
The target was 30 minutes
to shut down each mill and
restart it with the other fuel
– and the same process in
reverse – or two hours for all
four mills.Furthermore, it should
be checked if a direct switch
between operating modes
without stopping the mill is
possible.
A switch between the fuels
in a period of 30 minutes with
a shutdown and restart of
the mill was possible from the
beginning onward.
It is important to note that,
during the switch from coal
to biomass operation, the mill
is cooled down suffciently
prior to the biomass feeder
start in order to decrease
the material temperature at
the nozzle ring and the hot
air inlet channel below the
self-ignition temperature of
biomass in particular. During
the cooling-down process with
the operational programme,
the temperatures inside the
mill were measured.
When switching from
biomass to coal, it must be
ensured that no biomass
remains inside the mill, as
self-ignition could occur due
to the increased primary air
temperature in coal operation
mode. Complete clean-out
of the mill is ensured with
a special purge sequence.
The mill reject box has to be
cleaned completely as well.
Good dynamic behaviour
of the grinding systems
opened the possibility for a
direct switch between fuel
modes. Direct switching
without any infuence on
fame stability at the burner
was tested in a separate trial
run, and comprehensive
safety assessments were
conducted. As a result of these
assessments, the operation
programmes were modifed
accordingly. The previously
mentioned safety parameters
must be fulflled, and the
experience gained from prior
operating modes must be
incorporated.
During coal operation, the
material temperatures of the
complete mill must be lower
than 150°C prior to biomass
feeder start. To ensure this,
additional temperature
measuring points have been
installed. After switching
to biomass feeding, the
classifer’s rotational speed
has to be continually lowered
to the wood pellet classifer
speed to protect the mill from
overflling. At the same time,
the particles of the pulverised
coal leaving the classifer must
be fne enough to ignite safely.
Before starting with
coal operation, it must be
ensured that biomass can
be discharged from the mill
completely before setting
the primary air temperature
for coal operating mode.
In addition, cleaning of the
reject box is required prior
to an increase in primary air
temperature. After that the
classifer rotational speed
can be increased continually
towards coal operating mode
requirements. This must be
done carefully as the coarse
wood pellet particles have to
leave the mill frst.
Dr Thomas Krause is Head
of Process Engineering
Pulverizing Systems at
Mitsubishi Hitachi Power
Systems Europe. Dr Yaqoub
Al-Khasawneh is Process
Engineer for Pulverizing, Coal
and Ash Handling Systems
at MH Power Systems Europe
Service.
This article is available
on-line.
Please visit www.cospp.com
Pulverizer operating data for 930 MWth (boiler peak load)
Figure 3. Gas and fuel parameter per mill for 930 MWth (boiler peak load) with guarantee fuels
[email protected] , +420 483 363 642
www.tedomengines.com
GAS ENGINES
Reliable heart for your unit
Power range: 80 - 210 kW
Fuels: NG, Biogas, LPG,
Wellhead gas, CBM gas
and others
For more information, enter 9 at COSPP.hotims.com
1503cospp_27 27 3/12/15 5:02 PM
Page 30
Cogeneration optimisation
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com28
Mo s t
c o g e n e r a t i o n
installations are
housed in an
enclosure, which can be
a container or a special
boiler house. An enclosure
is generally needed to
avoid noise radiating to the
environment and to shield
sensitive equipment from
the weather. An enclosure
can also prevent unqualifed
people from tampering with
the installation.
The effciency of a
cogeneration plant is also
affected by its enclosure,
depending on the ambient
temperature and the way
the ventilation system works.
If no enclosure is present, the
intake air of the reciprocating
engine or gas turbine equals
the ambient temperature.
In that case, for an exhaust
temperature controlled at a
fxed value, a lower ambient
temperature results in higher
losses in sensible heat with the
intake air.
In addition, the
temperature difference
between the engine and its
surroundings will then vary
with the ambient temperature,
affecting the convection
loss. The temperature of the
cylinder block is normally
thermostatically controlled.
Here we will use a series of
examples to illustrate the effect
of enclosures on the effciency
of a cogeneration installation.
