Finding of No Significant Impact 

for 

Biomass Cogeneration and Heating Facilities 

at the 

Savannah River Site 

Agency: U.S. Department of Energy 

Action: Finding of No Significant Impact 

Summary: The Department of Energy (DOE) has prepared an environmental 

assessment (EA) (DOE/EA-1605) to analyze the potential environmental impacts of the 

proposed construction and operation of new biomass cogeneration and heating facilities 

located at the Savannah River Site (SRS). The draft EA was made available to the States 

of South Carolina and Georgia, and to the public, for a 30-day comment period. Based 

on the analyses in the EA, DOE has determined that the proposed action is not a major 

Federal action significantly affecting the quality of the human environment within the 

meaning of the National Environmental Policy Act (NEPA) of 1969. Therefore, the 

preparation of an environmental impact statement (EIS) is not required and DOE is 

issuing this finding of no significant impact (FONSI). 

Public Availability: Copies of the final EA and FONSI or further information on the 

DOE NEPA process are available from: 

 Andrew R. Grainger, NEPA Compliance Officer 

 U.S. Department of Energy, Savannah River Operations Office 

 Building 730-1B, Room 3150 

 Aiken, South Carolina 29808 

 Fax/telephone: 1-800-881-7292 

 e-mail: nepa@srs.gov

or drew.grainger@srs.gov 

Background: A large portion of SRS (the F, H, and S-Areas) is supplied with its energy 

and steam from a coal-fired powerhouse in D-Area, while an oil-fired steam plant in 

K-Area supplies steam energy to both K and L-Areas. The coal-fired D-Area 

powerhouse was constructed in the 1950s and the K-Area oil-fired steam plant was 

installed in 1992. Both are in need of significant modifications to reliably supply energy 

for DOE’s continuing missions and to meet current environmental regulations and air 

emission restrictions. In addition they represent significant overcapacity relative to 

current and projected needs. The project described in the EA will replace the two 

existing facilities with three biomass energy plants. Specifically, DOE’s proposed action 

is the construction and operation of the following facilities: a new biomass cogeneration 

facility to replace the existing D-Area powerhouse; and two new biomass heating plants 

at K and L-Areas to replace the existing K-Area steam plant. The proposed biomass 

cogeneration facility and heating plants will supply energy to the F, H, K, L, and S-Areas 

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of SRS. The proposed project will help SRS meet its energy requirements for an initial 

term of 21 years, with the potential for many years of continued operation after the initial 

term. 

The project is being proposed under the authority and terms of the DOE Biomass and 

Alternate Methane Fuel Energy Savings Performance Contract number 

DE-AC26-02-NT41457. DOE anticipates the proposed project will create significant 

energy and energy cost (dollar) savings to SRS. The savings will result from fuel 

switching, reductions in line losses by placing the steam plants several miles closer to end 

user facilities, and improved operations with new equipment that is sized to better match 

load requirements. In addition to providing for much of SRS’s steam needs with a 

renewable energy source, the project will create benefits to the surrounding area. All 

three plants will utilize biomass obtained from the region, and will use the best available 

control technology for the reduction of air emissions. 

Purpose and Need for Agency Action: The purpose of the proposed action is to supply 

large portions of SRS with reliable and efficient sources of energy. DOE needs to 

generate energy to support continuing and future SRS missions through more efficient 

and environmentally preferable means. DOE needs to utilize biomass and bio-derived 

fuels as fuel sources to move towards meeting requirements set forth in the Energy Policy 

Act of 2005, Public Law 109-58, which directs all Federal agencies to increase their 

renewable energy use, with a goal of using (1) 3 percent or more renewable energy in 

Fiscal Year (FY) 2007 through 2009, (2) 5 percent or more renewable energy in FY 2010 

through 2012, and (3) 7.5 percent or more renewable energy by FY 2013. 

Proposed Actions: The proposed action, the construction and operation of biomass 

cogeneration and heating facilities at SRS, will consist of the following two Energy 

Conservation Measures (ECMs): a new biomass cogeneration facility to replace the 

existing coal-fired D-Area powerhouse; and two new biomass heating plants, one in 

K-Area and one in L-Area to replace the existing oil-fired steam plant in K-Area. The 

ECM project components are described in detail below. 

