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Established in 1896, Power Engineering magazine is the comprehensive voice of the power generation industry that provides readers with the critical information needed to remain efficient and competitive in today's market. For three years in a row, Power Engineering has been named the most read and useful magazine in the power industry. Power Engineering Online provides up-to-the-minute energy news, stock quotes, five years of searchable editorial archives, power generation conference schedule and details, and an industry product and services guide. Power Engineering is part of the PennWell energy group, the largest U.S. publisher of electric power industry books, directories, maps and conferences.
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NUCLEAR SAFETYDEVELOPING A STRATEGY
GAS TURBINESINCREASING EFFICIENCY AND FLEXIBILITY
WIND TURBINESOPTIONS FOR LUBRICATION AND MAINTENANCE
the magazine of power generation
NATURAL GAS:NATURAALLLLLL GGGAS:NATURAAAALLLLLLLLL GAS:Investing in theRevolution
thhe magazine of power generatiion e
117YEARS
1305pe_C1 C1 5/7/13 8:56 AM
March 2013 www.power-eng.com
EMISSIONS CONTROL UNDERSTANDING YOUR OPTIONS
HYDROPOWER THE POWER OF REHABILITATION
PRB COAL CHALLENGES AND SOLUTIONS
the magazine of power generation
Wind Turbine TECHNOLOGY CHOICES
NHA S
pecia
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rtisin
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tion 3
5-47
117YEARS
the magazine of power generation
the magazine of power generation
A quick start guide to MAXIMIZING our interactive features.Welcome to the Digital Edition of
SHARE an article or page via social media.
Click PAGES to view thumbnails of each page and browse
through the entire issue.
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March 2013 www.power-eng.com
EMISSIONS CONTROL UNDERSTANDING YOUR OPTIONS
HYDROPOWER THE POWER OF REHABILITATION
PRB COAL CHALLENGES AND SOLUTIONS
the magazine of power generation
Wind Turbine TECHNOLOGY CHOICES
NHA S
pecia
l
Adve
rtisin
g Sec
tion 3
5-47
117YEARS
the magazine of power generation
the magazine of power generation
A quick start guide to MAXIMIZING our interactive features.Welcome to the Digital Edition of
SHARE an article or page via social media.
Click PAGES to view thumbnails of each page and browse
through the entire issue.
Easily browse all BACK ISSUES.
SEARCH for specific articles or content.
View the table of CONTENTS and easily navigate directly to an article.
DOWNLOAD the issue to your desktop.
PRINT any or all pages.SHARE an article via email.
Easily NAVIGATE through the issue.
Click directly on the page to ZOOM in or out. Fit the issue to your screen.
TabTransition_Template.indd 1-2 3/19/13 6:03 PM
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1305pe_C2 C2 5/7/13 8:56 AM
www.power-eng.com 1
OPINION
BY RUSSELL RAY, MANAGING EDITOR
COAL:An Important Option
The outlook for coal-f red
power production in the U.S.
is not as ominous as most
people think. Predictions of the death
of coal-f red power are based on hype
from enthusiastic idealists and unwit-
ting journalists caught in a popular
campaign against coal.
The transition to gas-f red generation
will continue, which is a good thing.
Increasing the use of this nations large
supply of shale gas will lead to fewer
emissions, better eff ciency and more
diversity.
But coal will continue to be the
backbone of the nations power
sector because of its reliability and
affordability. The natural gas industry,
for a number of reasons, is not ready to
take the lead in providing most of the
nations power supplies. Most power
producers acknowledge this risk. There
are too many questions about reserves,
pipeline capacity and pricing. Whats
more, the increasing use of natural
gas as a transportation fuel and the
opportunity to sell U.S. gas supplies
overseas at higher prices creates a large
amount of risk, which means power
producers will need signif cant coal
capacity to mitigate that risk. After all,
the nations grid was built around coal,
which makes coal largely more reliable
than gas.
Coal will remain the dominant
source of power generation in the
U.S. for the next 27 years, according
to the Department of Energys Annual
Energy Outlook, which was released
last month. Coal will account for 35
percent of the nations power in 2040,
down from 42 percent in 2011, the
report showed. Gas will be used to
produce 30 percent of the countrys
power supplies in 2040, up from 24
percent in 2011. The amount of power
produced from renewable resources
will grow from 13 percent in 2011 to
just 16 percent in 2040.
The lions share of future demand
will be met with whats left of the
nations existing f eet of coal-f red
plants, upgraded at great cost with
emission control technologies.
However, its not enough. In the
name of reliability and affordability,
power producers should be given the
option of building new generation
fueled with coal. Right now, they dont
have that option. It was eliminated
under a new greenhouse gas rule that
essentially bars the construction of
a coal-f red plant in the U.S. It is one
of the most ill-conceived rules ever
proposed by the EPA.
But the book on new emission stan-
dards for coal-f red plants is still be-
ing written. Just last month, the EPA
delayed the release of its greenhouse
gas standard for new plants. The agen-
cy said it needs more time to review
more than 2 million comments on the
rule. Industry observ-
ers say the delay
means the agency
may revamp the
rule in a way that
returns to power
producers the op-
tion of construct-
ing new genera-
tion f red by coal.
Given that op-
tion, I believe
U.S. power
producers will
bear the added cost of pollution con-
trols and pursue new coal projects as a
tool to mitigate the enormous risk and
vulnerability posed by natural gas.
Meanwhile, the market is telling us
that coal should play a starring role
in this nations plan to meet demand
with reliable and affordable energy.
In March, the use of coal-f red
generation was 21 percent higher
than the same month last year,
according to Genscapes Generation
Fuel Monitoring Service. The use of
gas-f red generation and renewable
power fell 11 percent and 14 percent,
respectively.
Natural gas prices are rising much
faster than coal prices, prompting
power producers to use more coal to
meet demand. Gas prices have risen
60 percent in the last year, while coal
prices have increased just 2 percent
during the same period.
Giving power producers the option
to pursue new coal projects by
establishing a reasonable GHG limit for
coal is a compromise that achieves the
right balance between environmental
concerns and economic concerns. Lets
hope the EPA is listening.
If you have a question or a com-
ment, please contact me at russellr@
pennwell.com.
1305pe_1 1 5/7/13 9:05 AM
Power Engineering is the f agship media sponsor for
TM
POWER ENGINEERING ONLINE : www.power-eng.com
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POWER ENGINEERING, ISSN 0032-5961, USPS 440-980, is published
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DEPARTMENTS
1 Opinion
4 Industry News
8 Clearing the Air
10 Gas Generation
12 View On Renewables
14 Demand Response
16 Nuclear Reactions
18 What Works
70 Products
72 Generating Buzz
FEATURES No. 5, May 2013
26 SPECIAL REPORTNatural GasExecutive Roundtable
Executives from the fastest growing sector of U.S. power generation sit down with Power Engineering to discuss issues currently affecting gas power generation, including EPA regulation and cost issues.
117VOLUME
38 Gas TurbinesWith an increased amount of U.S. power generation coming from
both renewable energy and natural gas, Power Engineering examines
the latest innovations in gas-turbine technology that can
accommodate the variability of wind and solar power.
