EPA 430-K-18-001
Identifying Opportunities for Methane Recovery
at U.S. Coal Mines: Profiles of Selected Gassy
Underground Coal Mines (2002-2016)
Updated July 2019
U.S. FP
Coalbed Methane
Executive Summary
This report provides information about specific opportunities to develop methane recovery and use
projects at large, underground coal mines in the United States (U.S.)- It contains profiles of the
35 gassiest U.S. coal mines (by state in Chapter 4), and provides details about ongoing recovery
and use projects at 13 of these mines (Table 4-13). The U.S. Environmental Protection Agency
(EPA) designed the profiles to help mine owner/operators and project developers perform an initial
screening of potential projects. While the mines profiled in this report appear to be good candidates
for a coal mine methane (CMM) project, a detailed evaluation would need to be done on a site-
specific basis to determine whether the development of a specific methane recovery and use
project is technically and economically feasible.
Total CMM produced from gas drainage systems peaked at 59 billion cubic feet (Bcf) in 2010, and
has since declined to 42 Bcf in 2016. The amount of CMM recovered and used also peaked in 2010
at 49 Bcf, but has since declined to 34 Bcf in 2016. The decline in gas drainage and CMM utilization
is due to several factors, including changes in the gas content of mined coals, natural fluctuations
in methane production, a continued reduction in underground coal production, closure of a limited
number of gassy mines, and low natural gas prices.
Methane Emissions and Recovery Opportunities
Methane is a greenhouse gas (GHG) that exists in the atmosphere for approximately 9-15 years.
As a GHG, methane is more than 251 times more effective in trapping heat in the atmosphere than
carbon dioxide (C02) over a 100-year period. Major anthropogenic sources of methane include
landfills, natural gas and petroleum systems, agricultural activities, coal mining, stationary and
mobile combustion, wastewater treatment, and certain industrial processes.
As a primary constituent of natural gas, methane is a relatively clean-burning energy source.
Utilizing CMM emissions using commercially available, cost-effective technologies can provide
significant energy, economic, and environmental benefits.
EPA
EPA's Coalbed Methane Outreach Program (CMOP) has worked voluntarily with the coal mining
industry and other key stakeholders since 1994 to recover and use methane released in and
emitted from mines. CMOP supports CMM project development to overcome institutional, technical,
1 EPA. 2019. Inventory of U.S. Greenhouse Gas Emissions and Sinks 1990-2017. EPA 430-R-19-001.
U.S. Environmental Protection Agency. Available: https://www.epa.Qov/ahaemissions/inventorv-us-
areenhouse-aas-emissions-and-sinks. Accessed 5/30/2019.
www.epa.gov/cmop
i
-------
regulatory, and financial barriers to implementation; and educate the general public on the benefits
of CMM recovery. More specifically, these efforts include:
• Identifying, evaluating, and promoting methane reduction options, including technological
innovations and market mechanisms to encourage project implementation
• Workshops to educate the CMM project development community on the environmental, mine
safety, and economic benefits of methane recovery
• Preparing and disseminating reports and other materials that address topics ranging from
technical and economic analyses to overviews of legal issues
• Interfacing with all facets of the industry to advance project development
• Conducting pre-feasibility and feasibility studies for U.S. mines that examine a range of end-use
options
• Managing a website that is an important information resource for the CMM industry.
CMM Recovery Opportunities
In the U.S., coal mines account for approximately 9 percent of all manmade methane emissions
(EPA, 2018); however, the recovery and use of CMM has been in practice for many years. Today,
there are methane recovery and use projects at active underground mines in Alabama, Colorado,
Pennsylvania, Virginia, and West Virginia. In addition, as shown in this report, there are other
gassy coal mines where utilization projects do not exist, but that could offer the potential for the
profitable recovery of methane.
CMM projects deliver direct financial benefits to project operators through the sale of gas to
pipelines or for use in applications ranging from electric power generation to industrial uses. In
addition, indirect financial and economic benefits may also be realized. To illustrate the impact of
methane recovery, developing a project at a mine recovering 300 thousand cubic feet of methane
per year could feed a 3-megawatt power plant, and result in GHG emissions reductions equating to
about 125,000 tonnes carbon dioxide equivalent (tC02e).2 Because of the large environmental
benefits that may be achieved, CMM projects could serve as cost-effective alternatives for utilities
and other industries seeking to offset their own GHG emissions. For example, certain CMM projects
produce emissions offsets that can be sold into the California Cap-and-Trade program, generating a
source of revenue for the project in addition to gas sales in energy and industrial markets.