Cogeneration effciency
with no enclosure
The fuel effciency of a
cogeneration installation
is 100% where the exhaust
temperature equals the
intake temperature and
the insulation ensures that
no heat escapes from the
machine to the environment.
Complete combustion should
also be present, and the heat
In the ffth of a series of articles on optimising cogeneration plant, Dr Jacob Klimstra
explains how the setup of an installation’s enclosure can affect its effciency.
Enclosuresand effciency
A properly designed enclosure can improve installation effciency and stability Credit: Emerson Process Management
1503cospp_28 28 3/12/15 5:02 PM
Page 31
Cogeneration optimisation
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 29
coming from the electricity
generator should not be lost
to the environment. Such
stringent boundary conditions
are diffcult to implement in a
practical installation.
A reference temperature of
25°C is a suitable value for the
sensible heat of the intake air
and exhaust gas, since it is, in
practice, the lowest possible
temperature used in heating
systems. At 25°C, heat can be
used for soil heating systems in
horticulture and for under-foor
heating systems in buildings.
When determining the heat
balance of a cogeneration
installation, we need to
calculate how much the fuel
gas and intake air must be
heated or cooled to reach
the reference temperature. The
same applies for the exhaust
gas.
Here, as we are focused
on the enclosure’s effect on
the energy balance, heat
loss resulting from an exhaust
temperature higher than the
reference temperature of 25°C
will not be discussed. (This was
the subject of an article in the
November–December 2014
issue of COSPP, now available
on-line at www.cospp.com.)
The sensible heat per unit of
calorifc value Especifc of the fuel
gas equals (eq. 1):
Especifc(gas)= cp(gas)(Tref
_Tin)
Hi
in which cp = specifc heat in kJ/
kg; Tref = reference temperature
in °C; Hi = lower calorifc value in
MJ/kg.
For methane, cp is about
2.2 kJ/kg and Hi is 50 MJ/kg
for a reference temperature of
25°C. The cp of nitrogen (N2) is
about 1.04 kJ/kg and that of
carbon dioxide (CO2) about
0.84 kJ/kg. Some natural
gases contain considerable
amounts of nitrogen. Biogas
can contain much CO2.
It is generally presumed that
natural gas from underground
pipelines has a temperature
of 15°C. The specifc sensible
heat needed to raise the
gas temperature from 15°C
to 25°C is 2.2 · (25–15)/50 =
0.44 kJ/MJ, equalling 0.044%
of the fuel energy, meaning
that it is close to negligible.
A cogeneration installation’s
enclosure has no effect on the
gas temperature, and therefore
we will ignore the small effect
of the gas temperature on
effciency.
The composition of natural
gas depends on its source,
but methane is always by
far the main constituent. The
properties of natural gas,
such as calorifc value and
stoichiometric air requirement,
depend on its composition. For
simplifcation purposes, we will
here use pure methane as our
fuel gas example. The infuence
of the actual gas composition
on an enclosure’s effect on
total energy effciency is very
small.
Stoichiometric combustion
of methane requires
17.36 kg of air per kg of
gas. Most prime movers in
cogeneration installations use
a fuel-lean mixture for better
performance and lower NOx
emissions. For an air-to-fuel
ratio λ of 2 with respect to a
stoichiometric mixture, one
needs 34.72 kg of air per kg of
methane.
The specifc sensible heat
to be added to the intake air
is (eq. 2):
Especifc(air)= λ • 17.36cp(air)(Tref
_Tin)
Hi
The cp of air at ambient
conditions is about 1 kJ/kg.
We now know how to
determine the sensible heat
required to bring the intake air
and fuel gas to the reference
temperature of 25°C. This
amount of heat, as a
percentage of the fuel energy
required to raise the intake
air temperature, is shown in
Figure 1.
Figure 1 reveals that a
cogeneration system which
draws its combustion air
directly from outside can need
up to 6% of the fuel energy to
bring the intake temperature
from -30°C to the reference
temperature of 25°C. Most
gas turbines operate at an
air-to-fuel ratio λ of 3 and
higher. Modern reciprocating
gas engines operate at a λ
between 1.8 and 2.1.
