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Table 1-2: Abandoned Mines Profiled as Project Candidates
Coal Basin
Piceance
Illinois
Illinois
Uinta
Total
State
Colorado
Illinois
Kentucky
Utah
Number of
Abandoned Mines
Profiled
3
8
1
2
14
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2. Abandoned Mine Projects
10
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Abandoned Mine Project Case Studies
This section includes three case studies of successful abandoned mine methane projects. All
three projects are operating in the Midwestern U.S. The Grayson Hill Energy project, operating in
Southern Illinois, is a pipeline sales project that also uses abandoned mine methane to operate
the project's gas processing plant. The Kings Station Mine project of Gibson County, Indiana is
selling gas through a local pipeline to an automobile plant. The DTE Methane Resources project
is selling abandoned mine methane to a pipeline in Southern Illinois. These particular projects
were selected for profiling based on their level of success and the variety of end uses the projects
present.
Basic information about the projects is outlined in the case studies, such as location and project
developer information, followed by a detailed analysis of each project. Each study explains how
the project was selected and what technology is in use, as well as any barriers that were
overcome.
11
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Grayson Hill Energy Project
1.0 Background Information
1.1 Name of mine or mines included in the project
1 .2 Mine owner and parent company when active
1 .3 Dates of mine abandonment
1.4 Mine methane emissions at time of abandonment (mmcfd)
1 .5 Region/coal seam
1.6 Coal type/rank
1 .7 All involved parties
Project developers
Funding sources
Equipment/technology vendors
1 .8 Project type
Peabody 46 & 43
Brushy Creek #6
O'Gara#1,#14, #8, #10
Deering Wasson
NA
N/A
N/A
Saline County, IL
Illinois 5 &6 Seams
Bituminous
Grayson Hill Energy and Itera International
Energy Corp. are joint project developers.
Privately funded by Itera and Grayson Hill
CAT, JOY, Cummins, and Engelhard
technologies are employed by the project.
Pipeline sales and electricity use for gas
processing plant
1 .9 Project size (MW equivalent or volume of gas produced)
• Approximately 1 .Ommcf/d of 96% methane gas is processed from the plant for pipeline sales to the
nearby 24" Texas Eastern pipeline.
• Their gas processing plant utilizes electricity produced from two 750 Kw coal mine methane-powered
Caterpillar motors.
1.10 Greenhouse gas emissions avoided per year (volume and MMTCO2e)
1.11 First year of operation
1.12 Actual or projected end-date of project
2003
N/A
1.13 Project operator contact information
Gravson Hill Enerqv Itera International Enerqv Corp. (USA)
Chris Schimp Robert Howells
1705 Grayson Road 995 Gate Parkway N #400
Eldorado, IL 62930 Jacksonville, FL 32246
(61 8) 967-3468 Cell (904) 61 8-967-3468 Cell
(61 8) 268-6027 Office (904) 996-8800 Office
graysonenergy@yahoo.com rhowells@itera.com
12
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2.0 Project description
The Initial business was electrical generation from four coal mine methane fueled 750 kw
generators into the local grid. The waste heat was utilized in 16 hydroponic greenhouses
producing 10,000 Ibs. of tomatoes per week. Imports of cheap Canadian fruit by area markets
made this business non-profitable; however, proximity of the Texas Eastern pipeline led to the
Grayson Hill Project's present business plan.
Gas has been produced from the project since 2003 and sold to the 24-inch Texas Eastern
Pipeline which crosses the property owned by Grayson Hill Energy (see Figure A-1).
Figure 2-1: Location of Texas Eastern Pipeline Relative to Grayson Hill Energy Property
.:••..
24" Teppco
pipeline
Grayson Plant
The project has a 50 mile gathering system of 4-inch HOPE pipe, laid by Grayson Hill Energy
using a plow. The gathering system is fed by rotary screw compressors, most of them driven by
6-cylinder Cummins diesel engines. All of these machines are leased.
Grayson Hill Energy installed and commissioned a 2,500 mcfd nitrogen reject unit at the project
site's processing plant. This aspect of the plant began delivering gas in June of 2004. The unit at
the site was built by Guild Associates Inc. of Ohio with adsorbent material manufactured by
Engelhard. Grayson Hill Energy leases a rotary screw compressor at the processing plant which
13
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allows gas to be supplied to the nitrogen rejection unit at 110 psi and has low maintenance and
repair costs. The nitrogen rejection unit is driven by a 250 horsepower electric engine.
The product gas is compressed with a refurbished JOY machine. This compressor is also driven
by a 250 horsepower electric engine and provides gas to the pipeline at 560 to 800 psi.
To protect the plant from the extreme weather in the area, a building has been erected over the
gas processing plant. Rollup doors were fitted to the main openings and two large extractor fans
provide necessary cooling to the plant in the summer.
3.0 Site Location
The site was located by identifying existing underground mines and drilling wells.
4.0 Identification of the Project as an Appropriate Project Candidate
The location is ideal as it is adjacent to the Texas Eastern Pipeline. There are multiple utilization
options available, as is evident by use in hydroponic greenhouses, pipeline sales, and electricity
generation. The market in the area is conducive to the project with the pipeline intersecting the
property as well as sales to the local power grid. There is also the potential for expansion of the
project, as it is possible other abandoned mines in the area may be in communication with the
project.
5.0 Ownership Issues Associated with the Project
The coal owner has the right to capture gas from abandoned mines in the state of Illinois.
Grayson Hill Energy obtained the rights to capture and sell the gas by acquiring leases or
ownership of the coal.