The proposed biomass cogeneration facility (EMC 1) will be located on a 30-acre site 

near the center of SRS. The facility will produce approximately 850,000,000 pounds of 

steam per year which will be exported to the 200-Area users and will meet all of the 

thermal energy steam requirements of the F, H, and S-Areas of SRS. The facility will 

also produce from 6 to 15 megawatts of electricity which will be connected and 

distributed to the SRS electrical distribution system for use onsite. Electricity output will 

vary based on the quantity of excess steam available after the steam load requirements are 

met. 

Biomass fuel will be burned in the new facility to produce steam and power. The 

biomass will consist of primarily low-value wood residues and wood waste by-products 

with a small percentage of biomass-derived fuel (BDF) and oil delivered from the local 

Aiken and Augusta area. Biomass sources may include low-value forest products, forest 

residues and wood processing waste by-products, agricultural crops, construction waste, 

and alcohol fuels. Wood is the most common form of biomass and is available from 

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several waste sources. This material includes by-products from manufacturers such as 

furniture mills, saw mills, paper mills and other wood product manufacturers; low-value 

forest products, such as small trees and top wood, and defective or deformed trees; forest 

residues, such as dead wood and hazardous wildland fire fuels and landscaping waste. 

Woodwaste is typically in the form of sawdust, woodchips, pellets, and wood scraps such 

as crates and pallets, and is regularly used as an energy source for heating and power 

generation. There are numerous sources of biomass available within 100 miles of SRS 

and the fuel will be procured through purchases from local biomass suppliers. Many of 

the local suppliers obtain a portion of their biomass through timber sales from SRS. 

BDF will make up to 30 percent of the heat input source for the cogeneration facility. 

The BDF will consist of tire-derived fuel (TDF) from scrap tires brought to transfer 

stations and landfills. The maximum permitted amount of BDF processed in the 

proposed facility will be approximately 1.1 million British thermal units (mbtu)/year or 

43,000 tons of tires/year. In addition, each biomass boiler will be capable of burning fuel 

oil in the event the biomass feed system fails. As fuel oil is used, the biomass 

consumption will decrease. Five percent of the fuel input for the proposed cogeneration 

facility could be fuel oil. This consumption will vary as it will be a backup fuel only. 

The biomass fuel delivery trucks will enter SRS using an existing primary road to the 

plant entrance. A deceleration lane will be added for trucks to enter the cogeneration 

facility as part of this project. Once onsite, the trucks will be unloaded using a truck 

dumper. A fire suppression system will be part of the cogeneration biomass fuel storage 

area. The trucks will exit behind the cogeneration facility where a new traffic light will 

be installed. The current graveled road will be paved to support the biomass truck 

deliveries. Peak truck traffic will be an 8 hour operation with 7 to 8 trucks per hour, 5 

days per week. 

The proposed cogeneration facility will include two 120,000 pounds per hour (pph) 

(210,000 mbtu/hr input) boilers and one 20 megawatt turbine. Each boiler will have full 

capacity fuel-oil burners that will serve as a back-up in case the biomass fuel system is 

inoperable. The proposed facility will have a footprint of approximately 20,000 square 

feet (sf), with an additional 2,200 sf administration building in front of the facility, a 

detached garage, and biomass fuel yard covering approximately 12 acres. The 

development on the site will include four main components: 1) the fuel handling yard, 2) 

the steam/combustion system, 3) the water treatment system, and 4) the turbine and 

electrical system. The 850 pounds per square inch (psi) steam produced by the steam 

plants will pass through a single extraction turbine. Steam required by SRS will then be 

transferred to an existing steam distribution system, and the remaining steam will flow 

through the other stage of the turbine for additional power generation. The 

combustion/steam system will include the components from the fuel feeder to the exhaust 

stack and the steam auxiliaries. 

A bubbling fluidized bed (BFB) combustion technology is proposed for this project. 

BFB technology uses high pressure air to fluidize a 2-3 foot bed of sand (inert material) 

in suspension. The fuel source is fed into the system through air spouts and dropped onto 

3 
the bed. The system operates using air to reduce the bed temperature and to minimize 

nitrogen oxide (NOx) emissions. BFB technology is preferable to the circulating 

fluidized bed (CFB) for biomass fuels due to its ability to better tolerate various fuel 

types, as well as larger variations in both fuel mixture density and moisture content. 

