Profitable EPA Boiler MACT Compliance at Eastman Business Park€¦ · Profitable EPA Boiler MACT...
Transcript of Profitable EPA Boiler MACT Compliance at Eastman Business Park€¦ · Profitable EPA Boiler MACT...
lRED | the new green
Profitable EPA Boiler MACT
Compliance at Eastman Business Park
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Thomas Casten, ChairmanRecycled Energy Development LLC
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Eastman Business Park
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Built by George Eastman in 1890, EBP has continuously operated, always with onsite steam/power generation.
EBP is the largest industrial complex east of Mississippi River.
EBP Utilities service 134 buildings / 17 million square feet of manufacturing operations on 1250-acre EBP campus in Rochester NY.
EBP assets include:
125 MW backpressure steam turbine generation
2.1 million lbs/hr coal, oil and gas fired steam generation
64,000 tons installed chilled water capacity
Chilled water, steam, electric and compressed air distribution infrastructure throughout EBP
EPB Utility Service District ~1252 Acres
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EPB Tenants/Owners
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Presentation summary
Presentation shares RED’s approach to profitably reducing greenhouse gas emissions by recycling normally wasted energy.
The presentation covers three areas, including:
Definitions and analytic metrics for CHP development
Application of these concepts to Eastman Business Park with resulting metrics.
Barriers to profitably reducing CO2 with best possible CHP
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Today’s EBP plant
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SteamBoilersCoal, some
oil and natural Gas
Steam Turbines
High Pressure
Steam
Chillers
EB
P E
nerg
y U
sers
Chilled Water
Steam
Electricity
Electricity purchases / salesexports
Low/MedPressure
Steam
Fuel
MP Steam
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MACT compliance option 1
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SteamBoilersCoal, Oil,
Natural Gas
Steam Turbines
High Pressure
Steam
Chillers
EB
P E
nerg
y U
sers
Chilled Water
Steam
Electricity purchases / salesexports
Low/MedPressure
Steam
Coal
MP Steam
/Electricity
Add $40-$50
MM controls
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Replacing controls with
efficiency
Analytic approaches to good CHP
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Measure fuel energy in lower heating value (LHV)
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Coal LHV is 99% of HHV, Oil LHV is 95% of HHV, while natural gas LHV is 91% of HHV. A dekatherm of natural gas, with 1000 Btus HHV only releases 910 Btus, (except with a special trick).
The trick; use condensing economizers with gas firing, extract some of the latent heat of vaporization.
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‘Byproduct power’
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‘Byproduct power’ is power generated by backpressure turbines that reduce steam pressure and temperature, before delivering the exhaust steam to site process and HVAC loads.
Backpressure steam turbines use about 3600 Btus per kWh, regardless of inlet and exhaust conditions.
This power is a byproduct of satisfying thermal demand by a ‘steam first’ CHP plant
By contrast, condensing turbines in electricity-only plants consume 10,000 to 13,000 Btus per kWh.
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Net Economic Heat Rate
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• ‘Net Economic Heat Rate’ is the net fuel credited to
electric generation divided by generated kWh.
• Take total fuel less the fuel conventional boilers
would have burned to produce the useful
thermal energy, then divide by the net kWh.
• Don’t be surprised if the ‘Net Economic Heat
Rate’ is lower than the 3,412 Btus of enthalpy /
kWh.
• Laws of physics remain intact! This is an
economic measure, which reflects the saved fuel
from generating steam with conventional boilers.
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Gas enables multiple cycles, increasing value capture
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• Solid fuel must be burned externally, in a Rankine cycle
that typically makes HP steam for a steam turbine.
• Gas (or liquid) can fuel gas turbines and piston engines
– a Brayton cycle – and then produce steam with hot
exhaust to power a second cycle.
• Best coal ~ 40% electric efficiency
• Best gas electric only CCGT ~ 50% efficiency
• Best CHP with CCGT >85% efficiency.
• Gas enables more value capture
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Supplementary Firing of GT Exhaust
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• GTs use four times the air required for combustion,
so GT exhaust has 16% free O2, which enables sup
firing.
• Sup firing avoids heating ambient air to exhaust
temperatures by burning pre-heated combustion air.
• Each Btu of sup fire produces 1.01 to 1.06 Btus of
steam energy, because sup firing lowers exhaust
temperature, thus recovering more of the energy in the
gas turbine’s exhaust.
• Sup firing can follow the site demand for steam, with
over 100% efficient conversion versus low part-load
efficiency of conventional boilers.
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Measure CO2 avoidance per unit of useful energy
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• Compare projected CO2 against the CO2 from conventional
separate generation of the same useful energy.
• The goal should be to produce goods and services with less
CO2,
• Environmental regulation of carbon that is based on
historic emissions ignores useful energy output and
blinds developers to optimal cycles.
• Regulating site total emissions of CO2 based on
historic emissions kills CHP, since it gives no credit for
the displaced grid CO2.
