[Federal Register: July 28, 2006 (Volume 71, Number 145)]
[Notices]
[Page 42840-42844]
From the Federal Register Online via GPO Access [wais.access.gpo.gov]
[DOCID:fr28jy06-49]
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DEPARTMENT OF ENERGY
Notice of Intent To Prepare an Environmental Impact Statement for
Implementation of the FutureGen Project
AGENCY: Department of Energy.
ACTION: Notice of Intent to Prepare an Environmental Impact Statement.
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SUMMARY: The U.S. Department of Energy (DOE) announces its intent to
prepare an Environmental Impact Statement (EIS) pursuant to the
National Environmental Policy Act (NEPA), the Council on Environmental
Quality (CEQ) NEPA regulations (40 CFR parts 1500-1508), and the DOE
NEPA implementing procedures (10 CFR part 1021), to assess the
potential environmental impacts for the proposed action of providing
Federal funding (up to $700 million) for the FutureGen Project. The
FutureGen Project would comprise the planning, design, construction and
operation by a private-sector organization of a coal-fueled electric
power and hydrogen gas (H2) production plant integrated with
carbon dioxide (CO2) capture and geologic sequestration of
the captured gas. Following an evaluation of 12 site proposals from
seven states, DOE identified four sites as reasonable alternatives: (1)
Mattoon, Illinois; (2) Tuscola, Illinois; (3) Jewett, Texas; and (4)
Odessa, Texas. DOE has prepared this Notice of Intent (NOI) to inform
interested parties of the pending EIS and to invite public comments on
the proposed action, including: (1) The proposed plans for implementing
the FutureGen Project, (2) the range of environmental issues and
alternatives to be analyzed, and (3) the nature of the impact analyses
to be considered in the EIS. A general overview of the proposed action
was published on February 16, 2006, in an Advance Notice of Intent (71
FR 8283).
DOE has signed a Cooperative Agreement that provides financial
assistance to the FutureGen Industrial Alliance, Inc. (Alliance) for
implementing the FutureGen Project. The Alliance is a non-profit
industrial consortium led by the coal-fueled electric power industry
and the coal production industry. Along with planning, designing,
constructing and operating the FutureGen power plant and the
sequestration facility, the Alliance would also monitor, measure, and
verify geologic sequestration of CO2.
The FutureGen Project aims to establish the technical and economic
feasibility of co-producing electricity and H2 from coal
while capturing and sequestering the CO2 generated in the
process. FutureGen would employ integrated gasification combined-cycle
(IGCC) power plant technology that for the first time would be
integrated with CO2 capture and geologic sequestration.
DOE is providing technical and programmatic guidance to the
Alliance, retains certain review and approval rights as defined in the
Cooperative Agreement, and oversees Alliance activities for compliance
with the terms of the Cooperative Agreement. DOE is responsible for
NEPA compliance activities. Both DOE and the Alliance encourage state
and local agencies, local communities, the environmental community,
international stakeholders, and research organizations to participate
in the FutureGen Project through the NEPA process.
Potential environmental impacts of each of the four alternatives
will be analyzed in detail in the EIS. Reasonable power plant
technologies and component configurations proposed by the Alliance will
be used in the evaluation. In addition, DOE will consider potential
mitigation opportunities in the EIS.
DATES: To ensure that all of the issues related to this proposal are
addressed, DOE invites comments on the proposed scope and content of
the EIS from all interested parties. Comments must be received by
September 13, 2006, to ensure consideration. Late comments will be
considered to the extent practicable. In addition to receiving comments
in writing and by telephone [See ADDRESSES below], DOE will conduct
public scoping meetings in which government agencies, private-sector
organizations, and the general public are invited to present oral
comments or suggestions with regard to the alternatives and impacts to
be considered in the EIS. Scoping meetings will be held during August
2006 near each proposed project site, at locations and on dates to be
announced in a future Federal Register notice and in local newspapers.