The cylinder block of a
reciprocating engine is often
controlled at a temperature
close to 85°C. This warrants a
proper temperature distribution
of the engine’s inner parts,
while the coolant provides
a suitable temperature for
heating systems. For a modern
turbocharged engine with a
brake mean effective pressure
at full load of about 20 bar,
the heat loss from the engine
block to its surroundings
is about 1.5% to 2% of the
fuel energy where the room
temperature is 30°C. The actual
value depends on the size and
construction of the engine.
Since, in a normal situation, the
heat transfer from the engine
block to its surroundings is
via convection, the heat
loss to the surroundings is
directly proportional to the
temperature difference. This
heat loss can be written as
(eq. 3):
Econvection= 85 – Tsurroundings·0.015·Hi
85 – 30
Figure 2 shows the
dependence of the convection
loss on the temperature of
the surroundings, in a case
where no forced air fow is
present around the machine.
Some packagers design the
ventilation system in such a
way that blowers create high
-2
-1
0
1
2
3
4
5
6
-40 -20 0 20 40
pe
rce
nta
ge
of lo
we
r c
alo
rifc
va
lue
intake temperature °C
Heat required for raising the intake air temperature to 25°C
lambda = 1
lambda = 2
lambda = 3
Figure 1. A low intake temperature requires much energy to heat up the intake air to 25°C
0
0.5
1
1.5
2
2.5
3
3.5
-40 -20 0 20 40
pe
rce
nta
ge
co
nve
ctio
n
loss
of fu
el e
ne
rgy
temperature surroundings (°C)
Convection loss reciprocating engine
Figure 2. The convection loss of a reciprocating engine is directly proportional to the temperature difference between the engine block and its surroundings
1503cospp_29 29 3/12/15 5:02 PM
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Cogeneration optimisation
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com30
air fows against the engine
block. This can substantially
increase the engine block’s
heat loss.
Figures 1 and 2 show that
a cogeneration installation
exposed to ambient air can
easily lose 6% of its fuel energy
if the ambient temperature
is very low. Unfortunately,
heat demand generally
increases with a lower ambient
temperature.
An enclosure with a
controlled internal
temperature
As mentioned earlier,
cogeneration installations are
normally inside an enclosure.
This includes the electricity
generator. At full load, the
generator loss is some 1.5%
of the fuel energy. Generators
have to be cooled in order
to avoid overheating of their
windings. Sometimes ambient
air will be used to cool the
generator, but in many cases
the air inside the installation’s
enclosure is cold enough to
cool the generator.
INTAKE AIR FROM OUTSIDE THE
ENCLOSURE
Figure 3 is a schematic
representation of a
cogeneration system in an
enclosure. The temperature
inside the enclosure is
controlled by a variable-speed
ventilator. If ventilation was not
present, the enclosure would
reach a temperature of over
85°C, which means that the
air inside the enclosure would
have the same temperature
as the engine block. Therefore,
convection from the engine
block to its surroundings would
stop.
However, there is still heat
input from the generator
and from radiation of the
turbocharger, and ultimately
the engine block will even
start to receive heat from
its surroundings. Only a few
examples exist where no
ventilation takes place in the
enclosure. This has, e.g., been
the case with the FIAT TOTEM,
a 15 kW cogeneration unit
with a water-cooled generator.
All larger installations use
ventilation within the enclosure.
In the example of Figure
3, the inner temperature of
the enclosure is controlled
at 30°C. This means that
the temperature difference
between the engine block and
its surroundings is constant,
resulting in a convection loss
at full load of some 1.5% of
the lower calorifc value of
the fuel (equation 3). The
generator loss of about 1.5% of
the fuel energy is also added
to the ventilation air, so that
in total 3% of the fuel energy
leaves the enclosure with the
ventilation air.
The air for the engine
process is drawn from outside,
which means that the energy
required to heat the intake air
to the reference temperature
of 25°C is dependent on the
ambient temperature. Figure
4 gives the resulting fraction
of the fuel energy that is lost
due to intake air heating and
enclosure ventilation.