BFBs have the advantage of reduced air emissions due to a more stringently controlled 

temperature in the combustion process. The BFB boiler will produce steam at 850 psi, 

825° F. The steam will pass through a condensing steam turbine when generating 

electricity, or, if the turbine is down, through a pressure reducing valve (PRV) station 

which will reduce the pressure to 385 psi. The 385 psi steam will be distributed to the 

existing system via the interconnection to the existing steam header located just across an 

existing road from the new plant. 

Each boiler will include a flue gas handling system, which will consist of an induced 

draft (ID) fan to pull the boiler flue gas through the economizer, and then through a 

multiple cone dust collector. The ID fan will exhaust into a fabric filter baghouse and 

then to an integral exhaust stack. The baghouse will capture particulate matter from the 

flue gas with removal efficiencies of 99.9+ percent. Because of the lower bed 

temperature of a BFB, a baghouse will be used instead of an electrostatic precipitator 

(ESP). The baghouse will be more effective in capturing sulfur and mercury components 

and has minimal energy requirements compared to the ESP. The flue gas will then exit 

through a stack adjacent to the ID fan and baghouse, to be located just outside of the new 

facility. The flue gas from the boiler will be treated in the combustion system using 

selective non-catalytic reduction (SNCR) technology to reduce nitrogen oxides. Urea 

will be injected into the furnace typically above the over-fire air ports, reacting with the 

oxides to form innocuous nitrogen and hydrogen. 

Cooling process water for the facility will be drawn from the Savannah River. New more 

efficient pumps will be installed in the 681-3G Pumphouse to provide the water to the 

biomass cogeneration facility. A new pipeline will be installed from the proposed facility 

site to the nearest water main pump house in C-Area, a distance of approximately 1.5 

miles. Of this distance, the pipeline will follow an existing right-of-way (ROW) for one 

mile and will then branch off for 0.5 miles through forested land. Industrial wastewater 

from the facility will be discharged via a discharge system to Upper Three Runs (UTR). 

The ash and other waste generated during facility operations will be disposed of at the 

nearby permitted Three Rivers Regional Municipal Solid Waste Landfill. A new 

electrical feeder line will be constructed to tie the facility into the SRS electrical grid 

system at the 251-F substation. 

Construction of the cogeneration facility is scheduled to begin in September 2008, and 

will continue for 2.5 years. A peak number of 200 construction workers will be required 

during the construction period. The facility will be online near the end of 2010, and will 

operate 24 hours per day for an initial term of 21 years, though the serviceable life of the 

facility will be over 30 years. Approximately 20 employees will be required for 

operation of the facility. 

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ECM 2 will consist of two new biomass heating plants; one will service K-Area and the 

other will service L-Area. The new K-Area plant will be adjacent to the existing oil-fired 

steam plant within the fenced area. The L-Area plant will be located on the footprint of 

Building 183-4L which was removed during site decommissioning and demolition. Both 

plants will consist of a combustion and steam system. The plants will each be capable of 

producing 10,500 pounds per hour (pph) of steam. Additionally, both the K and L-Area 

biomass heating plants will only burn clean biomass and no BDF. The biomass fuel 

(wood materials) will be stored at the fuel yard adjacent to the proposed cogeneration 

facility (ECM 1), and will be trucked to the K and L-Area plants up to a maximum of one 

trip per day to both sites. The fuel will be loaded onto a walking floor-bed truck at the 

fuel yard and then parked at the metering bin for each steam plant. Each of the new 

plants will be installed in a new enclosed metal building with an adjacent covered shelter 

to house the fuel storage and delivery equipment. A fire suppression system will be part 

of each of the fuel storage areas. The total footprint of construction will be 3 acres for 

each steam plant, for a total of 6 acres. The total construction period for both plants will 

be approximately 18 months. Once operational, both plants will only produce steam, and 

will distribute the produced steam within their respective service areas (K and L). The 

pipeline connecting K-Area and L-Area will no longer be needed and will be capped and 

left in place. The plants at the K and L locations will each have less than 1400 gallons a 

day of steam blow down water at peak per plant. This water will drain to the existing 

sanitary sewer system in K-Area and to permitted outfall L-07 in L-Area. 

Each of the two biomass plants will use up to 2,500 tons per year of biomass (5,000 tons 

total for both plants). The plants are scheduled to operate during the colder months of 

November through April. Each of the biomass plants will also be equipped with fuel oil 

burners for fuel oil combustion during system startup and backup. Up to about 5 percent 

of the plants’ total fuel input could be fuel oil. Steam feed water will be supplied from 

the river water system in L-Area and from the well water system in K-Area. 