Oral comments will be heard during the scoping meetings beginning at 7
p.m. (See Public Scoping Process). The public will be invited to an
informal session of the scoping meetings at the same locations
beginning at 4 p.m. to learn more about the proposed action. Various
displays and other information about the proposed action will be
available, and DOE personnel will be present at the informal session to
discuss the FutureGen Project and the EIS process.
ADDRESSES: Comments on the proposed scope of the EIS and requests for
copies of the Draft EIS may be submitted by fax (304-285-4403), e-mail
FutureGen.EIS@netl.doe.gov), or a letter addressed to the NEPA
Document Manager for the FutureGen Project: Mr. Mark L. McKoy, National
Energy Technology Laboratory, U.S. Department of Energy, P.O. Box 880,
Morgantown, WV 26507-0880, Attn: FutureGen Project EIS.
Comments or requests to participate in the public scoping process
also can be submitted by contacting Mr. Mark L. McKoy directly at
telephone 304-285-4426; toll free number 1-800-432-8330 (extension
4426); fax 304-285-4403; or e-mail FutureGen.EIS@netl.doe.gov.
[[Page 42841]]
FOR FURTHER INFORMATION CONTACT: To obtain additional information about
this project, contact Mr. Mark L. McKoy by the means provided above.
For general information on the DOE NEPA process, please contact: Ms.
Carol M. Borgstrom, Director, Office of NEPA Policy and Compliance (EH-
42), U.S. Department of Energy, 1000 Independence Avenue, SW.,
Washington, DC 20585-0119. Telephone: 202-586-4600. Facsimile: 202-586-
7031. Or leave a toll-free message at 1-800-472-2756.
SUPPLEMENTARY INFORMATION:
Background
President Bush proposed on February 27, 2003, that the United
States undertake a $1 billion, 10-year project to build the world's
first coal-fueled plant to produce electricity and H2 with
near-zero emissions. In response to this announcement, the DOE
developed plans for the FutureGen Project, which would establish the
technical and economic feasibility of producing electricity and
H2 from coal--a low-cost and abundant energy resource--while
capturing and geologically storing the CO2 generated in the
process.
DOE would implement the FutureGen Project through a Cooperative
Agreement that provides financial assistance to the FutureGen
Industrial Alliance, Inc., a non-profit corporation that represents a
global coalition of coal and energy companies. Members of the Alliance
would be expected to provide an estimated $250 million to help fund
Project development. The Alliance members are: American Electric Power
Company, Inc. (Columbus, Ohio); Anglo American, LLC (London, UK); BHP
Billiton Limited (Melbourne, Australia); China Huaneng Group (Beijing,
China); CONSOL Energy, Inc. (Pittsburgh, Pennsylvania); Foundation Coal
Holdings, Inc. (Linthicum Heights, Maryland); Kennecott Energy (now:
Rio Tinto Energy America based in Gillette, Wyoming); Peabody Energy
Corporation (St. Louis, Missouri); PPL Corporation (Allentown,
Pennsylvania); and Southern Company (Atlanta, Georgia). The U.S.
government would invest about $700 million in the FutureGen Project,
with up to $80 million of that money coming from foreign governments.
Several foreign governments have recently entered into discussions with
DOE regarding possible contributions.
Purpose and Need for Agency Action
In pursuing the United States' goal of providing safe, affordable
and clean energy for its citizens, coal must play an important role in
the Nation's energy mix. A key obstacle, however, is the fact that
combustion of fossil fuels leads to increased concentrations of
CO2 and other greenhouse gases in the atmosphere. Combined,
the electricity and transportation sectors are responsible for nearly
three-fourths of the country's man-made greenhouse gas emissions.
Because power plants are stationary sources, it is more feasible to
capture these emissions and sequester them than it would be to capture
greenhouse gas emissions from mobile sources, such as automobiles.
To this end, DOE has identified a need for a near-zero emissions,
coal-to-energy option that would produce electric power and
H2 from coal while permanently sequestering CO2
in deep geological formations. The technical, economic, and
environmental feasibility of producing electric power and hydrogen from
coal, when coupled with sequestration technology, must be proven. In
the absence of proven operations of a large, integrated, near-zero
emissions power plant, the contribution of coal to the nation's energy
mix could be reduced, particularly if environmental regulations
continue to tighten, thereby potentially increasing use of non-domestic
energy resources, and impacting energy security.
