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September 2013 • www.power-eng.com

GAS TURBINES THE LATEST INNOVATIONS

POWER-GEN INTERNATIONAL CELEBRATING 25 YEARS

INSTRUMENTATION & CONTROLS INCREASING SCADA SYSTEM FUNCTIONALITY

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Are You Ready for 316(b)?

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1309PE_C1 1 8/29/13 5:09 PM

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Power Engineering is the flagship media sponsor for

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Industry News:Global updates throughout the day Power Engineering ®

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DEPARTMENTS

2 Opinion

4 Clearing the Air

6 Gas Generation

8 View on Renewables

10 Nuclear Reactions

12 Energy Matters

67 Ad Index

68 Generating Buzz

FEATURES

14 EPA’s 316(b) Rule: Are you Ready?

More than 670 power plants will be affected by the proposed

316(b) regulation, which targets facilities using once-through cooling

systems. Managing Editor Russell Ray tells you what you need

to know to comply with the rule.

32 The Benefits of Gas Turbine Control Open Systems

Third-party open control systems for gas turbine systems can help owner/operators become self-maintainers who troubleshoot, repair and make improvements independent of the manufacturer.

50 Coupling for Fiberglass: An Alternative to Curing

When challenges presented by the weather made curing a difficult method to seal fiberglass pipes while installing scrubbers in DTE Energy’s coal-fired plant, project managers found an innovative solution.

42 Infusing SCADA Software with Real-Time Power Management Capabilities

Although SCADA systems have revolutionized the power industry, extending the system’s functionality will provide the system operator and engineer with a powerful new set of tools.

56 POWER-GEN 2013 PreviewGet all the details on POWER-GEN International, which is celebrating its 25th anniversary. We’re expecting more than 21,000 attendees at PGI 2013 in Orlando on Nov. 12-14.

S117VOLUME No. 9, September 2013

20 Aeroderivative Gas Turbine Fuel Flexibility

While natural gas is the principal fuel in aeroderivative gas turbines, there are other fuels that make economic and social sense. This article looks at some alternatives, including ethanol and syngas.

1309PE_1 1 8/29/13 5:31 PM

www.power-eng.com2

OPINION

In the past, a spike in gas prices

would have killed plans to build a new

gas project in the U.S. The circum-

stances have changed significantly.

Today, a sharp spike in gas prices

would not stop the growth in new

gas projects because of ever increas-

ing regulation of coal-fired plants, a

proliferation of state standards for the

production of renewable power, and

a generous supply of natural gas from

shale. For baseload capacity, there re-

ally is no other option for power pro-

ducers, thanks to the EPA.

The transition to natural gas will

continue, even in the face of higher

gas prices and potential regulation of

gas producers.

According to the EIA, the U.S. has

a 100-year supply of gas reserves. I

think the nation’s true supply of gas is

well below the EIA’s lavish estimate,.

Still, the nation’s gas supplies are large

enough to justify the construction of

more gas-fired capacity.

But the natural gas market remains

volatile because of the way the com-

modity is traded. The growth of spec-

ulative hedge funds, energy traders

and automatic trades can cause a lot

of volatility. More traders, with no of-

ficial connection to the producer or

consumer, are buying gas and imme-

diately selling it at a profit.

Although the nation’s dependence

on gas is sure to grow, it is not good for

the U.S. The nation’s growing depen-

dence on natural gas is the result of

bad public policy. If you have a ques-

tion or comment, please contact me at

russellr@pennwell.com.

Last month, the closure of anoth-

er nuclear plant was announced

and regulators sued Duke En-

ergy over its coal-fired assets in North

Carolina.

Although the construction of new

gas-fired generation in the U.S. has

been slower than expected, the tran-

sition to natural gas is gaining more

momentum.

The capacity lost from the closures

of Vermont Yankee, San Onofre, Ke-

waunee, and Crystal River nuclear

stations will likely be replaced with

natural gas. Meanwhile, the number of

announced coal plant retirements and

coal-to-gas retrofits continue to rise in

the face of low-priced gas and increas-

ing environmental regulation.

What’s more, a lawsuit over coal

ash storage operations at 12 coal-fired

plants owned and operated by Duke

Energy may spawn similar lawsuits in

other states. North Carolina regulators

are suing the utility for groundwater

and wastewater violations at all 12 sites.

The U.S. will be adding 340 GW of

generation capacity between now and

2040, according to the U.S. Energy

Information Administration. Natural

gas will account for 63 percent of the

added generation during that period,

while coal and nuclear will account for

just 3 percent each. The share of total

generation from gas will grow from 27

percent in 2011 to 30 percent in 2040.

In addition to low gas prices, the

growth of wind and solar power is an-

other factor driving the construction

of new gas-fired capacity. The added

capacity is needed to balance the

increasing load of intermittent wind

and solar power.

Meanwhile, natural gas prices re-

main low at about $3.50 per mmBtu.

“Our coal plants are not operating

as baseload plants in many places

across the country,” said Keith Trent,

executive vice president and chief op-

erating officer of Duke Energy. “Four

years ago, we were all projecting that

gas prices were going to be $6 to $8

per mmBtu. At that level, coal looked

good and nuclear looked good. But

that’s not the case today.”

A scan of last month’s news at www.

power-eng.com reflects the growth of

gas-fired generation in the U.S. mar-

ketplace:

•  Southern Power and Panda Power

announced plans to build gas-fired

plants in Texas and Maryland, re-

spectively.

•  Siemens received a $400 million

order for two gas turbines for a new

combined cycle plant in Pennsylva-

nia.

•  Fluor Corp. received full notice to

commence construction of a 1,358-

MW combined cycle plant in Vir-

ginia.

•  Invenergy said it wants to build a

$500 million natural gas plant near

Jessup, Pa.

• NRG Energy completed its repower-

ing and modernization of the 550-

MW gas-fired El Segundo Energy

Center near Los Angeles.

• Gemma Power Systems signed an

engineering, procurement and con-

struction contract to build an 800-

MW gas-fired plant in Pennsylvania.

All Signs Point to Natural GasBY RUSSELL RAY, MANAGING EDITOR

1309PE_2 2 8/29/13 5:31 PM

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FOCUSED

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TECHNOLOGY

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1309PE_3 3 8/29/13 5:31 PM

www.power-eng.com4

CLEARING THE AIR

BY BOB NICOLO, DIRECTOR, AQCS, HITACHI POWER SYSTEMS AMERICA LTD

When will it be TooHot in the Kitchen?

The recent White House GHG

agenda is trickling down the

EPA corridors, and will soon be a

major challenge to the power generation

industry. Although the EPA is expected

to issue final CO2 emission limits this

month for new units and proposed limits

for existing units mid next year, it is far

too soon to tell how this will affect our

country’s future energy landscape. Major

emissions regulations to date have result-

ed in many units of coal fired plants to

be shut down, and with these new GHG

regulations looming, we certainly expect

this trend to continue.

The originally proposed limit for new

plants was met with significant criticism

because at 1000 lb/MWh it would only

affect coal-fired power plants. This was

one many reasons that forced the EPA

to reconsider the limit, which is likely to

include considerations for various fuel

types and generation technologies.

GHG emissions generated from coal

plants are only a piece of this complex

puzzle. Effective regulations must ad-

dress all types of fuels and generation

technologies considering their respective

carbon footprints. A more sensible ap-

proach would be an economy-wide GHG

policy which would take into account ev-

ery ton of carbon emitted no matter if it

is from the power generation, the trans-

portation sector, etc. Furthermore, any

unilateral action by the U.S. would not

be sufficient to reverse the global trend

of GHG increase without the cooperation

from other leading economies.

Most people anticipate that GHG reg-

ulations will have a more profound im-

pact than any previous environmental

regulations. Clear and sensible regula-

tions based on technology rather than

ideology is the only way to avoid exces-

sive public confusion, political gridlock

and long delays, as is too often the case

with recent EPA regulations. Power plant

owners need the regulatory visibility and

certainty to make long-term investment

decisions that will affect generations of

current and future customers.

Technology developers, collaborat-

ing with government agencies like the

Department of Energy, have done a

good job in the past developing and

supplying new technologies necessary

for the power industry to comply with

new regulations, whether it is PM, SO2,

NOx, or mercury control, provided that

a clear regulatory pathway exists to jus-

tify the necessary investment to devel-

op the required technologies. The same

is happing now with GHG control. For

example, Hitachi has been investing

heavily in new and efficient power gen-

eration methods and the technologies

for direct capture of carbon dioxide.

Bringing in the next generation,

ultra-efficient generation technologies

on line to replace the aging generation

fleet is arguably the most cost effective

way for conserving energy resources

and for reducing all emissions includ-

ing CO2, not to mention the many

skilled jobs coming with it.

In this regard, Hitachi has developed

the design, material and manufactur-

ing methods necessary to supply the

700 degree C class ultra-supercritical

power plant, building on our experience

in supplying the global market with to-

day’s state-of the-art, 600 degree C class

supercritical plants. For natural gas, we

have developed the Advanced Humid Air

Turbine (AHAT) that has shown thermal

efficiency comparable to combined cycle

units and better operating flexibility and

short response time, without using a sep-

arate steam turbine.

For direct CO2 capture, based on de-

cades of R&D, we have developed de-

signs for both oxyfuel combustion and

post-combustion capture system that

are ready for full-size demonstration in

power plants.

In collaboration with DOE, South-

ern Company / National Carbon Cap-

ture Center (NCCC), and UND Energy

and Environment Research Center

(EERC), recent pilot tests at NCCC and

EERC have verified that a large reduc-

tion in energy consumption for CO2

capture can be realized.

To further improve design and reduce

capital cost, Hitachi is working with

SaskPower to build a large, 120-ton CO2/

day test facility which will begin testing

in 2014. Also with SaskPower, Hitachi is

supplying a 160-MW steam turbine for

the Boundary Dam Integrated Carbon

Capture and Storage Project.

The Boundary Dam Project is one of

the first and largest CCS demonstra-

tion projects in the world, and the new

Hitachi steam turbine is one of the first

designed specifically for optimized inte-

gration of a coal-fired power plant with a

carbon capture system.

Once again, equipment suppliers and

developers are doing their part to get the

technologies ready.

The power industry professionals

are resilient, resourceful and respon-

sible for our environment. Given real

and workable regulations and an op-

portunity to work like true engineers,

we will come up with solutions to keep

the lights on, the economy going and

the kitchen cool.

1309PE_4 4 8/29/13 5:32 PM

The power industry is challenged with evolving regulations and the need to operate cost effectively with fuel flexibility and at the highest efficiency. GE experts offer a complete package of innovative solutions for your challenges and tailor-made for your specific needs. We are your one source for chemistry, equipment, and monitoring solutions for all types of power plants. Your bonus - peace of mind in a grid-variable power generation environment.

Scan the QR code

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to learn what’s

inside GE’s complete

package for the

power industry.

www.geimagination.com/CMS/Power

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1309PE_5 5 8/29/13 5:32 PM

www.power-eng.com6

GAS GENERATION

capacity for wind will continue to in-

crease over the coming decades, grow-

ing approximately 14 GW by 2020, ac-

cording to the U.S. Energy Information

Administration’s Annual Energy Out-

look 2013 report. Solar energy genera-

tion capacity is also growing, by a faster

percentage than wind, with its total ca-

pacity at approximately 22 GW by 2020.

INTEGRATING RENEWABLES:

WIND CHASING WITH

FLEXIBLE GAS PLANTS

The increasing contribution of renew-

ables brings certain challenges. While

advances are being made, wind energy

generation remains a difficult thing to

forecast accurately. In the wind-heavy

Electric Reliability Council of Texas

market, wind energy generation can

fluctuate over 2 GW in less than four

hours on a typical day. RTO’s depend

on renewable forecasts to determine

the amount of power needed from tra-

ditional power sources such as coal, gas

and nuclear. Variations in forecasts need

to be accounted for by these traditional

plants. The need for predictable, flex-

ible, clean and efficient forms of energy

that can “wind chase” to balance unpre-

dictable variations in renewables arises.

Natural gas-fired combined cycle

power plants (CCPP) have become in-

creasingly flexible, able to react to varia-

tions in renewable generation, and are

substantially cleaner burning than tra-

ditional coal-fired plants. Many CCPP’s

have a relatively wide operating range,

safely between 70 percent to 100 per-

cent plant capacity and maintaining

low emissions. Once online, CCPP’s can

vary load faster than other traditional

fossil plants, allowing them to respond

As America’s energy landscape

continues shifting towards

cleaner and renewable sources,

the industry is looking for ways to com-

pliment this conversion with minimal

impact on the price and availability of

electricity. Due to the somewhat unpre-

dictable variations in wind and other re-

newables, operators must have an alter-

native generation source, a substitute.

Natural gas has proven to be a reliable,

fast ramping, flexible, safe, cost effective

and sustainable power source to fill in

the generation gaps inherent to the re-

alities of renewable energy.

ADDRESSING THE

CHANGING ENERGY MARKET

Renewable energy, once a punch

line for American environmental poli-

cies, has now become an integral part

of our power generation mix. Seeking

to increase America’s world standing as

a leader in renewable energy produc-

tion, thirty U.S. states and Washing-

ton, D.C. had established mandatory

renewable energy targets by mid-2010.

The contribution from wind energy has

significantly increased over the past ten

years, becoming the largest renewables

contributor in Regional Transmission

Organization (RTO) markets such as

ERCOT and PJM. The energy generation

minute-to-minute to the micro varia-

tions of wind energy. Furthermore, the

ability to operate at part loads provides

the benefits of grid frequency response,

the ancillary service of maintaining the

critical 60 Hz grid frequency should en-

ergy supply dip below demand.

FLEXIBILITY IN

A RENEWABLE MARKET

Recently, Alstom, a world leader in

energy solutions, has reinforced its gas

offering to the 60 Hz market with the

latest GT24 gas turbine and associated

2x1 CCPP, the KA24-2. The latest GT24

incorporates features designed to meet

the flexibility needs of a renewables

integrated energy market in a sustain-

able way. With its unique sequential

combustion, the KA24-2 can maintain

100 percent relative CCPP efficiency

down to 80 percent load, which helps

operators respond to micro variations

in wind production while maintaining

high plant profitability. The GT24 of-

fers industry leading turndown capa-

bilities with its Low Load Operation

(LLO) feature. LLO allows both GT’s to

operate at a lower load when demand

is low, maintaining close to base load

emissions. During plant turndown

both GT’s and the steam turbine are

kept completely online. With fast ramp

rates, the KA24-2 can ramp from LLO

to full plant load in just 10 minutes,

providing a spinning reserve capacity

of 500 MW.

As America moves forward in its

pursuit of cleaner energy and power

generation, natural gas fired combined

cycle power plants are critically impor-

tant to the integration of renewable en-

ergy sources.

Gas: Paving the Way for RenewablesTIMOTHY EFFIO, REGIONAL MARKETING MANAGER, ALSTOM POWER

GT24 MXL2 implementation

at Bayside Power Station,

Canada

1309PE_6 6 8/29/13 5:32 PM

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1309PE_7 7 8/29/13 5:32 PM

www.power-eng.com8

VIEW ON RENEWABLES

present, we’re working collaborative-

ly with ESA on the Energy Storage In-

vestment Tax Credit gaining support

in Congress.

There are 8,500 MW of cumulative

solar electric capacity installed in the

U.S. – enough to power more than

1.3 million homes.

Energy storage capacity is growing

at a similarly quick pace; it already

accounts for 24,000 MWh (mostly

pumped hydroelectricity) in nearly

every state. By 2017, grid-scale ener-

gy storage will reach an 185.4 GWh,

a $113.5 billion revenue opportunity

for an industry that currently gener-

ates sales of $50 billion a year.

The grid functions much the same

way as it did a century ago. It’s ripe

for innovation. Solar and energy

storage technologies offer vast im-

provements. Many initiatives are

underway to improve the reliability,

capacity, safety and cost of batteries/

energy storage technologies, making

them more useful in a wide variety of

applications. Energy storage, paired

with renewables, will make the grid

more robust, reliable, resilient and

secure – delivering tremendous en-

vironmental and health benefits.

The increased deployment of these

technologies, in tandem, will fur-

ther solidify solar and other renew-

able technologies as an increasingly

mainstream resource in our nation’s

energy portfolio, and help ensure an

uninterrupted supply of electricity.

Once we’ve perfected the pairing

of solar with energy storage — from

residential through utility-scale de-

ployment — the possibilities are

truly limitless.

As the world’s electricity de-

mand grows, it’s imperative

that we cut emissions. So-

lar electricity is meeting an increas-

ingly significant percentage of global

energy demand. Smart, consistent

long-term solar policies, such as the

investment tax credit and renewable

portfolio standards, and industry in-

novations in technology and financ-

ing, have made solar a bright spot in

our economy.

The Solar Energy Industries Asso-

ciation (SEIA) forecasts that 5.2 GW

of new solar electric capacity will

come online in 2013. As solar de-

ployment increases, SEIA is focused

on accelerating renewable energy

generation without sacrificing reli-

ability. Energy professionals, busi-

ness leaders, policymakers –and the

public– view storage as a crucial tech-

nology that complements solar. Ad-

vancing energy storage is vital to our

mission of ensuring that renewables

become an increasingly mainstream

source of our world’s power supply.

Universities, scientists and inves-

tors, among others, are engaged in

advancing storage technologies that

will revolutionize our world. An IMS

Research report forecasts that the

market for storing power generated

by solar will soar – from approxi-

mately $200 million in 2012 to $19

billion by 2017.

Catastrophic events such as Super-

storm Sandy have shown that lives

can be lost, homes and businesses

damaged and destroyed, and entire

regions crippled by natural disasters.

Pairing emissions-free solar with en-

ergy storage / back-up generation will

make our grid more resilient.

Several battery chemistries are be-

ing pursued: advanced lead acid, lith-

ium-ion, flow, etc. They’ve targeted

applications and unique benefits.

Several solar companies are al-

ready integrating energy storage in

their deployments – in utility-scale,

distributed generation and residen-

tial projects. Molten-salt batteries

used in several utility-scale concen-

trated solar power plants help pro-

vide uninterrupted electricity.

Microgrids incorporating solar

arrays are in operation at mission-

critical government and commu-

nity facilities. The U.S. military is

developing microgrids on bases,

such as at Fort Detrick, to pro-

vide critical power in the event

of outages. Backup storage is be-

ing paired with solar installed at

homes and businesses; additional

pilot projects are underway.