No Action Alternatives: Under the No Action Alternative, DOE will continue to 

operate the coal-fired D-Area powerhouse, which produces both steam and electricity for 

onsite consumption, and the oil-fired K-Area steam plant, which produces only steam. 

These facilities are past their design life and are in need of significant modifications and 

upgrades to bring them into compliance with current environmental standards and 

permitting requirements. The existing D-Area powerhouse currently burns almost 

160,000 tons of coal annually and will continue to use coal at a similar rate under the No 

Action Alternative. In FY 2007, 6,569 truckloads of coal were delivered to the D-Area 

powerhouse, totaling 153,954 tons of coal. On average, 26 truckloads were delivered to 

the site each day and the average weight of coal delivered per truckload was 23.4 tons. 

The D-Area powerhouse is close to the Savannah River and is located several miles from 

its end users (F, H, and S-Areas) and must distribute steam through a large distribution 

pipeline to these areas, losing valuable energy in the process. In addition to steam, the 

powerhouse also produces approximately 20 megawatts of electricity on average that is 

consumed by DOE facilities onsite. Electricity output is based on the quantity of excess 

steam available after the steam load requirements are met. The D-Area powerhouse 

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withdraws an average of 50 million gallons of water per day from the Savannah River. 

Water that is used for steam plant feedwater is treated at the 483-D water plant. 

Untreated raw water, which is used for condenser cooling passes directly through the 

condenser and is discharged directly through the powerhouse’s outfall. The primary 

National Pollutant Discharge Elimination System (NPDES) permitted outfall for the 

facility, D-01, discharges an average of 40.2 million gallons/day. Discharge limits are in 

effect for temperature, temperature difference between river water intake and discharge, 

residual chlorine, pH, total suspended solids, oil/grease, and manganese. The D-Area 

powerhouse employs 60 people and is operated by a contractor. 

The existing oil-fired K-Area steam plant is maintained by SRS personnel, but no 

employees are permanently assigned to the facility. The K-Area steam plant consists of 

two boilers, one 30,000 pph and one 60,000 pph; the 30,000 pph steam plant has been 

and will continue to be the primary boiler. The K-Area steam plant serves both K and 

L-Area users, and a 2.5 mile pipeline delivers steam to the L-Area from K-Area. The 

steam that travels in this distribution pipeline also loses valuable energy before reaching 

L-Area. The source for process water for the K-Area plant will continue to be from the 

well water system in K-Area. 

Alternatives Considered But Not Evaluated: For this project, two alternative locations 

were evaluated for the proposed biomass cogeneration facility, but were dismissed from 

further analysis. Alternative Site 1 is in close proximity to the main steam header, SC 

Highway 125, and a 115 kilovolts electrical system. Drawbacks to this location include 

the distance of the site from the F-Area production wells and the Central Sanitary 

Wastewater Treatment Facility (CSWTF). The major drawback to this site is the distance 

to the 200-Area end-users. This site is the closest of the evaluated locations to the 

existing powerhouse site. Therefore, compared to the other locations, more steam line 

would have to stay in service if this site were to be used. The cost of operating and 

maintaining this additional line would be considerable. The energy loss from 

transporting the steam across this distance would also be considerable. To compensate 

for this energy loss, more fuel would be needed. For these reasons, Alternative Site 1 

was dismissed from further evaluation. 

Alternative Site 2 is close to the 200-Area end-users and groundwater production wells. 

However, it is far from the highway, CSWTF, and the steam main. Because of the 

distance from a main SRS thoroughfare, this site location would create access difficulties 

for construction activities and fuel delivery. Further, the site is in close proximity to a 

remediated nuclear waste operations site. However, the key drawback of this site is that 

it is in close proximity to the H-Area meteorological tower and therefore would interfere 

with the tower’s operation. For these reasons, Alternative Site 2 was dismissed from 

further evaluation. 

DOE also considered alternatives related to water sources, the discharge of industrial 

effluent, and the cooling of process water, but did not evaluate them in the EA. 