6.0 Testing Procedures and Preliminary Studies Done at the Site
Ongoing gas analysis is conducted on product gas as it is sold to the pipeline. Inert gases are
somewhat of an issue for Grayson Hill Energy creating higher than anticipated losses; however,
the nitrogen rejection unit adjusts for this.
7.0 Type of Project
Ultimately, pipeline sales was selected as the best option at Grayson Hill Energy due to the
proximity of the Texas Eastern Pipeline and the aforementioned market issues associated with
tomato sales. Electrical generation for the gas processing operations is also appropriate here as
opposed to purchasing electricity from the local power grid.
8.0 Difficulties
Any ownership difficulties were addressed by obtaining the appropriate leases for the coal.
Market issues were only encountered in the case of the tomato sales; however, this was
alleviated by altering the course of the project to become a pipeline project. Logistical issues
were not a problem due to the ideal location of the project and it's proximity to the pipeline.
Technically, issues were encountered due to inert gas content; however, the nitrogen rejection
unit is adjusted to address this. The Grayson Hill Energy project is the first CMM project in the
United States to utilize a molecular gate nitrogen rejection unit.
14
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Kings Station Mine Project
1.0 Background Information
1.1 Name of mine or mines included in the project
Kings Station
1.2 Mine owner and parent company when active
Kings Station Coal Company
1.3 Dates of mine abandonment
10/26/1973
1.4 Mine methane emissions at time of abandonment (mmcfd)
0.35 mmcfd
1.5 Region/coal seam
Gibson County, IN
Illinois 5 &6 seams
1.6 Coal type/rank
Bituminous
1.7 All involved parties
Project developers
Roy Farmer and C.A. Robinson
Funding sources
Roy Farmer and C.A. Robinson
Equipment/technology vendors
Arial compressors, de-hy is QB Johnson,
Amine Units is Sivallis.
1.8 Project type
Gas supply to local automobile plant
1.9 Project size (MW equivalent or volume of gas produced) 150-200 mcfd
1.10 Greenhouse gas emissions avoided per year (volume and MMTCO2e)
NA
1.11 First year of operation
October 1997
1.12 Actual or projected end-date of project
Unkown
1.14 Project operator contact information
Roy Farmer
4353 Hy. 41 South
Princeton, IN 47670
(812)-677-2121 Office
rfarmer@coalmethane.com
2.0 Project Description
The Kings Station Project has two gas processing plants and sells gas to an adjacent Toyota
Truck Plant, located across Highway 41 from the gas plant. The mine has a total of five drainage
wells; however, three of these have encountered flooded areas of the mine. The gas processing
plant was constructed for the two wells drilled into the dry areas of the mine. These two wells
produce a cumulative of 150-200mcf/d of gas from the mine, consisting of 920-930 BTU gas (6%
CO2 and 1% N2). The King Station's gas processing plant is relatively small compared to DTE
Energy and Grayson Hill Energy's plants. It consists of a gas fired compressor, heat exchanger,
amine unit, and a dehydration unit. The mine gas is upgraded to 1,000 BTU by injecting it with
propane before it is sent to the Toyota Plant via a pipeline.
15
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3.0 Site Location
A refinery had drilled holes for disposal into the mine and reported gas. Roy Farmer took over
one of the water disposal wells for water disposal from the mine, and began drilling new
production wells over the mine and began producing gas. Gas from the mine is free flowed to the
compressor at 4-5 psi.
4.0 Identification of the Project as an Appropriate Project Candidate
The proximity of the Toyota Truck Plant provided the opportunity for gas sales at the Kings
Station Project. Though not being utilized as an option at this time, there is also a pipeline
approximately two miles from the gas processing plant as well.
It is believed that nearby abandoned mine sites may be in communication with the project,
opening up the possibility for expansion as well.
5.0 Ownership Issues Associated with the Project
The rights to the gas are owned either by the coal lessee or the lessee of CBM rights. The
project developers have encountered no ownership difficulties; however, damages are always
paid to surface owners when access is required for drilling new wells.
6.0 Testing Procedures and Preliminary Studies Done at the Site
Prior to the project, gas analysis and open hole flow testing were done for approximately 20 to 30
days.
7.0 Type of Project
The nearby Toyota Truck Plant provided an ideal opportunity to utilize the abandoned mine
methane from the Kings Station Mine. The King Station Project has a contract with the Toyota
Plant requiring the project to supply a minimum of 10% of their daily requirement, which is
presently 5mmcf/d.
8.0 Difficulties
The project developers have not identified any difficulties other than flooded portions of the mine.
16
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DTE Methane Resources Project
1.0 Background Information
1.1 Name of mine or mines included in the project
1 .2 Mine owner and parent company when active
1 .3 Dates of mine abandonment
1.4 Mine methane emissions at time of abandonment (mmcfd)
1 .5 Region/coal seam
1.6 Coal type/rank
1 .7 All involved parties
Project developers
Equipment/technology vendors
Funding Sources
1 .8 Project type
Interstate 22
Old Ben Coal 8
Old Ben Coal 14
Old Ben Coal 19
Old Ben Coal 21
Old Ben Coal 24
Old Ben Coal 26
Burlington Northern 15
Burlington Northern 22
Orient 1
Ziegler 1
Old Ben Coal Company & Orient Coal
Company
Old Ben Coal 24 and Old Ben Coal 26
abandoned 7/10/1998. Old Ben Coal 21
abandoned 11/13/1995. Dates unknown on
others.
From 1.2 to 1.6 mmcfd.
Franklin County, IL
Herrin No. 6 Seam
Bituminous
Illinois Methane developed the project. DTE
Methane Resources bought the project from
Illinois Methane and is now operating.