Several companies are develop-

ing sophisticated hybrid solar /

storage systems, including por-

table solar generators that provide

power when disaster strikes. These

include fully-integrated battery

back-up systems enabling custom-

ers to send excess energy back to

the grid for credit, while battery

storage provides backup electricity

– operating independently of the

grid during power outages.

SEIA and the Electricity Storage As-

sociation (ESA) have formed a new

partnership to accelerate grid stor-

age systems and renewables. We’re

focused on modernizing the grid,

making it more balanced, efficient,

clean, reliable and cost-effective. At

Solar Power and Energy Storage: Pairing Technologies Vital to Our FutureBY RHONE RESCH, PRESIDENT AND CEO, SOLAR ENERGY INDUSTRIES ASSOCIATION

Author

Rhone Resch is the

president and CEO of the

Solar Energy Industries

Association (SEIA).

Resch has more than

20 years of experience

in the public and private

sector working on clean

energy development and

climate change issues.

In addition to serving

as the vice president for

the Natural Gas Supply

Association, Rhone

also served as program

manager at the EPA’s

Climate Protection

Division during the

Clinton administration.

Rhone holds an M.P.A.

in management from

Syracuse University’s

Maxwell School, a

Master of Environmental

Engineering from SUNY

Syracuse, and a B.A.

from the University of

Michigan.

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NUCLEAR REACTIONS

the Integral Fast Reactor (IFR) as some

sort of technological savior for the nu-

clear industry. Technically, I don’t argue

that the IFR and its breeder cousins have

many positive characteristics, including

a much higher extraction of energy from

the nuclear fuel and the ability to “burn”

long-lasting nuclear waste components.

Short shrift is given, however, to

whether the economics of these fourth-

generation reactors would be competitive

with other options. Admittedly, it’s diffi-

cult to say since only a handful of breeder

reactors have been built – and only a few

remain operating. But economics need

to be part of the debate. Not just to keep

electricity prices as low as possible, but

also to educate the public about the im-

portance of comparing the levelized cost

of electricity over the life of the plant

rather than just the upfront capital costs.

Which leads me to musing #3. Presi-

dent Obama released his plan to con-

strain carbon dioxide emissions from

U.S. power plants in June. The president’s

plan directs EPA to work with the states

and industry to establish carbon pol-

lution standards for new and existing

plants; and provides loan guarantee au-

thority for advanced fossil and energy ef-

ficiency projects.

I’m not overly confident that these ac-

tions will prompt significant changes in

the generation mix, and I’m even less

confident that Congress would enact any

broader carbon legislation in the next 5

to 10 years. But any movement in this

direction is a potential plus for nuclear

power since it could tip the economics in

its direction.

So we end up at musing #4. Nuclear

power has a future…just not the future

you thought it would be.

You likely won’t be reading this

until September, but I’m writing

it in late June, so the title is ac-

curate. I’ve compiled some mid-year mus-

ings, only loosely connected, but they

all speak to where nuclear power is and

where it may be headed.

Musing #1: The decision by South-

ern California Edison in June to per-

manently shut down the San Onofre

Nuclear Generating Station due to its

steam generator problems cast a pall

over the industry. Coming on the heels

of the Kewaunee shutdown in May and

the announcement by Duke Energy

in February that it would not proceed

with efforts to repair the concrete con-

tainment structure at Crystal River, the

U.S. industry is now left with 100 re-

actors on the nuclear plant wall – and

some uncomfortable misgivings about

the future.

Because of nuclear power’s tenuous

hold on public perception and sup-

port, I believe many people feel that a

“domino effect” may be in play. In other

words, if one (or a few) nuclear plants

shut down, the rest will come down

with them. Anti-nuclear groups long

for the day when this happens; pro-nu-

clear groups fear it.

The fear and optimism are probably

both misguided. Reality simply doesn’t

conform to the domino theory. It didn’t

come to pass with respect to the expan-

sion of Communism around the world

and won’t happen with respect to nu-

clear power absent a spate of plant ac-

cidents or gross mismanagement.

Let’s face it: plants get old; markets

change; competition emerges. For some

nuclear plants, yes, that will mean re-

tirement. Not a happy thought, but

that’s the circle of life (as the Lion King

put it). The hope is that these decisions

can be made rationally, fully informed

by technical and economic realities.

Which leads me to musing #2. Ra-

tional discussion in the public sphere

about nuclear power has been chal-

lenged by Fukushima, by the fear of

radiation exposure and by the com-

mon conflation of nuclear weapons

with commercial nuclear power. Into

the fray steps Robert Stone, a long-time

documentary film-maker who released

Pandora’s Promise in June to limited the-

aters nationwide.

The movie examines nuclear power

from the perspective of five environ-

mentalists who each decided after much

investigation to support nuclear power.

One of these individuals, Mark Lynas, is

a self-avowed environmental activist who

has been heavily involved in the global

climate change debate. After significant

soul-searching and in-person witness –

including a trip to the Fukushima area –

Lynas realized that nuclear power had to

be part of the solution to climate change.

The film does a good job of address-

ing many of the misunderstandings re-

garding nuclear power, including claims

that the Chernobyl accident has killed

millions of people. As a movie made by

an environmentalist, about environmen-

talists, I believe Pandora’s Promise stands

a reasonable chance of engaging a wider

audience in discussions around energy

policy and nuclear power. I strongly rec-

ommend you go see it, and if you can’t

make it to a theater screening, CNN has

plans to show the film in late 2013.

My one quibble with the movie is the

absence of discussion around the eco-

nomics of nuclear power. Stone presents

Mid-Year MusingsBY BRIAN SCHIMMOLLER, CONTRIBUTING EDITOR

1309PE_10 10 8/29/13 5:33 PM

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1309PE_11 11 8/29/13 5:33 PM

www.power-eng.com12

ENERGY MATTERS

BY ROBYNN ANDRACSEK, P.E., BURNS & MCDONNELL

Dispersion Modeling: Hour-by-Hour

When it comes to the Na-

tional Ambient Air Quality

Standards (NAAQS), dis-

persion modeling is protective but not

necessarily predictive of actual air quali-

ty. New shorter 1-hour averaging periods

compound this issue and lead to restric-

tive and intricate permit conditions that

have little to do with actual air quality.

When the 1-hour NO2 and SO

2

NAAQS were set, it was only a matter

of time before coal plants would have

SO2 emission limits with averaging pe-

riods to match NAAQS modeling. In

May 2013, the Homer City power plant

in Pennsylvania was given a “precedent

setting” SO2 limit of 6,360 pounds per

hour for its three coal-fred boilers, in-

cluding during periods of startup and

shutdown. Also included was a prohibi-

tion on allowing more than one unit to

start up at the same time. This last con-

dition smacks of a dispersion modeling

work-around. Likely, during the worst

meteorological conditions the higher

startup emissions from multiple boilers

modeled as a violation of the 1-hour SO2

NAAQS. However, it is extremely unlike-

ly that in the real world such a startup

scenario would occur under those pre-

cise meteorological conditions. Never-

theless, this example encapsulates the

disparity between modeling and reality.

At its heart, dispersion modeling is

an attempt to mathematically represent

a complex natural phenomenon. By

knowing the initial emission charac-

teristics, dispersion models statistically

predict the behavior and movement of

emission plumes and chemical air con-

centrations at selected downwind recep-

tor locations. By design, dispersion mod-

els encompass all possible operating

conditions at all possible meteorological

conditions, yielding overly conservative

results. If those results meet the NAAQS,

then it can safely be said that the NAAQS

are protected.

EPA recognized the overly restrictive

nature of dispersion modeling in its

draft SO2 NAAQS Designations Mod-

eling Technical Assistance Document,

which is “primarily for use by air agen-

cies to assess likely areas of attainment

and nonattainment with the 1-hour SO2

NAAQS.” Many state agencies will use

dispersion modeling to help determine

non-attainment areas, something that

was previously only done based on ac-

tual monitored air quality. In its draft

guidance, EPA is allowing not only the

use of actual emission rates (instead of

potential emission rates) but is allow-

ing the use of actual stack heights, even

when they exceed Good Engineering

Practice (GEP) stack heights.

Suffcient information exists in the

public domain for an intervener group

to produce a rough dispersion model

on any facility they wish to oppose on

the basis of a perceived NAAQS vio-

lation. This opportunity might arise

during the Title V operating permit

renewal, which is required every fve

years and requires a public comment

period. The effective halt of new coal-

fred boiler permitting might free up

environmental activists to pursue such

efforts. This is where accurate model-

ing, using the best available data, could

serve a facility owner to defend against

any frivolous claims of a violation.

As the NAAQS have been revised

downwards with shortened averag-

ing periods, an individual facility must

take on more operating restrictions to

achieve a passing dispersion model.

Take haul roads, for example. The least

restrictive operating scenario to model is

that any haul road could be used at any

time. With the lower PM2.5 NAAQS,

however, this often models as a viola-

tion. The model can then be modifed

to exclude nighttime truck deliveries. In

reality, this might be outside of normal

operations and present little inconve-

nience to the facility. At night, ambient

wind conditions are calmer, which pro-

vides less dispersion and higher ground-

level emission concentrations. Exclud-

ing nighttime hours may be suffcient to

resolve the exceedances. However, the

facility now will need to accept a permit

condition that truck deliveries may nev-

er be allowed at night, creating the need

to forever monitor and keep records to

show compliance.

A second example focuses on emer-

gency diesel equipment operation. The

new 1-hour NO2 NAAQS means that

almost no fre pump or emergency gen-

erator models as in compliance, which is

why EPA needed to write a specifc policy

carving out an exemption to modeling

for these short-stack intermittent sourc-

es. Combustion equipment at rural mu-

nicipal power plants might rarely operate

but still may not meet conditions of EPA’s

modeling exemption. These facilities are

potentially subject to expensive control

devices or mandatory shutdowns, shift-

ing power production to larger utilities

and reducing grid reliability. Fortunately,

these small plants are not the target of

environmentalist scrutiny. Yet.

Dispersion modeling is a valuable tool

for protecting air quality when conduct-

ed by the right professionals, using the

proper data and methods.

1309PE_12 12 8/29/13 5:33 PM

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1309PE_13 13 8/29/13 5:33 PM

www.power-eng.com14

for cooling to install the best technol-

ogy available (BTA) to minimize the

mortality of aquatic life. Losses occur

when fish and other organisms become

trapped (impinged) against water in-

take structures or sucked (entrained)

into cooling systems and exposed to

heat, pressure and machinery. The

rule requires the best technology to

mitigate what it describes as “adverse

environmental impact” resulting from

entrainment and impingement.

COMPLIANCE OPTIONS

The measure would require some

power producers to modify cooling wa-

ter intake structures or construct new

cooling towers.

“There isn’t one technology that’s

best. The EPA has already made that

conclusion,” said Doug Dixon, a tech-

nical executive with the Electric Power

Research Institute. “The thing that

probably comes closest to controlling

impingement is modified traveling wa-

ter screens. For entrainment control,

there isn’t a best technology. It very

much depends on where the plant is lo-

cated. It’s site specific.”

EPRI has studied many methods for

controlling impingement and entrain-

ment, including the use of light, sound,

barrier nets, screens, electric fields and

closed-cycle cooling. In many cases, the

best technology depends on the ecosys-

tem around the plant, Dixon said. For

example, some species of fish are re-

pelled by light while other species of fish

are attracted to light.

“Barrier nets are probably the cheapest

method for controlling impingement.”

Dixon said. “However, barrier nets can

be fouled very easily by floating debris.

In flowing rivers or estuaries, they can

be almost impossible to maintain.”

There is a wide range of technologies

and technology combinations available

for controlling impingement. The most

promising technologies are modified

traveling screens and wedgewire screen

systems. Modified traveling screens ro-

tate continuously and are equipped with

fish buckets, a fish return system and

smooth mesh screens. “It’s smooth. It’s

not going to cause injury via the con-

tact to the fish,” Dixon said. The aver-

age cost of a modified traveling screen

is between $300,000 and $400,000,

which does not include the cost of ship-

ping and installation. A typical 700-MW

power plant is equipped with six or

seven screens. “The cost of the screen is

going to depend on the characteristics

of that screen,” Dixon said. If a modi-

fied traveling screen is used to comply

with the rule, the monthly maximum

For 41 years, the Environ-

mental Protection Agency

has been trying to impose

new standards for cooling

water systems at existing

power plants in the U.S.

The new standards are aimed at reduc-

ing the mortality of fish and other aquat-

ic life caused by water intake structures.

After a decades-old legal battle between

utilities and environmental groups, the

EPA is expected to release the final rule

in November.

Section 316(b) of the Clean Wa-

ter Act would affect roughly 670 U.S.

power plants. It would require plants

that draw more than 2 million gallons

a day and use 25 percent of that water

EPA’s 316(b) Rule: Are you Ready?BY RUSSELL RAY, MANAGING EDITOR

The controversial 316(b) rule is expected to be finalized in November

A cooling water intake structure at SCE&G’s Williams Power Plant on the Back River Reservoir in South Carolina. Photo courtesy of EPRI

Author

Nathan Henderson of Stantec and Richard Clubb of ENERCON Services contributed to this report.

1309PE_14 14 8/29/13 5:34 PM

For info. http://powereng.hotims.com RS# 8

1309PE_15 15 8/29/13 5:34 PM

www.power-eng.com16

Amendments. Since then, the rule has

been suspended and rewritten several

times in a long and drawn out legal bat-

tle between utilities and environmental

groups.

In 1979, the EPA withdrew the regula-

tion, but the agency was sued in the mid

‘90s by a coalition of environmental

groups for not reenacting the regulation.

The EPA was ordered to finalize the rule

and developed it into three phases. But

portions of the rule were remanded back

to the EPA for reconsideration in 2007.

As a result, a draft rule for existing

plants was published in April 2011. A fi-

nal version was initially expected to be

released in July 2012, but the release has

been extended several times. The EPA

expects to publish the final rule in No-

vember.

ENVIRONMENTAL

IMPACT IN QUESTION

The rule requires that “the location,

design, construction and capacity of

cooling water intake structures shall

reflect the best technology available

for minimizing adverse environmental

impacts” resulting from the drawing of

fish and larvae into and through the

cooling systems of power plants, where

mechanical and thermal stresses and

the trapping of fish against screens can

cause high mortality rates.

But new research indicates there is

no evidence that impingement and en-

trainment of aquatic life at U.S. power

plants cause a meaningful loss of fish

and other aquatic organisms. A peer-

reviewed article authored by Lawrence

Barnthouse and published in the May

issue of Environmental Science & Policy

found there is no scientific evidence that

shows a reduction in entrainment and

impingement would lead to measurable

improvements in fish populations.

“Any impacts caused by impingement

and entrainment are small compared to

other impacts on fish populations and

communities, including overfishing,

habitat destruction, pollution, and inva-

sive species,” wrote Barnthouse, whose

research was sponsored by EPRI.

The EPA has not performed a single

study that shows entrainment and im-

pingement impact fish populations any

more than commercial fishing, accord-

ing to Barnthouse.

“Adverse impacts have been implic-

itly or explicitly defined as entrainment

and impingement per se, irrespective of

mortality of impinged fish cannot ex-

ceed 31 percent.

The draft rule, released in April 2011,

contains a list of eligible technologies, in-

cluding closed-cycle cooling. Although

the rule does not mandate closed-cycle

cooling, it does target plants using once-

through cooling systems and could lead

to more closed-cycle cooling retrofits at

existing plants in the U.S. Closed-cycle

systems use less water from rivers and

bays and harm fewer fish. If there were

a national requirement for closed-cycle

cooling, the industrywide cost to com-

ply could near $100 billion, according to

a 2010 report published by EPRI.

“It was exceptionally expensive,”

Dixon said. “The cost was well beyond

the monetized benefits that could be

obtained.”

Despite pressure from environmental

groups and the courts, the EPA decided

not to mandate closed-cycle cooling for

entrainment in the draft rule.

“The environmental groups would

very much like to see all the existing

once-through plants go to closed-cycle

cooling,” Dixon said. “That’s what the

2nd Circuit Court of Appeals inferred to

EPA back in 2007. They said to EPA ‘We

don’t understand why you have not se-

lected closed-cycle cooling as BTA.’”

The 316(b) rule was first enacted

in 1972 when Congress passed the

Federal Water Pollution Control Act

A cooling water intake structure at Alabama Power’s Plant

Barry on the lower Mobile River. Photo courtesy of EPRI

A modified traveling screen. Photo courtesy of HDR Inc.

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The company was asked by its clients

to review the feasibility of converting a

power plant using once-through cooling

to closed-cycle cooling.

Sounds simple enough, but after con-

ducting several feasibility studies it was

obvious that each specific site evaluated

had a different set of physical constraints

and design considerations that may or

may not challenge the feasibility of a

closed-loop cooling retrofit, apprecia-

bly affect the implementation cost and

result in vastly differing levels of plant

performance post retrofit.

Closed-loop cooling relies on a

source of heat rejection different from

the existing water body drawn from in

once-through cooling. In most cases,

this means a cooling tower (or series of

whether any adverse changes in popula-

tions can be demonstrated or predict-

ed,” Barnthouse wrote. “The rarity of

documentation of such impacts, after 40

years of operation of large power plants,

some of which have been conducting ex-

tensive monitoring programs for several

decades, provides substantial evidence

that impacts related to entrainment and

impingement are generally small.”

The 316(b) rule does not provide a

definition for “adverse environmental

impact.” The term has long been un-

derstood by the scientific community

to refer to adverse changes in the abun-

dance and productivity of fish and other

aquatic life.

CLOSED-CYCLE COOLING

ENERCON Services Inc. provides

engineering services related to cool-

ing tower installations and modifica-

tions to closed-loop cooling systems.

A fine mesh screen. Testing of these screens was

performed at Alden Research Laboratory in Worcester,

Mass. Photo courtesy of EPRI.

1309PE_18 18 8/29/13 5:34 PM

www.power-eng.com 19

For info. http://powereng.hotims.com RS# 11

There’s virtually no risk in making

sure that both the plant’s owners and

operators fully understand the state

of planning at their facilities and how

that subjects them to the fundamental

changes that loom.

Operations & Maintenance staff

should be involved in these discus-

sions and planning early on.