6 
The biomass cogeneration facility would require process water for steam and cooling 

tower makeup and for backwash and regeneration cycles associated with the facility’s 

water treatment system. Expected water flow demand could peak at 2,000 gallons per 

minute. Alternative sources of process water identified but not evaluated in the EA 

included: (a) treated effluent from CSWTF, (b) groundwater from existing F-Area 

production wells or new production wells installed at the preferred facility site, and (c) 

the SRS domestic water system. DOE determined that the CSWTF was not a viable 

water source because the volume of treated effluent would not be sufficient to meet 

facility needs. Although the site’s groundwater resource could easily accommodate 

projected water demand, DOE determined the use of existing or new production wells 

would not be cost effective. From this analysis, DOE has determined the SRS domestic 

water system has sufficient capacity to support the proposed action, but its use for this 

purpose would not be economical. The biomass cogeneration facility will draw its water 

from the existing river water system. If, at some point in the future, the river water 

system is no longer available due to insufficient river flows, the above water source 

alternatives will be reevaluated. 

A potential alternative to discharging industrial effluent (steam and cooling tower blow 

down) to UTR is to discharge this waste stream to CSWTF. DOE determined that the 

site’s wastewater treatment facility could not accommodate the increased inflow, and this 

option was not evaluated in the EA. The use of air-cooled condensers as an alternative to 

the construction and operation of cooling towers was also identified. However, 

air-cooled condensers are space and energy intensive and will not function effectively 

during the hot and humid summer period. Therefore, DOE did not evaluate this 

alternative method for cooling process water in the EA. 

Environmental Impacts: The cogeneration facility site will be located on an old 

abandoned borrow pit that appears to have had no restoration. The soil is highly 

disturbed and not characteristic of an intact series. Based on the previous use of the 

proposed site, the potential for the construction and operation of the proposed action to 

impact environmental resources at SRS will be negligible. DOE also expects that the 

potential for the utility line right-of-way construction to impact environmental resources 

at SRS will be negligible. DOE expects that environmental impacts from the 

construction and operation of the plants at K and L-Areas to be similar to those for the 

proposed facility site. As these two areas currently house facilities, the land and soils are 

already disturbed and compacted. DOE expects that the potential for the utility line 

right-of-way construction in K and L-Areas to impact environmental resources at SRS to 

be negligible. DOE expects no adverse water quality impacts from the construction and 

operation of the proposed actions. The substantial decrease in Savannah River water 

withdrawal rates will be beneficial. 

DOE expects that air emissions resulting from construction-related activities (e.g., 

equipment emissions, fugitive dust) at the three sites will be short-lived and minimal. 

They will not require permitting by the State. Overall emissions will change with the 

shift from a coal-fired power plant to a biomass cogeneration facility. DOE expects the 

overall emission levels will decrease, but the emissions of some criteria pollutants will 

increase. SRS currently operates via a Title V-Part 70 Operating Permit. A new 

7 
operation permit will be obtained to include the new emissions from the cogeneration 

facility. Actions that will aid in decreasing the overall impacts of air emissions include 

limiting when the facility will be operating, and utilizing abatement technologies to help 

decrease emission levels at the source. The proposed facility’s abatement measures 

include a fabric filter baghouse to reduce particulate matter (PM), and selective 

non-catalytic reduction (SNCR) to reduce nitrogen oxide formation. Baghouse filters 

work to curb PM emissions by trapping particulate matter in a fabric bag, similar to the 

way a vacuum cleaner operates. The filters are cleaned by blowing air through in the 

reverse direction and collecting the PM. This process effectively removes up to 99.9+ 

percent of particulate matter. The SNCR method effectively reduces NOx emissions via a 

process of urea injection. Urea will be injected into the steam boiler at temperatures high 

enough to result in a chemical reaction between water and urea that forms ammonia 

which in turn reacts with NOx and oxygen to form nitrogen and water. In addition, 

limestone will be injected into the flue gas and, via sorption reactions, reduce NOx and 

sulfur compounds. Multicyclone technology will be implemented at the K and L-Area 

plants to aid in decreasing air emissions. This technology reduces the temperature of 

combustion by dilution of the combustion products with excess fuel, air, flue gas, or 

steam. The resulting chemical reactions prevent the majority of the nitrogen from 

becoming ionized and forming NOx. Replacement of the existing facilities with biomass 

fueled facilities will substantially reduce greenhouse gas (e.g., water vapor, carbon 

dioxide, methane, ozone) emissions and minimize environmental compliance issues 

while more reliably providing steam for SRS missions and decreasing the SRS carbon 

footprint. 