CMM projects also provide other benefits. Degasification systems prevent gas from escaping in
mine working areas, increase methane recovery, improve worker safety, and reduce ventilation
costs. Increased recovery also reduces methane-related mining delays. To learn about CMM
capture-and-use technologies, visit the CMOP website at httDs://www.eDa.aov/cmoD.
Opportunities for Methane Recovery Projects
This report profiles the 35 gassiest U.S. coal mines (Chapter 4), and provides details about ongoing
recovery and use projects at 13 of these mines. Since the last version of this document was
published in 2017, the number of mines with gas drainage systems nationwide decreased from
26 in 2015 to 25 in 2016. Twenty of these mines with gas drainage systems are profiled in this
document (Table 4-8). Further, the number of mines with active methane recovery and use
2 The C02-e of methane emissions is calculated by determining the weight of the methane collected (on a
100% basis), using a density of 19.2 grams per cubic feet (cf). The weight is then multiplied by the global
warming potential of methane, which is 25 times greater than C02 over a 100-year time period. This value is
downwardly adjusted to account for C02 emissions from combustion of the methane at some point in the
supply chain. One metric tonne (t) of combusted methane produced 2.75 tC02.
www.epa.gov/cmop
ii
-------
projects decreased from 18 in 2015 to 15 in 2016. At least 13 of these mines already sell
recovered methane, and at least 3 mines consume methane onsite for power generation, to heat
mine ventilation air, flare CMM, or use produced gas as fuel in onsite vacuum pumps. This
document only profiles 13 out of the 15 mines with use projects (Table 4-13). The Road Fork #51
Mine in West Virginia and the Emerald Mine No. 1 in Pennsylvania have pipeline utilization projects.
Mine drainage systems in place may be especially good candidates for the development of cost-
effective methane recovery and use projects because a ready supply of high- or medium-
concentration mine gas already exists.
There are also projects at abandoned mines in the U.S.; however, this report only profiles mines
that were active in 2016. For additional information on methane recovery projects at abandoned
coal mine sites, see the EPA report, U.S. Abandoned Coal Mine Methane Recovery Project
Opportunities, available on the CMOP website at
https://www.epa.gOv/cmoD/coal-mine-methane-sources#abandonedUnderaroundMines.
Surface mines may also be candidates for recovery and utilization projects. Surface mine
opportunities are addressed in EPA's report, U.S. Surface Coal Mine Methane Recovery Project
Opportunities, which is available on the CMOP website at
httPs://www.epa.aov/cmop/coal-mine-methane-sources#activeSurfaceMines.
Overview of Methane Liberation, Drainage, and Use at Profiled Mines
This report profiles 35 mines located in 9 states (Chapter 4). West Virginia has the largest number
of profiled mines with 12 mines; followed by Illinois with 6; Alabama, Indiana, and Pennsylvania
with 4; Virginia with 2; and Colorado, New Mexico, and Oklahoma with 1 each. In 2016, the
35 mines profiled in this report liberated an estimated 289 million cubic feet per day (mmcf/d) of
methane, or about 105 Bcf/yr (89 percent of all methane liberated from underground mines in the
U.S.).
As of 2016, 20 of the profiled mines operate drainage systems although not all systems were
operational that year. West Virginia has the largest number with seven; followed by Pennsylvania
and Alabama with four each; Indiana with two; and Colorado, New Mexico, and Virginia with one
each. In 2016, the 20 mines operating drainage systems reported an estimated 114 mmcf/d of
methane drained, or about 41 Bcf/yr. Table 4-8 shows mines that employ drainage systems, the
type of drainage system employed, and the estimated drainage efficiency.
Summary of Opportunities for Project Development
Most underground coal mines in the U.S. still do not recover and use methane. However, the
profiles in this report indicate that many of these mines appear to be strong candidates for cost-
effective recovery projects that potentially could result in substantial environmental, economic, and
energy benefits.
The featured mines are quite variable in terms of the amount of methane they liberate, their
gassiness or "specific emissions" (methane liberated per ton of coal mined), and their annual coal
production. The volume of methane liberated from each mine ranges from 2 mmcf/d to over
62 mmcf/d. Similarly, specific emissions range from 182 cf/ton to approximately 12,389 cf/ton.
Annual coal production ranges from approximately 0.3 million tons at some mines to over
12 million tons per year at others. These metrics affect each mine's potential as a project
opportunity. Furthermore, as shown in the profiles (Chapter 4), the candidate mines vary with
respect to other important metrics, such as the distance from the mine to a natural gas pipeline.
www.epa.gov/cmop
iii
-------
Accordingly, the overall feasibility of developing a methane recovery project will likely vary widely
among the candidate mines.