Proposed Action
DOE proposes to provide financial assistance (up to $700 million)
for the Alliance to implement the FutureGen Project. The Alliance would
plan, design, construct, and operate the FutureGen Project, an advanced
integrated coal gasification combined cycle power and hydrogen gas
production plant and CO2 sequestration facility sized
nominally at 275 MW (equivalent output), and appurtenant facilities
(electrical transmission line connector, new pipelines and compressor
stations to convey CO2, injection wells, and monitoring
wells). The goal of this initiative would be to prove the technical and
economic feasibility of a near-zero emissions, coal-to-energy plant
that could be commercially deployed by 2020. During the first phase of
the FutureGen Project, the Alliance and DOE would quantify the specific
emissions objectives. The FutureGen Project would co-produce electric
power and H2 in an industrial/utility setting while
capturing and geologically sequestering approximately one to two
million metric tons of CO2 per year. The FutureGen Project
would be a prototype facility that would facilitate large-scale
integrated testing of development-stage technologies and could also
provide a test platform for cutting-edge research on technologies that
support the goal of near-zero emissions.
The FutureGen Project would proceed through 2018 with design,
construction, operation, and monitoring. Performance and economic tests
results would be shared among all participants, industry, the
environmental community, and the public. DOE intends to invite
participation from international organizations to maximize the global
applicability and acceptance of FutureGen's results, helping to support
an international consensus on the role of coal and geological
sequestration in addressing global greenhouse gas emissions and energy
security.
FutureGen Project Processes
The FutureGen Project would employ advanced coal gasification
technology integrated with combined cycle electricity generation,
H2 production, CO2 capture, and sequestration of
the captured gas in geologic repositories. The gasification process
would combine coal, oxygen (O2), and steam to produce a
H2-rich ``synthesis gas.'' After exiting the conversion
reactor, the composition of the synthesis gas would be ``shifted'' to
produce additional H2. The product stream would consist
mostly of H2, steam, and CO2. Following
separation of these three gas components, the H2 would be
used to generate electricity in a gas turbine and/or fuel cell. Some of
the H2 could be used as a feedstock for chemical plants or
petroleum refineries or as a transportation fuel. Steam from the
process could be condensed, treated, and recycled into the gasifier or
added to the plant's cooling water circuit. CO2 from the
process would be sequestered in deep underground geologic formations
that would be monitored to verify the permanence of CO2
storage.
Technology Alternatives
The FutureGen Project would incorporate cutting-edge and emerging
technologies ready for full-scale or sub-scale testing in a power plant
setting prior to their commercial deployment. Identification of
technology alternatives is currently in progress for key components of
the FutureGen facility, involving gasification, O2
production, H2 production, synthesis gas cleanup,
H2 turbines, fuel cells and fuel cell/turbine hybrids,
CO2 sequestration, advanced materials, instrumentation,
sensors and controls, and byproduct utilization. Decisions on
incorporation of specific technologies would be made by the Alliance
consistent with the overall project goal of proving the technical and
economic feasibility of the near-zero emissions concept.
[[Page 42842]]
In identifying technology alternatives, the FutureGen Alliance
started with a list of major components and subsystems of the power
plant facility and created a matrix of potential configurations of
equipment. Following presentations by various technology vendors and
with assistance from numerous power plant experts, the matrix of
potential configurations has been gradually reduced to three
configurations, which will undergo more detailed cost and project risk
analysis. Ultimately, the Alliance will identify the specific
technology alternatives that would be most appropriate for the
FutureGen Project. The goal of this process is to arrive at an initial
conceptual design, which also will provide reference information to be
used in the EIS impact analyses.
It is expected that sequestration would be accomplished using
existing state-of-the-art technologies for both transmission and
injection of the CO2 stream. Various technologies will be
considered for monitoring at the injection sites.