52 Nuclear Safety in 2013:An Overview
Associate Editor Denver Nicks gives an overview of where the nuclear
industry currently stands on safety as plant operators deal with increased
concern and scrutiny in the aftermath of the Fukushima incident.
46 SteamTurbine Rehabs
Learn about the challenges and possible outcomes of
steam turbine rehabilitation, which can allow a power
producer a chance to optimize an entire turbine design.
60 Wind Turbine Lubrication and Maintenance
Wind turbines represent a large investment to their owners
and may present unique challenges when it comes to
lubrication and maintenance.
1305pe_2 2 5/7/13 9:05 AM
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INDUSTRY NEWS
Coalition of states threaten EPA with suit over NSPS delayTen states, the District of Columbia
and New York City have sent a letter to
the U.S. Environmental Protection Agen-
cy threatening to sue over the delay in
f nalizing the New Source Performance
Standard.
The notice provided EPA 60 days be-
fore the lawsuit is f led. EPAs deadline
to f nalize the NSPS rule was April 13.
The other states joining the action are
Connecticut, Delaware, Maine, Massa-
chusetts, New Mexico, Oregon, Rhode
Island, Vermont and Washington.
The rule was originally introduced in
March 2012 while Lisa Jackson was EPA
administrator. Gina McCarthy has been
nominated to take her place.
NRG Energy proposes three gas-f red projects in New YorkNRG Energy is proposing at least one
new natural gas-f red power plant and
possibly two others to replace the loss of
generation from the 2,037 MW Indian
Point nuclear power plant in New York if
it is shut down.
NRG is proposing a combined-cycle
natural gas-f red power plant that would
replace oil- and gas-f red units at the 580
MW Astoria plant in New York City. That
plant would cost up to $1.5 billion and
produce between 520 MW and 1,040
MW.
NRG is also proposing a new plant at
the site of the closed Lovett coal-f red
power plant. Reports have said closing
the plant could cost electricity customers
as much as $800 million.
In January 2012, a main generator out-
put breaker failed, and the missing in-
sulation caused a startup transformer to
short circuit, causing a loss of offsite pow-
er. The NRC said during an augmented
inspection the following September that
plant owners did not properly supervise
contractors and that they missed improp-
erly connected wires that led to the elec-
trical short.
Mississippi Power requests $540mn more for the Kemper County IGCC plantMississippi Power asked state regula-
tors for an additional $540 million to
build the 582 MW Kemper County inte-
grated gasif cation combined-cycle power
plant. The cost to build the plant is now at
$3.42 billion.
Due to a settlement agreement with
the state Public Service Commission, the
utility cannot recover the overruns from
customers. Instead, Mississippi Power is
reporting a $540 million loss for the f rst
quarter. The plant is expected to begin
operations in May 2014.
DOE announces nuclear fuel storage research The U.S. Department of Energy an-
nounced a new dry storage research and
development project to be led by the Elec-
tric Power Research Institute.
The project will design and demon-
strate dry storage cask technology for
high burn-up spent nuclear fuels that
have been removed from commer-
cial nuclear power plants. Burn up
Five-year uprate project completed at Turkey PointFlorida Light & Powers Turkey Point
nuclear power plant came back online
April 17 after a f ve-year uprate project in-
creased the output.
The $3 billion project was originally es-
timated to cost half as much. It was pro-
posed in 2007, but construction did not
begin until 2010. Unit 4 was upgraded
and connected to the grid on April 17.
Unit 3 was completed in 2012. Unit 4
will gradually be scaled up to 100 percent
output, at which point, the plant will be
capable of producing an extra 525 MW, or
15 percent above its pre-uprate capacity.
U.S. solar industryputs people to workin all 50 statesThe Solar Foundations interactive map
shows that California leads the nation in
the number of workers employed in the
solar industry. Arizona, New Jersey, Mas-
sachusetts, Pennsylvania, Colorado, New
York, Texas, Michigan and Ohio round
out the top ten states for solar jobs.
The maps also break down jobs by sub-
sector in each state, compiling data on in-
stallation jobs, manufacturing jobs, sales
and distribution jobs and project devel-
opment jobs.
ABB sued over nuclear plant shutdownKansas City Power & Light and other
co-owners of the Wolf Creek nuclear
power plant in Kansas are suing ABB for
more than $25 million in damages for
claims that ABB did not perform proper
repairs on a startup transformer that led
to a 10-week shutdown at the plant in
2012.
The repairs involved electrical path-
ways for redundant offsite power sources
that keep safety systems running without
interruption. An April 2011 inspection
showed that the replacements were not
properly insulated.
1305pe_4 4 5/7/13 9:06 AM
Bechtel is among the most respected engineering,
project management, and construction companies in
the world. Bechtel operates through five global
business units that specialize in power generation;
civil infrastructure; mining and metals; oil, gas and
chemicals; and government services.
Since its founding in 1898, Bechtel has worked on
more than 22,000 projects in 140 countries on all
seven continents. Today, our 53,000 employees team
with customers, partners and suppliers on diverse
projects in nearly 50 countries. We stand apart for our
ability to get the job done rightno matter how big,
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Building Confidence
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1305pe_5 5 5/7/13 9:06 AM
www.power-eng.com6
INDUSTRY NEWS
hydroelectric plant near Great Falls.
The single, 60 MW unit replaced
smaller units with a combined capac-
ity of 35 MW that were installed be-
tween 1910 and 1930, which increased
the output by 70 percent. The new unit
began commercial operation on April
22.
The overhaul also included a new
turbine with wider f ow passages and
fewer rotating surfaces for increased
f sh safety and a $38 million, 100 kV
interconnection project that will con-
nect the f ve hydropower plants to
NorthWestern Energys grid.
Fluor to continue nuclearO&M work with PG&EPacif c Gas & Electric (PG&E) ex-
tended a contract with Fluor Corp. for
operations and maintenance work at
the Diablo Canyon units 1 and 2 in
California.
The initial contract was awarded in
May 2010. Fluor will continue to pro-
vide ongoing maintenance, modif ca-
tion and outage services for the units.
Wind power projectin Ontario breaks groundSamsung Renewable Energy Inc. and
Pattern Energy Group broke ground on
the 270 MW South Kent wind project
in Ontario on April 30.
The project will use 124 turbines
made up of Siemens blades and CS
Wind towers.
There will be approximately 300
workers on-site during construction,
with 500 workers expected during
peak construction periods. The proj-
ect is scheduled to be completed in the
spring of 2014.
power from the Navajo Generating Sta-
tion in Arizona and the Intermountain
Power Plant in Utah.
LADWP is selling its share of the Na-
vajo plant to the Salt River Project by the
end of the year, and has already approved
an amendment to its contract with the
Intermountain plant to switch to receive
the output from a smaller gas-f red power
plant in southern California.
The ratepayer advocate also said end-
ing the contract with the Navajo plant
three years ahead of the termination date
could cost between $150 million and
$200 million.