If a plant is scheduled for system up-

grades or changes in the next year or

two, those plans should be shelved for

now. Making those changes along with

those required by 316(b) may be more

sensible in cost and functionality.

cooling towers) are used to reject heat

to the atmosphere. Other closed-loop

cooling designs are available and typi-

cally involve a cooling pond or cooling

canals, possibly equipped with power

spray modules; however, the space re-

quired to produce the necessary cooling

capacity restricts where these options are

available. Similarly, cooling towers can

be either wet (relying on air and evapo-

ration for cooling) or dry (relying solely

on air cooling); however, dry cooling

towers have limited applicability for ret-

rofit use given their reduced capacity for

cooling. In either circumstance, cooling

towers reject heat to the atmosphere and

their ability to cool varies with the am-

bient weather conditions. In particular,

wet cooling towers ability to cool varies

in relation to the wet-bulb temperature,

which is a combination of dry-bulb tem-

perature and humidity.

The ability to reject the design heat

load is a basic requirement of any fa-

cility generating electricity using a

steam cycle. Steam traveling through

the turbines is converted to water in

the condenser, which in turn transfers

heat to the circulating water system.

When warm and humid weather con-

ditions impact a cooling tower’s ability

to cool the circulating water, the con-

denser’s cooling efficiency is reduced.

The loss of power due to a reduced

ability to cool the circulating water is

termed an operational power loss. In

circumstances where a power plant

was designed with a relatively small

condenser accounting for a source of

cold once-through cooling (i.e., ocean

intakes, great lakes, reservoirs, etc.),

the power plant retrofit to closed-loop

cooling would be operating at reduced

capacity or potentially shut down for

periods of time in the summer when

energy use is typically at its highest

demand. Conversely, in circumstanc-

es where a power plant was designed

with a large condenser to allow once-

through cooling from a relatively

warm water body, a power plant may

be able to install cooling towers with

little to no operational power losses.

PLANNING FOR 316(B)Some power producers may be

reluctant to invest too much time and

money into 316(b) compliance because

of the uncertainty surrounding the

final rule. However, many industry

observers say the EPA won’t make

significant changes in the final rule.

There are some low-risk actions power

producers can take to position their

plants for the new requirements once

they are finalized.

1309PE_19 19 8/29/13 5:34 PM

www.power-eng.com20

minor gas turbine modifications and/

or fuel cleaning.

Fossil fuels are not going to be re-

placed in bulk anytime soon. Global

commerce and power generation de-

pend on fossil fuels. Biofuels are grow-

ing through mandates in the trans-

portation sector, but they are only

price competitive when subsidized.

Synthetic gas fuels have also gained

popularity, but they are not available

in volumes that would support world’s

energy needs. Still, there are fuels of

opportunity that make economic and

in some cases, social sense. This article

explores those fuels, and the challeng-

es and solutions associated of utilizing

them for aeroderivative gas turbine

power generation.

BY JAMES DICAMPLI, P.E., GE DISTRIBUTED POWER

Gas turbine fuel costs,

even for efficient com-

bined cycle plants, can

be more than 80 per-

cent of the cost of elec-

tricity over the life of the plant. Histori-

cally a niche segment, utilities, marine

and industrial plants are increasingly

seeking options to run lower cost alter-

native fuels. New technologies and ap-

plications have been developed to meet

the growing demand for fuel flexibility.

Natural gas is the principal fuel of

the aeroderivative gas turbine. Natural

gas is a clean fuel and relatively inex-

pensive when compared to most fossil

fuel options such as diesel or kerosene.

There are many other gas and liquid

fuels that can also be burned with

ETHANOL

Ethanol derived from sugarcane in

Brazil or from other sources such as corn

in the U.S. is one of the most efficient

biofuels in terms of energy balance and

carbon emissions. Almost 80 percent

of the ethanol produced in the world

today is used as fuel, primarily by land-

based vehicles. Less than 10 percent of

the world’s ethanol production is used in

the beverage industry, and approximately

10 percent is used in industrial products

such as paints, medicines and solvents.

Ethanol production was about 22.7 bil-

lion gallons in 2010 compared to 19.5

billion gallons in 2009, a greater than 16

percent increase. Figure 1 shows how fuel

ethanol has grown over the years while

beverage and industrial use ethanol has

1309PE_20 20 8/29/13 5:35 PM

www.power-eng.com 21

The GE LM6000 Aeroderivative

Gas Turbine. Photo courtesy of GE.

remained fairly constant.

Two GE LM6000PC aeroderivative

gas turbines have been converted at a

power plant in Brazil to run on etha-

nol. Located in southern part of Minas

Gerais, approximately 180 kilometers

north of Rio de Janeiro, this 87-MW

simple-cycle power plant was converted

from a natural gas-only plant to a dual

fuel, ethanol capable plant. This en-

hances the plant’s energy security and

reliability by providing a valuable al-

ternative fuel source when natural gas

is not available. This is the world’s first

use of sugarcane-based ethanol in a gas

turbine system to produce electricity on

a full commercial scale.

The goal of the project was to assess

gas turbine performance in terms of

emissions, efficiency and component

durability when fueled with ethanol.

The demonstration consisted of 975

hours of testing (actual gas turbine op-

erating time on ethanol), including load

variation, water injection variation,

fuel transfers between natural gas and

ethanol, and startup and shutdown of

the gas turbine on ethanol. The dem-

onstration included interim borescope

inspections, and at the conclusion of

the demonstration, the gas turbine was

disassembled for a detailed component

inspection. The performance of the gas

turbine was equivalent to the same gas

turbine operating on natural gas and

the emission levels of sulfur dioxide

(SO2), aldehydes, carbon monoxide and

unburned hydrocarbons were very simi-

lar. Nitrous oxide (NOx) emissions were

reduced when compared distillate fuels,

and all the carbon emissions were from

renewable sources. Hot section compo-

nent deterioration was comparable to

distillate fuel operation for the same

run time.

To reach full designed power, about

1.6 times more ethanol flow is required

compared to diesel, given the lower vol-

umetric energy content of ethanol. The

ethanol used is hydrous, meaning that

it contains 6 perccent to 10 percent wa-

ter. The increased water content is actu-

ally beneficial, cooling the combustion

temperature and resulting in lower NOx

emissions.

This site drew international attention

when then President of Brazil, Mr. Lula

da Silva, attended the site’s inauguration

to highlight that Brazil’s ethanol could

be used for clean power generation.

BIODIESEL

Biodiesel is derived from plants (jatro-

pha, rapeseed, palm, algae, etc.) or ani-

mal fat by products; all having a varied

amount of C14-C22 saturated and un-

saturated fatty acids. The production pro-

cess is called transesterification: the oil in

the presence of a base catalyst is reacted

with alcohol (usually methanol) to form

methyl esters, with glycerin as a by-prod-

uct. Biodiesel contains practically no sul-

fur and no aromatics (toluene, benzene,

etc.). Relevant biodiesel specifications

include ASTM D6751, and European

1309PE_21 21 8/29/13 5:35 PM

www.power-eng.com22

Ethanol Production by Type Fig 1

80000

7000

6000

5000

4000

3000

2000

1000

01975 1980 1985 1990 1995 2000 2005 2010

Industrial Beverage Fuel

NOx emissions were found to be about 5

ppm lower for biodiesel operation than

for diesel operation, while requiring less

water injection for NOx abatement. Car-

bon monoxide emissions were lower as

Specification EN 14214.

Diesel made from crude oil (petro-die-

sel) is a mixture of hydrocarbons, while

biodiesel is a mixture of unsaturated fatty

acid esters. Biodiesel has a detrimental

effect on elastomers commonly found

in many of the gaskets and sealants in a

typical gas turbine package, so care must

be taken in selecting compatible compo-

nents. The heating value of biodiesel is

less than that of diesel by about 10 per-

cent; to get the same power output fuel

flow to the combustor must be increased

by that amount.

One of the better qualities of biodiesel

is its lubricity; it can be used as an addi-

tive to improve the lubricity of most fos-

sil fuels such as ultra-low sulfur diesel.

It also burns cleaner and creates about

60 percent less net carbon dioxide emis-

sions in diesel engines, inclusive of the

plant growing cycle and associated CO2

absorption.

With the above considerations, bio-

diesel is an excellent alternative fuel for

aeroderivatives.

Marine Application: GE ma-

rine customers have periodically run

LM2500+ gas turbines on biodiesels,

some for a period of 6 to 12 months,

when it is price competitive to marine

gas oil. When fossil fuel prices receded

and biodiesel prices increased, the ships

returned to their normal use of fos-

sil fuels. The ships remain capable of

running either fuel, or blends, and can

switch pending the price of fuel.

Industrial Power Plant: A power

plant in New York conducted a biodiesel

fuel demonstration on a GE LM6000PA

gas turbine in 2007. Today, biodiesel

continues to be used as a backup fuel

for the plant. The purpose of the dem-

onstration was to evaluate effects on

load variation, emissions and operabil-

ity. The combined cycle plant produces

105 MW when its two LM6000PA’s are

running along with a 25 MW steam tur-

bine. The biodiesel used for this test met

GE and ASTM D6751 specifications and

had a LHV of 16,250 BTU/lb. No chang-

es were made to the engine or package

for this demonstration. The gas tur-

bine was started on biodiesel and shut

down on biodiesel without any issues.

Source:

Engine Fuel LHV Comments

Region BTU/lbm BTU/SCF

Natural Gas (CH4) 21530 913 For Comparison

LM2500/+

US (IL) 18148 100312.9 percent hydrogen, 12 percent olefin

Brazil 18974 104814.2 percent hydrogen, 21.5 percent olefin

LM5000

Germany 24893 594 50 percent vol. hydrogen

LM6000

US (CA) 18016 95429.5 percent hydrogen, 12.5 percent olefin

19185 90432.8 percent hydrogen, 16.5 percent olefin

Japan 21944 849 10 percent hydrogen

LM2500+ and +G4

China (COG) 17363 462 58.5 percent hydrogen

15385 458 54 percent hydrogen

GE aeroderivative turbine hydrogen commercial experience

Table 1

1309PE_22 22 8/29/13 5:35 PM

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between volatile energy production and

consumption.

Until recently, most hydrogen experi-

ence has been in the petro-chemical in-

dustry, utilizing by-product gases such as

excess hydrogen from steam reforming.

Table 1 summarizes GE’s aeroderivative

turbines’ commercial experience with

hydrogen in gaseous fuel.

From 1986 until just recently, the

LM5000 package (33 MWe, ISO condi-

tions) in Germany operated on various

mixes of methane with up to 50 percent

hydrogen. Other packages include the

LM2500 (22MWe) in the U.S. and Brazil,

and the LM6000 (42 MWe) in the U.S.

and Japan.

For pre-mixed, dry-low emissions

(DLE) combustion systems, the hydro-

gen content is limited to 5 percent by vol-

ume. The limit is due to fast flame speeds

from high hydrogen fuels that can result

in flashback or primary zone re-ignition.

For single annular combustor (SAC, or

diffusion flames) systems, limits range

from 35 percent hydrogen by volume for

well for biodiesel. A borescope inspec-

tion of the hot section of the turbine

showed the internal parts to be cleaner

after biodiesel operation. Exhaust fil-

ters were also shown to be significantly

cleaner after biodiesel operation.

Distributed Power Plant: An east

coast university demonstrated bio-

diesel on its boilers and a GE LM1600

gas turbine. Emission components

tested were carbon monoxide (CO),

nitrous oxide (NOx), non-methane hy-

drocarbons (NMHC), total suspended

particulates (TSP) and PM10. The tur-

bine was initially started on gas and

then transferred to biodiesel, but was

eventually started and shut down on

biodiesel as well. Fuel heating was not

required for this testing, but could be

an issue at this site while operating

during winter months. Without modi-

fications, the unit was not able to reach

full power as the fuel control valve

reached its full stroke at about 13.5

MW (LM1600 can produce 14 MW). A

higher flow fuel control valve would

allow this turbine to reach base load.

SYNTHETIC GASES

The power generation technology of

tomorrow will demand fuel flexibility. As

such, biogas or hydrogen-based fuels will

increasingly be in the mix for gas turbine

simple and combined cycle power plant

operations.

Hydrogen-containing fuels can come

from various sources. Certain industrial

processes form by-products, such as coke

oven gas, which are attractive options for

gas turbine applications since they are

“free.” The gasification of coal or biomass

provides a precombustion solution for re-

ducing carbon dioxide emissions, leaving

a high hydrogen syngas fuel.

Another source of hydrogen-based fu-

els is the power-to-gas application where

excess power from renewables is used to

electrolyze water to hydrogen and oxy-

gen. This is one possibility to store abun-

dant energy, and one that will be impor-

tant for future networks where a high

amount of renewables calls for a balance

Source: GE internal

LNG Source 1 2 3 4 5 6 7 8 9

Compositions, percent vol.

CO2

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

N2 0.01 0.01 0.02 0.08 0.10 0.16 0.26 0.43 0.09

C1 96.07 97.06 97.81 92.85 92.28 92.86 90.68 89.68 89.18

C2 2.75 2.41 2.01 4.69 4.71 4.36 5.04 6.19 7.07

C3 0.77 0.36 0.07 1.93 2.16 1.96 2.99 2.31 2.50

i-C4 0.21 0.08 0.04 0.24 0.36 0.31 0.59 0.71 0.46

n-C4 0.18 0.07 0.01 0.19 0.37 0.33 0.44 0.66 0.69

i-C5 0.01 0.01 0.00 0.02 0.00 0.00 0.00 0.02 0.01

n-C5 0.00 0.00 0.04 0.00 0.02 0.02 0.00 0.00 0.00

C6 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00

Properties

LHV, BTU/scf 1056 1037 1028 1084 1095 1086 1114 1119 1127

WI, BTU/scf 1385 1375 1367 1396 1402 1397 1410 1410 1420

MW 16.82 16.55 16.39 17.44 17.64 17.51 18.05 18.2 18.24

SG 0.44 0.43 0.43 0.45 0.45 0.45 0.46 0.47 0.46

Compositions of LNG gases from various gases Table 2

1309PE_24 24 8/29/13 5:35 PM

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Operational Limits on Condensate Fuel with Example Composition A Fig 2

40

35

30

25

20

15

10

5

0

Fuel

Pre

ssu

re –

b a

rA

-100 -50 0 50 100 150 200 250 300

Fuel Temperature – °C

Safe for Liquid Operation

Safe for

Gas Operation

56 °C

28 °C

Max Liquid Temp Bubble Pt Temp Dew Pt Temp Min Gas Temp

purge the gas fuel circuit prior to initiat-

ing the flow of fuel. The CE/ATEX also

purges any remaining fuel following the

termination of the flow.

Another consideration is the absorp-

tion of hydrogen into metals that can

cause a general loss of ductility, or hy-

drogen embrittlement. Hydrogen will

diffuse through most materials and can

collect in “dead” cavities. This creates an

explosive hazard with the potential to

shorten component life. Gas path mate-

rials and components must be selected

with appropriate specification criteria.

larger turbines (up to 100 MWe), to about

85 percent by volume for smaller turbines

in the 18 MWe to 30 MWe power range.

Engineering factors include combustor

geometry, airflow, and cooling patterns.

GE recently introduced the LM2500+

and +G4 series of aeroderivative gas

turbines for operation on coke oven

gas (COG) as fuel for power generation.

The LM2500 is an ideal fit for COG ap-

plications because it requires minimal

changes and best fits power demand

and available COG at typical coking

facilities. COG has very high hydrogen

content (up to 65 percent by volume)

and contains many by-products such

as BTX (benzene, toluene, and xylene),

naphthalenes, tar, sulfur compounds

and alkali metals. With the right fuel

treatment, conditioning and fuel deliv-

ery system, COG fuel used in a gas tur-

bine is both a cost-effective solution and

significantly reduces the environmental

impact of the steel making process. The

first two GE aeroderivative COG units

entered commercial service in the sum-

mer of 2011; they generate 60 MW in a

combined cycle configuration.

High hydrogen fuels pose ignition

risks when initiating the flow of gas and

following the termination of the flow of

gas to the gas turbine. Non-combusted

fuel can exist above the lower explosion

limit (LEL) in the gas fuel circuit, which

in the presence of oxygen creates the

potential for igniting within a confined

volume. This risk is mitigated by using

a CE/ATEX certified inert gas system to

Source:

Phase Combustor type Fuel temperature requirement

Gas Single Annular +50°F (+28.1°C) above fuel Dew Point

Gas Premixed (DLE) +50°F (+28.1°C) above fuel Dew Point

Liquid Single Annular - 100°F (-56.2°C) below fuel Bubble Point

Liquid Premixed (DLE) -100°F (-56.2°C) below fuel Bubble Point

Fuel temperature requirements at fuel design pressure

Table 3

1309PE_26 26 8/29/13 5:35 PM

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Operational Limits on Condensate Fuel with Example Composition B Fig 3

40

35

30

25

20

15

10

5

0

Fuel

Pre

ssu

re –

b a

rA

-100 -50 0 50 100 150 200 250 300

Fuel Temperature – °C

Safe for Liquid Operation

Safe for

Gas Operation

56 °C 28 °C

Max Liquid Temp Bubble Pt TempDew Pt Temp Min Gas Temp

Marine Application

Recently GE announced that two

LM2500 turbines, capable of generating

59,000 horsepower, were installed on a

325-foot passenger and vehicle ferry. The

ship carries LNG, which is re-gasified on

board to fuel the engines. Marine grade

oil is also used to start the engines and

as a backup fuel. The wave piercing cat-

amaran can travel at a speed of over 58

knots (67 miles per hour) while running

on natural gas. The ferry will operate be-

tween Buenos Aires, Argentina and Mon-

tevideo, Uruguay, shuttling up to 1,000

passengers and 150 cars between two

ports.

LNG Plant Application

For LNG plants, the reliability of gas

turbines used for power generation or as

mechanical compressor drivers remains

critically important to plant economics.

Another valuable feature is the ability to

operate on process-off gas streams. If gas

LNG FUELS

Since natural gas fuel reserves are often

located remotely from major centers of

demand, there is a global need to trans-

port it. Around one-third of the natural

gas internationally traded is transported

in a form of liquefied natural gas (LNG)3,

and this fraction is projected to grow.

LNG is a mixture of gases, predomi-

nantly methane, liquefied at a tempera-

ture of -262 °F (-163 °C). The feedstock

gas is first processed to remove hydrogen

sulfide (H2S), carbon dioxide (CO

2) and

water vapor (H2O) to desirable levels by

absorption, adsorption and separation

processes. These contaminants are un-

desirable as they will freeze in the very

low temperature cooling processes. H2S

is also a toxic, corrosive, acid (sour) gas;

CO2 is also acidic (sour) and corrosive in

the presence of water.