Compressors: Arial/Cat driven
Amine Unit: Dicks & Tryer
The nitrogen rejection unit is provided by
BCCK.
End use of the gas is pipeline sales to the
Trunkline Gas Company.
Funding is internal.
Pipeline sales
1 .9 Project size (MW equivalent or volume of gas produced)
NA
1.10 Greenhouse gas emissions avoided per year (volume and MMTCO2e)
NA
17
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1.11 First year of operation
September 2002
1.12 Actual or projected end-date of project
Unknown
1.14 Project operator contact information
Matt Smith (Michigan)
(734) 913-6043 Office
(734) 548-0884 Cell
Phil Coleman (Michigan)
425 South Main Street, Suite 201
Ann Arbor, Ml 48104
(734) 913-6284 Office
(734) 730-4870 Cell
Mark Benifel (Mt. Vernon, manager)
20227 Thorn Rd
Thompsonville, IL 62890
(618) 982-9710 Office Gas Plant
2.0 Project Description
DTE Methane Resources operates the Corinth Gas Processing Plant. Mine gas is delivered to
this plant via a 29 mile gas line with several compressor stations along the way. DTE is presently
producing 5.5mmcf/d from 16 wells out of 10 abandoned mines. Gas produced from these mines
average 750 BTU (17% N2 and 9% CO2). DTE uses a BCCK Nitrogen Rejection Unit (NRU) to
strip the N2 and CO2 from the mine gas. Electricity is purchased from the local utility to run the
gas plant at the price of approximately $15k per month. The amount of gas processed for sales
is undisclosed. Product gas is sold to the Trunkline Gas Company's pipeline which is
approximately one half mile from the plant.
3.0 Site Location
Acquisition of an existing project provided historical data for evaluation of productive potential.
4.0 Identification of the Project as an Appropriate Project Candidate
A site survey and economic analysis was conducted at the site. Also, proximity to the Trunkline
Gas Company's pipeline provides the necessary infrastructure for this pipeline project.
5.0 Ownership Issues Associated with the Project
In Illinois, the coal owner has ownership of coal mine methane. A surface agreement is typically
executed with the surface owner involving payment of damages and compensation. No royalties
are involved. Title research regarding ownership has prevented any ownership issues.
6.0 Testing Procedures and Preliminary Studies Done at the Site
Acquired production, well, and gas composition data are done at the DTE project site.
7.0 Type of Project
A pipeline sales project was selected at this location due to proximity to the Trunkline Gas
Company's pipeline. DTE acquired this project from Illinois Methane, which was already
employing the compressor technology and conducting pipeline sales upon acquisition.
8.0 Difficulties
Due to the proximity of the pipeline, market issues are not a difficulty encountered by the DTE
project. A consistent logistical problem at the project is acquiring easement rights to install flow
lines on land where DTE Methane Resources does not have coal mine methane rights.
Ownership of the methane, however, is not a problem due to coal mine methane rights residing
18
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with DTE as the coal mineral owner. The gas processing plant required adjustment to match gas
production, resulting in the plant and field compressor capacities being decreased from 12 mmcfd
to 6 mmcfd.
19
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3. Potential Abandoned Mine Project Sites
20
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Abandoned Mine Profiles
This section profiles 14 abandoned mines that may be considered as project sites. Many of these
mines were selected based on the amount of methane liberated when active and thus the power
generation or pipeline sales potential estimated. Others, such as those in the Illinois basin, where
the time of abandonment prohibits methane liberation information from being obtained by MSHA,
are selected due to proximity to known project successes. A number of the mines profiled are
also part of a complex of mines, such as the Willow Creek and Kenilworth mines of Utah and the
Jefferson County and Macoupin county groups of Illinois. Notable in the case studies of Section
2, larger scale abandoned mine methane projects such as Grayson Hills and DTEMR involve a
complex of mines, thus providing enough methane for an economically feasible project.
Information provided in the profiles, such as availability for end uses, estimated power generation
and/or pipeline sales potential, and ownership information may be used in identifying prospective
abandoned mine methane projects. The report also includes mine maps which may be helpful to
potential project developers.
Table 3-1 below summarizes the mines profiled in this report by the coal basin in which they are
located and key statistics relevant to project potential.
Table 3-1: Abandoned Mines Profiled
Basin
Piceance
Piceance
Piceance
Uinta
Uinta
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Mine Name
Sanborn Creek
Hawk's Nest**
Bowie No. 1
Willow Creek
Kenilworth**
Orient 3**
Orient 6
Nasson 20**
Little Dog**
Superior 1**
Superior 2**
Superiors**
Superior 4**
Baker
Estimated
Emissions at
Abandonment
(mmcf/day)
5.0
NA
0.11
2.0
NA
NA
0.7
NA
NA
NA
NA
NA
NA
1.51
Estimated Power
Generating
Capacity (MW)*
7.6
NA
0.6
3.0
NA
NA
1.0
NA
NA
NA
NA
NA
NA
2.3
Estimated
Pipeline Sales
Potential (Bcf)*
0.7
NA
0.06
0.30
NA
NA
0.1
NA
NA
NA
NA
NA
NA
0.2
Assuming 40% recovery efficiency. Other estimates are provided in profiles below.
* Emissions from the pre-1972 mines are characterized using the methodology described in
USEPA (2004) on a regional, not individual mine basis. This prevented reporting on individual
production and emissions from mines abandoned before 1972 as part of the profiling done in
this report.
21
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Piceance Basin Mines
22
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Updated: 7/10/2008
Sanborn Creek
GEOGRAPHIC DATA
Basin: Piceance
Coalbed: D Seam
CORPORATE INFORMATION
Operator When Active: Oxbox Mining, LLC
Current/Most Recent Controller: Oxbow Carbon & Minerals, Inc.