Construction beginson 579 MW solar projectin CaliforniaMidAmerican Solar and SunPower
Corp. started major construction at the
579 MW Antelope Valley solar projects
in California. SunPower is designing and
developing the projects, while MidAmer-
ican Solar owns them. SunPower is also
the engineering, procurement and con-
struction contractor and will provide op-
erations and maintenance services under
a multi-year agreement. Southern Cali-
fornia Edison has two power purchase
agreements for the output
The plant is expected to be completed
by the end of 2015.
Overhaul completed at Montana hydroelectricpower plantPPL Montana completed a three-
and-a-half year, $209 million ex-
pansion at the now 60 MW Rainbow
relates to the power extracted from
reactor fuels. The work builds on the
steps the DOE is taking in FY 2013,
and has proposed for FY 2014, to sup-
port a new strategy for the back end of
the nuclear fuel cycle.
Gas plant relocation could cost Canadian taxpayers $275mnA decision to end construction on a
280 Mw natural gas-f red power plant
in Mississauga, Ontario, and relocate
it to Sarnia will likely cost taxpayers
$275 million, according to the Ontario
Auditor General.
Construction on the plant began in
June 2011, but after the general elec-
tion the following October, the Liberal
Party said it would cancel construction
of the plant. At the time, the party said
the costs would be around $190 mil-
lion once a litigation settlement was
included. However, a special report
said total costs are about $351 million,
but that is offset by an estimated sav-
ings of about $76 million.
LAs move from coalcould cost $600mnLos Angeles Mayor Antonio Villarai-
gosas plan to end the use of coal-f red
generation could cost the city more than
$600 million, according to the LA Times.
The ratepayer advocate for the Los An-
geles Department of Water and Power
(LADWP) said he was not sure what that
effect would have on electric bills. Cur-
rently, the city receives 39 percent of its
1305pe_6 6 5/7/13 9:06 AM
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CLEARING THE AIR
costs by installing a solution today
that will only be regretted later as it
may be too costly to operate because
of the increase in costs for intangibles
required. Some more expensive solu-
tions upfront may offer certainty of
outcome for many years to come by
eliminating the need for externalities
such as sorbents or other chemical
additions. These running costs could
rise due to supply and demand issues,
transportation, etc. But you can say the
cost of money is more pressing now.
We all know the pay me now or pay me
later routine, just keep these factors in
front of you.
Many decisions face our coal f eet
today. Retrof t, retirement, gas conver-
sions all come with various costs, risks
and yes uncertainty. And, there are
more regulations that are coming that
will most certainly play a signif cant
role in making these decisions even
more diff cult. The National Ambient
Air Quality Standards (NAAQS) and
Green House Gas (GHG) regulations
are just two more giant gorillas in the
waiting room, not to mention water
eff uent guidelines, 316(b) and coal
combustion residue. Will your MATS
solutions add complications to your
wastewater streams or solid byprod-
ucts? Will they contribute to GHG /
CO2 emissions?
These daunting facts may favor
the consideration of shutting down a
coal asset. We wouldnt say that the
decision to shut down a plant is easy,
as we know many factors come into
play. Each plant has its own set of
Utilities have until April 2015 to
comply with the Mercury and
Air Toxics Standard, otherwise
known as MATS. If you do the math in
regards to evaluating your options in-
cluding bidding and procuring a solu-
tion, the time is running short to pull the
trigger on deciding the fate of your plant.
In some cases, depending upon your spe-
cif c needs, time may be too short to im-
plement the necessary technologies and
avoiding generation interruption (GI).
You (Joe) may be forced to take a unit off
line while the changes are being installed
and commissioned.
Many solutions to meet MATS
may be less onerous then you think.
Companies supplying technology
solutions are willing to provide proven
options that could be implemented in
stages. Remember not to paint yourself
into a corner by electing a solution that
will get you into compliance now but
force you into other issues down the
road. Economical heartburn can result
from having to rip out equipment
that was installed in a location that is
needed for future upgrades.
Drill a step deeper and remember
when making plans or decisions now
to consider what will be implemented
next. Always think smart and do not
overlook something obvious like
layouts with future upgrade potentials,
auxiliary transformer sizing or draft
system sizing when making decisions
about a technology solution.
There are many cases where there is
more than one solution for meeting
MATS. It could be attractive to save
specif c factors to evaluate including
the impacts on the local economy. Re-
powering is in some cases possible,
but nothing can justify an outcome
that leaves our nation with voids
of depleted energy and a less than
dependable grid. Natural gas prices
have made this even more complex
and at the same time easier for some to
determine their path ahead for MATS
compliance.
Logically, it would make sense to
have a balanced portfolio of energy
sources and fuel mix which will include
coal. Clean coal technology is real and
available today. Dont leave your coal
plant behind without considering all
of the available options.
This write-up would be incomplete
without mentioning MATS for new
units, although few in the U.S. are
building or planning new coal-f red
plants at this moment. We do not see
good reasons for new units to have
so much more stringent limits than
existing ones. After all, the same state-
of- the-art pollution control equipment
is used for retrof t and new build units.
Limits too low to measure accurately
and repeatedly present tremendous
uncertainties to owners and suppliers
alike and yet contribute little to protect
the environment.
It may take some time for these
newer rules to impact specif c utility
units, but the clock is ticking, and the
pressure is on. Fasten your seat belts
and lets giddy up.
Think Smart, Act Fast and Enjoy the
ride.
MATS Its Timeto Giddy Up or GIJoeBOB NICOLO, DIRECTOR, AQCS, HITACHI POWER SYSTEMS AMERICA, LTD.
1305pe_8 8 5/7/13 9:06 AM
Founded in 1988, PIC has been a leader in the
power generation industry for over 20 years. We
are experts at managing multi-faceted projects
including start-up and commissioning, operations
and maintenance, installation, turbine outages,
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Combine these capabilities with our responsive
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GAS GENERATION
gas emissions since 1992.
Natural gas combined-cycle tur-
bines are also far more eff cient than
boilers or other forms of combustion
about 40 percent more power comes
from each unit of energy input.
Perhaps most importantly, utilities
are responding to the broad scientif c
consensus of our nations prolonged
abundance of natural gas and the low,
steady prices that will accompany con-
tinued development.
ABUNDANT BY ANY
ESTIMATE
This game-changing abundance and
the potential for consumer savings
have become key factors in the energy
choices of some of our biggest custom-
ers. As representatives of the nations
largest independent natural gas pro-
ducers, Americas Natural Gas Alliance
(ANGA) has been working with utili-
ties, independent generators, regula-
tors, organized markets and legisla-
tors to ensure conf dence in the ability
of natural gas to fulf ll the major and
growing role it now plays in U.S. power
generation.
Thanks to the shale gas revolution,
North Americas recoverable resource
base is projected to last for generations.
Todays expectations of natural gas
production in the lower 48 states are
dramatically higher than they were
in 2007, the year before shale-driven
abundance was truly recognized. Nat-
ural gas productivity has led to dra-
matic decreases in price, resulting in
impressive consumer savings. Conser-
vatively, U.S. utility consumers are sav-
ing more than $50 billion per year, and
by some measures more than twice
The promise of shale gas has
been dominating the energy
debate for several years now.