Heavier fractions are removed as well,

including propane, butane and ethane

commonly referred to as natural gas

liquids (NGLs). Aeroderivatives can be

fueled with either LNG or NGLs. Re-

gasified LNG can be used in either pre-

mixed, dry low emissions or diffusion

flame combustion systems with no tur-

bine/package modifications required.

NGLs may also be utilized, and pending

the ratios of the hydrocarbons present,

may be used in either gas or liquid form.

More on this later.

The resulting fuel derived from LNG

after regasification is extremely pure. As

such, it meets the requirements of the

standard GE Aeroderivative’s fuel speci-

fication and is suitable for combustion

in either premixed (dry low emissions)

or diffusion type combustion systems

in aeroderivative gas turbines, and no

engine/package modifications are re-

quired. Table 2 summarizes composi-

tions of processed LNG produced by

different LNG facilities.

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turbines operating on “light” liquid fu-

els far more different than the standard

distillate fuel diesel #2. LM6000 engines

alone have more than 450,000 hours of

cumulative experience on naphtha.

To utilize condensates as fuels, the

package and engine fuels system

and configuration may require

some level of customizations. These

are briefly summarized in the list

below:

•  Start-up on “standard” fuel such

as diesel or natural gas

•  On engine equipment and hard-

ware including dual fuel nozzles,

primary manifold, pressurization

valve kits and parts.

• Gaseous purge system

•  Components and piping to purge

gas fuel manifold with CDP air

when engine is operating on liq-

uid fuel

•  Liquid fuel drain piping and com-

ponents

• Upgraded control system hard-

ware and software

• Condensate fuel forwarding skid

• Condensate boost pump skid

• HP water injection skid

•  Low-pressure fuel filter skid

• Vent fans in area of fuel metering

valves

CONCLUSION

Aeroderivative gas turbines continue

to exhibit the excellent performance

on standard fuels such as natural gas

and petro-diesel. There is a growing

global demand to burn alternative fu-

els of opportunity that would lower

the cost of gas turbine operation and/

or improve emissions.

References:

1. Dr. Christoph Berg, F.O. Licht, “World Fuel

Ethanol – Analysis and Outlook”

2. EIA, Annual Energy Review, Oct. 2011

3. BP Statistical Review of World Energy, Jun.

2012

streams with elevated content of nitro-

gen or CO2 could be injected into the gas

turbine instead of being stripped from

inert in nitrogen/CO2 rejection units, this

would increase the overall efficiency of

the plant and bring considerable operat-

ing and capital expense savings.

Over the last few years, GE Aero

has executed a series of engine

tests with fuels of medium BTU

content and fuels of varying com-

position, demonstrating that such

fuels can be successfully burned,

and that the turbine combustion

systems can manage significant

gas composition variability. The

successful demonstrations lead to

GE Aeroderivative selection for me-

chanical drive for major LNG facili-

ties, currently in the build phase.

NGL FUELS

As discussed, heavier fractions

can be removed from natural gas,

consisting primarily of ethane,

propane and butane, commonly

known as Natural Gas Liquids (NGL).

NGLs may be burned in aeroderivative

gas turbines, and pending the ratios of

the hydrocarbon components, are uti-

lized as a fuel in either a liquid or gas

phase.

The key consideration is the hydrocar-

bon dew point and bubble point tem-

perature as a function of pressure. At

given pressure, a fluid having tempera-

ture higher than its dew point remains

entirely in the gas phase. Similarly, the

bubble point is the highest temperature

at which given composition of the fluid

is entirely liquid at given pressure. Fluid

having the temperature between its dew

and bubble point at given pressure will

be a two-phase mixture.

For continuous and reliable operation,

gas turbines may operate on either gas

or liquid fuel with appropriate fuel de-

livery systems. For this reason, GE Aero

has developed a set of temperature limits

for condensates, which ensure that given

fuel remains in the same phase when

flowing through the entire fuel delivery

system. Table 3 below summarizes these

requirements.

Two examples below illustrate how

fuel composition and dew and bubble

point properties influence the possibility

to run aeroderivatives with single annu-

lar combustor systems on condensate-

type fuels in either gas or liquid phase.

Compositions are given in table 4 below.

Both Figures 2 and 3 illustrate how

dew point and bubble point tempera-

tures change differently with pressure

due to different fuel compositions. Fuel

temperature requirements from Table 3

define the operational area (pressures

and temperatures) at which given stream

may be used either as a gas or as a liquid.

Condensate B has much “broader” dis-

tribution of hydrocarbons, compared to

Condensate A. Because of that, it would

need to be super-cooled to operate it

safely as a liquid. Aeroderivatives require

high fuel pressures (specific to the given

engine model). At such pressures, con-

densate B requires more super-cooling

than A to maintain it in the liquid phase.

Naphtha-type liquid fuels have similar

compositions and physical properties as

condensates. GE Aero has multiple gas

Source:

Condensate A Condensate B

Methane 3.57 1.7

Ethane 1.93 12.42

Propane 2.43 11.08

Butanes 11.41 16.47

Propanes 16.21 10.96

Hexanes 37.98 23.08

Heptanes 17.27 10.4

Octanes 5.4 5.9

Nonans 2.7 4.19

Decans 1.1 3.8

Total 100.00 100.00

Exemplary condensate compositions

Table 4

1309PE_30 30 8/29/13 5:35 PM

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1309PE_31 31 8/29/13 5:35 PM

www.power-eng.com32

For utilities and IPPs operating older gas turbines, the superior reliability,

availability and safety resulting from the application of open control systems

equates directly to greater unit profitability. Photo courtesy of ABB.

manufacturer (OEM) controls between

2013 and 2020. Turbines of even older

origin will be ready for their second con-

trols upgrade in the same time period.

Owners and operators of many OEM-

supplied gas turbines are now facing the

decision of how best to upgrade their

turbine control systems and should real-

ize they have new options in the form of

open control systems provided by a third

party. These solutions provide the owner/

operator with the tools and data neces-

sary to become a self-maintainer who

can troubleshoot, tune, repair and make

improvements independent of the tur-

bine manufacturer. In addition, the third

party open system platform is not just

Hundreds of gas tur-

bines (GTs) first in-

stalled between 1990

and 2005 will be

ready for an update or

replacement of their original equipment

The Benefits of Gas Turbine Control Open SystemsBY ED DUPRE, CAMILO LOPEZ AND KEVIN KOCHIRKA, ABB INC.

1309PE_32 32 8/29/13 5:35 PM

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www.power-eng.com34

frequently create great cost and incon-

venience for the GT owner, not only in

terms of direct costs, but also in lost gen-

eration opportunities.

For equipment owner/operators, the

closed-system approach creates a recur-

ring set of roadblocks to the improve-

ment of unit reliability and availability.

They cannot quickly diagnose or respond

to problems because they lack access to

system data and critical troubleshooting

tools. Essentially, owner/operators are

prevented from taking full “ownership”

of their turbine. For example, older HMI

hardware failures contribute to poor re-

liability and availability. Because of the

black box design and OEM-customized

computer components, it is impossible to

make repairs to outdated computers and

to have upgrades implemented quickly.

The equipment typically has to be re-

turned to the OEM for service and up-

dates. While that server or client is out for

repair, the generating facility must adjust

by reallocating one of the remaining

computers or changing their work flow.

In the meantime, they have the addition-

al risk of lost control system redundancy,

which further erodes reliability.

These types of computer issues can also

create safety risks. At the facility of one

independent power producer, the client

computer in the control room failed and

had to be sent for repairs, which typically

took about four weeks. With the normal

client unavailable, an operator had to

work from the HMI at the server location

adjacent to the turbine. This put the oper-

ator within one foot of 480VAC distribu-

tion breakers and directly in front of the

13.8 kV generator circuit breaker, within

a high hazard arc-flash zone. Safety prac-

tices at this plant required the operator

to leave the arc-flash zone during certain

events (e.g., generator breaker opening or

closing). This made unit troubleshooting

quite difficult, because it forced the oper-

ator to exit the structure that housed the

limited to the gas turbine application – it

is also frequently found controlling the

rest of the plant’s processes. This allows

the user to integrate and consolidate over-

all control, protection and communica-

tion infrastructures, providing significant

benefits in the areas of plant performance

and cost effectiveness.

In this article, we will discuss:

•  Limitations imposed on owners/op-

erators by “black box” (closed archi-

tecture) control systems

•  Enhanced reliability, availability,

safety and profitability benefits us-

ing open control system

•  “Core competency” advantages of

open system suppliers

BLACK BOX LIMITATIONS

OEM gas turbines typically come with

a proprietary “black box” control system

that makes it impossible for their owner/

operator to troubleshoot, maintain or

improve the system by themselves. There

are some good reasons for a turbine OEM

to employ this closed-system approach:

it prevents end users from altering their

products, minimizes the risk of unau-

thorized modifications and ensures con-

sistent operation of the installed base of

equipment. However, by locking their

control system design and configura-

tion inside the black box, they put their

customers at a significant disadvantage

and create a captive customer base, held

hostage to the OEM’s controls and service

offerings.

Customers who retain OEM controls

are often forced to rely solely upon the

OEM for troubleshooting, service and

parts, regardless of time, cost or quality

issues. It’s readily apparent that closed

control system benefits accrue almost

exclusively to the manufacturer and can

Gas turbine operators can benefit greatly by considering the

many advantages of relying on a third-party open control

system. Photo courtesy of ABB.

1309PE_34 34 8/29/13 5:35 PM

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1309PE_35 35 8/29/13 5:35 PM

www.power-eng.com36

also able to monitor and tune their tur-

bine control systems, identifying poten-

tial turbine issues in advance and taking

corrective action proactively.

In the closed-system environment that

most OEM-controlled GT owners work

in, this type of fast response is simply im-

possible. They are often forced to rely on

remote telephone support from the OEM.

Repairs are delayed while the appropriate

support person is reached. Once in con-

tact with the support person, there are

additional delays as the plant represen-

tative describes the issue. Since the plant

representative doesn’t even have access

to live control data, they are frequently

dispatched to measure inputs at a device

in the plant and report back via a return

phone call. Cycling through any problem

using this old-school problem-solving

technique can obviously take a long time

and incur significant service costs and

down-time generation losses.

The open system approach also re-

duces issues related to clients and servers.

The ability to use standard components

that can be repaired or upgraded locally

and to easily update or patch software

makes it possible to quickly repair or re-

place a troublesome computer. This en-

sures that the appropriate complement of

HMIs will be available at nearly all times.

It also reduces or eliminates the need for

operators to ever have to work inside an

arc-flash zone or to remove themselves

from hazardous control system areas dur-

ing crucial operating and troubleshoot-

ing exercises.

A MORE PROFITABLE

APPROACH

For power generators, the greater reli-

ability and availability enabled by open

control system architecture equates di-

rectly to greater profitability. At peaking

power plants, operators of gas turbines

are required to bring them online as

needed and at a moment’s notice. The

equipment being investigated.

All of the above is made even more

problematic by the fact that many gas tur-

bines are located at significant distances

from the main control room, or even in

an entirely different facility, and thus are

normally unattended. Client failures or

communication failures in proprietary

control systems can then become ex-

tremely inconvenient and costly to solve.

THE FREEDOM

OF OPEN SYSTEMS

Today, many third-party providers of-

fer open access to their control systems.

For the first time, GT owners can see live

data flowing across the logic and use it to

make faster, better-informed decisions re-

garding turbine operations. They are able

to rapidly identify issues preventing tur-

bine starts and make repairs, adjustments

or workarounds to rectify the issue and

resume power generation. Operators are

Centralized unit operations can be a major improvement on the control systems pro-

vided from a gas turbine’s original equipment manufacturer. Photo courtesy of ABB.

1309PE_36 36 8/29/13 5:35 PM

www.power-eng.com 37

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fabric structuresunit might be required to be online in just 15 minutes

and then run for only 30 minutes. In this scenario, start-

ing reliability is of paramount concern. Independent

power producers (IPPs) typically enter into agreements

with some sort of liquidated damages for failure to meet

requested demand as well as possible bonuses for having

a high reliability/availability factor. With a solid, open

control system and the resulting improved reliability of

the plant, IPPs can confidently enter into more aggres-

sive and therefore more lucrative contracts. The higher

the reliability and availability the IPP can guarantee, the

greater the premium their power commands.

Utilities have a different profitability picture. Some

rely on IPPs as a backup and pay the peaking premiums

discussed above. Others have their own peaking genera-

tion assets. Given the chance that the utility’s peaking

GTs will not start when needed, it’s common to have

multiple turbines as backup. With the greater reliability

created by an open control system, utilities can confi-

dently reduce the redundant assets with considerable

savings or, conversely, have more peaking power reliably

available.

Furthermore, these units are often becoming more

than occasional peaking units as natural gas continues

to become more attractive versus other fuel sources. In

short, these units may now be scheduled to run far more

often and longer than originally expected, which makes

their reliability and availability that much more impor-

tant to the power generator’s profitability.

A BENEFICIAL

LONG-TERM PARTNERSHIP

Beyond the reliability improvement and resulting

profitability enhancement, owners of gas turbines can

realize many additional benefits by working with a sup-

plier that offers open control systems as their core com-

petency. The major benefits include:

•  Collaboration: OEMs offering only closed systems

can be less sensitive to the specific needs of the

owner/operator and are typically unwilling to in-

novate at that level. The GT OEMs know they have

a captive market and can therefore offer only their

own standard solutions. Absent any competition,

they have no pressure to offer their solutions at a

reasonable price. On the other hand, open sys-

tem vendors realize they must actively compete to

earn their customers’ business. They understand

the need to listen to an individual customer’s spe-

cific issues and respond with targeted solutions.

These third-party suppliers appreciate the need to

1309PE_37 37 8/29/13 5:35 PM

www.power-eng.com38

For info. http://powereng.hotims.com RS# 21

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more predictive and less routine or

reactive maintenance.

•  Latest Technology: The gas turbine

OEM’s main focus is the machine

itself, not the control system. It is not

uncommon for them to rely on ex-

ternal low-cost PLC solutions for ad-

dressing their control needs. In this

situation, the ability of the turbine

OEM to dictate the functionality and

performance specification of the

control system they supply is lim-

ited. Their main interest is ensuring

that the chosen technology allows

for the locking or “black-boxing” of

their control algorithms to support

their financial strategies. The third-

party open system provider has a

greater focus on the control system

capabilities, as DCS technology is at

the core of its business. These com-

panies invest heavily in this area to

ensure they are always positioned

in the vanguard of their industry in

terms of performance, safety, func-

tionality, reliability, flexibility and

openness. The end result is a supe-

rior control system supported by one

single vendor with ownership fully

transferred to the customer.

•  Customization: Owner/operators

can choose to customize the HMI

graphics in a variety of ways, either

during or after the upgrade. As one

simple example, device tags can be

changed to names that are more

meaningful to the plant staff. In

most cases, control room person-

nel manage multiple systems, each

with its own graphic standards or

conventions. With an open system,

the owner/operator can specify that

the new control system graphics

match existing systems’ graphics.

innovate at such a level and are eager

to demonstrate their ability to cure

longstanding and troublesome op-

erational issues.

•  Independence: Open systems are de-

signed to allow owner/operators to

take full responsibility and owner-

ship of their asset and be self-main-

tainers of that asset. This concept is

at the core of the open system sup-

plier’s value proposition, so a full set

of troubleshooting tools come stan-

dard with the product. Plant staff

can observe high-resolution, real-

time and historical process trends,

enabling them to identify issues that

can be quickly investigated and, if

necessary, remedied independent

of OEM support and its inherent

limitations. Moreover, this data can

form the basis of an improved as-

set management program, enabling

1309PE_38 38 8/29/13 5:35 PM

www.power-eng.com

A well designed open control system provides access to live GT operational data.- ABB

For info. http://powereng.hotims.com RS# 22

This simplifies the unit operator’s

job, reduces operator errors and en-

ables faster training and operator

response.

•  Security: Third-party control provid-

ers can also ensure that NERC-CIP

requirements can be met and offer

services that help GT owners/op-

erators implement comprehensive

security programs. These issues can

be considered and addressed during

the upgrade project or process.

•  Lifecycle management: GT OEMs

typically do not offer an elegant,

cost-effective mi-

gration path for

their control sys-

tems. “Rip-and-

replace” is their

usual approach

to keeping the

control system

current. Many

third-party pro-

viders follow a lifecycle approach

instead. They provide a stepwise

evolutionary path for control system

upgrades. This allows the owner/op-

erator to maintain a state-of-the-art

system over the entire turbine life-

cycle while minimizing the cost and

risk to the unit that are frequently

associated with rip-and-replace up-

grades. Owners/operators are also

not locked into buying upgrades or

add-ons from the OEM. New tech-

nology that could add a desired

capability can be readily interfaced

with an open control system archi-

tecture (e.g., optimization software,

new and improved field devices,

etc.).

• More responsive controls service:

Some GT OEMs are clearly focused

on the sale and installation of the

original equipment. Lifecycle ser-

vices are an afterthought, especially

when it comes to the control system.

As described earlier, some GT own-

ers/operators are well-acquainted

with the painfully slow and aggra-

vating telephone-tag style of remote

service. Onsite service is often pro-

vided by an OEM-authorized service

representative. For both phone and

on-site service, it is common to have

different service representatives with

each call. Lacking familiarity with

the specific facility and turbine, each

new service representative has to be

brought up to speed on the equip-

ment, adding time to each service

call and delaying critical repairs.

Open-system providers are more

service oriented and

have organized their

support resources to

better meet customer

needs. They have

technicians who are

on call and located

throughout the ser-

vice region in order to

respond more quickly

and in person when the situation

requires. Many are willing to dedi-

cate individuals to a specific plant.

Simply put, third-party control sys-

tem providers realize that they need

to support their controls customers

every day. This mindset is evident in

their control system’s evolution pro-

grams, comprehensive set of service

offerings and overall responsiveness

to customer needs.

While such supplier-sourced service

advantages are very real, turbines that

are equipped with an open system

provide another truly significant ad-

vantage. A well-designed open control

system provides access to live GT oper-

ational data and capable troubleshoot-

ing tools. Result: Many local operators

are typically able to troubleshoot and

resolve issues without external ser-

vice intervention. This significantly

reduces the time and cost of problem

resolution and provides another criti-

cal operational advantage.