Previous Owner (s): Somerset Mining Company
Previous or Alternate Name of Mine: None
Status: Abandoned
State: CO
County: Gunnison
ADDRESS
Contact Name: Robert Koch Phone Number: (970)929-5122
Operator Main Address: 7901 S. Park Plaza, Ste. 202
City: Littleton State: CO ZIP: 80120
Address When Active: PO Box 535
City: Somerset State: CO ZIP: 81434
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: 119 Mining Method: Longwall
Year of Initial Production: 1991 Primary Coal Use: Steam/Metallurgical
Date of Abandonment: 10/1/2003
BTUs/lb of Coal Produced: 12,370 Coal Type: Bituminous
Depth to Seam (ft): 1,500 - 2,000 Seam Thickness (ft): 9 -12
PRODUCTION, VENTILATION AND DRAINAGE DATA
1999
2000
2001
2002
Coal Production (million short tons/year):
Estimated Total Methane Liberated (million cf/day):
Emission from Ventilation Systems:
Estimated Methane Drained:
Estimated Specific Emissions (cf/ton):
Estimated Drainage Efficiency at Mine Closure: 25%
2003
1.1
5.3
5.3
0.0
1759
2.2
7.0
5.3
1.7
1161
2.8
7.0
5.2
1.8
913
2.5
5.4
4.1
1.3
788
0.5
5.0
-
-
_
23
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Sanborn Creek (continued)
ENERGY AND ENVIRONMENTAL VALUE OF EMISSIONS REDUCTIONS
Assumed Potential Recovery Efficiency
(Based on 2003 data) 20% 40% 60%
CO2 Equivalent of CH4 Emissions Reductions (mm tons) 0.2 0.3 0.5
Power Generation Potential
Utility Electric Supplier:
Parent Corporation of Utility:
MW GWh/year
Potential Generating Capacity (2003 data)
Assuming 20% Recovery Efficiency: 3.8 33.3
Assuming 40% Recovery Efficiency: 7.6 66.5
Assuming 60% Recovery Efficiency: 11.4 99.8
Pipeline Sales Potential
Potential Annual Gas Sales (2003 data) Bcf
Assuming 20% Recovery (Bcf): 0.4
Assuming 40% Recovery (Bcf): 0.7
Assuming 60% Recovery (Bcf): 1.1
Description of Surrounding Terrain: Mountains
Transmission Pipeline in County? Yes
Owner of Nearest Pipeline: Rocky Mountain Natural Gas
Distance to Pipeline (miles): < 25
Pipeline Diameter (in): 8.0
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles):
Comments: Gas well drilling (CBM) to the north may eventually provide a gas pipeline for a project.
24
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Updated: 7/10/2008
Hawk's Nest
GEOGRAPHIC DATA
Basin: Piceance
Coalbed: E Seam
CORPORATE INFORMATION
Operator When Active: Western Slope Carbon
Current/Most Recent Controller: Oxbow Mining, LLC
Previous Owner (s): Champion Coal Company
Previous or Alternate Name of Mine: Hawk's Nest East/West
Status: Abandoned
State: CO
County: Gunnison
ADDRESS
Contact Name: Robert Koch
Operator Main Address: 7901 S. Park Plaza, Ste. 202
City: Littleton
Address When Active: PO Box 535
City: Somerset
Phone Number: (970)929-5122
State: CO ZIP: 80120
State: CO ZIP: 81434
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: NA
Year of Initial Production: Pre-1972
Date of Abandonment: 1/3/1986
BTUs/lbof Coal Produced: NA
Depth to Seam (ft): NA
Mining Method: Longwall
Primary Coal Use: Steam/Metallurgical
Coal Type: Bituminous
Seam Thickness (ft): NA
Pipeline Sales Potential
Description of Surrounding Terrain: Mountains
Transmission Pipeline in County? Yes
Owner of Nearest Pipeline: Rocky Mountain Natural Gas
Distance to Pipeline (miles): < 25
Pipeline Diameter (in): 8.0
Owner of Next Nearest Pipeline: NA
25
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Hawk's Nest (continued)
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter: NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments: Gas well drilling (CBM) to the north may eventually provide a gas pipeline for a project.
26
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Figure 3-1: Sanborn Creek and Hawk's Nest Mines
fTForkGunnison River
Sanborn Creek Mine
Hawk's Nest Mine
0 1000 FT
27
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Updated: 7/10/2008 Status: Abandoned
Bowie No. 1
GEOGRAPHIC DATA
Basin: Piceance State: CO
Coalbed: B Seam County: Delta
CORPORATE INFORMATION
Operator When Active: Bowie Resources, Ltd.
Current/Most Recent Controller: Horizon Natural Resources
Previous Owner (s): Cyprus Orchard Valley Coal Corp.