Alternatives, Including the Proposed Action
NEPA requires that agencies evaluate the reasonable alternatives to
the proposed action in an EIS. The purpose of the agency action
determines the range of reasonable alternatives. In this case, DOE
proposes to provide financial assistance to the Alliance to build the
first ever coal-fueled plant to produce electricity and H2
with near-zero emissions. DOE believes the utility and coal industries
should lead the project since they have significant interest in the
success of near-zero emissions technology.
The EIS will analyze reasonable alternative sites for the FutureGen
Project. These sites have been identified through a process that
started with a solicitation by the Alliance for proposals. Twelve
proposals were submitted by state and local organizations, representing
sites in seven states (Illinois, Kentucky, North Dakota, Ohio, Texas,
West Virginia, and Wyoming). The Alliance, working through various
technical experts, first applied qualifying criteria that eliminated
four sites and then subjected the remaining site proposals to scoring
criteria. Along with the scoring criteria, best value criteria were
applied in the final step of determining which sites are reasonable
from a technical, environmental and economic perspective. At the
conclusion of the review of proposals, the Alliance provided DOE with a
report that describes the screening process, the results of the
screening process, and identifies the sites that the Alliance concludes
are candidates. The report is available at the Web site of the
FutureGen Alliance, http://www.FutureGenAlliance.org.
DOE has reviewed the Alliance's selection process for fairness and
compliance with the established approach, and DOE is satisfied with the
results. Furthermore, having considered all proposed site alternatives
in ascertaining which ones were reasonable, DOE has determined that the
Alliance's candidate site list is the preliminary list of reasonable
alternative sites for detailed analysis in the EIS. The preliminarily
identified site alternatives are:
Illinois--Mattoon
The proposed 240-acre Mattoon power plant site is located in east-
central Illinois approximately one mile northwest of the city of
Mattoon and approximately 150 miles south of Chicago. This Coles County
site is currently used as farmland, is flat, and is surrounded by a
rural area of low-density population. The Rural King warehouse is
located nearby. The site has access to coal delivery via rail and
truck, and natural gas can be supplied via connection along rail right-
of-way to an existing pipeline located one mile from the site. Cooling
water would be gray water from wastewater treatment facilities in
Mattoon (five miles southeast of the plant site) and Charleston (13
miles east of the plant site) and would be delivered via proposed new
pipelines. Additional water would be supplied from local potable
sources or from the Kaskaskia River, which is located about five miles
to the north. Lake Shelbyville is more than eight miles to the west.
The site would require the construction of two miles of additional
transmission line to reach a 138 kV substation southeast of the site or
16 miles of new line to connect to a 345 kV substation south of the
site. The site is outside the 500-year floodplain, and while no
wetlands were identified onsite, wetlands may be present 0.75 mile
downstream of the site and may also exist in the water supply pipeline
corridors. CO2 injection is proposed onsite, requiring no
offsite pipeline construction. The Mt. Simon saline-bearing sandstone,
the injection target at Mattoon, is expected to be between 1800 and
2100 meters (5900 and 6900 ft) deep beneath the site. The Mt. Simon is
capped by the Eau Claire Formation, which is a laterally persistent
shale expected to be between 100 and 150 meters (330 and 500 ft) thick
at Mattoon.