But the conversation is shifting from
the potential to the practical in the
choices utilities are making, in the fa-
cilities and pipelines being built and in
the real, tangible progress being made
in reducing our greenhouse gas emis-
sions. In other words, shale gas has ar-
rived, and its here to stay.
TURNING IT ON
In the last decade, natural gas-f red
power generation has accounted for
the lions share of electricity additions
in the U.S., making up 73 percent of
new capacity. Together with wind,
the two have captured 99 percent of
all new generation capacity. Until just
recently, however, many of these ad-
ditions were sitting dormant, under-
utilized and passed over for coal-f red
generation.
The tide is changing. In April 2012,
for the f rst time in history, actual gen-
eration produced from natural gas-
f red plants equaled that produced
from coal-f red plants, at 96 million
MWh apiece. Market share still de-
pends on relative prices, but this was
an important landmark.
Why the change? For one, natural
gas is our cleanest conventional fuel,
emitting far less NOx, SOx, and CO2
and none of the particulates or mer-
cury. This means cleaner air and, more
practically, fewer hurdles to construc-
tion. It is precisely this use of more
natural gas in power generation that,
according to the U.S. Energy Informa-
tion Administration, last year helped
us reach our lowest level of greenhouse
that, thanks to the drop in natural gas
prices.
TO MARKET TO MARKET
There is little credible debate about
the fact that abundant natural gas sup-
plies are available and could be used
virtually anywhere in the U.S. Today,
we have over 2.4 million miles of natu-
ral gas pipelines. On a national level,
16,000 miles of interstate pipeline
have been approved in the last decade,
the largest amount in 40 years. By con-
trast, only 900 miles of electric trans-
mission lines have been approved.
Our role has been to assure all par-
ties of the large supplies that now are
produced, often right in the market
area. The distance natural gas now
has to travel to market has dropped
dramatically, thanks to shale gas pro-
duction in 30 states. Take for example
the Marcellus and Utica shales: two
impressive resources that are being
produced near major industrial and
population areas precluding our his-
toric reliance on long pipelines to get
gas where it needs to go.
A PROMISE FULFILLED
As the shale gas revolution has come
of age, we have seen the enormous
promise of this resource fulf lled; as a
base load- capable fuel that is cleaner,
available at stable prices and vastly
abundant. Our air quality has seen its
greatest improvement in 20 years, ca-
pacity additions and actual generation
are up dramatically, and this f exible
resource is being delivered to market
via a rapidly expanding pipeline in-
frastructure. Shale has indeed arrived,
and its here to stay.
Shale Gas Comes of AgeMICHELLE BLOODWORTH, VICE PRESIDENT OF STATE AFFAIRS AND BUSINESS DEVELOPMENT, AMERICAS NATURAL GAS ALLIANCE
Author
Michelle works with
ANGAs State Affairs
Committees, as well
as utilities, regulators,
legislators and other
business-to-business
stakeholders to
communicate the
economic and envi-
ronmental benef ts
of the increased use
of clean, abundant,
domestic natural gas.
Prior to off cially join-
ing the ANGA team in
2010, Michelle was
extensively involved
in its creation through
her previous position
with ANGA member
company Energen,
where she spent
more than 20 years.
Michelle served as
the f rst co-chair of
ANGAs Communica-
tions Committee and
has made signif cant
contributions to the
organizations devel-
opment.
1305pe_10 10 5/7/13 9:06 AM
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1305pe_11 11 5/7/13 9:06 AM
www.power-eng.com12
VIEW ON RENEWABLES
BY TOM LEVY, MANAGER, TECHNICAL & UTILITY AFFAIRS, CANADIAN WIND ENERGY ASSOCIATION
Wind energys contributions of
clean power in North Ameri-
ca in 2012 grew signif cantly.
The U.S. installed over 13 GW of new
wind capacity. In Canada, utilities con-
nected nearly 1 GW of new wind capacity.
The cumulative global capacity of wind
energy is now approaching 300 GW. This
growth is not by accident it has been
driven by forward thinking policy, and
has been enabled through sophisticated
design, tools and technologies.
There are many widely known and
accepted benef ts that wind energy de-
velopment brings to communities the
overwhelming positive environmental
attributes, increased taxes, revenue and
job creation. What is less well known are
the positive attributes that wind energy
brings to the bulk power grid. The pri-
mary purpose of the electrical system is
to deliver electricity on demand, when
needed reliably, safely and affordably.
The introduction of wind energy on the
electrical grid must not cannot com-
promise these underlying principles. The
modern power grid was designed based
on one-way f ow of electricity from a
centralized power source to a distributed
customer. Wind energy does not neces-
sarily f t this mould, and power engineers
have gone to great lengths to ensure that
wind energy can be interconnected with
the power grid without compromising
system reliability. In fact, wind farm and
system operators have sophisticated tools
that allow this f exible source of electric-
ity to provide clean electricity to the trans-
mission system in a reliable manner if it
could not accomplish this, all of the ben-
ef ts that wind has would be lost.
In Ontario, wind energy now repre-
sents an increasing portion of the prov-
inces generation f eet. Centralized Fore-
casting will be implemented to more
accurately predict variable wind and solar
generation output, and is an essential
tool for the Independent Electricity Sys-
tem Operator (IESO) to maintain system
reliability and market eff ciency. This
Centralized Forecasting service is similar
to services implemented in most jurisdic-
tions with comparable amounts of wind
generation.
Let us back up just a bit. Humans have
been harnessing energy from the wind
for literally thousands of years. The late
1800s saw the f rst documented use of
wind energy to create electricity. Prior to
this, wind energy was used for produc-
tion of mechanical power that pumped
water or ground grain. During the oil
embargos of the 1970s, engineers saw the
potential of an unlimited fuel source to
create electricity. The wind generators of
the 1970s were rudimentary in their de-
sign relative to the sleek and modern ma-
chines that are being built today. These
earlier models produced limited amounts
of electricity, and they did not have so-
phisticated power electronics to eff cient-
ly manage their operation. These were the
early designs; they were a squirrel cage
induction motor that had to disconnect
from the electrical grid when there was a
fault or a blackout. But they opened the
eyes of engineers and planners, and while
the industry faced a few hills and valleys,
varying policies and the like, those early
wind energy pioneers continued to see a
limitless energy potential.
Fast forward thirty years. Engineers
have advanced wind energy technology
from these early designs into the present
day sophisticated doubly fed induction
motors or Type 4 full converters. These
are marvels of engineering. They bring
with them SCADA systems that permit re-
mote operation and fault detection; they
contain advanced controls, sensors and
state-of-the-art power electronics. Mod-
ern wind turbines now have the capacity
to contribute to the reliable operation of
the bulk power transmission system.