1309PE_39 39 8/29/13 5:35 PM

www.power-eng.com40

For info. http://powereng.hotims.com RS# 23

software elements (PLC or other),

user HMIs, panels, cabinets, input/

output, fuel and other valve actuators,

generator excitation system, condition

monitoring sensors and other elements

of the instrumentation and controls

for a GT unit.

NEW OPPORTUNITIES FOR

GT OWNERS

Many GT owner/operators already

have, or soon will have, a pressing need

to replace OEM control systems because

of the obsolescence of the HMI clients

and servers as well as reaching end-of-life

for critical actuators and instrumenta-

tion. They face long delays as these items

are repaired and/or updated, and are at

greater operational, safety and profit risk

while these assets are unavailable. The

reduced reliability of their generation as-

sets will prevents IPPs from bidding on

more lucrative contracts and increases

their chance of paying penalties for fail-

ing to meet existing contractual require-

ments. Utilities may be forced to carry

additional equipment, overhead and op-

erating expenses for redundant assets in

order to ensure that they have sufficient

generation capacity when one or more

turbines fail to start. Even operators with

recently installed units who have not yet

experienced the pain of unreliable older

equipment are still seeking third-party,

open-architecture control systems. They

are frustrated at being held captive by the

turbine manufacturer’s controls. They are

eager to achieve a higher degree of plant

controls integration and/or consolida-

tion, have access to useful live data, re-

spond on their own to issues and take

true ownership of their turbine and its

control system.

Open control system upgrades and re-

placements have been field proven to in-

crease availability, reliability, safety and

profitability versus OEM and other black

box control solutions because the owner/

operator is provided with the tools and

data necessary to become a self-main-

tainer who troubleshoots, tunes, repairs

and improves independently from the

GT’s OEM. Regardless of the reason for

upgrading the control system, GT opera-

tors can benefit greatly by considering the

many advantages of relying on a third-

party open control system.

ELEMENTS OF A

CONTROLS RETROFIT

Open control system (OCS)

upgrades and replacements can

cover every instrument and control

aspect of a GT unit. This includes the

control and protection hardware and

1309PE_40 40 8/29/13 5:35 PM

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www.power-eng.com42

dynamic, the user must invest addi-

tional hours of engineering effort.

Complex scripts are developed to

show the status of devices and electri-

cal power flow. This not only increases

the cost of implementation, but also

makes the maintenance and modifi-

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ficult.

Real-Time Power Management

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If information is missing or faulty,

the software estimates the parameters

even without signals actually coming

from hardware in the field. The model-

based environment makes it very easy

to add equipment (drag, drop, con-

nect). This is extremely useful during

plant expansions or revamps.

Utilizing RTPM software will reduce

development time by 30 percent over

traditional SCADA systems, providing

a more comprehensive level of intel-

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long term cost of ownership of the

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the future.

A true real-time power management

application should provide the follow-

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2. Intelligent Monitoring

3. Online Predictive Simulation

4. Sequence of Events Playback

Supervisory Control and

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electrical on-line diagrams and do not

contain interconnectivity informa-

tion. In order to be made functionally

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www.power-eng.com44

model of the system for proper presen-

tation of actual operating status.

All this information should be acces-

sible to the system operator through

advance man-machine interfaces such

as an interactive one-line diagram that

provides logical system-wide view.

Compensation for

absent physical meters

Traditional monitoring is based on

visualizing meter information from

certain limited parts of the system.

It is not cost effective to place meters

throughout the entire system. The

real-time power management system

eliminates this need by processing

the telemetry data and determines the

missing or faulty meter values using

advanced techniques such as State and

Load Estimator (SLE). Maintenance re-

sponsibility and cost are substantially

decreased every time equipment is

added to the monitoring network as

operations can get immediate visibil-

ity of the electrical operating condi-

tions without physically metering the

equipment.

The system therefore generates

pseudo-measurements such as voltage,

losses, power flows, etc. and compen-

sates for absence of physical meters –

especially in low voltage regions. By

generating pseudo-measurements, it

is also possible to alarm the operator

regarding unobservable or unmetered

equipment that is operating

abnormally such as over-

loads.

RAW Data Checking

(RDC)

The Intelligent Monitoring

module has the capability

of determining whether the

data monitored makes sense

electrically. It utilizes the

Network Topology Processor

to determine if the measure-

ments follow the basic elec-

trical rules. Some examples

are:

•  Power in and out of nodes

• Measurements on both

sides of feeders and trans-

formers

• Out of range values

Online Predictive Simula-

tion

In order to design, oper-

ate and maintain a power

system, one must first understand

its behavior. The operator must have

firsthand experience with the system

under various operating conditions to

effectively react to changes. This will

avoid the inadvertent plant outage

caused by human error and equipment

overload. The cost of an unplanned

outage can be staggering. The ability to

perform system studies and simulate

“What If” scenarios using real-time

operating data on demand is of the es-

sence.

(RTPM) offers the powerful fea-

tures in (RTPM) Power Simulator with

an interface to utilize online data for

simulation. With this feature you can

INTELLIGENT

ONE-LINE DIAGRAM

A Real-Time Power Management

system operates on an intelligent one-

line diagram that provides the follow-

ing features:

Electrical Network

Topology Processor

An electrical Network Topology Pro-

cessor (NTP) automatically

determines if a component

is energized\de-energized. It

looks at the status of switch-

ing devices such as break-

ers, switches and contacts as

well as the interconnectivity

between components.

In SCADA software, the

HMI’s that are built-in do

not contain interconnectiv-

ity information. Status of

components has to be de-

termined from signals actu-

ally coming from hardware

in the field and scripts have

to be written for making

the animation on the HMI

screens.

Ratings and settings of

every component in the

electrical network

Ratings and settings of

the electrical components

are stored in the (RTPM) database. Ac-

cessing this information is as easy as

double clicking on the component in

the one-line diagram view. This infor-

mation serves as a base for all simula-

tion capabilities of the software as well

as some automatic features such as

overload and under/over voltage con-

ditions alarming.

Intelligent Monitoring

Monitoring is the base function for

any power management software. In

addition, seamless integration with

metering devices, data acquisition

and archiving systems are essential

to monitoring software. Real-time or

snapshot data are linked to an online

1Production Savings Per Event Using

PSMS 10 Percent Reduction

In Downtime

Estimated Production Loss $ per Outage Event = $/kW x Recorded Peak kW for Large (50 MW) industrial users. The graph shows the increasing loss in revenue for longer outage times.

$200,000

$167,000

$133,000

$100,000

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check for electrical system component

status, operator actions and telemeter

data. The Playback feature has a direct

interface to the RTPM Power Simulator

modules for operators and engineers

to study alternate solutions for the

problems at hand.

Supervisory and Advisory Controls

State-of-the-art supervisory and ad-

visory control capabilities should be

used to control and optimize in real-

time various parameters throughout

the system. Using optimization algo-

rithms, the user can program the power

management system (i.e., assist energy

consumers by automatically operat-

ing their system to minimize system

losses, reduce peak load consumption

or minimize control adjustment). For

energy managers, the power manage-

ment system can be set up to minimize

energy fuel costs and optimize system

operation.

In a recent study performed for a

simulate the following scenarios and

more:

•  Start of a motor or group of mo-

tors for determining the impact in

the electrical system

•  Energize/De-energize feeders

(steady state and dynamic)

•  Check for Short-Circuit and Arc

Flash levels under existing opera-

tion

•  Check sequence of operation of

protective devices under existing

configuration of the network

Sequence of Events Playback

The ability to recover from a system

disturbance depends on the time it

takes to establish the cause of the prob-

lem and take remedial action. This re-

quires a fast and complete review and

analysis of the sequence of events prior

to the disturbance. Power management

software should assist operation and

engineering staff to quickly identify

the cause of operating problems and

determine where energy costs can be

reduced. The software should also be

able to reconstruct exact system condi-

tions to check for operator actions and

probe for alternative actions after-the-

fact. This important tool serves as an

on-going learning process for the op-

erator.

Besides reducing losses and improv-

ing data gathering capability, such an

application should assist in increase

plant reliability and control costs. The

event playback feature is especially

useful for root cause and effect in-

vestigations, improvement of system

operations, exploration of alternative

actions and replay of “What If” scenar-

ios. Event playback capability trans-

lates into savings. These savings for a

typical 50-MW plant are illustrated in

Figure 1. For example, a conservative

estimate of 10 percent reduction in

downtime for an outage that lasts an

hour yields about $33,000 in savings.

The RTPM Playback module recon-

structs exact system conditions to

Event Playback Replays Archived Historian Data and

Investigates Cause and Effect In Order To Explore

Alternative Actions and Replay “What If” Scenarios

2

PowerManagement

Console

Real-TimeData

Real-TimeServer

Playback Historian

Intelligent Load Shedding Offers Fast Load Shedding

That Can Dynamically Manage The Stability Of a

System By Responding Faster To Disturbances

3

Real-Time Data

Simulator

Disturbances

KnowledgeBase

LoadShedding

SystemControl

Display

Alarm

Predict

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large industrial facility (150MVA), advanced optimi-

zation algorithms, native to the power management

system, were utilized to reduce real and reactive power

losses. Assuming a conservative power loss reduction

of only 0.1 percent at an average electrical energy cost

of USD $0.13/kWh, an energy management system

would yield savings of more than $135,000 per year

and would pay for itself through the immediate real-

ization of savings in operating and maintenance costs.

Online Control

An advanced power management system should

provide the options for full remote control to the sys-

tem elements such as motors, generators, breakers,

load tap changers and other protection devices direct-

ly or through the existing SCADA system.

In addition, the software should provide user-defin-

able actions that can be added or superimposed on the

existing system for automating system control. This is

similar to adding PC-based processors/controllers (kV,

kW, kvar, PF, etc.) or simple breaker interlocks to any

part of the system by

means of the soft-

ware.

Intelligent Load

Shedding

A major distur-

bance in an electri-

cal power system

may result in certain

areas becoming iso-

lated and experienc-

ing low frequency

and voltage, which can result in an unstable opera-

tion. The power management system should have the

intelligence to initiate load shedding based on a us-

er-defined Load Priority Table (LPT) and a pre-con-

structed Stability Knowledge Base (SKB) in response

to electrical or mechanical disturbances in the system.

Load shedding schemes by conventional frequency re-

lays are generally a static control with fixed frequency

settings. Based on Neural Networks, a power manage-

ment system would be able to adapt to all real-time

situations and provide a true dynamic load shedding

control (Figure 3). This would allow the operator to

optimize load preservation, reduce downtime for criti-

cal loads and simulate/test the load shedding recom-

mendations.

Another significant cost component of operations is

demand charge of the energy bill. The demand charge

is 40 to 60 percent of the bill for sites without peak

The power management system can be set up to minimize energy fuels costs and optimize system operation.

1309PE_47 47 8/29/13 5:36 PM

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or sequenced or penalty can be paid if

certain processes are vital.

CONCLUSION

A typical SCADA system displays col-

lected electrical power data in a non-

electrical system environment with-

out recognizing the

interdependencies of

equipment. Extend-

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Using these tools, the user can accurately

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The playback of recorded message logs

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of alternative actions during historical

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shaving generation. A single unman-

aged demand charge can produce a very

large hike in the power bill each month

and with “ratcheting” demand charges

(the Eskom Network Access (NAC)

charge applies to the highest recorded

demand above the notified demand

for 12 consecutive

months), the penalty

then has a bearing

for a whole year. An

intelligent combina-

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tions can provide the

current and predicted

demand for each day

thus managing peak

demands on a continuous basis. Loads

can be shed intelligently and automati-

cally, peak-shaving generators can be

started, load startup can be postponed

A single unmanaged demand charge can produce a very large hike in the power bill each month.

1309PE_49 49 8/29/13 5:36 PM

www.power-eng.com50

the cost would be considerably higher

than with FRP piping.

Chemicals that run through the pipes

are high in corrosive properties. This is a

problem for steel, which is far more sus-

ceptible to corrosion than is fiberglass.

Sealing the latter, however, is another

matter. Just how challenging that project

could be became painfully clear during

the first phase, which was implemented

during the height of the winter season. Fi-

berglass piping has unique coupling and

connection issues. It is difficult to seal in

the cold and the task becomes more oner-

ous when there is moisture in the air.

Beaubien said the previous project was

challenged by suspect field joints that

failed due to environmental conditions

during the joint fusion process in the

construction phase. “The fusion process

of the FRP joints requires a controlled

DTE Energy, the Detroit-

based generator, trans-

mitter and distributor

of energy to 2.1 million

customers in Southeast-

ern Michigan, is the state’s largest electric

utility. With a system capacity of 11,084

MW, DTE uses coal, natural gas, nuclear

fuel, hydroelectric pumped storage and

renewable resources to generate its elec-

trical output. DTE’s Monroe Power Plant,

located near Lake Erie in Monroe, Mich.,

is the largest plant of its type in the state

and fifth largest in the U.S. according to

DTE. The facility, situated on a 1,200 acre

site, is comprised of four units and has a

capacity of 3,200 MW.

The Monroe plant is in the second of

three phases of a $600 million upgrade:

the DTE Monroe Energy Scrubber Proj-

ect, which represents a clean coal com-

mitment for the nearly 40-year old facil-

ity. “We are reducing sulfur dioxide (SO2)

emissions by installing scrubbers in the

power plants,” said Jason Beaubien, DTE

major enterprise project start-up man-

ager.

Flue Gas Desulfurization (FGD),

commonly referred to as the scrubber,

is designed to control 95 percent of SO2

emissions, according to Beaubien. “One

Monroe FGD will control 12 percent of

the forecasted fleet SO2 emissions,” he

said. Two scrubbers are to be brought

online in Phase II. In Phase I, which was

completed in 2009, two FGD scrubbers

went online.

The U.S. Environmental Protection

Agency has placed a high priority on

greatly reducing SO2 emissions. When

gaseous emissions combine with water,

they form a dilute aqueous solution of

Coupling for Fiberglass:An Alternative to Curing

BY CHUCK RAYMOND, MACOMB GROUP

sulfurous acid, which can easily oxidize

in the atmosphere to become sulfuric

acid (H2SO

4). The EPA has long warned

that dilute H2SO

4 is a major component

of acid rain. Given the agency’s intense

scrutiny on reducing such emissions

from coal-fired plants, DTE also places a

high priority on completing its initiative

on time.

THE CHALLENGE FOR

PIPING CONTRACTORS

Installation represents a major prob-

lem for contractors who are responsible

for $1.5 million worth of fiberglass pip-

ing. Project managers and contractors

generally prefer fiberglass or FRP piping

instead of steel for the FGDs. The reason

is resistance to corrosion. “FRP piping is

the preferred material based on the high

chlorides, abrasive qualities of the slurry,

and cost,” Beaubien said, adding that al-

loy piping was not considered because

Pipe coupling can be a labor intensive process, requir-

ing specialized workers in the skilled trades.

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or externally, and the coupling cannot

be disturbed for as much as two days,

perhaps even longer depending on

weather conditions.

Delays can obviously

jeopardize the project

timeline. According

to Marc Robertson,

power generation

specialist for Victau-

lic, a developer and

manufacturer of me-

chanical pipe joining systems, the pro-

cess is too time consuming.

“It’s all very labor intensive and you

might need to hire specific people in the

trades who are familiar with these spe-

cialties to complete the process,” Robert-

son said. He noted that fiberglass piping

contractors face other issues such as the

possible need for additional curing with

a heat blanket and greater protection

environment which was difficult to ob-

tain at times with the elements found

near Lake Erie in the winter months,”

the manager said. Beaubien said that

later during commissioning, DTE Energy

experienced some joint failures, particu-

larly with field joints.

“We didn’t have couplings on the

previous build, so the field joints were

wrapped with layers of fiberglass,” Beau-

bien said. It was here that the piping con-

tractor ran into trouble.

THE TROUBLE

WITH CURING

The use of the curing process for cou-

pling and sealing pipes has been left

fundamentally unchanged through the

years. Most pipe joints require resin

applied to the joint that then must be

cured. The surface resin is cured with

heat applied either through a catalyst

from the elements. “Worse yet, you may

have to completely tear it out and start

over if any leaks are detected during test-

ing,” Robertson said.

“It means that every-

thing has to be dried

out and reworked.”

One of the piping

contractors found that

to be the case dur-

ing Phase I. External

methods were insuf-

ficient, and heat blankets and even in-

dustrial blow dryers did not completely

solve or resolve the problems with adhe-

sion. Making matters worse for the con-

tractor, the adhesive, which apparently

had not been properly cured, most likely

due to the impact of Michigan’s bitter

winter on the curing process, tended

to peel away. The result: the failure of

joints reported by Beaubien resulting in

“We didn’t have couplings on the previous build, so the field joints were wrapped with layers of fiberglass.”

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eliminate the need for the curing pro-

cess. What their research discovered

was that an aluminum coupling (296A)

manufactured by Victaulic could resolve

the dual time and connection issues.

“We groove pipe and create rigid joints

instead of flexible ones that would have

bowed or caused other problems to the

fiberglass,” said Victaulic’s Robertson.

expensive repairs that are bound to im-

pact the contractor’s expenditures.

FINDING AN ALTERNATIVE

The piping contractor, with assistance

from the Macomb Group, a distributor

of pipe valves and fittings, sought an

alternative coupling method that could

stand up to the elements and perhaps

“Fiberglass piping can be easily frac-

tured so we are careful not to add ad-

ditional stress to the particular groove

that we use.” The grooves for the 296A

are placed at the end of the pipe.

Time and cost savings occur with the

coupling attachment process. A gasket

is installed on the outside diameter of

the pipe, the housing is placed and fit-

ted over the gasket and the coupling is

attached. The company says installa-

tion can be conducted in severe weather

or even when the piping is submerged.

“There is no waiting period and no cur-

ing,” Robertson said, adding that the

installation process is completed in

minutes through the use of a “simple

mechanical joint.” The company states

there is no special training required to

complete the coupling installation.

DTE’s Beaubien agreed that the

coupling saved the contractor and the

utility a significant amount of time.

“During the construction phase, sig-

nificant man-hours were reduced as

the field joints could be assembled

in a few minutes versus hours with

the wrapped joint method,” Beaubien

said. “With hundreds of connections

on the spool pieces, the savings in

construction were substantial.” The

project manager also determined that

the joints did not require the special

enclosures and scaffold configurations

to maintain temperature that wrapped

joints would require. “These also re-

duced costs,” he said.

RESULTS FROM TESTING

DTE conducted pressure testing of

the piping with the couplings. Beaubien

said that DTE’s comprehensive and in-

tensive testing confirmed that the cou-

plings and the piping performance were

meeting the utility’s exacting standards.