Illinois--Tuscola
The proposed Tuscola site is a 208-acre parcel of land located in
east-central Illinois 1.5 miles west of the city of Tuscola and
approximately 20 miles north of the Mattoon site. The city of Champaign
is located approximately 20 miles to the north, and Decatur is located
approximately 35 miles to the west. This Douglas County site is located
on flat farmland near an industrial complex, which is immediately west
of the site. To the immediate north and south the area is rural with a
very low population density. From this site the proposed project would
be able to connect to the power line grid via construction of a one-
mile connection to reach the 138 kV line to the north, or a 14-mile
connection to reach the 345 kV line to the east. The site is situated
along the CSX railroad and is about three miles from Interstate Highway
57. Therefore, it has access to coal delivery via rail and truck, and
natural gas would be supplied by an existing onsite pipeline. The site
is outside the 500-year floodplain, and while no wetlands were
identified on the site, wetlands are likely to occur in the proposed
CO2 and electricity transmission corridors. Cooling water
for the plant would be obtained from the Equistar Chemical Company,
which draws water directly from the Kaskaskia River 1.5 miles to the
west of the site, and would require the construction of a new pipeline
of this length. An additional new pipeline between 9.5 and 11.5 miles
in length would also be required to transport CO2 to one of
two potential injection fields due south of the plant site. The primary
injection site, located 11.5 miles from the plant site, is a 10-acre
parcel in a rural, agricultural area. Tuscola's proposed injection
target is the Mt. Simon sandstone, a saline-bearing formation expected
to be between 1200 and 1800 meters (4000 and 5900 ft) deep at the
proposed injection site. The primary cap rock here is the Eau Claire
Formation, which is a laterally persistent shale expected to be between
100 and 150 meters (330 and 500 ft) thick at the Tuscola injection
site.
Texas--Jewett
Located north of the town of Jewett, in east-central Texas, 65
miles north of Bryan/College Station, and 60 miles east of Waco, the
proposed 400-acre Jewett site is also known as the ``Heart of Brazos''
site. The site is located at the intersection of Leon, Limestone and
Freestone counties along U.S. Highway 79 and Farm Road 39 in an area
characterized by very gently rolling
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reclaimed mine lands immediately adjacent to an operating lignite mine
and the 1800 MW Jewett power plant. It has access to coal delivery via
rail and truck, and natural gas would be supplied by an existing onsite
pipeline. Proposed groundwater wells on property immediately west of
the site would supply cooling water to the plant via a new pipeline.
Transmission infrastructure with excess capacity exists on the site.
This site is outside of the 500-year floodplain. There are no
jurisdictional wetlands on the site. Lake Limestone and the Navasota
River are located about 3.5 miles to the west. It would be necessary to
construct 33 miles of new CO2 pipeline, 25 miles of which
would be built along an existing gas pipeline right-of-way, to
transport CO2 to the storage site, which is located on 1550
acres located northeast of the power plant site. The land use at the
sequestration site is pastures, wooded hills and open fields. The
proposed target injection formations are the Travis Peak sandstone, and
the Rodessa and Pettit limestones, all of which are saline-bearing
formations between 1400 and 3600 meters (4600 and 11,800 ft) deep. The
primary seal overlying these formations is the 120-meter (400 ft) thick
Eagleford Shale.
Texas--Odessa
The proposed Odessa site is located on 600 acres, approximately 15
miles southwest of the city of Odessa in Ector County, Texas. The site
is on flat land adjacent to Interstate Highway 20. There is an
extensive junk yard of abandoned oil and gas equipment along the site's
southern border. The proposed power plant property is entirely above
the 500-year floodplain and contains no jurisdictional wetlands.
Surrounding land is or was used primarily for oil and gas exploration
with some scattered industrial plants (sulfur manufacturing, cement
kiln, etc.). The site has access to coal delivery via rail and truck,
and natural gas would be supplied by an existing onsite pipeline. Water
would be provided via a pipeline to be constructed by the City of
Odessa to transport water from the Texland Great Plains Water Supply
well located 49 miles to the north, which produces water from the
Ogallala aquifer. Alternatively, water may be purchased from the West
Texas Water Supply System, located 37 miles west of the site. Two miles
of new transmission line would be needed to connect the plant to either
a 138 kV line or a 345 kV line. The proposed 6,000-acre injection field
is 58 miles south of the Odessa plant site. CO2 would be
transported in (and co-mingled in) an existing regional CO2
pipeline network. A short new CO2 pipeline would connect the
power plant site to the existing pipeline, and a new four-mile
(approximately) pipeline would connect the existing CO2
pipeline to the proposed injection sites. Proposed injection targets
for this site are the Queen Formation and the Delaware Mountain Group,
both of which are more than 1100 meters (3600 ft) deep beneath grazing
lands and scrub lands at the site. The system is capped by layers of
anhydrite, dolomitic anhydrite, and anhydrite-halite, which are
identified as the upper Queen and the overlying Seven Rivers
Formations.