• PPM regulation is essentially an input standard –
pollution per Btu of fuel.
• The ideal regulation would tie allowed emissions to
output of useful energy services.
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MACT compliance with fuel switch
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New Gas-fired
SteamBoilers
,
Steam Turbines
High Pressure
Steam
Chillers
EB
P E
nerg
y U
sers
Chilled Water
Steam
Electricity
Electricity purchases / salesexports
Low/MedPressure
Steam
Coal
MP Steam
Switch to Gas
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MACT compliance with fuel switch and efficiency
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Steam Turbines
High Pressure
Steam
Chillers
EB
P E
nerg
y U
sers
Chilled Water
Steam
Electricity
Electricity purchases / exports
Low/MedPressure
Steam
Heat Recovery Boilers
Gas turbines with Heat recovery steam gen
Added elec. Gen.
<MP Steam
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Impact of various design options for MACT compliance at EBP
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The chart that follows depicts key variables per thousand MMMBtus of fuel,
We must also increase efficiency to pay the cost of added capital investment .
The biggest efficiency gain comes from BP turbine generators with effective heat rates of ~3,600 Btus/kWh versus 10,000 average for electric-only plants
Key metrics are per thousand MMBtus of consumed fuel.
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Key metrics per MMMBtu of fuel for EBP MACT Compliance options
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Values per
MMMBtus
Operating
margin
Avoided
CO2 tonnes
MWh Elec.
& shaft
power
Thermal
MMBtus
Econ. Heat
Rate
Coal, Boilers and
BP turbines
$1.08 5.6 707 4,297
Switch to gas $2.43 80.7 5.2 691 4,698
Gas, boilers and
BP turbines
$2.33 81 45.7 732 4,085
1 X GT/HRSG
train
$3.01 93.5 6.4 686 4,122
2 X 11MW SGT /
HRSG trains
$3.47 104 65.5 712 3,188
3 X 11 MW GT /
HRSG trains
$3.59 107 69.1 711 3,035
Observations on MACT compliance options for EBP
Best margin, net economic heat rate and avoided CO2 achieved with 2 gas turbines, 22 MW new capacity
However, gain versus one 11 MW GT does not provide risk-adjusted return on incremental capital without capacity sales
If NYISO allows CHP plants to sell capacity, two turbines support incremental capital
Switching to gas saves 85% of carbon, given existing CHP, but cuts margin per MMMBtu by25%
Coal fired margin per MMMBtu is ~ 1/3rd of 2 GT approach
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What is best MACT compliance option?
Answer depends on:
Whether project can capture value for added capacity,
Cost of capital given Kodak is dominant load, just out of bankruptcy
Likely load growth in EBP
Imposed pollution controls on new gas turbines
Carbon avoidance now trading at $5 to $7 per tonne, could be worth $4 to $5 million / year, but regulations do not count the avoided carbon dioxide, so no value capture
With value for carbon, optimal solution would be to install three 11 MW gas turbines.
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Barrriers to profitable CHP
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Subsidies of fossil, nuclear and renewable suppress prices and thus undervalue the efficiency of CHP.
Most ISO’s don’t allow CH{ plants to sell capacity and ancillary services, reducing potential revenue.
Environmental rules do not recognize efficiency as a pollution control strategy.
Environmental rules deny tradeoffs between emissions.
Although RED MACT compliance plan cuts NOx, PM and mercury by 95% to 99%, it slightly increases CO emissions
To obtain an air permit, we must install CO catalysts, with no discernible societal benefit.
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Outsourcing values and problems
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The complexities and capital requirements of optimized CHP cry out for outsourcing industrial utility services.
Good CHP is not a core competency of any industrial or other campus
Smart utility managers seldom persuade managers to invest above
minimum capital for reliable utility service, but good CHP takes capital
However, utility outsourcing scares management and the specialist CHP firm.
The industrial management fears loss of reliability – if the third party
does not make steam, the brewery cannot make beer
The third party returns depend on continued demand for utility services
from the industrial(s), which could drop for exogenous reasons.
Outsourcing cost of capital will likely exceed utility cost of capital, due to
the site risk and lack of diversity. Better for multiple tenant industrial
sites, but still problematic.
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Conclusions
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There are numerous ways to develop combined cycle CHP
plants to served industrial utility loads that profitably reduce
carbon emissions
Deploying those approaches requires a new vocabulary and
analytical approaches that are foreign to the electric-only
generating industry.
Numerous barriers tilt the playing field against CHP and in favor
of less efficient separate generation of heat and power.
Meanwhile, worldwide human activity adds 5 million tonnes of
CO2 equivalent greenhouse gas every 90 seconds.
We must join together to level the playing field and enable more
efficient CHP to profitably lower CO2 emissions.
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Thank You
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Thomas Casten, ChairmanRecycled Energy Development [email protected]