DTE continues to monitor the couplings

and their performance. “We fully expect

them to be successful,” Beaubien said.

DTE plans to continue use of fiber-

glass piping with the coupling at anoth-

er of its locations.

1309PE_54 54 8/29/13 5:36 PM

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www.power-eng.com56

conference sessions.

To commemorate POWER-GEN’S

25th anniversary, PennWell will be rec-

ognizing the power generation industry’s

25 most influential people over the last

25 years. The industry’s most influen-

tial person will be named the week of

POWER-GEN International 2013. The 25

most influential people were nominated

and selected based on a poll of industry

professionals.

Once again, POWER-GEN will come

to Orlando with three co-located events:

NUCLEAR POWER International; the

POWER-GEN International Financial

Forum; and the Renewable Energy World

Conference & Expo. That’s four confer-

ences under one roof.

KEYNOTE SESSION

The keynote session on Nov. 12 will

feature high-ranking executives, includ-

ing James Rogers, chairman of Duke

Energy Corp., Peter Delaney, chairman,

president and CEO of OGE Corp., and

David Dunning, group executive of Fluor

Corp. The plenary session will be a rapid-

fire, content rich discussion featuring Mi-

chelle Bloodworth, vice president of Busi-

ness Development for America’s Natural

Gas Alliance, and Revis James, director of

Generation Research & Development at

the Electric Power Research Institute.

PROJECTS OF

THE YEAR AWARDS

Presented by Power Engineering, the

Annual Awards Gala begins Monday,

Nov. 11 with a cocktail reception, fol-

lowed by a three-course dinner and in-

cludes award presentations for Projects

of the Year and Papers of the Year. The

Papers of the Year recognizes the top

papers in each conference track. The

Projects of the Year Awards recognize

the world’s best power projects, honor-

ing excellence in design, construction

and operation of power generation

facilities. The award winners – nomi-

nated by the industry and selected by

the editors of Power Engineering and

RenewableEnergyWorld.com – are an-

nounced and presented with awards

recognizing their exceptional contribu-

tions to the power generation industry.

The gala is open to the award final-

ists, their guests and all POWER-GEN

International, NUCLEAR POWER In-

ternational, Renewable Energy World

Conference & Expo North America

POWER-GEN Internation-

al, the world’s largest an-

nual forum for the power

generation industry, made

its debut 25 years ago

in Orlando, Fla. The inaugural event,

“POWER-GEN ’88,” was small, with

less than 100 exhibiting companies and

about 600 registered attendees.

Today, more than 1,200 exhibiting

companies showcase their products and

services on the exhibit floor at POWER-

GEN, and more than 21,000 people at-

tend the three-day event. POWER-GEN

International is returning to Orlando

Nov. 12-14 for its 25th anniversary in what

promises to be the most exciting POW-

ER-GEN to date.

POWER-GEN International and its

co-located events offer a wealth of net-

working opportunities with leading

professionals and key decision makers.

More than 300 speakers will share their

thoughts on trends, technology and

project development in more than 70

Celebrating

25 YearsBY RUSSELL RAY, CHAIRMAN, POWER-GEN INTERNATIONAL

James Rogers Peter Delaney David Dunning

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TO THE RESCUE

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1309PE_57 57 8/29/13 5:37 PM

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1 is a General Electric LM6000 PA aero-

derivative simple cycle combustion tur-

bine that is primarily used for peaking.

Unit 2 is a GE Frame MS7001EA in com-

bined cycle with a Nooter Erikson triple

pressure HRSG that provides steam for a

GE Fitchburg axial exhaust straight con-

densing turbine. Unit 3 is a GE 7241FA+e

in combined cycle with a Aalborg triple

pressure reheat HRSG that provides

steam for a GE A10 reheat steam turbine.

Unit 3 was the first combined cycle in

Florida to install a SCR. Unit 4 consists of

a GE 7241FA+e in combined cycle with a

Vogt triple pressure HRSG that provides

steam for a GE A14 reheat steam turbine.

Including duct firing capability, this unit

will produce 300 megawatts.

Curtis H. Stanton Energy Center

and DSI Systems

With more than $275 million invest-

ed in state-of-the-art pollution control

equipment, the Curtis H. Stanton Energy

Center has the power to safeguard the

air,  water and quality of life in Central

Florida. It is owned and operated by the

Orlando Utilities Commission (OUC).

And, with a gross capacity of 1,833 mega-

watts, it also has the power to deliver

reliable electric service both now and

for generations to come. Unit 1 began

commercial operation in 1987 and has a

capacity of 450 MW. Unit 2 began com-

mercial operation in 1996 and also has a

capacity of 450 MW. It is the first pulver-

ized coal unit of its size in the U.S. to use

Selective catalytic Reduction to remove

nitrogen oxide.

Stanton Solar Power Project

The 6-MW Stanton Solar Power Proj-

ect, completed in December 2011, deliv-

ers clean, affordable energy to the OUC.

The ground-mounted photovoltaic sys-

tem, comprised of more than 25,000

poly crystalline panels, is located at the

OUC’s Curtis H. Stanton Energy Center.

A single axis tracking system increases

output by up to 30 percent, and the sys-

tem performed at 104 percent of estimat-

ed production during its first six months.

Stanton was the first solar farm in

Orange County, Florida and can generate

enough renewable energy to power more

than 600 homes.

Culture Fuels Inc.

Culture Fuels Inc., an algae-to-fuels

company based in Lakeland, Fla. has

developed a patent pending hybrid cul-

tivation platform FloatAlgae, a highly-

productive, low-cost photobiorector that

floats on a body of water. It significantly

increases algal biomass density, which

according to the company reduces the

capital and energy needed for harvest-

ing equipment. This improved engineer-

ing solution allows for the production

of cost-competitive end products using

natural algae strains. Visitors will be able

to see the Culture Fuels laboratory.

PV Solar Installation

It’s one of the largest rooftop solar ar-

rays in the southeast! The roof of North-

South Building of the Orange County

Convention Center is home to a 1.1 MW

photovoltaic array that was designed and

installed by Johnson Controls. Costing

more than $8 million, funding partners

included the State of Florida and the local

utility. The project went online in Febru-

ary 2010. The tour will begin at the reg-

istration area in the West building and

will walk across the pedestrian overlook

bridge to the South building. Attendees

will then take the freight elevators to the

HVAC Penthouse level, where they view

and learn about the inverters and other

components necessary to run the solar

array. Finally, they will step out onto the

roof to take in the full array and ask ques-

tions about the project.

SEE YOU IN ORLANDO!

POWER-GEN International has cov-

ered it all, providing a world stage for

the innovations, ideas and solutions

that have defined the industry for two

decades.  Since its inception in 1988,

POWER-GEN has evolved into the larg-

est power generation event in the world.

Visit www.power-gen.com for com-

plete conference exhibition and registra-

tion information.

and POWER-GEN Financial Forum at-

tendees.

CONFERENCE HIGHLIGHTS

At POWER-GEN, more than 40 con-

ference sessions will be held under

eight tracks: Emissions Control, On-Site

Power, Plant Performance, Gas Turbine

Technologies, Fossil Technologies, En-

vironmental Issues, Demand Response,

and Industry Trends/Competitive Power

Generation.

Here’s a sample of the some of the ses-

sions that will be offered: “Flexible Gen-

eration,” “Compliance Control Strategies

and Technologies,” “Gas Turbine Tech-

nology Developments,” “Gas Turbines:

An O&M Perspective,” “Steam Turbine-

Generator Reliability, Availability and

Efficiency,” “Multi-Pollutant Emissions

Control Technologies,” and “How De-

mand Response is Impacting Utility

Planning.”

WOMAN OF THE YEAR

The first POWER-GEN International

Woman of the Year Award will be given to

a pioneering woman from the power gen-

eration industry. Nominated and selected

by a committee of her peers, the honor of

being named the POWER-GEN Interna-

tional 2013 Woman of the Year will be

given to a leader who has advanced the

power industry in a meaningful way. The

winner of the POWER-GEN Internation-

al 2013 Woman of the Year Award will

be announced during the Projects of the

Year Awards Gala on Nov. 11 at 7 p.m.

TECHNICAL TOURS

Technical tours of five power genera-

tion facilities and technologies will be of-

fered on Monday, Nov. 11.

Cane Island

On 170 acres surrounded by nearly

1,000 acres of protected wetland, Cane

Island burns natural gas as the primary

fuel. The plant is capable of producing

710 megawatts of electricity. The Cane

Island Power Park is a mixture of modern

gas and steam turbine technology. Unit

1309PE_58 58 8/29/13 5:37 PM

© 2013 by AMETEK Inc. All rights reserved.

The new WDG-V.Impressing even theworld’s most demandingcombustion manager.

The new AMETEK Thermox WDG-V extractive combustion analyzer offers

industry-leading safety support. First in its class to be third-party certified for

SIL-2 implementation in safety-instrumented systems, the WDG-V provides

a complete solution for combustion process control and safety.

Reliable detection of low-combustion oxygen and/or high CO in a fired heater

or boiler is critical to burner management system effectiveness. The WDG-V

analyzer monitors hot, wet flue gas to minimize excess oxygen, lower

NOx emissions, and improve operating efficiency in power generation

and petrochemical refining. It can also monitor methane levels to

assure safe burner startup and shutdown.

The all-new WDG-V. Combustion management and safety capabilities

so good, they make this guy jealous. Learn more at www.ametekpi.com.

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1309PE_59 59 8/29/13 5:37 PM

POWER GENERATION WEEK

NOVEMBER 12–14, 2013 | ORANGE COUNTY CONVENTION CENTER | ORLANDO, FL, USA

Covering every aspect of the power generation industry, POWER-GEN International, NUCLEAR POWER International,

Renewable Energy World Conference & Expo North America and POWER-GEN Financial Forum converge in 2013 to

form POWER GENERATION WEEK. Benef t from f ve days packed with pre-conference workshops, technical tours,

over 70 conference sessions, panel discussions, three exhibition days and multiple networking events. Like never

before, you’ll have access to nearly every facet of the market – all under one roof.

4 Events. 5 Days. 1 Roof.

Owned & Produced by Presented by Supported by

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Why Should You

Filter Your Water?

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The Best Engineered Water Filteration Solution Always Costs Less

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Automatic Filters

A new innovationfor bolted joints:

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The X-series washer

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Learn more and request a sample today!

Video and brochure available:

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Bolting Solutions

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������������������� ���������������������������� ���������������������������������� �������� �� ��� ����� ������� ���� ������������������������������ �������������������������������������� ��� ����������

PE113

Concrete Buildings

call 1 800 544 2947

visit martin-eng.com

Martin Engineering offers

replacement blades for the full

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Electric Control-Valve Actuators

Rotork electric CVA control-valve actuators provide a major technological advance in precise operation, HMI capabilities, and fail-to-position protection. Available in linear and quarter-turn actions, they are ideal for a wide range of control-valve applications throughout the power plant. They can deliver an absolute positioning

accuracy of 0.1%, have a built-in data ORJJHU��DQG�FDQ�SURYLGH�VLJQL¿�FDQW�HQHUJ\�savings. Learn more at www.rotork.com.

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miller-stephenson chemical company, inc.California - Illinois - Connecticut - Canada

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Miller-Stephenson has a family of non-

flammable and economical cleaning

agents that restore electrical or mechani-

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Removes oxides, soot, oil, grease and

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panels and switching devices. Eva-

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New Low Global Warming formulations

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For more information and sample call

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Phone: (877) 486-3522

E-mail: BetterCrushers@GundlachCrushers.com

www.TerraSource.comTerraSource™ Global is a wholly-owned subsidiary of Hillenbrand, Inc.

(NYSE: HI) ©2013, TerraSource™ Global. All rights reserved.

Handling a World of Materials

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POWER PLANT

Decommissioning

Environmental Remediation

Retrofitting

(800) 932-2869 | www.brandenburg.com

Brandenburg®

Brandenburg is the premier demolition and

environmental remediation contractor for

power plant decommissioning and retrofi t-

ting. Brandenburg services utility companies

throughout the U.S. by performing demo-

lition and repurposing projects ranging from

selective removal of obsolete equipment

to complete closure of power plant facilities.

Demolition/Decommissioning

www.lt-eng.com/products/nema_motors

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UNMATCHED PERFORMANCE AT AN UNBEATABLE PRICE

NEMA PREMIUM® EFFICIENCY MOTORS

Efficiency Motors

Clean, reliable electricity. Our MOBILEPAC® gas turbine package delivers 25MW within a day of site arrival.Our stationary, modular SWIFTPAC® gas turbine package can be generating 30–60MW in 21 days or less. Our newest product, the FT4000™ engine, powered by Pratt & Whitney® PW4000™ derivative gas generator generates 60–120MW. What’s more, these systems use proven industrial gas turbines, meaning less noise, lower emissions and higher base-load and part-load efficiency. Visit www.pwps.com or call

1-866-PowerALL (1-866-769-3725) to learn more.

Clean, reliable energy. We get you electricity a lot faster.

Gas Turbine PackageEngineering Services

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Increase Steam Boiler Efficiency:

Brochure HRS 1188 describes three differ-ent types of continuous boiler blowdown heat recovery systems manufactured by Penn Separator Corp. All systems recover up to 90% of the BTU’s normally lost to drain. Visit our website www.pennseparator.com for a sales representative nearest you.

Heat Recovery Systems

http://powereng.hotims.com/RS#312

1309PE_62 62 8/29/13 5:37 PM

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www.power-eng.com 63

High Temperature

Industrial Solutions When you need high temperature

thermal performance or personnel and

fire protection, ROXUL® has you covered

with a wide range of Pipe, Board, Blanket

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www.victoryenergy.com

HRSG

INNOVATION

IN NUCLEARFluor’s Subject Matter Expert Protégé program

provides a platform for long-term succession

planning and accelerated growth. Active in

the global nuclear community, Clay Smith

and his protégés are collaborating to improve

the industry for our clients and the long-term

sustainability of our environment.

www.fuor.com

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BETE’s XA Series Air Atomizing

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Spray Nozzles, Absorber

Silo and Bin

Cleaning Services and Equipment

Call 800-322-6653

or visit

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Silo and Bin Cleaning Sevices

Crown Electric

Iso Phase Bus

FabricationInstallation

Upgrades & UpratesGSU Change Outs

175 Edison Dr.

Middletown, OH 45044

www.crown-electric.com

sales@crown-electric.com

ext.

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Iso Phase Bus

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Turbine Services

Trust your Turbo Generator Service to the Manufacturer with more than 100 years experience.

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����!� ��������! ���� ����!����������������!�� !������!�� ���������!��!������������!��!����������������! ���!��� � ������! ����������� ���! �� ���!���������������������� ��������� �!����� ����� ����� ��� ������������!����������� � �����

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Books, Books…So Many Books

www.PennEnergy.com

Check out over 50,000 Books Related to the Energy Industry at PennEnergy.com

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For sale or rent

The world’s verybest portable end

prep tools and abrasive saws

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GEORGE H. BODMAN, INC.Chemical cleaning advisory services for

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rental

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CONDENSER OR GENERATOR AIR COOLER TUBE PLUGS

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Just Plugging Along

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1309PE_66 66 8/29/13 5:37 PM

www.power-eng.com 67

INDEX

RS# COMPANY PG# SALES OFFICERS# COMPANY PG#

1421 S. Sheridan Rd., Tulsa, OK 74112 Phone: 918-835-3161, Fax: 918-831-9834 e-mail: pe@pennwell.com

Sr. Vice President North American Power Group Richard Baker

Reprints Foster Printing Servive 4295 Ohio Street Michigan City, IN 46360 Phone: 866-879-9144 e-mail: pennwellreprint@fosterprinting.com

National Brand Manager Rick Huntzicker Palladian Professional Park 3225 Shallowford Rd., Suite 800 Marietta, GA 30062 Phone: 770-578-2688, Fax: 770-578-2690 e-mail: rickh@pennwell.com AL, AR, DC, FL, GA, KS, KY, LA, MD, MO, MS, NC, SC, TN, TX, VA, WV

Brand Sales Manager Dan Idoine 806 Park Village Drive Louisville, OH 44641 Phone: 330-875-6581, Fax: 330-875-4462 e-mail: dani@pennwell.com CT, DE, IL, IN, MA, ME, MI, NH, NJ, NY, OH, PA, RI, VT, Quebec, New Brunswick, Nova Scotia, Newfoundland, Ontario

Brand Sales Manager Tina Shibley 1421 S. Sheridan Road Tulsa, OK 74112 Phone: 918-831-9552; Fax: 918-831-9834 e-mail: tinas@pennwell.com AK, AZ, CA, CO, HI, IA, ID, MN, MT, ND, NE, NM, NV, OK, OR, SD UT, WA, WI, WY, Alberta, British Columbia, Saskatchewan, Northwest Territory, Yukon Territory, Manitoba

International Sales Mgr Anthony Orfeo The Water Tower Gunpowder Mills Powdermill Lane Waltham Abbey, Essex EN9 1BN United Kingdom Phone: +44 1992 656 609, Fax: +44 1992 656 700 e-mail: anthonyo@pennwell.com Africa, Asia, Central America, Europe, Middle East, South America

European Sales Asif Yusuf The Water Tower Gunpowder Mills Powdermill Lane Waltham Abbey, Essex EN9 1BN United Kingdom Phone: +44 1992 656 631, Fax: +44 1992 656 700 e-mail: asify@pennwell.com Europe and Middle East

Classifieds/Literature Showcase Account Executive Paige Rogers 1421 S. Sheridan Rd. Tulsa, OK 74112 Phone: 918-831-9441, Fax: 918-831-9834 email: paiger@pennwell.com

9 Industrial Cooling Tower Services Inc. 17 www.ictsinc.com

13 John Zink Co 25 www.johnzinkhamworthy.com

18 Magnetrol International 35 www.magnetrol.com

30 Man Diesel SE 51 www.man-bluefire.com

35 Michigan Seamless Tube 57 www.mstube.com

14 Mitsubishi Power Systems Americas, Inc. 27

www.mpshq.com

26 New York Blower Company 45 www.nyb.com

10 Nol-Tec Systems Inc 18 www.nol-tec.com

15 Philadelphia Gear Corporation 29

37 Power Generation Week 60 www.powergenerationweek.com

28 POWER-GEN International 48 www.power-gen.com

7 Robinson Fans 13 www.robinsonfans.com

34 Santee Cooper 55 www.santeecooper.com/wpsale

8 SMA America LLC 15 www.sma-america.com

1 Solvay Chemicals Inc C2 www.solvair.us

33 The Society for Protective Coatings 54

www.sspc.org

21 Volvo Penta of the Americas 38 www.volvopenta.com

2 Westinghouse Electric Co 3 www.westinghousenuclear.com

Advertisers and advertising agencies assume lia-

bility for all contents (including text representation

and illustrations) of advertisements printed, and

also assume responsibility for any claims arising

therefrom made against the publisher. It is the

advertiser’s or agency’s responsibility to obtain

appropriate releases on any items or individuals

pictured in the advertisement.

