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2/538 Engineered Systems June 2010
Cogeneration can be employed anywhere there is
a simultaneous need for electrical and thermal
energy, and it is often referred to as combined heat
and power (CHP). CHP is any number of applied
technologies that simultaneously produces two or
more forms of energy from a single fuel source.
Prior to the development of the electrical distribution grid, indus-trial concerns generated their power on-site and developed cogeneration
techniques and applications to utilize the resulting waste heat. As the util-
ity industry grew and took hold, their economies of scale and reliability
eventually made on-site generation of electricity uneconomical in many
cases and thereby significantly reduced the prevalence of cogenerated
power. But in 1978, the Public Utilities Regulatory Policy Act (PURPA)
required public utilities to purchase a portion of their electric generating
capacity from non-utility generators that use alternative energy sources
and cogeneration in order to reduce dependence on foreign oil.
In the 80s, lower natural gas rates allowed the economical produc-
tion of on-site power and helped to spur cogeneration projects. Growth
in this sector was then stalled due to higher gas prices. The recession
has kept gas prices depressed and discoveries in Texas Barnett shale
and Pennsylvanias Marcellus shale may keep these prices low. Present
concerns about global warming and the long-term availability of fossil
fuels have created an environment where re-exploring the application
of cogeneration makes good sense, since this process can result in less
fossil fuel consumption and fewer emissions than generating electrical
power and heat through separate processes.
CHP SYSTEMS
Most CHP systems use a topping cycle, in which the fuel source is
first used for generating electricity and then to recover the resultant
heat for thermal needs, such as space and domestic water heating
and cooling and the regeneration of desiccants used for dehu-
midification. A bottoming cycle uses fuel to drive industrial thermal
processes, with the exhaust gases then being used to produce power,
typically with a heat recovery steam generator in series with a steam
turbine. The topping cycle can use a variety of prime movers, such
as reciprocating engines, steam turbines, gas turbines, microtur-
bines, and fuel cells to generate electrical power.
A common prime mover for CHP applications is the recipro-
cating engine, which has high mechanical efficiency over a wide
BY CARL C. SCHULTZ, P.E., LEED AP
Hospitals, hospitality, municipalities, and industrial applications may face their best chance in years to
save money (and natural resources) with a combined heat and power (CHP) system. From steam turbines
that rely on boilers to gas turbines, on to reciprocating engines and fuel cells, the variety of options is aswide as the range of settings where it might make sense. Reacquaint yourself with CHP, including the
sidebars small example that can save over $100,000 per year.
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Closing The Cogeneration Gap
range of loading. By adding a turbocharger, the capacity of an
engine can be increased by 30 to 40%. Four-stroke engines operat-
ing at 1,800 rpm are a typical configuration. Engines can be run
on natural gas, diesel, or heavy (residual) fuel oils. In addition
to the electrical power produced, thermal
energy can be recovered from radiation off
the engine block, exhaust gases, lubricating
oil, jacket water, and the engine after-cooler.
Jacket heat can be recovered either as hot
water or as low-pressure steam, either underpressure in a forced circulation system or an
ebullient (boiling water) system.
The gas or combustion turbine consists
of a compressor that takes air at atmospheric
pressure and increases its pressure for entry
into the combustor where it is combined with
fuel and burned. The exhaust gases in the
neighborhood of 2,300F are then delivered
to the turbine, where they are converted to
mechanical work. Up to 50% of the turbine
power can be used to drive the compressor,
so strategies to cool the inlet air and increase
overall efficiencies are often implemented.The turbine exhaust temperatures are typi-
cally less than half that of the temperature
entering the turbine and can be used in a heat
recovery steam generator (HRSG) to produce
steam for heating, or they can be used directly for a process that
includes a direct-fired absorption chiller. Microturbines operate on
the same principal as gas turbines but have the advantage of being
small and lightweight, therefore offering installation flexibility.