Use of the profiles in this document can serve to guide interest and decision-making on prospects
for CMM project development and implementation, with the goal of focusing attention on those
mines that present the most favorable opportunities in the near- to medium-term based on publicly
available data. Users should still remember, however, that mining and market conditions often
change. Further, mines not listed in this edition of the Gassy Mine Profiles may also present
attractive CMM opportunities in the future, whether they are existing mines with growing gas
emissions or new mines being developed to mine gassy seams.
A ckn o wledgem ents
This document provides profiles of underground gassy U.S. mines compiled by EPA's Coalbed
Methane Outreach Program (CMOP).
The EPA thanks the U.S. Mine Safety and Health Administration for the ventilation emissions data
used in this document.
www.epa.gov/cmop
iv
-------
Table of Contents
Identifying Opportunities for Methane Recovery at U.S. Coal Mines: Profiles of Selected Gassy
Underground Coal Mines (2002-2016) Updated July 2019 i
Executive Summary i
Methane Emissions and Recovery Opportunities i
EPA i
CMM Recovery Opportunities ii
Opportunities for Methane Recovery Projects ii
Overview of Methane Liberation, Drainage, and Use at Profiled Mines iii
Summary of Opportunities for Project Development iii
Acknowledgements iv
Terms Used in Report viii
Abbreviations ix
1. Introduction 1
Purpose of Report 1
Recent Developments in the Coal Mine Methane Industry 1
2. Mine Profiles Guide 4
Chapter 2 contains information that will assist the reader in understanding and evaluating the
data presented in Chapters 3 and 4 4
Mine Status 4
Drainage System 4
Use Project 4
MSHA ID 4
Geographic Data 4
Corporate Information 2
Mailing Address 2
General Information 2
Production, Ventilation, and Drainage Data 3
3. Mine Summary Tables 5
Chapter 3 contains data tables (Table 3-1 through Table 3-13) summarizing information for the
35 gassiest U.S. mines 5
4. Profiled Mines 18
Chapter 4 profiles individual underground coal mines that appear to be good candidates for the
development of methane recovery projects. At least 13 of these mines already sell recovered
methane, and at least 3 mines consume methane onsite for power generation, to heat mine
ventilation air, flare CMM, or use produced gas as fuel in onsite vacuum pumps 18
Alabama Mines 18
Colorado Mine 23
Illinois Mines 24
Indiana Mines 31
New Mexico Mine 36
www.epa.gov/cmop
v
-------
Oklahoma Mine 37
Pennsylvania Mines 38
Virginia Mines 43
West Virginia Mines 46
5. References 59
www.epa.gov/cmop
vi
-------
List of Figures and Tables
Figure 1-1: Comparison of CMM Projects and CMM Drainage, Recovery, and Use in 2015 and 2016 1
Figure 1-2: Mines with Active Coal Mine Methane Recovery and Use Projects 1
Figure 1-3: Estimated Annual Use of Methane Recovered from U.S. Coal Mines (based on publicly available
information) 2
Table 1-1: Summary of Existing Methane Recovery and Use Projects in Alabama, Colorado, Pennsylvania, and
Virginia 2
Table 1-2: Summary of Existing Methane Recovery and Use Projects in West Virginia 3
Table 3-1: Mines Listed Alphabetically 5
Table 3-2: Mines Listed by State and County 6
Table 3-3: Mines Listed by Coal Basin 7
Table 3-4: Mines Listed by Company 8
Table 3-5: Mines Listed by Mining Method 9
Table 3-6: Mines Listed by Primary Coal Use 10
Table 3-7: Mines Listed by 2016 Coal Production 11
Table 3-8: Mines Employing Methane Drainage Systems 12
Table 3-9: Mines Listed by Estimated Total Methane Liberated in 2016 13
Table 3-10: Mines Listed by Daily Ventilation Emissions in 2016 14
Table 3-11: Mines Listed by Estimated Daily Methane Drained in 2016 15
Table 3-12: Mines Listed by Estimated Specific Emissions in 2016 16
Table 3-13: Mines with CMM Recovery and Use Projects 17
www.epa.gov/cmop
vii
-------
Terms Used in Report
Coalbed methane: A generic term for the methane-rich gas naturally occurring in coal seams
typically comprising 80 percent to 95 percent methane with lower proportions of ethane, propane,
nitrogen, and carbon dioxide. In common international use, this term refers to methane recovered
from un-mined coal seams using surface boreholes.