Actually, the energy required
to heat the intake air is exactly
the same as in Figure 1. No
line for λ = 3 has been given
in Figure 4, since the data on
the convection loss apply for
reciprocating engines only
and these engines do not
operate at such high lambda
values as the turbines. In this
solution, the convection loss
will never exceed 1.5% at full
load. This is in contrast with a
no-enclosure situation, where
the convection loss can reach
3% of the fuel energy in the
case of very low ambient
temperatures.
Again, the heat from a
cogeneration installation is
generally most needed when
the ambient temperature is
very low. Therefore, this solution
with intake air taken from
outside the enclosure is not
ideal.
INTAKE AIR FROM INSIDE THE
ENCLOSURE
A better solution is to draw
the required intake air for the
engine from the enclosure
itself. Figure 5 illustrates this
concept. The air infow into
the enclosure is now the sum
of the intake air for the engine
and the ventilation air. If the
average temperature inside
the enclosure is below 30°C,
the ventilator will stop, and the
0
1
2
3
4
5
6
7
-40 -20 0 20 40
pe
rce
nta
ge
of lo
we
r c
alo
rifc
va
lue
Losses due to intake air heating +ventilation (intake air from outside)
lambda = 1
lambda = 2
Figure 4. The heat loss for the intake air and ventilation air of a reciprocating engine-driven cogeneration installation running at full load in a temperature-controlled enclosure, expressed as a percentage of the lower heating value of the fuel
Figure 5: A cogeneration installation that draws its combustion air from inside its enclosure
Figure 3. A cogeneration installation in an enclosure with forced ventilation to keep the inner temperature at 30°C.
1503cospp_30 30 3/12/15 5:02 PM
Page 33
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Page 34
Cogeneration optimisation
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com32
heat from the generator and
engine block will only heat
the infow of air which exactly
equals the intake air of the
engine.
The question now is which
average temperature will
be present in the enclosure,
depending on the ambient
temperature. If the air fow into
the enclosure equals the intake
air fow, the energy needed to
heat the infow of air to the
enclosure temperature equals,
for a λ of 2:
Einfow=34.72·(Tenclosure– Tambient)/500%
The heat provided from the
engine block (see equation
3) and the generator (= 1.5%)
equals:
Eprovided= 85–Tenclosure ·1.5% +1.5%
55
Therefore, as long as
the temperature inside the
enclosure is lower than 30°C:
Tenclosure = 39.69 + 0.717 Tambient
The result of this relationship
is shown in Figure 6.
Figure 6 immediately
shows the huge advantage
of drawing the intake air from
inside the enclosure, instead
of directly from the ambient
air. In the previous case, with
intake air drawn from outside
the enclosure, almost 4% of
the fuel energy is needed to
heat the intake air from -30°C
to + 25°C, while 3% of the fuel
energy resulting from engine
block and generator losses
had to be ventilated away. In
the case of drawing the intake
air from inside the enclosure,
for the same low temperature
of -30°C, only about 0.5% of
the fuel energy is needed
to raise the intake air to the
reference temperature of
25°C. Therefore, for ambient
temperatures below -12°C,
the energy effciency of a
cogeneration plant is about
three percentage points better
when the air for the engine
is drawn from inside the
enclosure.
A positive side effect of
taking the intake air from
inside the enclosure is that its
temperature varies only slightly
with the ambient temperature.
This makes the task of the
lambda control system much
easier, since the temperature
of the intake air considerably
affects the air-to-fuel ratio
prepared by carburettors.
Finally, fgure 7 shows how
much heat has to be ventilated
away when the intake air for
the engine is drawn from inside
the enclosure at ambient
temperatures from -12.5°C.
If the ambient temperature
exceeds 30°C, the ventilation
system is no longer able to
keep the temperature in the
enclosure at 30°C. For ambient
temperatures exceeding 30°C,
the convection loss from the
engine block will begin to
decrease.
The output of turbocharged
reciprocating engines does
not depend on the intake air
temperature as long as this
temperature remains below
30°C. This is in contrast with
gas turbines, where the power
capacity is proportional to the
intake air temperature.