38 American Council on Renewable Energy C3

www.reffwest.com

36 Ametek Process Analytical 59 www.ametekpi.com

6 Areva 11 us.areva.com/atrium

31 Babcock Power Inc. 52 www.babcockpower.com/

dsianimation

16 Basler Electric Co 31 www.basler.com/9pe11g

17 BETE Fog Nozzle, Inc. 33 www.bete.com

27 Braden Manufacturing 47 www.braden.com

32 Brand Energy and Infrastructure Services 53

www.beis.com

19 Clearspan Fabric Structures 37 www.clearspan.com/adpwre

24 Cleaver Brooks Inc/Nebraska Boiler 41 www.cleaverbrooks.com/engineered

12 Colfax Fluid Handling 23 www.colfaxcorp.com/power-

generation

29 Dresser-Rand 49 www.guascorpower.com

22 Fibrwrap 39 www.fibrwrap.com

39 Foster Wheeler USA C4 www.fwc.com/GlobalPoweGroup

25 GE 43 www.ge-energy.com/energysavings

3 GE Water & Process Technologies 5 www.geimagination.com/cms/power

20 Graphite Metallizing Corp 37 www.graphalloy.com

23 Harco 40 www.harcolabs.com

4 HYTORC 7 www.hytorc.com

5 HYTORC 9 www.hytorc.com

11 Industrial Cooling Tower Services Inc. 19

www.ictsinc.com

1309PE_67 67 8/29/13 5:38 PM

www.power-eng.com68

GENERATING BUZZ

SnakeBotIt can see, and slither, and writhe its way into tight spaces. Is it a snake? Well, kind of.

The modular snake robot developed by researchers at Carn-

egie Mellon’s Robotics Institute made big news this sum-

mer when it successfully inspected the bowels of Austria’s

dormant Zwentendorf nuclear power plant.

Just two inches in diameter and 37 inches long, its body tethered

to a control and power cable out the rear end, the robot’s 16 mod-

ules with two half-joints each gives it 16 degrees of movement, af-

fording it the dexterity to reach places and get high-quality, well-lit

viewing angles that would be diffcult or impossible for a human or

even a boreoscope.

The “right-side-up” feature, in which the video feed from the

camera on its head is corrected to align with gravity, makes operat-

ing the robot more intuitive.

“With further development and testing, such a robot could give

operators a more complete understanding of a plant’s condition and

perhaps reduce a plant’s downtime by enabling faster, more eff-

cient inspections,” said Martin Fries, an engineer with EVN Group,

owner of the Zwentendorf facility.

Next, engineers hope to make the robot even more like a snake:

waterproof.

1309PE_68 68 8/29/13 5:38 PM

More Info at: www.refwest.com

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1309PE_C3 3 8/29/13 5:09 PM

Mercury and Air Toxics Standard Ö CSAPR Replacement ÖRegional Haze ...

Whatís Next? With an unpredictable path forward for US air regulation,

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1309PE_C4 4 8/29/13 5:09 PM

Fo r t he i ndu s t r y ’ s c a r e e r - m ind e d p r o f e s s i ona l s SUMMER 2013

A sup p l emen t t o P ennWe l l pub l i c a t i on s | w w w. P ennEne r g yJ O B S . c om

New Horizons:

The Growth of

Offshore Wind

Around the World

FROZEN ASSETS:

The Artic Push

in Offshore

Oil & Gas

INDUSTRY INSIGHTS

Offshore Energy: Mitigating Risk

TRAINING INSIGHTS

Empowering our Troops: AEP Career Initiatives for Veterans

ENERGY 101

Wave & Tidal Power

1308pejew_C1 1 8/20/13 2:58 PM

1308pejew_C2 2 8/20/13 2:58 PM

2 EDITOR’S LETTER

Offshore Energy: Towards the Great Horizon

Dorothy Davis Ballard, PennWell

3 NEW HORIZONS

The Growth of Offshore Wind Around the World

Dorothy Davis Ballard, PennWell

5 FROZEN ASSETS

The Artic Push in Offshore Oil & Gas

Hilton Price, PennWell

6 INDUSTRY INSIGHTS

Offshore Energy: Mitigating Risk

Matthew Gordon, Viking SeaTech

8 CAREER INSIGHTS

Regulatory Experts: Career Opportunities Galore

Volker Rathman, Collarini Energy Staffng

10 TRAINING INSIGHTS

Empowering our Troops: AEP Career

Initiatives for Veterans

Dorothy Davis Ballard, PennWell and Scott

Smith, American Electric Power

12 ENERGY 101

Wave & Tidal Power

PennEnergy.com

w w w . P e n n E n e r g y J O B S . c o m

SUMMER 2013

A PENNWELL PUBL ICAT ION

Stacey Schmidt, Publisher

staceys@pennwell.com

Dorothy Davis Ballard, Content Director

dorothyd@pennwell.com

Hilton Price, Editor

hiltonp@pennwell.com

Cindy Chamberlin, Art Director

cindyc@pennwell.com

Daniel Greene, Production Manager

danielg@Pennwell.com

Tommie Grigg,

Audience Development Manager

tommieg@pennwell.com

PennWell Corporation

1421 South Sheridan Road

Tulsa, Oklahoma 74112

918 835 3161

PennWell.com

Recruitment Advertising Sales:

Courtney Noonkester

Sales Manager

918 831 9558

courtneyn@pennwell.com

Ad ve r t i s e r s ’

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Sou

rce:

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ergy

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1308pejew_1 1 8/20/13 2:57 PM

2 Summer 2013 | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | EnergyWorkforce

Ed i to r ’ s

Le t t e r

THE world’s oceans and vast waterways have always evoked feelings of wonder

and piqued the adventurous spirit. Teeming with life and uncharted depths,

these fuid bodies are awe inspiring in the way they are so vast and yet joining together

everything.

In the ancient world the challenge was to transverse these great expanses, to fare

into the horizon of the unknown for sustenance and wealth. Today, the world beyond

our shores holds the promise of new bounties. We turn again towards the great horizon,

abundant with the promise of resources to fuel all we have developed.

In this issue of Energy Workforce we delve into offshore energy as it is moving

ahead in great leaps and

bounds. We begin with an

overview of offshore wind

power on page 3, highlighting

the incredible global growth

of this industry as it moves

towards becoming a truly

competitive resource.

Next, we look to the

offshore oil & gas industry

and its renewed push into artic territories on page 5, followed by a timely editorial on

mitigating risk on page 6 as offshore exploration & production moves to tap these once

unreachable resources.

With a focus on career development, we hear from an industry expert on expanding

opportunities for regulatory experts on page 8 and speak with an executive of U.S.

energy major AEP about initiatives for veterans in energy on page 10.

We close this issue with another round from our Energy 101 series, this time a brief

introduction to the evolving wave and tidal power industry on page 12.

We hope you enjoy these insights and encourage you to keep us on your summer

reading list to stay ahead with the latest energy news, research, and jobs at PennEnergy.

com and PennEnergyJobs.com.

Carpe diem!

—Dorothy Davis Ballard

Towards the Great Horizon

“Today, the world beyond our shores holds

the promise of new bounties. We turn again

towards the great horizon, abundant with

resources to fuel all we have developed.”

1308pejew_2 2 8/20/13 2:57 PM

Cover STORY

EnergyWorkforce | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | Summer 2013 3

The Growth of Offshore

Wind Around the WorldBy Dorothy Davis Ballard

AS more countries around the

globe realize the potential of

offshore wind, new turbines

are being installed off of our coasts.

In 2012, 1,296 megawatts of new off-

shore capacity were installed — a 33

percent increase from 2011, according

to the Global Wind Energy Council

(GWEC). The world now has at least

5,415 MW of offshore wind energy gen-

erating around the globe.

Offshore wind represents about 2 per-

cent of global installed energy capacity,

but that number could, and is expect-

ed to, increase rapidly. This renewable

resource, which is able to generate far

more power than onshore wind tur-

bines, could meet Europe’s energy de-

mand seven times over, highlights the

GWEC. While in the United States, off-

shore wind has the potential to provide

four times the energy needed capaci-

ty needed.

Europe’s lead in offshore wind

Currently, more than 90 percent of the

globe’s offshore wind power is installed

off the coast of northern Europe in the

North, Baltic and Irish seas. There is

now also a solid presence in the Eng-

lish Channel. Last year, the United

Kingdom took the lead in new wind ca-

pacity, adding 854.20 MW of offshore

wind power assets. Denmark added 46.8

MW in 2012 and Belgium 184.5 MW.

As of this article, Europe has a to-

tal of 4,336 MW generating from 1,503

offshore wind turbines at wind farms

located across 10 countries. The Euro-

pean Union has set a goal to generate

20 percent of its electricity from renew-

able sources by 2020, and offshore wind

is slated to play a major role in making

that a reality.

In early July, the offshore wind

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4 Summer 2013 | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | EnergyWorkforce

industry celebrated a milestone: Dong

Energy inaugurated the world’s largest

offshore wind power facility. The proj-

ect, which includes 175 Siemens wind

turbines, is called London Array and lo-

cated 12.4 miles off the Kent and Essex

coast in the Thames estuary. It has a to-

tal capacity of 630 MW, enough to pow-

er 500,000 households.

The UK’s Department of Energy &

Climate Change recently approved an-

other major offshore wind project, which

will add to Europe’s expanding wind en-

ergy output. The 1.2 GW Triton Knoll

project will be led by RWE and located

off the Lincolnshire and Norfolk coast.

Along with supplying clean, alternative

energy, the project is expected to gener-

ate more than $5.5 billion of investment

in the region and create about 1,130 jobs.

Germany, too, has had its sights set

on the development of alternative ener-

gies like wind and solar as part of a na-

tional commitment towards the phase

out of nuclear power. The country add-

ed 80 MW of offshore wind energy to the

electric grid in 2012, and another six util-

ity scale offshore wind projects are under

construction. Petrofac, and Siemens En-

ergy also recently entered into a $53 mil-

lion contract to build two major offshore

wind projects in the North Sea off the

coast of Germany - one totaling 576 MW

and another set for 800 MW.

US makes commitment to offshore wind

North America is aiming to add some

6.5 GW of wind power this year, and the

United States is looking to be a major con-

tributor. While there are no offshore wind

farms in the U.S. at the moment, the fed-

eral government has recently completed

its frst-ever round of auctions

for offshore wind leases. Deep-

water Wind, a company based

in Rhode Island, came in with

the highest bid of $3.8 million

for two areas totaling more than

164,000 acres off the coasts of

Massachusetts and Rhode Is-

land. The auction was viewed

as a historic moment for the

U.S.’s future commitment to

clean energy.

The federal government is

expected to hold another auc-

tion in September for a possi-

ble wind project off the coast of

Virginia. Areas offshore Mary-

land, New Jersey and Massa-

chusetts have also been sited as possible

locations for future wind developments.

PensionDanmark announced in June

it will be funding $200 million in capi-

tal for the planned Cape Wind project

expected to include up to 130 Siemens

turbines of 3.6 MW each. If completed,

the project off the coast of Massachu-

setts’ Cape Cod would become one of

the world’s largest offshore wind farms.

Asia will boost wind output

According to the GWEC, Asia will con-

tinue to boost its wind energy output an-

nually, reaching 25.5 GW by 2017. When

it comes to offshore wind energy, Japan

reached 25.3 MW last year. Meanwhile,

South Korea reached 5 MW of offshore

wind generation.

China holds the third spot for most

offshore wind capacity, with 258.4 MW

installed. China is also home to the frst

commercial offshore wind project outside

Europe. The Shanghai Donghai Bridge

project was installed in 2010 and totals

102 MW. China hopes to have 5 GW

of offshore wind by 2015 and 30 GW by

2030, according to the GWEC.

Cheaper costs will drive demand

A major challenge for expanding off-

shore wind development is the current

high costs of the technology. Deep wa-

ters far offshore, higher waves and steeper

construction costs can make these proj-

ects somewhat cost prohibitive. Howev-

er, like other renewable energy sources

being developed around the globe, off-

shore wind technology is steadily improv-

ing to boost its overall return on invest-

ment. Investment remains strong across

the broader wind power industry with

2012 marking several milestones. It ap-

pears with continued cost reductions and

the growing push towards renewable re-

sources, offshore wind is positioned to be

a key player in meeting global energy de-

mand through the next decade. ⊗

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EnergyWorkforce | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | Summer 2013 5

Frozen Assets

Despite immense challenges, the Arctic can’t

keep away exploration and drilling.

By Hilton Price

WHEN U.S. arctic waters saw

a drillship for the frst time

in 2 decades, it seemed the

return to a bygone era of exploration

had begun. Although Shell was ready

to usher in a new age for exploration

in those icy waters, process hurdles,

equipment issues, and natural obstacles

left the company’s dream unrealized.

Immediately after, as word of techni-

cal violations added insult to injury, it

seemed potential reservoirs in U.S. arc-

tic waters would remain unexplored for

at least a little while longer.

The frigid waters of the arctic present

one of the greatest challenges for any ex-

ploration company. These natural hin-

drances, combined with ongoing legis-

lation from the countries that lay claim

to those waters, make it a massive un-

dertaking. Shell lost billions in its failed

2012 campaign, and as the season end-

ed the company announced it would not

attempt a return in 2013.

However public Shell’s struggle in

the region may be, it is only a set-back.

2014 looms, and there is still no word

whether Shell will attempt a return to

the Arctic, but it is looking likely.

Shell is planning specialized surveys

of the area, using ships deployed to ar-

eas in the Chukchi and Beaufort seas.

This kind of data collection will be in-

valuable to potential future exploration

campaigns, and could save Shell in both

cost and risk if it chooses to return.

The same success Shell is hoping for

in U.S. arctic waters is being realized by

other companies in other areas of the

tumultuous region.Offshore Norway is

proving successful for numerous compa-

nies exploring the area. In the UK, three

of the country’s “Big 6” energy compa-

nies are planning Arctic drilling. E.On,

Centrica, and RWE Npower are all ex-

pressing interest in the region.

Likewise, there is a growing interest

offshore Russia, where legislation is loos-

er than the U.S. and reservoir potential

just as high. Shell has turned its atten-

tion to this area. If the company is suc-

cessful there, it could affect U.S. arctic

drilling policy, and possibly open the re-

gion further in the future.

In the U.S., however, there is an-

other element that could swing the

pendulum the other way, and close

off the country to further arctic ex-

ploration. The U.S. shale exploration

boom is changing the global energy

landscape. The country is expected to

become a major exporter in the com-

ing decades, and successful produc-

tion of these unconventional resources

could affect the interest in traditional

exploration. It could end the return to

the U.S. arctic before it truly begins.

There is a growing call for environ-

mental stewardship, the same kind that

brought an end to U.S. arctic drilling

decades ago. That concern for our natu-

ral environments isn’t likely to fade. Any

company heading to the area must show

respect for the land, and for those who

fght for it, or risk an evaporation of sup-

port for its work in the region.

Arctic drilling is hardly over. In ar-

eas offshore Norway, it thrives as much

as ever. In U.S. arctic waters, the pro-

cess may be stalled, but across the

sea in Russia’s arctic waters, oppor-

tunities are increasing. Success there

could further push exploration inter-

est here, and possibly overcome the

fnancial and legal hurdles that stand

in the way.

Meanwhile, success with shale oil

and gas could turn U.S. interests away

from the arctic, and back on land. But

that isn’t stopping companies from re-

viewing the region, and critically an-

alyzing collected data. For an area of

the Earth where even basic exploration

means a multi-billion dollar campaign,

every move matters and every decision

is crucial. ⊗

1308pejew_5 5 8/20/13 2:57 PM

6 Summer 2013 | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | EnergyWorkforce

INDUSTRY Insights

Offshore Energy: Mitigating Risk

By offering an integrated offshore support package, variant

forms of risk can be avoided, according to Viking SeaTech

Survey’s General Manager Matthew Gordon.

By Matthew Gordon

POST-MACONDO, there has been

an increased focus on the miti-

gation of risk. The industry has

reviewed operational practices from top

to bottom. Everyone from the

operators to offshore specialists

has been affected by the major

incident. 

As a result, there has been an

increase in the contractual tug

of war between operators and

contractors in relation to the ac-

ceptance of risk and liabilities.

This has led to lengthy nego-

tiations as legal teams look to

reach middle ground, resulting

in increased administration,

time and cost.

It could be said that offering

an integrated and streamlined service re-

duces administration, costly contract ne-

gotiation and indemnities. Expanding in-

house services could not only hold the

key to unlocking cost savings, but also

to reducing risk in a risk wary industry.

Bringing new thinking to an old problem

Offshore service businesses are reinforc-

ing their position in the marketplace

by providing a fully integrated package.

Previously, smaller companies offered

a niche service that was considered sat-

isfactory twenty years ago. But as the

large corporations’ priorities adapt in

line with supply and demand, support

companies have risen to the task.

Viking SeaTech has looked at how

a new business stream can be injected

into a maturing and heavily saturated in-

dustry, in order to meet the changing re-

quirements of their clients.

By offering more services under a sin-

gle contract, including survey services,

we can provide a convenient package that

offers all the benefts, minus the opera-

tional burden.  Our integrated approach

supports our efforts to make rig-moving

safer, faster, cheaper and eas-

ier to execute. 

Reducing the

operational burden

Contract negotiations can

be time consuming; la-

bor intensive, costly and

can often impact project

scheduling. This is multi-

plied by having several con-

tracts to set up and manage

simultaneously.

An integrated approach

works towards removing

these barriers. It is highly advantageous

to the client to have a single contract in

place for service provision. This equates

to a single point of contact, invoice and

company-specifc set of terms and condi-

tions to manage.

The benefts of such a contracting ap-

proach are realized when an issue arises.