Previous or Alternate Name of Mine: None
ADDRESS
Contact Name: Bill Bear Phone Number: (970) 929-5257
Operator Main Address: 1855 Old Hwy. 133
City: Somerset State: CO ZIP: 81434
Address When Active: PO Box 1488
City: Paonia State: CO ZIP: 81428
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: 53 Mining Method: Continuous
Year of Initial Production: 1986 Primary Coal Use: Steam
Date of Abandonment: 12/10/1998
BTUs/lbof Coal Produced: 11,312 Coal Type: Bituminous
Depth to Seam (ft): Seam Thickness (ft): 14
PRODUCTION, VENTILATION AND DRAINAGE DATA
1994 1995 1996 1997 1998
Coal Production (million short tons/year): 0.71 0.41 0.61 0.76 0.0
Estimated Total Methane Liberated (million cf/day): 0.0 0.0 0.2 1.14 0.11
Emission from Ventilation Systems: 0.0 0.0 0.0 1.14 0.11
Estimated Methane Drained: 0.0 0.0 0.0 0.0 0.0
Estimated Specific Emissions (cf/ton): - - 120 548
Methane Recovered (million cf/day): 0.0 0.0 0.0 0.0 0.0
Estimated Drainage Efficiency at Mine Closure: 0%
28
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Bowie No. 1 (continued)
ENERGY AND ENVIRONMENTAL VALUE OF EMISSIONS REDUCTIONS
Assumed Potential Recovery Efficiency
(Based on 1998 data) 20% 40% 60%
CO2 Equivalent of CH4 Emissions Reductions (mm tons) 0.0 0.0 0.0
Power Generation Potential
Utility Electric Supplier: Delta - Montrose Electric Coop.
Parent Corporation of Utility: Touchstone Energy Cooperatives
MW GWh/year
Potential Generating Capacity (1998 data)
Assuming 20% Recovery Efficiency: 0.3 2.6
Assuming 40% Recovery Efficiency: 0.6 5.3
Assuming 60% Recovery Efficiency: 0.9 7.9
Pipeline Sales Potential
Potential Annual Gas Sales (1998 data) Bcf
Assuming 20% Recovery (Bcf): 0.03
Assuming 40% Recovery (Bcf): 0.06
Assuming 60% Recovery (Bcf): 0.10
Description of Surrounding Terrain: Mountains
Transmission Pipeline in County? Yes
Owner of Nearest Pipeline: Rocky Mountain Natural Gas
Distance to Pipeline (miles): <25
Pipeline Diameter (in): 8.0
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments: Gas well drilling (CBM) to the north may eventually provide a gas pipeline for a project.
29
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Figure 3-2: Bowie #1 Mine
30
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Uinta Basin Mines
31
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Updated: 7/10/2008
Willow Creek
GEOGRAPHIC DATA
Basin: Uinta State: UT
Coalbed: Bookcliffs Coal Field, Castlegate D Seam County: Carbon
CORPORATE INFORMATION
Operator When Active: Plateau Mining Corp.
Current/Most Recent Controller: Foundation Coal Company
Previous Owner (s): Amwest Exploration Company, Cyprus Plateau Mining Corp.
Previous or Alternate Name of Mine: None
Status: Abandoned
ADDRESS
Contact Name: Dennis Ware
Address: PO Box 30
City: Helper
Address When Active: 847 NW Hwy 191
City: Helper
Phone Number: (435) 472-4737
State: UT ZIP: 84526
State: UT ZIP: 84526
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: 267 Mining Method: Longwall
Year of Initial Production: 1996 Primary Coal Use: Steam
Date of Abandonment: 8/3/2003
BTUs/lb of Coal Produced: 12,825 (average) Coal Type: Bituminous
Depth to Seam (ft): NA Seam Thickness (ft): 8 to 20 feet
PRODUCTION, VENTILATION AND DRAINAGE DATA
Coal Production (million short tons/year):
Estimated Total Methane Liberated (million cf/day):
Emission from Ventilation Systems:
Estimated Methane Drained:
Estimated Specific Emissions (cf/ton):
Estimated Drainage Efficiency at Mine Closure: NA
1999
2000
2001
2002
2003
0.5
1.63
1.63
0
1.3
NA
NA
0
0
1.12
1.12
0
0
0.56
0.56
0
0
2.0
2.0
0
32
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Willow Creek (continued)
ENERGY AND ENVIRONMENTAL VALUE OF EMISSIONS REDUCTIONS
Assumed Potential Recovery Efficiency
(Based on 2003 data) 20% 40% 60%
CO2 Equivalent of CH4 Emissions Reductions (mm tons) 0.0 0.1 0.2
Power Generation Potential
Utility Electric Supplier:
Parent Corporation of Utility:
MW GWh/year
Potential Generating Capacity (2003 data)
Assuming 20% Recovery Efficiency: 1.5 13.0
Assuming 40% Recovery Efficiency: 3.0 26.0
Assuming 60% Recovery Efficiency: 4.6 40.0
Pipeline Sales Potential
Potential Annual Gas Sales (2003 data) Bcf
Assuming 20% Recovery (Bcf): 0.15
Assuming 40% Recovery (Bcf): 0.30
Assuming 60% Recovery (Bcf): 0.44
Description of Surrounding Terrain: Tablelands; Open High/Low Mountains
Transmission Pipeline in County? Yes
Owner of Nearest Pipeline: Questar Pipeline Company
Distance to Pipeline (miles): NA
Pipeline Diameter (in): 20.0
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: Utah Power Carbon Plant
Distance to Plant (miles): 1
Comments:
33
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Updated: 7/10/2008 Status: Abandoned
Kenilworth
GEOGRAPHIC DATA
Basin: Uinta State: UT
Coalbed: Kenilworth Seam County: Carbon
CORPORATE INFORMATION
Operator When Active: North American Coal Company
Current/Most Recent Controller: United States Bureau of Land Management, Price, UT
Previous Owner (s): Price River Coal Company, Independent Coal & Coke Company
Previous or Alternate Name of Mine:
ADDRESS
Contact Name: Sue Burger Phone Number: (435) 636-3651
Address: BLM 125 S 600 W
City: Price State: UT ZIP: 84501
Address When Active:
City: Kenilworth State: UT ZIP: 84529
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: NA Mining Method: Longwall
Year of Initial Production: Pre-1972 Primary Coal Use: Steam
Date of Abandonment: October 1960
BTUs/lb of Coal Produced: NA Coal Type: Bituminous
Depth to Seam (ft): Seam Thickness (ft):
Pipeline Sales Potential
Description of Surrounding Terrain: Tablelands; Open High/Low Mountains
Transmission Pipeline in County? Yes
Owner of Nearest Pipeline: Questar Pipeline Company
Distance to Pipeline (miles): NA
Pipeline Diameter (in): 20.0
Owner of Next Nearest Pipeline: NA
34
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Kenilworth (continued)
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: Utah Power Carbon Plant
Distance to Plant (miles): 2
Comments:
35
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Figure 3-3: Kenilworth and Willow Creek Mines
Kenilworth Mine
Willow Creek Mine
Castlegate C Mines
Castlegate B Mines
36
-------
Illinois Basin Mines
37
-------
Jefferson County Group
Updated: 7/10/2008 Status: Abandoned
Orient 3
GEOGRAPHIC DATA
Basin: Illinois State: IL
Coalbed: Herrin #6 County: Jefferson
CORPORATE INFORMATION
Operator When Active: Freeman United Coal Mining Co.