In practice, the temperature
inside an enclosure is not
always uniform. In some
designs, ventilators push
ambient air into the enclosure
instead of drawing the air
out. In such situations, the
engine’s intake air can have
a temperature close to the
ambient temperature. The
convection heat and the
generator loss are then not
used to heat the intake air,
resulting in less-than-optimum
fuel effciency. High convection
losses also occur when cold
ambient air is blown against
the engine block. Sometimes
incoming air jets from the
ventilators are the cause of a
heavily fuctuating intake-air
temperature, which creates
unsteady engine operation. It
is recommended here to keep
the atmosphere inside an
enclosure as quiet as possible,
with ventilators drawing the
air from the enclosure. A
slight underpressure inside
the enclosure also prevents
foul gases escaping when
the doors are opened during
running.
A properly designed
enclosure can clearly improve
a cogeneration installation’s
energy effciency and stability,
especially on cold days.
Dr Jacob Klimstra is
Managing Editor of COSPP
This article is available
on-line.
Please visit www.cospp.com
0
0.5
1
1.5
2
2.5
3
3.5
-20 -10 0 10 20 30
fue
l en
erg
y ve
ntila
ted
aw
ay
(%)
ambient temperature (°C)
Figure 7. The fraction of fuel energy ventilated away as heat from a cogeneration installation, where the intake air is taken from inside the enclosure and the set point for the enclosure temperature is 30°C
0
5
10
15
20
25
30
35
-40 -20 0 20 40
en
clo
sure
te
mp
era
ture
(°C
)
ambient temperature °C
Set value enclosure T = 30°C
Figure 6. The enclosure temperature as a function of the ambient temperature where the engine intake air is drawn from the enclosure
Cogeneration plant in Lubmin, Germany Credit: Siemens
1503cospp_32 32 3/12/15 5:02 PM
Page 35
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Page 36
Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com34
Genset Focus
Trigeneration powers Russian hospital
Genset supplier FG Wilson
has delivered a vital power
solution for a major new
medical centre in Russia.
FG Wilson’s Russian
dealer Technoserv has
commissioned and installed
gas gensets and combined
gas heat exchanger systems
for a power station that runs
Hospital VIT in Nizhny Tagil City,
in the Ural district.
Technoserv designed the
power plant based on four FG
Wilson PG750B gas generator
sets. The units work in base
load operating mode in
parallel with the local mains
grid at full load. For water
heating, a combined heat
and power system was used
in conjunction with a local
Russian manufacturer, CTM.
FG Wilson said that
in order to ensure the
maximum effciency of
natural gas consumption,
the power solution operates
in trigeneration mode,
producing not only heat but
also cooling – the CHP systems
supply exhaust gas-heated
water to the chemical
absorption chiller for cold
water produce, meaning the
total electric power plant
capacity is 2.4 MW and
around 2 MW thermal or cold
water power.
Finning offers new gensets for CHP and continuous power applicationsFinning Power Systems has
launched its Cat G3520H gas
generator set for combined
heat and power and
continuous electric power
applications.
The G3520H gas generator
is ideal for use in industrial and
commercial facilities, as well
as in distributed generation
power plants, Finning said,
adding that it features the
lowest total lifecycle cost in its
class.
It has a long stroke design,
high compression-ratio pistons,
a high effciency turbo, and
a high effciency generator
design. The company
claims that time and costs
associated with maintenance
are reduced due to to the
G3520H’s optimised piston, ring
and liner designs, which help
to minimise oil consumption.
The G3520H is the second
genset to be introduced as
part of the G3500 H-series,
following the G3516H, which
Finning launched in January
2013.
The gensets are offered
with power ratings of up to
2500 ekW, with three
confgurations available: High
Effciency (HE), High Response
(HR), and High Altitude (HA).
With the HE option turbo trim
is optimised for maximum
total electrical effciency,
while the HR and HA turbo
trim confgurations provide
optimisation for altitude
and ambient performance
capability and dynamic load
response, Finning said.
Aggreko commissions diesel plant in MozambiqueA new power plant has been
commissioned in Mozambique
by Aggreko and state power
utility Electricidade de
Moçambique (EDM).