Instead of managing multiple contactors,

it takes one call to a single organization to

1308pejew_6 6 8/20/13 2:57 PM

EnergyWorkforce | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | Summer 2013 7

Matthew Gordon joined Viking SeaTech in November 2012 as General Manager, Viking SeaTech Survey. His role is to oversee the development of the newly created Survey division.  He is responsible for initial recruitment, project management and contracting, proft and loss.  Matthew joined the company from Subsea 7, where he was a Client Account Manager overseeing sales for the UK, Ireland and the Netherlands.  Previously, he was in a general management position with VERIPOS and a project engineer with Fugro.  He specializes in hydrographic survey positioning, project management, ROV and TDU operations, business development and personnel development. Matthew has an MSc in Management Studies from The Robert Gordon University and a BSc in Electronic Engineering from Glasgow Caledonian University.

remove the issue. If a single contractor is

working towards a shared goal, the time

taken to resolve the issues is also reduced. 

The rig moving food chain

Operational effciency is improved when

operators use the integrated approach,

and also removes the need for multiple

contractors. By having numerous disci-

plines working together in-house, com-

munication is strengthened and it is en-

tirely realistic to suggest that the risk to

client operations is reduced.

From a quality assurance perspective,

Viking SeaTech Survey is involved at ev-

ery stage of the life cycle, from design

to evaluation and through working with

other disciplines. This process identifes

errors that may not be uncovered until

much later in the job, resulting in proj-

ect delays and increased cost.

Eradicating the blame culture

Contractor confict can trouble clients.

We have found that the greatest issue for

our clients is managing multiple contrac-

tors, especially when they are in confict,

as this can often lead to spending vast

amounts of time acting as arbitrator.

This is understandably irksome and

often it is the client who pays for this in

the form of lost time and additional costs.

An Integrated service approach can re-

move much of the operational burden

and the single contractor can resolve

problems on the client’s behalf. This

approach allows the client to spend their

valuable time working on other things,

while we deal with the issue at hand. This

is becoming even more important as or-

ganizations become fatter and individ-

uals within those companies have more

responsibility, meaning that time is a pre-

cious commodity.

Bespoke options

Large frms have the option of using

the offshore support specialist for their

rig moving operations expertise. It may

seem obvious, but advising clients at the

earliest point in the process is fundamen-

tal to the success of the job at hand. Step-

ping in at the initial engineering and de-

sign stages makes things easier later in

the job. Once these specifcations have

been approved by the client, a list of ma-

rine procedures can be made. This step-

by-step guide advises as to how the boats

and personnel will move the rig from

start to fnish. 

Our potential clients may have fve

or six different options from multi-

ple contractors. To make the decision

easier, we tailor the options to ft the

client exactly. By offering multiple ser-

vices, operational burden is lifted and

risk is less likely. The more links in the

operational chain, the more things that

can go wrong. We are trying to bring it

down to just two links, us and the client.

Furthermore, uniform policies and pro-

cedures lead to a safer operation. A unit-

ed quality system that clearly informs all

personnel of operational methods will

drive a safer practice.

Looking to the future

The integrated service model brings end-

less possibilities. Removing the burden

for the operator is not only advantageous

in terms of costs, time and schedule, but

it can remove the incidence of risk within

an operation. Risk comes in many forms,

but can be reduced by using a stream-

lined business with one goal, the swift,

safe, coordinated and accurate comple-

tion of a contract. 

I foresee integrated services becom-

ing more common place as the indus-

try continues to adapt. The often long

and drawn out processes attached to

drawing up contracts between opera-

tors and contractors, and subsequent

legal associations, has proved costly in

the past. Integration will become the

norm once the industry realizes this

effcient business prototype is one to

be utilized. ⊗

Risk comes in many forms, but can be reduced by using

a streamlined business with one goal, the swift, safe,

coordinated and accurate completion of a contract.

1308pejew_7 7 8/20/13 2:57 PM

CAREER Insights

8 Summer 2013 | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | EnergyWorkforce

Regulatory Experts Career Opportunities Galore

Evolving regulatory systems in the petroleum industry

provides an emerging career path

By Volker Rathman, Collarini Energy Staffng

WITH the drilling moratorium

lifted, the oil and gas indus-

try is trying to fgure out how

to deal with the onslaught of new regu-

lations. The effects on the job markets

have already been felt: Thousands of

jobs in the offshore industry were tem-

porarily lost after the moratorium was

put in place in the wake of the Macondo

incident.

We say “temporarily,” since over time

many of these jobs will come back. This

is in no way belittling the effect the loss of

jobs has had on those involved and their

families. It is stating a belief that our in-

dustry is resilient and will come back –

stronger and better.

Well over 80 percent of this country’s

energy comes from hydrocarbons. No

number of alternative or renewable energy

sources will change that percentage quick-

ly. Oil and gas are here to stay; and, frank-

ly, the country needs us to produce hydro-

carbons for them, even if the importance

is not always realized by many Americans

outside of our industry.

So our take on the future job market

is positive. Regulations about to be dealt

with by the industry will have an increas-

ing effect on job creation, since many

1308pejew_8 8 8/20/13 2:57 PM

EnergyWorkforce | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | Summer 2013 9

more people will be needed to under-

stand what the new rules mean and to

develop the best practices to implement

them. Regulatory experts and analysts

may apply here!

The role of the regulatory analyst has

expanded in all sectors of the oil and gas

industry as a result of proposed, new and

revised legislation.

• A regulatory analyst’s position may in-

clude such responsibilities as:

• Preparing and submitting permitting

requests for all new operations activi-

ty and any revisions to prior approvals

• Monitoring and reporting gas and oil

production and inventory for compa-

ny-operated wells

• Managing and updating regulatory in-

formation and forms

• Interfacing with local, state and feder-

al regulatory agencies

An experienced analyst will have pri-

or regulatory permitting and reporting

experience for full cycle development

planning, drilling completion, workover

operations, and feld abandonment. The

role also requires knowledge of permitting

specifc to the governing agency and geo-

graphic area.

Additionally with conventional on-

shore drilling, the process of shale ex-

traction is regulated under a number of

laws, most notably at the federal level,

the Environmental Protection Agen-

cy, The Clean Water Act, The Safe

Drinking Water Act, and The Nation-

al Environmental Policy Act. While

the federal agencies administer a gen-

eral “one-size-fts-all” set of guidelines,

the regulatory bodies at the state and

local levels may be distinctly different

due to geographic location, hydrology,

population density, wildlife, climate

and local economics.

This stew of agencies and rules cre-

ates career opportunities for experts in

each area and for generalists keeping an

eye on the big picture and the interface

among all parties.

Experts in this feld will be needed in

the permitting processes. This will create

employment opportunities particularly in

the context of:

• Greenhouse gas and air emissions

• Noise pollution

• Erosion and sediment control and

• Environmental threats to endangered

and threatened species

We do not know how the regulatory

scene will play out. We are certain, how-

ever, that regulatory compliance needs

will not decrease; this could create a boon

for those professionals seeking a switch

in their careers.

Tis fast-growing sector of the indus-

try holds promise to any regulatory pro-

fessional due to the diversity of agency

interface, geographic variety and environ-

mental concerns. As industry technolog-

ical developments and practices improve

and legislative requirements continue to

evolve, so will the unique opportunities

in these regulatory roles. ⊗

Volker Rathmann is the President of Collarini Energy Staffng Inc. Prior to joining the frm

in 2001, he held the position of Chief Financial Offcer for INTEC Engineering, a provider

of specialized engineering services in global frontier and deepwater projects. Before INTEC

Engineering, Volker held a number of leading positions in operations, marketing and fnance

within the Daimler AG. Volker earned a Bachelor’s degree in business administration in

Berlin, Germany.

The role of the regulator y analyst has expanded

in all sectors of the oil and gas industr y as a

result of proposed, new and revised legislation.

1308pejew_9 9 8/20/13 2:57 PM

10 Summer 2013 | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | EnergyWorkforce

Empowering our Troops: AEP Career Initiatives for Veterans

HEADQUARTERED in Colum-

bus, Ohio, American Electric

Power (AEP) is one of the

largest electric utilities in the United

States, delivering electricity to more

than 5.3 million customers in 11 states.

AEP has a long history of community

engagement and has established itself

as one of the top employers for military

men and women.

As a leading utility, AEP partners

with veterans’ organizations and job pro-

grams, provides special benefts to vet-

eran employees, and supports veteran

employees and their families through

mentoring and recognition programs.

Recently, PennEnergy was invited to

learn more about AEP’s veterans’ ini-

tiatives and given the opportunity to

engage Scott Smith, AEP Senior Vice

President for Transmission Strategy and

Business Operations.

A former U.S. Army captain and com-

bat engineer, Smith serves as an execu-

tive sponsor for AEP’s Military Veteran

employee resource group. Smith collab-

orated with PennEnergy content direc-

tor, Dorothy Davis, to offer greater in-

sight into AEP’s veterans’ initiatives and

how they beneft our military heroes,

the energy industry, and the communi-

ties they serve.

PennEnergy (PE): What percentage of

AEP’s current workforce is represented

by veterans?

Scott Smith (Smith): Veterans com-

pose 10 percent of AEP’s workforce, with

1,770 military veterans working through-

out our 11-state service territory.

PE: When did AEP’s veteran outreach

initiatives begin and what prompted

them?

Smith: Though AEP has a long his-

tory of supporting military veterans, it

became even more pertinent in recent

years as we increasingly realized that the

skills military veterans could bring to the

workplace closely match the skills we are

seeking for new employees. Many vet-

erans have the job-related training we

need to operate equipment and to per-

form other technical functions, along

with the personal attributes we value,

including leadership skills, f lexibili-

ty, adaptability, dedication and team-

work. We also have recognized the

signifcance of building a skilled work-

force pipeline that will help us meet the

future needs of our ever-evolving indus-

try. With this in mind, we have placed

increasing attention on our military re-

cruiting efforts as well as on our compa-

ny pay and benefts policies that support

Reservists and National Guard members

who are called into active duty.

PE: What programs does AEP have

in place for helping to recruit and

transition veterans into civilian ener-

gy careers?

Smith: At AEP, we have taken a

number of approaches to target the vet-

eran community and transition them

to successful careers at AEP. For exam-

ple, instead of fltering through thou-

sands of resumes, which can be time

consuming, we work with veterans’ or-

ganizations and national and state jobs

programs to locate veterans who have

the skill sets that match utility jobs.

This spring, AEP hosted an open

house at the AEP Transmission train-

ing facility near Columbus, Ohio, for

an up-close and personal view of the

daily activities of linemen, station tech-

nicians, protection and control elec-

tricians and other jobs. The event,

co-sponsored with veterans groups,

TRAINING Insights

1308pejew_10 10 8/20/13 2:57 PM

EnergyWorkforce | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | Summer 2013 11

provided an orientation about the types

of careers available at AEP. Several AEP

military veterans served as mentors dur-

ing the event. AEP seeks out veterans at

traditional recruiting events, too. For ex-

ample, we participate in Hire Our He-

roes, a U.S. Chamber of Commerce-

sponsored job fair.

In addition, AEP is one of a handful of

utilities that directs ex-military job appli-

cants to an online “military occupational

specialty” decoder that translates military

skills, capabilities and training into civil-

ian terms. The decoder helps veterans

recognize the meaning and value that

their military skills and training have in

the civilian workforce.

PE: What impact has AEP’s veteran

program had on the company and its

service communities?

Smith: For 10 consecutive years, AEP

has been ranked among the top “mili-

tary friendly” employers in the country

by GI Jobs Magazine. Our program has

not only increased the number of veter-

ans in our ranks, but it has helped veter-

ans transition successfully through men-

toring and company support.

I serve as an executive sponsor for

our Military Veteran employee resource

group, which was launched on Veterans’

Day in 2012. The group not only men-

tors newcomers, but it also supports em-

ployees by assisting their families while

the employees are away on active duty.

The resource group partners with veter-

ans groups and sponsors events to honor

veterans throughout AEP’s 11-state ser-

vice territory. Ultimately, we want to show

our employees and our service commu-

nities that we value the service of veter-

ans who have fought to protect our free-

doms and want to help them secure the

economic prosperity, ongoing support,

and respect they deserve.

PE: How does AEP envision the role

of veterans in evolving energy industry?

Smith: When we look at the veter-

an community, we see a skilled, disci-

plined workforce that can help our in-

dustry succeed as we begin a period of

rapid infrastructure modernization and

expansion. Nationwide, utilities will

need to replace an estimated 200,000

skilled Baby Boomers expected to retire

in the next fve years – a third of the ener-

gy workforce. At the same time, utilities

across the U.S. are expected to invest $50

billion to modernize electric transmis-

sion infrastructure through 2020. This

estimate could surpass $100 billion if

additional investments are made to en-

hance communications and cyber secu-

rity capabilities.

Through 2020, AEP alone plans to

spend billions to build around 480 new or

enhanced transmission substations and

roughly 1,800 miles of new transmission

lines. We plan to rebuild another 3,900

miles of transmission lines between 2013

and 2015. We also are focused on prepar-

ing ourselves for success in a competi-

tive transmission business environment,

which will require us to move quickly and

fnish projects on time and on budget.

As a result, targeting military veter-

ans who are transitioning to civilian ca-

reers makes sense since their capabilities

match the qualities necessary for us to

succeed in a rapidly growing, competi-

tive transmission landscape.

PE: What is ahead for AEP’s veteran

initiatives?

Smith: As we seek to recruit more

veterans into our ranks, we have looked

at how we can best support this popu-

lation of employees, particularly those

who continue to serve. AEP recently an-

nounced it will make up the difference

between an employee’s military pay and

his or her AEP base wage when the em-

ployee is off work for required training.

Additionally, we are supporting indus-

try-wide efforts to leverage the talents of

the veteran community. AEP helped es-

tablish the Troops to Energy Jobs pro-

gram, a product of the Center for En-

ergy Workforce Development. The

Center recently published a 54-page na-

tional model to help energy companies

develop a comprehensive program for

military outreach, education, recruit-

ing and retention. Through such col-

laborative efforts, we are determined to

help more veterans by providing a road-

map to civilian employment in the en-

ergy industry. In turn, we are ensuring

that we have the skilled workforce need-

ed to continue generating and deliver-

ing the reliable electricity that is essen-

tial to American homes, businesses and

national security. ⊗

“When we look at the veteran communit y,

we see a skilled, disciplined workforce...”

To learn more visit: AEP – A Military Friendly Employer

For career resources in the power and petroleum sectors visit: PennEnergyJobs.com

1308pejew_11 11 8/20/13 2:57 PM

12 Summer 2013 | FOR JOB OPPORTUNITIES, VISIT www.PennEnergyJOBS.com | EnergyWorkforce

Energy 101: Wave & Tidal EnergyPennEnergy.com

WAVE and tidal energy is

a predictable form of re-

newable energy that uses

the power and movement of wave

and tidal fows to generate electric-

ity. With the use of underwater tidal

turbines, energy from the sea is cap-

tured to create a non-polluting form

of electricity. 

A dam approach with hydraulic

turbines is the most modern tech-

nology being used across the world

to harness  tidal power. Tidal dams

are most effective in bays with nar-

row openings. Gates and turbines are

installed at certain points along the

dam, and when an adequate differ-

ence in water elevation on the dif-

ferent sides of the barrage occurs,

the gates open, creating a “hydrostatic

head,” the Ocean Energy Council re-

ported. During this process, water fows

through the turbines to create electric-

ity. The technology used at tidal ener-

gy facilities is similar to that used at

traditional hydroelectric p ower plants.

Wave and tidal power is one of the

oldest forms of energy used by humans,

with tide mills used by the Spanish,

French and British as early as 787 A.D.

It’s estimated the world’s potential for

ocean tidal power is 64,000 megawatts

electric, the OEC reported. However,

tidal power has a low capacity, usually in

the range of 20 to 30 percent. The tech-

nology for tidal energy is also expensive,

though powerful. It is estimated that if

a barrage was placed across a high-tid-

al area of the Severn River in western

England, it could provide 10 percent of

the country’s electricity needs, accord-

ing to the OEC.

Growing popularity

Tidal and wave energy technology is ad-

vancing rapidly as more countries are

beginning to realize the renewable en-

ergy’s benefts.

In the United States alone, there are

about 2,110 terrawatt-hours of wave en-

ergy being generated each year. Yet, ac-

cording to the Renewable Northwest

Project, this is just 25 percent of how

much the U.S. could be generating on

its coasts from tidal power.

Using special buoys, turbines or

other means, the country is captur-

ing the power in waves and tides from

the ocean - power that can be more

predictable than wind. Because tidal

energy reacts to the gravitational pull

of the moon and sun, experts can pre-

dict their arrival centuries in advance.

Oregon and Washington experience

the strongest waves in the lower 48

states. In Washington’s Puget Sound,

the U.S. could develop wave and tidal

technology that could capture sever-

al hundred megawatts of tidal power.

The U.S. Department of Energy

also recently unveiled a foating off-

shore wind platform that uses under-

water turbines to capture tidal energy

and create electricity, Forbes report-

ed. Another wave project that includes

10 buoys is being tested off the coast of

Oregon. It is expected to generate 1.5

MW. U.S. regulators see projects like

this as a smart and valuable solution to

diversify the country’s energy mix with

greener technologies. These regulators

also see wave and tidal power as more

predictable than wind and solar.

The United Kingdom also sees tidal

power as a viable alternative to fossil fuel

power. The U.K. is seen as a world lead-

er in wave and tidal stream technologies

due to its abundance of marine energy

resource. It is estimated that tidal tech-

nologies could generate up to 300 MW

of power by 2020. However, overall po-

tential is between 25 and 30 gigawatts. ⊗

1308pejew_12 12 8/20/13 2:58 PM

Actionable data for the Power industry:

Make your next step your BEST step.

Power Generation

Renewable Energy

Transmission & Distribution

Smart Grid

...and much more

www.PennEnergyResearch.com

DIRECTORIES SURVEYS FORECASTS INDUSTRY ANALYSISSTATISTICAL TABLES CUSTOM RESEARCH

1308pejew_C3 3 8/20/13 2:58 PM

We’ve got people.

PennEnergy JOBS is the key to attracting the

energy industry professionals you need to hire to

meet your business goals. Our process puts your

recruitment message in front of the industry’s best

talent whether it’s online, in print, or at an event.

This approach offers you the f exibility to create

custom recruitment advertising campaigns best

suited to meet your budget and objectives.

| Learn More |

Visit: www.PennEnergyJOBS.com

Call: 1-800-738-0134

Got jobs?

1308pejew_C4 4 8/20/13 2:58 PM