The steam turbine is the workhorse of the utility power indus-
try and can be used on a smaller scale for CHP applications. Fuel
is burned in a boiler to generate high-pressure steam, where it is
sent to a steam turbine to generate electrical power. Before return-
ing to the boiler, the turbine exhaust must be condensed, and thiscan be done by using the heat to drive thermal processes instead
of being rejected to a heat sink such as a river or cooling tower. A
steam turbine can also be used in combination with a combustion
turbine in what is known as a combined cycle, where the output
from the HRSG is used to drive the steam turbine for additional
electric power production. Unlike the combustion turbine, which
can be dispatched quickly, the steam turbine system may take sev-
eral hours for warm-up.
Fuel cells produce electric power without combustion by a direct
conversion of the fuel into electricity typically by stripping the hydro-
gen from natural gas, propane, or butane and combining it with
oxygen in air. The byproducts include water, direct-current electricity,
heat, and low levels of CO, CO2, and NOx. Electrolyte filled cells areplaced in series to produce the voltage potential and are arranged in
parallel to develop amperage capacity. An inverter is used to convert
the direct current power to alternating current power. Although the
quantity of waste heat is limited since much of it is used in the conver-
sion process, the usable temperature can be high and can develop hot
water as well as low- and high-pressure steam. Although it is viewed
as an emerging technology, a fuel cells low noise level is an advantage
compared to other types of CHP systems.
APPLICATIONS
A base-loaded system will operate so that the prime mover is generat-
ing at full capacity nearly year-round only being stopped for annual
maintenance. At times when the rejected heat cannot be fully utilized,it will be dumped to the environment. CHP prime movers can also be
FIGURE 1. Diagram of a small congeneration system with a reciprocating prime mover.
500KW RECIPROCATING
GENERATOR500KW
ELECTRICITY
NATURAL GAS
5.3 MMBTUH
5,300 FT /HR
EXHAUST
LUBE OIL
HEAT EXCHANGER
JACKET WATER
HEAT EXCHANGER
EXHAUST GAS
HEAT EXCHANGER
RETURNLP STEAM
2,700 PPH
Input 125 at www.esmagazine.com/instantproductinfo
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4/542 Engineered Systems June 2010
operated to track either the electrical load
or thermal load requirements of the site, or
they can be used in a limited capacity in a
peak-shaving operation. For facilities that
have negotiated interruptible rates or are
located in areas where the utility has insti-
tuted real-time pricing for electricity, theCHP system can be operated in an economic
dispatch mode to produce power when it is
less to do so that purchasing the power from
the utility.
Since CHP systems use a single fuel
input to provide electrical power and ther-
mal energy, having a simultaneous need for
both is a prerequisite for implementation.
Leading examples of industrial applications
include chemical, pulp and paper, textile,
and ethanol production. The hospitality
industry, where large hotels, resorts, and
casinos have on-site laundry, shower, andother thermally intense needs, can find a
CHP system to be an attractive proposi-
tion. Corporate research campuses offer
opportunities when there is a steam distri-
bution system that requires thermal input
year-round.
Hospitals and other types of critical
facilities can obtain the added benefit of a
redundant power supply. Health care and
higher education campuses have led the way
with smaller CHP plants, but municipalities
have gotten into the act with installations at
airports and with municipal district heating
and cooling systems. The thermal energy
developed through cogeneration can be used
during the cooling season to operate steam
turbine-driven chillers and absorption chill-
ers as well as for the regeneration process
involved with desiccant dehumidifiers.
Municipalities have tied CHP opera-tions with their waste programs by utiliz-
ing digester and landfill gas, trash, and
other urban wastes. District Energy St.
Paul operates the largest wood chip power
plant in the United States. This combined
heat and power plant heats 185 buildings
and 300 single family homes (31.1 million
sq ft), cools more than 95 buildings (18.8
million sq ft) as well as generates 25 MW
of electricity. The plant uses 280,000 tons
of wood waste/yr per year from the citys
recycling center, which is supplemented by
natural gas, oil, and coal. Military installa-tions account for CHP applications, includ-
ing remote facilities such as radar sites in
Alaska. In this application cogeneration is
the obvious choice as there is no grid to tie
into and there is a need for simultaneous
thermal and electrical production.