The diesel plant in the port
city of Nacala comprises 22
diesel generator sets and has
a maximum output of 18 MW.
Power demands across
Mozambique are rapidly
increasing as the country’s
annual GDP grows by more
than 7 per cent and its industrial
sector rapidly expands.
However, electricity supplies in
the north have been strained
due to seasonal fooding
that has caused disruption to
networks in several provinces.
EDM executive board
member Carlos Yum said:
‘Nacala is experiencing
rapidly growing commercial
and industrial activity based
around its role as a logistics
hub of northern Mozambique.
By adding additional
generation capacity close to
areas of high energy demand,
EDM is addressing increased
power requirements with
fast-track power provision
until longer-term sustainable
solutions can be deployed.’
1503cospp_34 34 3/12/15 5:02 PM
Page 37
Genset Focus
www.cospp.com Cogeneration & On–Site Power Production | March - April 2015 35
Cummins ships European Grid Code-compliant gensetsCummins Power Generation
has announced that its
certifed Grid Code Compliant
generator sets have been
delivered successfully to a
customer in Germany.
Compliance for grid-
connected power plants is
already a legal requirement
in Germany, with many other
countries expected to follow
suit. DNV GL has validated
the Cummins 60-litre and
91-litre lean-burn gas genset
range as fully compliant with
the grid code requirements of
Germany, France and Italy.
Cummins said its team
studied variations in grid code
requirements across network
operators and countries with
the aim of designing genset
components that could meet
the electrical and mechanical
stresses encountered during
grid faults. Computer-aided
design tools were used to
determine the stresses and
optimise designs for the
products’ expected lifetime.
The gensets then underwent
testing in parallel with the
live UK National Grid, using a
simulation device to create a
localised fault. Real test results
were then used to validate a
model which could predict the
gensets’ performance in the
event of a low-voltage grid fault.
For more information, enter 13 at COSPP.hotims.com
Himoinsa gensets used in Egyptian water treatment plants Himoinsa has supplied
Acciona Agua with fve
gensets for operation in four
water treatment plants in Egypt.
The project aims to purify
150,000 m3/day of urban
wastewater, and re-use it for
irrigation. The gensets activate
the water purifcation system
whenever a power cut occurs,
‘something that happens
quite frequently in this area,’
said Leopoldo Lainz, Asia
Pacifc Development Manager
for Acciona Agua.
The largest plant, with a
fow of 82,000 m3/day, is the
Abnoub-El Fath plant where
two open gensets were
installed, the HMW-1135 T5 and
HTW-2030 T5 models. The two
gensets, with outputs of 1200
kVA and 2250 kVA, will allow
supply to reach a population
of over 300,000 people,
Himoinsa said. The sewage
plants of Sodfa-El Ghanayem
and El Ayat, which have
similar characteristics, have
been equipped with HTW-920
T5 gensets. Both emergency
gensets will help maintain
activity at the plants, which will
supply over 200,000 people.
The plant in Abu Simbel, a
popular tourist destination,
is equipped with a 400 kVA
generator set, the HMW- 350 T5
model.
HAVE YOUR SAY: BAROMETER OF POWER SECTOR CONFIDENCE LAUNCHES IN APRIL
This month sees the launch of a poll of power industry professionals which will provide a comprehensive guide to confdence in the European sector.
The European energy industry is undergoing widespread changes in the way it produces and delivers electric power to industry and consumers.
This energy transition is shifting the sands under the baseload providers in the coal, gas and nuclear sectors, so that distributed generation, renewables, smart energy systems and consumers are playing an increasingly important part in the electricity value chain.
As power industry companies contemplate their next important step, it is crucial that they have an understanding of the current state of the industry and a vision of where it is going. Thus research and reports are essential to support their strategic thinking.
Building on its expertise and the audience generated by its global POWER-GEN events, PennWell International is launching a POWER-GEN Confdence Index.
A comprehensive pan-European report for the power industry, the POWER-GEN Confdence Index will provide key market information, insights and trends to aid strategic decision making. Compiled on an annual basis to facilitate year-on-year trend analysis and comparison, this authoritative industry study will deliver insight, perspective and direction.