Current/Most Recent Controller: Crown Family
Previous Owner (s): Egyptian Energies
Previous or Alternate Name of Mine:
ADDRESS
Contact Name: Bill Kolf Phone Number: (312) 899-4964
Address: NA
City: Waltonville State: IL ZIP: NA
Address When Active: Freeman United Coal Mining Co., 4400 Ash Grove Drive, Suite A
City: Springfield State: IL ZIP: 62708
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: NA Mining Method: Longwall
Year of Initial Production: NA Primary Coal Use: Steam
Date of Abandonment: 2/1/1984
BTUs/lb of Coal Produced: NA Coal Type: Bituminous
Depth to Seam (ft): 685 Seam Thickness (ft): 9.5
Pipeline Sales Potential
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
38
-------
Orient 3 (continued)
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
39
-------
Jefferson County Group
Updated: 7/10/2008 Status: Abandoned
Orient 6
GEOGRAPHIC DATA
Basin: Illinois State: IL
Coalbed: Herrin No. 6 County: Jefferson
CORPORATE INFORMATION
Operator When Active: Freeman United Coal Mining Co.
Current/Most Recent Controller: Crown Family
Previous Owner (s): Egyptian Energies
Previous or Alternate Name of Mine:
ADDRESS
Contact Name: Bill Kolf Phone Number: (312) 899-4964
Address:
City: Waltonville State: IL ZIP:
Address When Active: Freeman United Coal Mining Co., 4400 Ash Grove Drive, Suite A
City: Springfield State: IL ZIP: 62708
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: Mining Method: Longwall
Year of Initial Production: Primary Coal Use: Steam
Date of Abandonment: 3/13/1997
BTUs/lb of Coal Produced: Coal Type: Bituminous
Depth to Seam (ft): 700 Seam Thickness (ft): 7
PRODUCTION, VENTILATION AND DRAINAGE DATA
1993 1994 1995 1996 1997
Coal Production (million short tons/year): 1.3 1.4 1.4 1.1 0.25
Estimated Total Methane Liberated (million cf/day): 0.8 0.7 0.8 0.7
Emission from Ventilation Systems: 0.8 0.7 0.8 0.7
Estimated Methane Drained: 00000
Estimated Specific Emissions (cf/ton): 224 183 209 232
Estimated Drainage Efficiency at Mine Closure: NA
40
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Orient 6 (continued)
ENERGY AND ENVIRONMENTAL VALUE OF EMISSIONS REDUCTIONS
(Based on 1996 Data)
CC>2 Equivalent of ChU Emissions Reductions (mm tons)
Assumed Potential Recovery Efficiency
20% 40% 60%
0.0
0.0
0.0
Power Generation Potential
Utility Electric Supplier:
Parent Corporation of Utility:
Potential Generating Capacity (1996 data)
Assuming 20% Recovery Efficiency:
Assuming 40% Recovery Efficiency:
Assuming 60% Recovery Efficiency:
Pipeline Sales Potential
Potential Annual Gas Sales (1996 data)
Assuming 20% Recovery (Bcf):
Assuming 40% Recovery (Bcf):
Assuming 60% Recovery (Bcf):
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
MW
0.5
1.0
1.6
GWh/year
4.5
9.1
13.8
Bcf
0.05
0.1
0.16
41
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Jefferson County Group
Updated: 7/10/2008
Nasson 20
GEOGRAPHIC DATA
Basin: Illinois
Coalbed: Herrin #6
CORPORATE INFORMATION
Operator When Active: Bell & Zoller
Current/Most Recent Controller: NA
Previous Owner (s): NA
Previous or Alternate Name of Mine: NA
Status: Abandoned
State: IL
County: Jefferson
ADDRESS
Contact Name: NA
Address: NA
City: Waltonville
Address When Active: NA
City: NA
Phone Number: NA
State: IL
State: IL
ZIP: NA
ZIP: NA
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: Mining Method: Longwall
Year of Initial Production:
Date of Abandonment:
BTUs/lb of Coal Produced:
Primary Coal Use: Steam
Depth to Seam (ft): 700
Coal Type: Bituminous
Seam Thickness (ft): 7
Pipeline Sales Potential
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
42
-------
Nasson 20 (continued)
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
43
-------
Figure 3-4: Jefferson County Group
44
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Macoupin County Group
Updated: 7/10/2008 Status: Abandoned
Little Dog
GEOGRAPHIC DATA
Basin: Illinois State: IL
Coalbed: Herrin #6 County: Macoupin
CORPORATE INFORMATION
Operator When Active: Florida Coal Company
Current/Most Recent Controller: Norfork Western
Previous Owner (s): NA
Previous or Alternate Name of Mine: NA
ADDRESS
Contact Name: NA Phone Number: NA
Address: NA
City: NA State: NA ZIP: NA
Address When Active: NA
City: NA State: IL ZIP: NA
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: Mining Method: Room & Pillar
Year of Initial Production: 1941 Primary Coal Use: NA
Date of Abandonment: 1968
BTUs/lb of Coal Produced: NA Coal Type: Bituminous
Depth to Seam (ft): 325' Seam Thickness (ft): 6.5
Pipeline Sales Potential
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
45
-------
Little Dog (continued)
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
46
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Macoupin County Group
Updated: 7/10/2008 Status: Abandoned
Superior 1
GEOGRAPHIC DATA
Basin: Illinois State: IL
Coalbed: Herrin #6 County: Macoupin
CORPORATE INFORMATION
Operator When Active: Superior Coal Company
Current/Most Recent Controller: Ayshire Land Co.