Coal mine methane (CMM): Gas captured at a working coal mine by underground methane
drainage techniques. The gas consists of a mixture of methane and other hydrocarbons and water
vapor. It is often diluted with air and associated oxidation products due to the unavoidable leakage
of air into gas drainage boreholes or galleries through mining-induced fractures, and also due to air
leakage at imperfect joints in underground pipeline systems. Any gas captured underground,
whether drained in advance of or after mining, and any gas drained from surface gob wells is
included in this definition. Pre-mining drained CMM can be of high purity and is considered CMM
only when the well is mined through.
Coal Mine Methane Inventory: The U.S. Environmental Protection Agency publishes an annual
Inventory of U.S. Greenhouse Gas Emissions and Sinks, which includes a comprehensive
assessment of methane emissions from coal mining, including emissions from active underground
and surface mines, post-mining emissions, and abandoned mines.
Degasification system: Refers to methods for capturing the naturally occurring gas in coal seams
to prevent it from entering mine airways. The gas can be removed from coal seams in advance of
mining using pre-drainage techniques and from coal seams disturbed by the extraction process
using post-drainage techniques. If methane is the main gas component target to be captured, this
is often referred to as methane drainage and mine degasification. A drainage system may consist
of only one well or borehole or multiple wells or boreholes.
Methane drained: The amount of methane removed via a drainage system.
Methane emissions: This is the total amount of methane that is not used and therefore emitted
to the atmosphere. Methane emissions are calculated by subtracting the amount of methane used
from the amount of methane liberated (emissions = liberated - used).
Methane liberated: The total amount of methane that is released, or liberated, from the coal and
surrounding rock strata during the mining process. This total is determined by summing the
volume of methane emitted from the ventilation system and the volume of methane that is
drained.
Methane recovered: The amount of methane that is captured through methane drainage
systems.
Methane used: The amount of captured methane put to productive use (e.g., natural gas pipeline
injection, fuel for power generation) or destroyed (e.g., flaring or oxidation).
Ventilation air methane (VAM): Methane emitted from coal seams that enters the ventilation air
and is exhausted from the ventilation shaft at a low concentration, typically in the range of
0.01 percent to 1.0 percent by volume.
Ventilation system: A system that is used to control the concentration of methane within mine
working areas. Ventilation systems consist of powerful fans that move large volumes of air through
the mine workings to dilute methane concentrations.
www.epa.gov/cmop
viii
-------
Abbreviations
Bcf
billion cubic feet
CARB
California Air Resources Board
CCO
California Compliance Offset
cf
cubic feet
CMM
coal mine methane
CMOP
Coalbed Methane Outreach Program
C02
carbon dioxide
CO2S
carbon dioxide equivalent
EPA
U.S. Environmental Protection Agency
GHG
greenhouse gas
ID
identification
mcf
thousand cubic feet
mmcf
million cubic feet
MSHA
Mine Safety and Health Administration
NA
not available
T (or T)
short ton (for coal production)
U.S.
United States
VAM
ventilation air methane
www.epa.gov/cmop
ix
-------
1. Introduction
Purpose of Report
This report provides information about
specific opportunities to develop methane
recovery and use projects at gassy
underground mines in the United States
(U.S.)- The audience for this report consists
of those who may be interested in identifying
such opportunities, including coal miners,
utilities, gas resource developers,
independent power producers, and local
industries or institutions that could directly
use the methane recovered from a nearby
mine.
This introduction provides a broad overview of
the technical, economic, regulatory, and
environmental issues concerning methane
recovery from coal mines. Chapter 2 contains
information that will assist the reader in
understanding and evaluating the data
presented in Chapters 3 and 4. Chapter 3
contains data summary tables, and finally,
Chapter 4 profiles individual underground coal
mines that appear to be good candidates for
the development of methane recovery
projects.
Mines with Gas Drainage Systems and CMM
Projects
in 2015
Mines with gas drainage
systems
Coal production from underground mines
decreased significantly in 2015 and 2016, and
several gassy mines either closed or were
Recent Developments in the Coal Mine
Methane Industry
Since the last version of this document was
published in August 2017, the number of
mines with gas drainage systems decreased
from 26 in 2015 to 25 in 2016, and the
number of mines with active methane
recovery and use projects decreased from 18
in 2015 to 15 in 2016 (Figure 1-1). The total
methane produced from gas drainage
systems declined from 48 billion cubic feet
(Bcf) to 42 Bcf, but the amount of methane
recovered and used remained constant at 34
Bcf from 2015 to 2016 (Figure 1-1). Gas
drainage and coal mine methane (CMM) use
peaked in 2010 with 59 Bcf drained and 49
Bcf used. The decline in drainage and
utilization since 2010 is due to several
factors, including changes in the gas content
of mined coals, natural fluctuations in
methane production, a continued reduction in
underground coal production, closures of
some gassy mines, and low natural gas
prices.