To ensure that the POWER-GEN Confdence Index for Europe represents the views and opinions of all aspects of the industry, COSPP invites you to participate in the study.
Why contribute to the POWER-GEN Confdence Index?
1. An opportunity to contribute to a ground-breaking initiative in the power sector – the inaugural POWER-GEN Confdence Index
2. An opportunity to contribute to an authoritative and comprehensive report providing key market information and insights
3. An opportunity to have your say on the key issues facing the power sector
4. An opportunity for your voice to be heard and for you to infuence and help shape strategic thinking in the power sector
5. Respondents completing the Confdence Index questionnaire will receive the full Confdence Index report free of charge
6. Respondents to the Confdence Index questionnaire will be invited to join a dedicated Social Media Group designed to elicit further discussion
As a power industry professional, your opinion has never been more important. Please contribute to the POWER-GEN Confdence Index to help shape the power industry of the future.
For further information please visit www.powergeneurope.com/
index/power-gen-confdence-index
POWER-GEN CONFIDENCE INDEX
A PennWell Event
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Cogeneration & On–Site Power Production | March - April 2015 www.cospp.com36
Diary
DistribuGen Conference and
Trade Show 2015
7 – 9 April
Houston, Texas, USA
www.distribugen.org
Energy Cities 2015
22 – 24 April
Aberdeen, Scotland
http://aberdeen2015.energy-cities.
eu/
37th Euroheat & Power
Conference
27 – 28 April
Tallinn, Estonia
www.ehpcongress.org
POWER-GEN India
& Central Asia
7 – 9 May
New Delhi, India
www.indiapowerevents.com
COGEN Europe Annual
Conference
19 – 20 May
Brussels, Belgium
www.cogeneurope.eu
POWER-GEN Europe
9 – 11 June
Amsterdam, The Netherlands
www.powergeneurope.com
Renewable Energy World
Europe
9 – 11 June
Amsterdam, The Netherlands
www.renewableenergyworld-
europe.com
5th China International
Distributed Energy Expo
Beijing, China
15 – 17 June
www.cdee-expo.com/en/
ASME Turbo Expo
Montreal, Canada
15 – 19 June
www.asmeconferences.org
POWER-GEN Africa
15 – 17 July
Cape Town,
Republic of South Africa
www.powergenafrica.com
Asia-Pacifc District Cooling
Conference
25 – 27 August
Bangkok, Thailand
http://energy.feminggulf.com/
asia-pacifc-distric-cooling-
conference
POWER-GEN Asia
1 – 3 September
Bangkok, Thailand
www.powergenasia.com
POWER-GEN Asia Financial
Forum
1 – 3 September
Bangkok, Thailand
www.powergenasiafnance.com
44th Turbomachinery, 31st
Pump Symposia
14 – 17 September
Houston, Texas, USA
www.pumpturbo.tamu.edu
POWER-GEN Middle East
4 – 6 October
Abu Dhabi, UAE
www.power-gen-middleeast.com
POWER-GEN International
8 – 10 December
Las Vegas, Nevada, USA
www.power-gen.com
Send details of your event to Cogeneration and On-Site Power Production:
e-mail: [email protected]
Diary of events
ASME INTERNATIONAL GAS TURBINE INSTITUTE - ASME TURBO EXPO IBC
CIRCOR ENERGY BC
CMI ENERGY 5
HILLIARD CORPORATION IFC
LESLIE CONTROLS, INC. BC
MAN DIESEL & TURBO SE 1
POWER-GEN EUROPE / RENEWABLE ENERGY
WORLD EUROPE CONFERENCE & EXHBITION 31
POWER-GEN INDIA & CENTRAL ASIA /
DISTRIBUTECH INDIA CONFERENCE & EXHIBITION 33
SEL 23
SIPOS AKTORIK 11
SOHRE TURBOMACHINERY, INC. 21
TEDOM 27
WORLD ALLIANCE FOR DECENTRALIZED ENERGY 17
YOUNG & FRANKLIN, INC. 19
Advertisers’ index
1503cospp_36 36 3/12/15 5:02 PM
Page 39
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