The potential for these activities to significantly impact the human environment (e.g., 

air, aquatic, terrestrial, and biotic resources) will be negligible. The potential for 

the proposed and alternative actions evaluated in the EA to significantly impact 

archaeological or cultural resources at SRS will be negligible. None of the proposed 

actions evaluated in the EA will be expected to have a measurable impact on migratory 

avian species. DOE expects overall impacts to both vegetation and wildlife to be 

long-term and minor for the proposed actions. There will be no effect on the population 

status of any threatened and endangered species within the proposed project areas or on a 

site wide level. 

The potential for the proposed actions evaluated in the EA to result in terrorism-related 

activity or impacts at SRS are expected be negligible. The potential for the proposed 

actions evaluated in the EA to result in accidents from operation activities at SRS are 

expected to be negligible. Impacts to worker health and safety will be negligible due to 

the use of appropriate safety practices, personal protective clothing and equipment, and 

the provision of a safe and healthful workplace as required by Federal regulations. 

Workforce requirements and project costs of implementation of the proposed projects 

will be minimal when compared to the total SRS budget and employment 

(approximately $1.15 billion per year and 10,000 personnel, respectively). The 

socioeconomic impact(s) of the proposed projects on the human environment will be 

negligible. Based on the information and analysis presented in the EA, DOE has 

determined that the proposed construction and operation of the new biomass cogeneration 

8 
facility and heating plants at SRS will not cause disproportionately high and adverse 

human health or environmental effects on minority and low income populations in the 

SRS region of interest. Infrastructure impacts from the proposed actions will be 

negligible as the new facility and plants will be smaller than the existing powerhouse and 

therefore require less infrastructure resources. 

Cumulative Impacts: Construction-related activities of implementation of the proposed 

projects will be short-lived and the potential for any resulting air emissions to interact 

with other SRS pollutant sources or have a cumulative impact on criteria air pollutants 

will be negligible. SRS could be in an area declared nonattainment for PM10, PM2.5, and 

ozone at some future date. When an area is designated nonattainment for any of the 

criteria pollutants, the affected State must draft a plan known as a State Implementation 

Plan (SIP) to improve air quality and outline the control measures the State will take in 

order to meet National Air Quality Standards (NAAQS). These air pollution control 

measures include a process called Nonattainment New Source Review (NA NSR) 

permitting. NA NSR applies to new major sources or major modifications at existing 

sources for pollutants where the source location is not in attainment with NAAQS. All 

NA NSR permits require that the proposed air pollution source install the Lowest 

Achievable Emission Rate (LAER), pollution controls, emission offsets, and an 

opportunity for public involvement. LAER is the most stringent emission limitation 

derived from either of the following: the most stringent emission limitation contained in 

the SIP for a similar source, or the most stringent emission limitation achieved in practice 

by a similar source. Also, sources must obtain emissions reductions from existing 

sources located in the vicinity of the source NA NSR source. The emission reductions, 

generally called “offsets” must offset the emissions increase from the new source or 

major source modification to ensure reasonable progress toward meeting the NAAQS. 

The emission reductions must also provide a net air quality benefit. DOE expects that 

there will be a decrease of approximately 100,000 tons a year of carbon dioxide 

emissions by switching from coal combustion to biomass combustion and that the 

potential cumulative impacts of the actions evaluated in the EA on the human 

environment will be minimal. 

Floodplain Statement of Findings: This is a Floodplain Statement of Findings prepared 

in accordance with Title 10 Code of Federal Regulations Part 1022. A floodplain and 

wetlands assessment was incorporated in the EA. With the implementation of all best 

management practices, to both minimize runoff from the construction site and minimize 

direct encroachment on the wetlands and their associated floodplains, DOE expects the 

overall impacts to wetlands and floodplains of UTR from the proposed project will be 

minimal and short term. No long-term impacts are foreseen. DOE will allow 15 days of 

public review after publication of this statement of findings before implementing 

construction of the proposed biomass cogeneration facility and two new biomass heating 

plants at K and L-Areas. 

Determination: Based upon the information and analyses in the EA (DOE/EA-1605), 

DOE has determined that the proposed construction and operation of the new biomass 

cogeneration facilities and heating plants at SRS do not constitute a major Federal action 

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