Previous Owner (s): NA
Previous or Alternate Name of Mine: NA
ADDRESS
Contact Name: NA Phone Number: NA
Address: NA
City: NA State: NA ZIP: NA
Address When Active: NA
City: NA State: IL ZIP: NA
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: NA Mining Method: Room & Pillar
Year of Initial Production: 1904 Primary Coal Use: NA
Date of Abandonment: 1952
BTUs/lb of Coal Produced: NA Coal Type: Bituminous
Depth to Seam (ft): 325 Seam Thickness (ft): 7
Pipeline Sales Potential
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
47
-------
Superior 1 (continued)
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
48
-------
Macoupin County Group
Updated: 7/10/2008 Status: Abandoned
Superior 2
GEOGRAPHIC DATA
Basin: Illinois State: IL
Coalbed: Herrin #6 County: Macoupin
CORPORATE INFORMATION
Operator When Active: Superior Coal Company
Current/Most Recent Controller: Ayshire Land Co.
Previous Owner (s): NA
Previous or Alternate Name of Mine: NA
ADDRESS
Contact Name: NA Phone Number:
Address: NA
City: NA State: NA ZIP: NA
Address When Active: NA
City: NA State: IL ZIP: NA
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: Mining Method: Room & Pillar
Year of Initial Production: 1904 Primary Coal Use:
Date of Abandonment: 1954
BTUs/lbof Coal Produced: NA Coal Type: Bituminous
Depth to Seam (ft): 300' Seam Thickness (ft): 7
Pipeline Sales Potential
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
49
-------
Superior 2 (continued)
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
50
-------
Macoupin County Group
Updated: 7/10/2008 Status: Abandoned
Superior 3
GEOGRAPHIC DATA
Basin: Illinois State: IL
Coalbed: Herrin #6 County: Macoupin
CORPORATE INFORMATION
Operator When Active: Superior Coal Co.
Current/Most Recent Controller: Ayshire Land Co.
Previous Owner (s): NA
Previous or Alternate Name of Mine: NA
ADDRESS
Contact Name: NA Phone Number: NA
Address: NA
City: NA State: NA ZIP: NA
Address When Active: NA
City: NA State: IL ZIP: NA
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: Mining Method: Room & Pillar
Year of Initial Production: 1906 Primary Coal Use: NA
Date of Abandonment: 1968
BTUs/lbof Coal Produced: NA Coal Type: Bituminous
Depth to Seam (ft): 325' Seam Thickness (ft): 7
Pipeline Sales Potential
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
Owner of Next Nearest Pipeline: NA
51
-------
Superior 3 (continued)
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
52
-------
Macoupin County Group
Updated: 7/10/2008
Superior 4
GEOGRAPHIC DATA
Basin: Illinois
Coalbed: Herrin #6
CORPORATE INFORMATION
Operator When Active: Superior Coal Company
Current/Most Recent Controller: Ayshire Land Co.