ECONOMICS
The average coal-fired power plant in the
U.S. operates at an efficiency of about 32%,
which is primarily due to the 40% efficiency
of the typical steam turbine in converting
mechanical power to electrical power. Con-
Closing The Cogeneration Gap
Input 124 at www.esmagazine.com/instantproductinfo
Cogeneration Economics: An Example A research campus has minimum low-pressure steam consumption of 2,700 lb/hr in the summer at night just to offset losses in the distribution system and has
decided to install a CHP plant using a 500-kW natural gas reciprocating generatorin a base loaded configuration, which will operate 8,600 hrs/yr. The facility has anaverage purchased-power cost of $0.07/kWh and a gas cost of $5/MMBtuh. Theplant assumptions are an electrical conversion efficiency of 32% and a heat recoveryeffectiveness of 70%, for an overall efficiency of roughly 80%.
The plant will consume 46,000 MMBtuh of natural gas annually x $5 = $230,000/yr The plant will produce 8,600 hr/yr x 500 kWh = 4,300,000 kWh for an avoided cost
of 4,300,000 kWh x $0.07/kWh = $301,000 Annual maintenance is assumed at $0.01/kWh production or $43,000 The annual heat recovery is estimated at 22,500 MMBtuh, which would require a
boiler input of 27,500 MMBtuh assuming an 80% efficient boiler, for an avoidedcost of 27,500 MMBtuh x $5 = $137,500/yr
Total electric and gas avoided cost is $301,000 + $137,500 = $438,500.
The avoided cost of $438,500 minus the gas consumption of $230,000 yields a$208,500 annual utility cost savings. Subtracting out the $43,000 maintenance costresults in a $165,500 net annual savings.
At an installed cost of $1,100 per kWh or $550,000, the CHP plant has a simplepayback of $550,000/$165,500 = 3.3 years.
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sequently, two-thirds of the prime energy
input is wasted as heat to the atmosphere.
Because of this, CHP systems can be viable
in applications where there is a large and
continuous demand for thermal energy in
close proximity to the cogeneration plant.To be economical, this thermal load should
be year-round and not just seasonal in nature.
CHP systems obtain most of their econom-
ic benefit from the production of electrical
power where large installations may sell excess
power to the electric utility, while smaller
systems will typically use the power on-site to
offset purchased power from the grid. CHP
economics fare better where they have a high
generating efficiency, so a microturbine-based
system with a 24% efficiency may not be as
attractive as one with a reciprocating engine
with a 36% efficiency.An example of a small CHP application
is shown in the sidebar, using a gas recipro-
cating engine that has an electric efficiency
of 32% that coincidently matches the U.S.
average of coal-fired plants.
CONCLUSION
The ultimate appeal of the concept of cogen-
eration depends on ones vantage point, with
technicians marveling at its sheer efficiency,
the environmentally minded at its promise
for the economical use of the Earths remain-
ing fossil fuels, and with the plant managerlooking to reduce operational costs.
Most of us should by now have the sense
that the cost of fossil fuels will rise over time
in one of three possible scenarios: 1) slowly,
as technological advances in exploration and
discovery help offset increases in consump-
tion; 2) rapidly, as we emerge from economic
recession or are faced with carbon caps or
taxes; or 3) catastrophically, as we head off a
production cliff. Whatever your profession,
political tendencies, or social disposition,
you should applaud advances in the devel-
opment of cogeneration technologies, sincethey will help slow the use of finite resources,
reduce pollution, and help us compete in a
competitive global economy. ES
Schultz is a vice president with Advanced
Engineering Consultants in its Columbus,
Ohio office. He is a graduate of the Ohio State
University with a BSME and has 20 years of
experience designing mechanical systems for
commercial and institutional facilities. In addi-
tion, he has extensive design experience with
central steam, high temperature hot water,
and chilled water plants. He is a registered
professional engineer in over a dozen states
and is the author of many technical articles
related to HVAC system design and commis-
sioning. Contact him at [email protected].
Founded in 1998, Advanced Engineering
Consultants (AEC) provides a wide varietyof mechanical and electrical engineering ser-
vices to support the commercial, industrial,
and institutional facilities sectors. AEC is a
minority-owned firm
committed to offering
the latest in sustain-
able design practices.
For more information,
visit the companywebsite at www.aec-
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