In addition to the site alternatives preliminarily identified in
the NOI, the EIS will describe different technologies and strategies
for implementing important elements of the FutureGen Project. Critical
technology alternatives for various components and subsystems of an
integrated gasification combined-cycle power plant exist for the air
separation unit (e.g., cryogenic separation versus physical membrane
separation), gasifier (various commercial gasifiers with differing feed
types, wall structures, and ash/slag recovery and cooler systems), gas
turbine (e.g., syngas turbine versus H2 turbine),
CO2 capture system (e.g., chemical scrubbers, pressure-swing
absorption systems, physical membranes), and synthesis gas as well as
turbine combustion gas clean-up systems (e.g., selective catalytic
reduction versus selective non-catalytic reduction). The Alliance will
provide to DOE a conceptual design that will be analyzed in the EIS for
each of the alternative sites. This conceptual design will encompass
the power plant and sequestration requirements and attributes (e.g.,
emissions, effluents, feed stocks, workers) for any of the technology
alternatives that may be selected by the Alliance in the final designs.
Mitigation will be addressed for the potential impacts of the FutureGen
Project at each of the four sites and for the conceptual design and
technologies considered.
DOE will also consider a no-action alternative whereby DOE would
not fund the FutureGen Project. In the absence of DOE funding, it would
be unlikely that the Alliance, or industry in general, would soon
undertake the utility-scale integration of CO2 capture and
geologic sequestration with a coal-fired power plant. Absent DOE's
investment in a utility-scale facility, the development of integrated
CO2 capture and sequestration with power plant operations
would occur more slowly.
Decision Making Process
No sooner than 30 days following completion of the Final EIS, DOE
will announce in a Record of Decision (ROD) either the no-action
alternative or those sites, if any, that are acceptable to DOE. If DOE
selects the action alternative, the Alliance will subsequently select a
host site from among those, if any, listed in the ROD as acceptable to
DOE. Following the tentative selection of a host site, the Alliance
will conduct extensive site characterization work on the chosen site.
Information obtained from the characterization will be reviewed by the
DOE and will support the completion of a supplement analysis (see 10
CFR 1021.314) by DOE to determine whether the newly gained information
would have altered in a significant way the findings in the EIS. The
supplement analysis will be used to determine whether a Supplemental
EIS must be prepared.
Preliminary Identification of Environmental Issues
DOE intends to address the issues listed below when considering the
potential impacts resulting from the siting, construction and operation
of the FutureGen power plant, sequestration field, and associated
facilities. This list is neither intended to be all-inclusive nor a
predetermined set of potential impacts. DOE invites comments on whether
this is the correct list of important issues that should be considered
in the EIS. The environmental issues include:
Air quality impacts: potential for air emissions during
construction and operation of the power plant and appurtenant
facilities to impact local sensitive receptors, local environmental
conditions, and special-use areas, including impacts to smog and haze
and impacts from dust and any significant vapor plumes;
Noise and light impacts: potential impacts from
construction, transportation of materials, and facility operations;
Traffic issues: potential impacts from the construction
and operation of the facilities, including changes in local traffic
patterns, deterioration of roads, traffic hazards, and traffic
controls;
Floodplains: potential impacts to flood flow resulting
from earthen fills, access roads, and dikes that might be needed in a
floodplain;
Wetlands: potential impacts resulting from fill, sediment
deposition, vegetation clearing and facility erection that might be
needed in a wetland;
Visual impacts associated with facility structures: views
from
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neighborhoods, impacts to scenic views (e.g., impacts from water vapor
plumes, power transmission lines, pipelines), internal and external
perception of the community or locality;
Historic and cultural resources: potential impacts from
the site selection, design, construction and operation of the
facilities;
Water quality impacts: potential impacts from water
utilization and consumption, plus potential impacts from wastewater
discharges;
Infrastructure and land use impacts: potential
environmental and socioeconomic impacts of project site selection,
construction, delivery of feed materials, and distribution of products