The 2011 IEEE Special Edition (Vol. 9,
No. 6, Nov/Dec 2011) reports that mod-
ern wind turbines have a myriad of offer-
ings voltage and var control/regulation;
fault ride-through capabilities; real power
control, ramping and curtailment; prima-
ry frequency regulation; inertia response;
short-circuit duty control. This evolution
in wind energy technology is not by ac-
cident the need to ensure that the mod-
ern wind turbine is a good citizen on the
grid has been driven by an overarching
need to invest in our electrical system,
which is in part being driven by demands
of society for cleaner, less impactful elec-
tricity sources. The demand that we clean
up our act is not at the expense of reliable
and affordable electricity wind energy
more than f ts this role, and has clearly
risen to the challenge just ask Texas,
California, Iowa, Denmark, Ontario - or
even a little Canadian province called
Prince Edward Island.
North American Utilities Commit to Reliable, Affordable Wind Energy
1305pe_12 12 5/7/13 9:06 AM
Powerful Player in PowerTIC is one of the leading industrial contractors serving todays Power industry. With over 44,000 MW of installed capacity, TIC is consistently ranked in Engineering News-Record (ENR) as one of the Top 10 contractors for Power and/or Cogeneration installations.
TICs extensive power experience spans a variety of technologies, fuel types and confgurations, including Gas/Combustion Turbine installations in both combined and simple cycle operation; large Coal-Fired and other fossil fueled plants including both sub-critical boilers and supercritical steam generators, Integrated Gasifcation Combined Cycle (IGCC) projects, and Renewable Energy including Wind, Geothermal, Solar and Hydroelectric facilities, plus Alternative Fuels plants.
TIC - The Industrial Company9780 Mt. Pyramid Court, Suite 100Englewood, CO 80112(970) 871-7209
TIC-INC.COMFor info. http://powereng.hotims.com RS# 6
1305pe_13 13 5/7/13 9:06 AM
www.power-eng.com14
DEMAND RESPONSE
optimization of DR resources across pro-
grams or geography; Device technologies
not using or supporting open standards
for communications protocols and mes-
sages; No performance measurement ca-
pabilities or settlements ; Very little inte-
gration into back off ce systems; No data
sync across disconnected systems
STAGE 4: DEMAND RESPONSE
MANAGEMENT SYSTEMS (DRMS)
When DR challenges reach a level of
complexity, frustration, and operational
risk at which tools are not being effec-
tively used, or when the cost of operating
many disparate systems in parallel is sig-
nif cant enough, or when the lack of in-
tegration and automation investment in
large-scale harmonization, there is a cost
effective solution implement a DRMS.
A DRMS is an integrated command and
control system that manages the entire
lifecycle of DR programs and resources
across customer segments, device types,
and communications technologies. It
also acts as the integration hub managing
all DR related data f ows between opera-
tional and back off ce systems.
The Market for DR is maturing at every
level. Utilities like Nevada Energy have
proven the value and shown that DRMS
is the ultimate command and control
tool for forecasting and eff ciently using
DR so control rooms can preserve reli-
ability, energy traders can hedge against
high prices, and network planning en-
gineers can push out infrastructure up-
grade projects and direct capital to more
pressing needs.
Whether you are just beginning your
DR journey, in the middle of it, or at
Maturity Level 4, it is never too soon to
consider the savings and f exibility of DR,
and of implementing a DRMS.
Demand Response (DR) is a
proven alternative to adding
new generation with an ap-
proach that is zero-carbon, cost-effective
and environmentally-friendly.
DR technologies deliver a temporary
adjustment in energy consumption
usually due to a severe network reliability
issue or extremely high price in the real
time energy market. It is an effective tool
for postponing capital expenditures in re-
lieving network reliability constraints, or
avoiding spikes in energy prices and en-
ergy consumption. But what is the path to
implementing a successful DR strategy?
This article examines the traditional
4-stage Demand Response (DR) Maturity
Model. There are points along the DR ma-
turity path when a utility fully embraces
and implements DR such that it becomes
a real and reliable resource, but there can
be challenges in f elding successful DR
programs.
The market for DR is heating up. Utili-
ties of all sizes with multiple DR programs
in place are growing their portfolios.
Much of the industry is not implement-
ing its f rst DR program, but perhaps its
eighth or tenth.
THE UTILITY DR
MATURITY LIFECYCLE
STAGE 1: GETTING STARTED
Most utilities use some form of DR
perhaps just a phone call to a few large
industrial customers to reduce energy
consumption during a network reliability
emergency, or a legacy residential hot wa-
ter heater cycling program.
These f rst load reduction programs
usually were launched to preserve reli-
ability. They reduce overall network
outages and provide either time for a
network upgrade or replace the need for
network upgrades all together. For Retail-
ers, Coops, and Munis in Texas and oth-
er markets where scarcity pricing allows
peak energy prices to reach $5,000 per
MW this year and up to $7,000 in 2014,
it is not hard to justify DR. The measur-
able success of these programs usually
prompts utilities to extend DR deploy-
ment until the targeted network segment
or audience is saturated.
STAGE 2: SCALE & LEARN
Whether the f rst program was a suc-
cess or failure, need often arises for an-
other program, possibly due to network
capacity issues, avoiding peak energy
prices, or the unfavorable economics of
building high cost peaker plants.
Usually, the latest available device
technology is studied and deployed in a
new program with different rules often
targeted at new customer segments or
load prof les. A DR Aggregator is some-
times hired to handle part of, or most of
the DR management recruiting cus-
tomers, installing devices, scheduling DR
events when needed and signaling the
devices to reduce energy consumption.
In either case, a new program is created
with new rules, incentives, device tech-
nology and even new communications
infrastructure.
STAGE 3: DR CHALLENGES EMERGE
Multiple DR programs, device technol-
ogies, and communications paths man-
aged by multiple systems can quickly
become unmanageable.
Typical challenges faced by utilities
include: No single system for register-
ing customers and devices; No single
view or forecast of DR availability by
network segment; No ability to forecast
device response prof les or snap back; No
The Market for Demand Response
the DR MaturityModel Perspective
BY MARK TRIPLETT, MANAGING DIRECTOR, DRMS, ALSTOM GRID
1305pe_14 14 5/7/13 9:06 AM
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1305pe_15 15 5/7/13 9:06 AM
www.power-eng.com16
NUCLEAR REACTIONS
Blind Squirrels and ChinaBY BRIAN SCHIMMOLLER, CONTRIBUTING EDITOR
I cant say I put much stock in the
adage that posits, Even a blind
squirrel f nds a nut once in a
while. Seems to me that the squirrel
would encounter some other predator,
or the front tire of a passing car, long
before f nding that nut. I may have to
re-evaluate my lack of faith in that say-
ing, however, in light of a crystal ball
prognostication I made a few years ago
in this column.
Back in early 2011, I offered f ve
Lead-Pipe Cinch Predictions, one of
which concerned Chinas burgeoning
nuclear program. I boldly predicted
that China would offer a nuclear plant
design for export within f ve years. Not
only was this blind squirrel right, but I
was right three years ahead of schedule
(maybe that means I was wrong).
