Keeping Ethanol Production Green

With over 70 ethanol plants under construction, there is a need for quality pollution control.

Originally published in the July 2007 issue of Pollution Engineering Magazine.

By Scott W. Golla, QEP, MBA, senior consultant for Malcolm Pirnie, and Richard Grzanka, BSME, MBA, regional vice president for Anguil Environmental Systems

Recent increases in ethanol production and trends in plant design

In an effort to reduce the world’s dependence on fossil fuels, there has been a major push towards alternatives. Ethanol has been at the forefront of this movement because it reduces greenhouse gas emissions from automobiles and its production has a positive net energy balance. The homegrown fuel also reduces the need for imported oil from sometimes unfriendly and unreliable supplier nations.

The Energy Policy Act of 2005 required the blending of 7.5 billion gallons per year of renewable fuels with gasoline by 2012. According to the Renewable Fuels Association, that threshold should be met sometime this summer, on a capacity basis. Ethanol plants are expanding and being developed at a significant rate in North America and throughout the world. There are currently over 70 ethanol production plants under construction in the United States alone. Washington is talking about a goal of 25 percent of our transportation fuel supply from renewable biofuels by 2025. This ethanol development has expanded to nearly all regions of the country; suffice it to say there is a boom going on the ethanol industry and it is expected to continue for some time.

There are currently over 70 ethanol production plants under construction in the United States alone.

Ethanol is produced by fermenting and distilling starch, creating a 200-proof alcohol suitable for combustion in a vehicle. When processing corn, only 70 percent of the kernel is made into ethanol; the remaining fats, proteins, fiber, oils and minerals are referred to as distiller’s grain (DG). If a production plant is not very proximate to dairy operations or other significant livestock feeding needs, it will have to dry the DG in order to prevent spoilage during transport to more distant regional markets. Operating restrictions, penalties and fines, as well as community pressures, are forcing many plants to strive for the lowest possible emission levels from their dryers, enabling future capacity expansions.

Since air permits are granted on a facility-wide basis, when developing, designing and permitting ethanol production facilities, selecting the most appropriate process equipment as well as air pollution control equipment is critical. Some unique DG dryer designs are steam-heated or compressed air-based, but the vast majority of installed dryers are heated with natural gas. Regardless of the dryer type, volatile organic compounds (VOCs), odors and aerosols are emitted from the drying activity. By far the most commonly installed technology for this critical emissions source is some form of efficient thermal oxidation. Most of the major ethanol design firms incorporate thermal oxidation of this exhaust stream into their plant designs, and most state air permitting agencies require it.

Process configurations & air permit implications

Selecting a dryer technology and its corresponding pollution control equipment often is the underlying decision for determining air permitting major source status. Prevention of significant deterioration (PSD) thresholds are now 250 tons per year (tpy) per pollutant facility-wide, since the EPA changed its interpretation of PSD rules for ethanol plants, in 72 FR 24060, on May 1, 2007.

In some non-corn-belt areas of the country where ethanol plants are now being proposed, such as those in ozone non-attainment areas or transport regions, major source thresholds are as low as 50 or even 25 tpy of VOCs to trigger non-attainment New Source Review (NNSR) permitting. When combustion emissions from boilers, emergency generators, fire water pump engines and load-out flares are added to those from the dryer and thermal oxidizer, one can envision why these decisions are critical.

NNSR permitting involves determining and installing lowest achievable emissions rate (LAER), control technology, obtaining emissions offsets, and analysis of alternatives for the entire development project. PSD permitting involves dispersion modeling, best-available control technology (BACT) determination and commitment, and other impact analyses. Both NNSR and PSD permitting involve additional expense and longer permitting timelines, neither of which finds fondness with ethanol developers. Efficient, properly tuned thermal oxidizers are generally considered to meet BACT and LAER requirements, but there is surprisingly little history in the EPA’s RACT/BACT/LAER Clearinghouse database[1], since most ethanol developers to date have sought to avoid NNSR and PSD permitting by maintaining emissions below the threshold levels.

Abatement equipment selection

Some ethanol facilities in the upper Midwest were originally constructed without thermal oxidizers. However, odor complaints and EPA consent orders forced the installation of oxidizers, and hence some form of thermal oxidation is now a part of any new ethanol plant design involving a dryer. Certain plants with solid fuel boilers (often major sources) may vent the dryer exhaust into the boiler for thermal destruction. Others may recover some energy from direct-fired thermal oxidizers by generating steam.

In general, the following two technology solutions have been considered preferred for the ethanol plant DG dryer emission control:

Regenerative thermal oxidizer (RTO):

• Destruction Efficiencies of 98 to 99 percent for VOCs, hazardous air pollutants (HAPs) and CO
• Designed to handle a wet air stream with some particulate.
• Pre-filters available for higher levels of particulate.
• Thermal energy recovery of 95 percent insures low fuel usage, and low NOX production.
• Fuel injection system further lowers NOX.

Direct-fired thermal oxidizer/waste heat boiler:

• Designed to oxidize 99+ percent of VOCs, HAPS, CO and organic particulate without obstructions, eliminates the potential for plugging.
• Generates steam for use in the process.
• Can reduce overall capital cost of plant and air emissions.
• Optional turbine produces power for driving electric motors or for distribution within the plant.

A natural gas RTO may have the highest efficiency, the lowest emissions and a lower total installation cost versus other options. A natural gas RTO may allow a larger capacity plant to be constructed (greater than 100 MGY) while remaining a minor source, but most other options will trigger major source permitting. Tradeoffs are between capital expenditures and operating expenses, as well as a shorter timeline to construction, versus potential future competitive advantages. A good natural gas supply deal is a must, with some portion of the net input reserved for hedging on the spot market.

An ethanol developer’s speed-to-market, permitting timeline and expenses, material logistics, feedstock, energy source, and selected co-products all relate to the dryer type and air pollution control technology decisions.
Several other parameters need to be considered to evaluate the selection and design of a fully integrated air abatement system, including regulatory requirements and emission characteristics for VOCs, NOX, CO and HAPs. Other parameters include the following process characteristics:

• New or existing plant
• Airflow requiring treatment
• Steam requirements and cost to produce
• Power availability and cost to distribute

Environmental impact

According to the Department of Energy’s Argonne National Laboratory, ethanol-blended fuels reduced CO2-equivalent greenhouse gas emissions by 7.8 million tons in 2005, which had the equivalent effect of removing the annual greenhouse gas emissions of over 1 million automobiles from the road. Many agree that ethanol is a cleaner-burning fuel than gasoline. With state-of-the-art control technology in place at ethanol plants, it can be ensured that production does not counteract the positive impact of this alternative fuel.

Scott W. Golla, QEP, MBA, is a senior consultant in Malcolm Pirnie’s Pittsburgh office. He assists new energy development clients with permitting and strategy, and can be reached at (724) 934-4112.

Richard Grzanka, is regional vice president - sales for Anguil Environmental Systems, and holds a BSME, and an MBA. He has been active in heat recovery and thermal oxidizer applications for 25 years, and can be reached at (973) 543-8923 or visit www.anguilasia.com.

1. Visit http://cfpub1.epa.gov/rblc/htm/bl02.cfm to learn more about the RACT/BACT/LAER Clearinghouse.

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