Previous Owner (s): NA
Previous or Alternate Name of Mine: NA
ADDRESS
Status: Abandoned
State: IL
County: Macoupin
Contact Name: NA
Address: NA
City: NA
Address When Active: NA
City: NA
Phone Number: NA
State: NA ZIP: NA
State: IL
GENERAL INFORMATION
ZIP: NA
Number of Employees at Mine at Last Operation: NA
Year of Initial Production: 1918
Date of Abandonment: 1954
BTUs/lb of Coal Produced: NA
Depth to Seam (ft): 300'
Mining Method: Room & Pillar
Primary Coal Use: NA
Coal Type: Bituminous
Seam Thickness (ft): 7
Description of Surrounding Terrain: Flat
Transmission Pipeline in County? NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Pipeline Diameter (in): NA
Pipeline Sales Potential
53
-------
Superior 4 (continued)
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: NA
Distance to Plant (miles): NA
Comments:
54
-------
Figure 3-5: Macoupin County Group
Nlacoupm County Mines
Explanation
Madison
55
-------
Updated: 7/10/2008
Baker
GEOGRAPHIC DATA
Basin: Illinois
Coalbed: W. Kentucky No. 13
CORPORATE INFORMATION
Operator When Active: Ohio County Coal Company
Current/Most Recent Controller: Peabody Energy
Previous Owner (s): Lodestar Energy, Inc.; The Renco Group
Previous or Alternate Name of Mine: Pyro/Baker
Status: Abandoned
State: KY
County: Webster
ADDRESS
Contact Name: Peabody Energy
Address: 701 Market Street
City: St. Louis
Address When Active: 735 St. Route 857
City: Clay
Phone Number: (314) 342-3400
State: MO ZIP: 63101
State: KY ZIP: 42404
GENERAL INFORMATION
Number of Employees at Mine at Last Operation: 390 Mining Method: Longwall/Continuous
Year of Initial Production: NA Primary Coal Use: Steam
Date of Abandonment: 4/4/2005
BTUs/lb of Coal Produced: 9,400 (average) Coal Type: Bituminous
Depth to Seam (ft): 800 - 1,000 Seam Thickness (ft): 6.0
PRODUCTION, VENTILATION AND DRAINAGE DATA
1999
2000
2001
2002
2003
Coal Production (million short tons/year):
Estimated Total Methane Liberated (million cf/day):
Emission from Ventilation Systems:
Estimated Methane Drained:
Estimated Specific Emissions (cf/ton):
Estimated Drainage Efficiency at Mine Closure: NA
4.48
2.20
1.98
0.22
179
4.28
2.19
2.19
0
187
3.36
3.37
3.37
0
366
2.87
2.27
2.27
0
289
0.61
1.51
1.51
0
898
56
-------
Baker (continued)
ENERGY AND ENVIRONMENTAL VALUE OF EMISSIONS REDUCTIONS
Assumed Potential Recovery Efficiency
(Based on 2003 data) 20% 40% 60%
CO2 Equivalent of CH4 Emissions Reductions (mm tons) 0.0 0.1 0.1
Power Generation Potential
Utility Electric Supplier: Kentucky Utilities Co.
Parent Corporation of Utility: KU Energy
MW GWh/year
Potential Generating Capacity (2003 data)
Assuming 20% Recovery Efficiency: 1.1 10.0
Assuming 40% Recovery Efficiency: 2.3 20.0
Assuming 60% Recovery Efficiency: 3.4 30.1
Pipeline Sales Potential
Potential Annual Gas Sales (2003 data) Bcf
Assuming 20% Recovery (Bcf): 0.1
Assuming 40% Recovery (Bcf): 0.2
Assuming 60% Recovery (Bcf): 0.3
Description of Surrounding Terrain: Open hills
Transmission Pipeline in County? No
Owner of Nearest Pipeline: Texas Gas Transmission
Distance to Pipeline (miles): 8.3
Pipeline Diameter (in): 26.0
Owner of Next Nearest Pipeline: NA
Distance to Next Nearest Pipeline (miles): NA
Pipeline Diameter (in): NA
Other Utilization Possibilities
Name of Nearby Coal Fired Power Plant: None
Distance to Plant (miles): NA
Comments:
57
-------
Figure 3-6: Baker Mine
.
.. . - / •. •
-, V "x *
• , ".
".•"' " • •
••" f> &
TaAin
Adjacent Abandoned Mines
Baker Mine
.-•' .-
^w"-
- • \
". .
'
58
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References
IPCC (Intergovernmental Panel on Climate Change) 1997. Revised 1996IPCC Guidelines for
National Greenhouse Gas Inventories. Japan. 1997
Keystone. 1997-2001. Keystone Coal Industry Manual. Years 1997, 1998, 1999, 2000, 2001,
2002, 2003, 2004, and 2005. Chicago, Illinois: Maclean Hunter Publishing Co.
MSHA (Mine Safety and Health Administration). Online, http://www.msha.gov
USEPA (U.S. Environmental Protection Agency). 2004. Methane Emissions from Abandoned
Mines in the United States: Emission Inventory Methodology and 1990-2002 Estimates.
USEPA (U.S. Environmental Protection Agency). 2006. Inventory of U.S. Greenhouse Gas
Emissions and Sinks 1990-2004, Office of Atmospheric Programs, USEPA # 430-R-06-
002. April 2006.
59
-------
References and Calculations Used in the Mine Profiles
Data Item
Geographic Data (State,
County, Basin, Coalbed)
Corporate Information:
Current Owner
Previous Owner
Parent Company
Phone/Address/Contact
Information
General Information:
Number of Employees
Year of Initial Production
Mining Method
Primary Use
Production, Ventilation, and
Drainage Data
Coal Production
Emissions from
Ventilation Systems
Estimated Methane
Drained
Estimated Total Methane
Liberated
Energy and Environmental
Value
CO2 Equivalent of
Methane Emissions
Sources
Keystone Manual
Past versions of Keystone
Coal Manual and recent
coal industry publications
Past versions of Keystone
Coal Manual
Past versions of Keystone
Coal Manual
Past versions of Keystone
Coal Manual
Past versions of Keystone
Coal Manual
MSHA; Past versions of
Keystone Coal Manual and
articles in coal industry
publications
Past versions of Keystone
Coal Manual
Past versions of Keystone
Coal Manual
MSHA
MSHA
The number of mines
assumed to have drainage
systems is based on calls
to individual MSHA
districts.
Global Warming Potential
of Methane Compared to
Calculations
Sum of "emissions from ventilation
systems" and "estimated methane
drained."
60
-------
Data Item
Reductions (mm tons)
Power Generation Potential
Electricity Supplier
Potential Electric
Generating Capacity
Pipeline Potential
Potential Annual Gas
Sales
Sources
CO2 based on IPCC
(1997). GWPis21 over
100 years.
Directory of Electric Utilities
Calculations
Capacity = Estimated CH4 liberated
in cf/day x recovery
efficiency x 1 day/24
hours x 1 000 BTUs/cf x
kwh/11000BTUs
Estimated methane liberated (mmcf/d) x
365 days/yrx recovery efficiency
61
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