In early February, an executive at
Chinas state nuclear corporation,
SNPTC, said that the reactor being
built for export the CAP1400
would be ready the end of 2013. The
exploration of business opportuni-
ties on the world market will begin in
2013, Gu Jun was cited as saying in
the China Daily newspaper. The third-
generation CAP1400 reactor, which is
based on the AP1000 design, was de-
veloped through a 2008 agreement be-
tween SNPTC and Westinghouse, and
there are reportedly plans in place for
a larger, more advanced version called
the CAP1700.
While the Westinghouse association
will certainly add some validity to the
technical viability of the Chinese reac-
tor on the world market, commercial
success outside China will likely take
some time. Global familiarity with the
Chinese design and with the track re-
cord of Chinas operating nuclear f eet
is limited.
Still, I hesitate to hazard a guess as
to how long that some time might
be. Whatever the guess, export suc-
cess will probably come sooner than
expected. With 18 operating reactors,
China currently breaks into the top
10 in terms of countries with the most
number of operating reactors, but with
28 more under construction, and doz-
ens more in the planning and develop-
ment stages, China will soon be rival-
ing the United States for the top spot.
And no one can say that China is sat-
isf ed with older designs. China is the
only country where two of the worlds
most advanced designs the Westing-
house AP1000 (at Sanmen) and the
Areva EPR (at Taishan) are being
built. Beyond the CAP1400, China has
a memorandum of understanding in
place with Areva and EDF to develop a
new 1,000 MW Generation III reactor
that would be common to EDF, Areva,
and the China Guangdong Nuclear
Power Corp. (CGNPC).
Operationally, China is also deploy-
ing modern technology to standardize
and improve eff ciency. CGNPC, for
example, recently completed an ambi-
tious three-year effort to implement
f nancial and enterprise asset manage-
ment software from SAP at Daya Bay,
which will help the plant coordinate
daily operations, maintenance, supply
chain, and f nancials. CGNPC plans to
use this as the foundation for manag-
ing a nuclear f eet that will exceed 20
units in the next decade.
So whos on the list of potential early
buyers of Chinese nuclear technology?
South Africa is one possibility, based
on its plan to build six new nuclear
power stations by 2030 to deal with
that countrys energy supply challeng-
es. Turkey is another, with plans for a
5,000 MW nuclear facility in the Black
Sea province of Sinop. China is report-
edly on Turkeys short list along with a
Japanese-French consortium.
Even if China doesnt win either of
these awards, there are a few elements
in Chinas favor that will ultimately
convince someone to take the chance.
One is money. Financing a large mod-
ern nuclear plant is a roughly $10 bil-
lion investment, and China has the
deep pockets to support a given coun-
try in turning nuclear ambitions into
commercial reality. Another is time. As
more countries consider embarking on
commercial nuclear programs, China
will continue gaining experience from
the construction and operation of the
newest generation of nuclear reactors
in the world. Theyll be ready.
So keep your eyes on China. The day
is coming when a Chinese reactor will
be nearer to you than the provinces
of Guangdong and Guangxi. For now,
Ill bask in the glory of a prediction
come true.
Just dont ask me about one of the
other prognostications I made back in
2011that the U.S. Congress would
pass legislation allocating signif cant-
ly more money to the loan guarantee
program. Apparently, this squirrel was
too blind to f nd that nut.
1305pe_16 16 5/7/13 9:07 AM
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1305pe_17 17 5/7/13 9:07 AM
www.power-eng.com18
WHAT WORKS
part of the VRT offering, the AE Utility
inverters can perform Zero Voltage Ride-
Through (ZVRT), High Voltage Ride-
Through (HVRT) and LVRT. The AE Util-
ity inverters followed the utility required
timing prof le and quickly ramp back up
after an event has cleared. VRT allows
the inverters to ride through disturbance
events and enables the generation station
to stay online, and limit the revenue lost
to the investors while helping to stabilize
the grid. This event successfully demon-
strated the LVRT capabilities of the AE
Utility PV Inverters. The Solar Stations
graphs provide data for PG&E to better
understand the impacts of inverters with
LVRT capabilities to support the grid in
areas with a high penetration of distrib-
uted generation.
Figure 2 displays the voltage and cur-
rent waveforms captured by the SEL re-
lay at Westside Solar Station during the
February LVRT event. It can be seen that
the current temporarily increases for ap-
proximately 2 cycles at the inception of
the fault. This is expected behavior as
the units are operating at less than 50%
of their nameplate rating. When the line
voltage began to drop, the units attempt-
ed to maintain a constant output power
The 30 Advanced Energy (AE) 500
kW 1kV DC Utility PV Inverters
at PG&Es 15MW Westside Solar
Station successfully passed multiple low
voltage sag events. This sites inverters
are equipped with Voltage Ride-Through
(VRT) capabilities and are connected to a
Pacif c Gas & Electric substation outside
of Fresno, Calif.
AE 500kW 1kV Inverters at PG&Es
Westside Solar Station
On March 17, 2012, there were a to-
tal of 4 low voltage events caused by
momentary phase to phase faults on an
adjacent 12 kV circuit which is fed from
the same substation where this Solar
Station is connected. The Solar Station
is equipped with a Schweitzer Engineer-
ing Laboratories (SEL) relay at the 12kV
switchgear. The oscillography traces from
the SEL relay at Westside Solar Station
showed close to a 50% voltage depression
at the 12 kV bus for approximately 7 cy-
cles. During each of these events the units
were between 20 percent and 80 percent
of full-power. All the inverters remained
online, demonstrating the Low Voltage
Ride-Through (LVRT) capability of AEs
Utility inverters.
A similar event occurred on Feb. 7,
2012, when the adjacent feeder experi-
enced a short circuit condition causing
both A and B phases at the connected
substation to experience a 50 percent
voltage sag which activated the inverters
LVRT capabilities. The protective relays
on the faulted 12 kV circuit detected
the short circuit and cleared the fault in
approximately 7 cycles. The inverters
successfully rode through the event and
returned to normal operation upon clear-
ance of the short circuit condition. The
SEL graphs were collected and reviewed
by PG&Es Renewable Resource Develop-
ment department.
VRT timing prof les are features of-
fered in the AE Utility inverters. They
provide the inverter the ability to stay
connected with the grid under these ex-
ternal fault conditions. While there are
no specif c VRT requirements imposed
by the existing interconnection require-
ments at this time, PG&E voluntarily
implemented the VRT feature at this
solar site to demonstrate the benef ts of
having these features.
VRT enables inverters to stay online
during grid disturbances and produce
reactive power to stabilize the grid. As
Advanced EnergyPV InvertersRide-Through PG&E Low Voltage EventsBY ANASTASIOS HIONIS, PE, UTILITY APPLICATIONS ENGINEER, AE SOLAR ENERGY & STEVEN NG, PE, MANAGER, ENGINEERING RENEWABLE RESOURCE DEVELOPMENT, PACIFIC GAS & ELECTRIC
AEVRT & Utility Profles 1p. u. Volta
ge
1.2
1
0.8
0.6
0.4
0.2
01 0 1 2 3 4
SecondsThe VRT profle for the AE Utility PV Inverters is programmable to multiple regional profles
such as for FERC 661, NERC, & ERCOT, shown above.