(e.g., power transmission lines, pipelines);
Marketability of products and market access to feedstocks;
Solid wastes: pollution prevention plans and waste
management strategies, including the handling of ash, slag, water
treatment sludge, and hazardous materials;
Disproportionate impacts on minority and low-income
populations;
Connected actions: potential development of support
facilities or supporting infrastructure;
Ecological impacts: potential on-site and off-site impacts
to vegetation, terrestrial wildlife, aquatic wildlife, threatened or
endangered species, and ecologically sensitive habitats;
Geologic impacts: potential impacts from the sequestration
of CO2 and other captured gases on underground resources
such as potable water supplies, mineral resources, and fossil fuel
resources;
Ground surface impacts from CO2 sequestration:
potential impacts from leakage of injected CO2, potential
impacts from induced flows of native fluids to the ground surface or
near the ground surface, and the potential for induced ground heave
and/or microseisms;
Fate and stability of sequestered CO2 and other
captured gases;
Health and safety issues associated with CO2
capture and sequestration;
Cumulative effects that result from the incremental
impacts of the proposed project when added to other past, present, and
reasonably foreseeable future projects;
Compliance with regulatory requirements and environmental
permitting;
Environmental monitoring plans associated with the power
plant and with the CO2 sequestration site;
Mitigation of identified environmental impacts; and
Ultimate closure plans for the CO2
sequestration site and reservoirs.
Proposed EIS Schedule
A tentative schedule has been developed for the EIS. The public
scoping period will close on September 13, 2006. The Draft EIS is
scheduled to be issued for public review and comment in March 2007,
followed by a 45-day public comment period and public hearings. The
Final EIS is scheduled to be issued in June 2007, followed by the ROD
in August 2007.
Public Scoping Process
To ensure that all issues related to this proposed action are
addressed, DOE seeks public input to define the scope of the EIS. The
public scoping period will begin with publication of the NOI and end on
September 13, 2006. Interested government agencies, private-sector
organizations and the general public are encouraged to submit comments
or suggestions concerning the content of the EIS, issues and impacts to
be addressed in the EIS, and alternatives that should be considered.
Scoping comments should clearly describe specific issues or topics that
the EIS should address to assist DOE in identifying significant issues.
Written, e-mailed, faxed, or telephoned comments should be received by
September 13, 2006 (see ADDRESSES).
DOE will conduct public scoping meetings at locations, dates and
times specified in a future Federal Register notice and in notices
published in local newspapers. These notices are scheduled to be
published within the next two weeks and will provide the public with at
least two weeks notice. Generally, one scoping meeting will be held
near each proposed power plant site.
An informal session of the public scoping meetings will begin at
approximately 4 p.m., followed by a formal session beginning at
approximately 7 p.m. Members of the public who wish to speak at a
public scoping meeting should contact Mr. Mark L. McKoy, either by
phone, fax, e-mail, or in writing (see ADDRESSES in this Notice). Those
who do not arrange in advance to speak may register at a meeting
(preferably at the beginning of the meeting) and may speak after
previously scheduled speakers. Speakers will be given approximately
five minutes to present their comments. Those speakers who want more
than five minutes should indicate the length of time desired in their
request. Depending on the number of speakers, DOE may need to limit all
speakers to five minutes initially and provide second opportunities as
time permits. Speakers may also provide written materials to supplement
their presentations. Oral and written comments will be given equal
consideration. State and local elected officials and tribal leaders may
be given priority in the order of those making oral comments.
DOE will begin the meeting with an overview of the proposed
FutureGen Project. The meeting will not be conducted as an evidentiary
hearing, and speakers will not be cross-examined. However, speakers may
be asked questions to help ensure that DOE fully understands the
comments or suggestions. A presiding officer will establish the order
of speakers and provide any additional procedures necessary to conduct
the meeting.
Issued in Washington, DC, this 25th day of July, 2006.
Andrew Lawrence,
Acting Assistant Secretary, Environment, Safety and Health.
[FR Doc. E6-12118 Filed 7-27-06; 8:45 am]
BILLING CODE 6450-01-P