FERC 661
ERCOT
NERC
AEVRT
1305pe_18 18 5/7/13 9:07 AM
Reality Is Better than Simulated ValidationIts one thing to mimic dynamic load conditions once or twice in a controlled test
environment with a pre set batch of tests...then profess proper validation. But its a
major difference when youre outputting real, on demand power to a utility grid with
a mind and priorities of its own.
At T-Point, were not just the turbine OEM were the Owner/Operator of a power
station with our leading edge technology serving an industrialized city of nearly
100,000. That means our tests arent just rehearsals theyre as real as it gets.
And since 1997, weve tested every milestone in the evolution of our G- and
J-Series engines the same way, under the very same conditions youd expect them
to perform for you.
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That gives us the freedom to run longer, run harder and test more comprehensively
-- including parallel testing on integrated gear such as steam turbines, condensers,
generators and static frequency converters. And the result is a highly reliable
installed G-Series eet thats logged over 1,951,000 Operating Hours and
17,000 starts as of January 2013.
Thats testing that pays off for us in faster development of better, more dependable
power systems; and pays off for you when you put them to work. For real.
Our T-Point Demonstration Plant Tests
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M501J Validation
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1305pe_19 19 5/7/13 9:07 AM
www.power-eng.com20
For info. http://powereng.hotims.com RS# 10
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and the AC current increased up to the
AC current limit before the LVRT features
were activated.
The February and March LVRT
events at Westside Solar Station pro-
vided PG&E with the actual data to
demonstrate the effect of successful
LVRT. It is expected that large PV Solar
Stations, such as Westside Solar Sta-
tion, will be required to be equipped
with VRT features in the near future.
The following are the two guiding doc-
uments that utilities and the system
operators are using to develop the VRT
requirement for large PV generating
stations:
NERC Standard PRC-024
The Technical Justif cation for the
New WECC Voltage Ride-Through
(VRT) Standard, A White Paper De-
veloped by the Wind Generation
Task Force (WGTF), dated June 13,
2007, a guideline approved by WECC
Technical Studies Subcommittee.
As utilities connect more large PV
projects onto the grid, it becomes more
important that these large PV projects be
equipped with VRT capabilities to stay
online during grid disturbances.
Voltage and current plot from the SEL
relay at Westside Solar Station2
This plot confrms that the Advanced Energy Utility PV inverters successfully rode throughthe February low voltage event.
VA(kVVB(kV
)VC(kV) IA IB
IC
50
0
50
5
0
5
IA IB IC VA(kV) VB(kV) VC(kV)
2.5 5.0 7.5 10.0 12.5 15.0
Cycles
1305pe_20 20 5/7/13 9:07 AM
FLUOR, WE ARE
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recently completed Dominions 590-megawatt combined cycle project, the Bear Garden Generating Station.
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Two TRIM-NOX(R) urea injection skids with the day tanks, f ow meters and control panels with HMI operator touch screens. Each of the two boilers had its own injection system and each injection system controlled three injec-tors. Photo courtesy of Nationwide Boiler
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www.power-eng.com26 www.power-eng.com26
The discussion centered on the future of
gas-f red generation, the sustainability
of todays low gas prices and the poten-
tial impact of increasing environmental
regulation.
The participants were: Tom Alley,
vice president of generation for EPRI;
Scott Austin, manager business devel-
opment for Bechtels thermal business
line; Amy Ericson, vice president gas
product platform for Alstom Power;
and Toby Thomas, vice president gen-
erating assets for AEP.
What follows is a transcript, edited for
length and style, of that discussion.
POWER ENGINEERING: With the re-
cent increase in the price of natural
gas, do you see power plants con-
tinuing to turn to it as the preferred
fuel choice as they have for the past
several years?
AMY ERICSON: Theres one thing that
we know for certain, and thats that fossil
fuel prices are uncertain and will remain
uncertain. Its interesting particularly
Power Engineering sat down with four executives to discuss the future of gas-f red generation in the U.S. and the potential impact of increasing environmental regulation.BY JUSTIN MARTINO, ASSOCIATE EDITOR
Natural gas is becom-
ing more important
in the power gen-
eration industry each
year. With increas-
ingly strict regulations on emissions
controls and growing concerns about the
environment, more companies are look-
ing to natural-gas f red generation as a
reliable, clean source of energy.
Natural gas-f red plants can also quick-
ly increase to peak load, making the fuel
a good complement to renewable energy
sources, and are also faster and less ex-
pensive to build than many other power
sources. With the growing use of natural
gas, however, many questions remain to
be answered about the fuel sources cost,
the increasing reliance on natural gas over
other fuel sources and upgrading natural
gas pipelines to cover the increased usage,
among other issues.
I recently moderated a roundtable
discussion with executives from Ameri-
can Electric Power, Electric Power Re-
search Institute, Alstom and Bechtel.
over the past several years that weve seen,
not just in the US but globally, an obvious
connection between coal and gas usage
and pricing. Weve seen gas generation
go up in the US on the heels of the low
prices, and weve seen that usage temper
while there has been a comeback a bit in
coal. I think these f uctuations are what
were going to continue to see. In fact,
we hear from our customers that at this
point, theyre taking a long-term view.
Theres no doubt that their interest in us-
ing natural gas for electricity has grown
steadily for the reasons that arent likely
1305pe_26 26 5/7/13 9:07 AM
www.power-eng.com 27
Alstom Power, which is working to create new technology for the power industry,
recently delivered GT24 natural gas turbines to the El Sauz Plant in Mexico. Photo
courtesy of Alstom.
1305pe_27 27 5/7/13 9:07 AM
www.power-eng.com28
of a coal plant, so when folks are trying to
plan and build, gas is certainly one of the
least cost options. Smaller staff, easier to
site gas is just an easy decision, and it re-
ally concerns me that the industry doesnt
have the f exibility to provide more diver-
sity. Again, I think everybody is kind of
being led in that direction.
ERICSON: I can tell you from a tech-
nology development perspective that
we preach diversity. We invest in diverse
technologies, and its exactly for this pur-
pose, and for the protection of supply and
price and policy and even public atti-
tudes because they change in time. But
I would have to say that the prospect of all
gas and renewables in the future is prob-
ably not the optimal prospect for the U.S.
and for the industry, and I think people
probably agree with that.
AUSTIN: From a Bechtel perspective,
weve been around for about 115 years.
Weve seen the peaks and the valleys of
gas pricing over that time and the desire
to move forward with gas in the current
environment. I would concur with Amys
comment that maintaining diversity from
a capability perspective is an important
to go away, which would be the match-
ing of renewables and the speed with
which they can be constructed and com-
missioned. Personally, from an Alstom
perspective, we def nitely see the trend
toward natural gas continuing.
TOM ALLEY: I think that the pricing
change we see here for units that are op-
erating on the margin, the coal units that
are operating right on the margin, may
come back into play, but for a regulated
utility, I dont see that impacting their
business very much. For the unregulated
generators out there, it may open up a
little opportunity for a highly-eff cient,
environmentally-controlled coal plant
to come back into play, because theyve
been under a lot of pressure with the low
gas prices. I dont see this pricing change
really inf uencing the industry much.
SCOTT AUSTIN: Based on the informa-
tion that weve received and interaction
were having with our customers, I would
echo Toms comments that what were
seeing here in the U.S. is a lean toward
new builds from a natural gas perspec-
tive. Given the outlook of the relatively
stable $5 to $7 range in the long term, we
would see the gas-f red generation being
the mid-term selection.
POWER ENGINEERING: EPA regula-
tions are making it more expensive to
operate coal-f red power plants. With
some of the rules coming out, it may
be almost impossible to build new
coal-f red plants. With more com-
panies building natural gas-f red fa-
cilities to compensate for that, does
that raise concerns about maintain-
ing f eet diversity?
TOBY THOMAS: We certainly do have
concerns from a fuel diversity perspec-
tive. In any long term view, if you focus
too much on one fuel or one technology,
youre going to potentially have problems
long term. You def nitely want to be di-
versif ed. The other side of it is that the
more power plants you have relaying on
gas pipelines, the more potential risk you
have to grid reliability. On those warm
summer days, youre starting to get close
to peak f ows on gas pipelines, similar
to what you see with the winter heating
load, and sooner or later somebodys go-
ing to have to get cut. You can build a
gas-f red power plant, but you do have to
line up the fuel supply not necessarily
the commodity but the transportation to
make sure you can get gas when you need
it. Also, if the pressure on that gas pipe-
line goes too low, all those gas plants are
coming off.
ALLEY: I would say Im def nitely con-
cerned about diversity. I think the indus-
try is being led down a path toward natu-
ral gas as a destination fuel source. We
hear it in the presidents recent State of the
Union Address. We see the EPA rulings for
Mercury and Air Toxic Standards putting
extra pressure on the coal plants and coal
plants closing. We see the EPA proposed
rulings for greenhouse gas emissions for
the New Source Performance Standard,
which put a lot of pressure on coal. I think
the very eff cient natural gas combined
cycle plants can meet that standard at
least as its proposed, but not coal plants.
Plus, a gas plant is about one-third the
cost of a nuclear plant and half the cost
Toby Thomas
Scott Austin
Amy Ericson
Tom Alley
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manage that situation pretty well. I dont
foresee that EPA rulings are going to
heavily impact the business. I dont think
you can say there will be no impact, but
I just dont see a heavy impact. Im more
concerned, when it comes to gas pricing,
with the demand side of the equation,
with as many industries as we see moving
toward gas. Its not just the electric sector.
Its transportation. Weve seen some an-
nouncements recently on locomotives
being converted to natural gas. The au-
tomobile industry is looking at it. The
chemical industry is looking at it. There
is a lot of discussion about whether the
U.S. ends up being a exporter of natural
gas. I see all of this having a much greater
impact on the pricing than I would EPA
regulations.
POWER ENGINEERING: One thing
it seems people are concerned
about on the volatility of natural
gas is so many other places uses
natural gas as well, while coal
is predominately used for power
generation. How much does that
factor into the equation?
THOMAS: There are a lot of petro-
chemical ref neries and others that can
use natural gas, and you could potentially
increase demand quite a bit. On the pow-
er generation side, weve spent hundreds
element that we strive for, to be able to
facilitate the diversity thats needed in
our energy mix as a nation. We look to
our customers to make those decisions as
demand warrants, and we stand ready to
implement those technology solutions as
theyre appropriate.
POWER ENGINEERING: The EPA is
starting to look at the affects of hy-
draulic fracturing on the environ-
ment. Is there a concern the EPA
may make rules that make fracking
an uneconomical source for obtain-
ing natural gas and cut down on the
current gas reserves?
ALLEY: The EPA and other government
agencies are all sorting out the jurisdic-
tion over fracking and everything associ-
ated with it. Weve seen a lot of discussion
about the water use and cleaning up wa-
ter from fracking were sitting at a wa-
ter conference right now in Atlanta and
some of the technologies were looking
at are actually coming out of that indus-
try so I think the industry is trying to
The 550-megawatt combined cycle natural gas-f red
J. Lamar Stall Unit at AEPs Arsenal Hill Power Plant in
Louisiana went into commercial operation in June 2010.
Photo courtesy of AEP.
1305pe_30 30 5/7/13 9:07 AM
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of millions, if not billions, to build a pow-
er plant, youre kind of stuck with it for a
while, so its certainly a concern to add to
the volatility. We have a lot more supply
now, but it wasnt that long ago we had
double digit gas prices because the mar-
ket thought supply/demand was tight. It
doesnt take too many traders and others
that feel things are tightening up to really
start pushing the market. Will it happen?
I certainly dont know. Im not an expert
on that, but its a concern.
POWER ENGINEERING: What ben-
ef ts do you receive from a natural
gas-f red plant as opposed to a
coal-f red plant using state of the art
technology that would cut down its
emissions, or a power project using
renewable resources?
ERICSON: Many plants are operating
with daily starts and stops or on a season-
al basis, and this operating is changing
throughout the lifetime of these plants,
which are coming up on their 10-year
or 12-year installation date. The reasons
that are driving that are the renewables
penetration and, again, the f uctuation of
fossil prices. Those arent likely to change,
and the beauty of natural gas is that its
always available. Not just that its always
available, because certainly so are nuclear
and coal, but that it can actually deliver
large amounts of electricity directly onto
the grid in a short period of time for ex-
ample, 450 MW in 10 minutes. And so I
do think that given the changing market
conditions and the need for f exibility,
natural gas generation is being chosen
because it can respond when it needs to
respond. It can be f exible.
AUSTIN: I would concur with Amys re-
marks there. From a general perspective,
it was alluded to earlier that the initial
capital cost of a combined cycle plant is
much lower than a coal plant. The time
frame to implement the construction is
probably on the order of magnitude of
half of the schedule. The obvious envi-
ronmental benef t weve spoken about
and the operability f exible that Amy just
described, I think, are very important
variables when you speak about natural
gas. At Bechtel, were currently build-
ing several combined cycle plants. Were
building three signif cant plants in Texas
for Panda Power Funds, which are good
examples of this technology in operation
or in deployment. These projects have
state of the art environmental controls
and will be some of the cleanest plants
in the nation when theyre built. One of
the things theyre able to do is respond
to f uctuations in the grid. For example,
within 10 minutes the plants will be to
50 percent capability, and within 30 min-
utes be at base load. When the wind stops
blowing in west Texas, there are plants
that are going to be able to support the
grid and provide an opportunity for more
deployment of renewable resources.
THOMAS: The number of people it
takes to run a comparably sized com-
bined cycle natural gas plant are far less,
so my f xed costs are lower. Most of my
bigger costs are variable costs, so if Im
not running the plant Im not incurring
those costs. Operational f exibility is
probably the biggest piece of it, meaning
that when Im not making money I can
shut down. Whether youre in the regu-
lated or competitive power business, you
still try to dispatch your units economi-
cally to either save customers money on
the regulated side or maximize prof tabil-
ity on the competitive side. Having a low-
er f xed cost is a big