CMM Produced, Recovered, and Used in
2015 and 2016
(ii
Methane produced from gas
drainage systems
40 60
idled for significant periods of time, reducing
the volume of available gas. Low natural gas
prices resulting from the rapid growth in
and 2016
Mines with active methane
recovery and use projects
Methane recovered and
used
12015
12015
0 10 20 30
0 20
Figure 1-1: Comparison of CMM Projects and CMM Drainage, Recovery, and Use in 2015 and 2016
www.epa.gov/cmop
1
-------
natural gas supply from hydraulically
fractured gas wells made utilization of some
drained gob gas uneconomic. This led to
larger volumes being vented rather than
being treated and sold to natural gas
pipelines. In 2010, for example, 84 percent of
the drained methane was used, but in 2016,
only 80 percent of the available drained gas
was utilized.
Despite these challenges, many promising
developments are expected to encourage
greater CMM capture and use in future years.
Two commercial ventilation air methane
(VAM) projects have been implemented in the
U.S. since 2009. The Biothermica VAM project
operated at the Warrior Met Coal Blue Creek
Number 4 Mine from 2010 to 2013; and the
Verdeo McElroy VAM Project began operation
at the Murray Energy Marshall County Mine in
2012 (then the CONSOL McElroy Mine), and
remains in operation as of September 2018.
The success in demonstrating both the
technical and commercial viability of these
projects suggests the potential for additional
VAM project deployment in coming years.
In addition, another notable development has
been the California Air Resources Board
(CARB) adoption of the Mine Methane Capture
Protocol allowing CMM projects, other than
natural gas pipeline sales, to qualify as offsets
in the California Cap-and-Trade program.
CARB allows covered entities to purchase and
trade California Compliance Offsets (CCOs),
including emissions reductions from CMM
projects anywhere in the U.S. This has
renewed interest in CMM projects, especially
VAM destruction projects and projects that
use drained gas for power production, flaring,
and liquefied or compressed natural gas
production. CCO prices are attractive and
capable of generating cash flow to make the
projects economically sustainable. Since the
adoption of the Protocol, CCO prices have
ranged from $9.00 to 14.00 per metric ton of
C02 equivalent (C02e).3
Figure 1-2 shows the number of mines
engaging in CMM recovery and use since
1994. Figure 1-3 shows the volume of gas
recovered from CMM projects since 1990.
Table 1-1 and Table 1-2 summarize the
methane recovery and use projects.
California Carbon. 2019. California Carbon.info.
Trading & Auctions. Available:
http://californiacarbon.info/. Accessed 5/30/2019.
www.epa.gov/cmop
2
-------
Methane Recovery and Use Projects (by State)
West Virginia
Virginia
Pennsylvania
New Mexico
Colorado
Alabama
10
15
Number of Mines with Methane Recovery and Use Projects
(based on publicly available information)
~ 2016
¦ 2015
~ 2014
~ 2006
¦ 2003
¦ 2001
¦ 1997
~ 1994
20
Figure 1-2: Mines with Active Coal Mine Methane Recovery and Use Projects
www.epa.gov/cmop
1
-------
50
45
40
Jps
u
m
35
—*
¦u
0)
30
D
75
V
c
n
20
.c
01
1
15
10
5
0
riii
0 J J J
^i. .1 i.
¦*% ^ •?% ^ *%
Figure 1-3: Estimated Annual Use of Methane Recovered from U.S. Coal Mines (based on publicly available
information)
Table 1-1: Summary of Existing Methane Recovery and Use Projects in Alabama, Colorado, Pennsylvania, and Virginia
Mine
Approximate
Location
Amount of Gas
Methane Use
Degasification
Mine Name
(State)
Used in 2016*
Option
Notes
System
No. 4 Mine
No. 7 Mine
Alabama
22.5 mmcf/day
Pipeline sales
The two mines collectively
liberated 42.4 mmcf/day of
gas in 2015.
Vertical gob boreholes;
horizontal pre-mine
boreholes; vertical pre-
mine boreholes
Oak Grove
Alabama
3.3 mmcf/day
Pipeline sales
Most of the production in the
Oak Grove Field is beyond the
limits of the mine plan and is
therefore not included in this
summary.
Vertical gob boreholes;
horizontal pre-mine
boreholes; vertical pre-
mine boreholes
Shoal Creek
Alabama
6.8 mmcf/day
Pipeline sales
Most of the production from
the White Oak Field is outside
the limits of the mine plan and
is therefore not included in
this summary.
Horizontal gob
boreholes with pumps
West Elk
Mine
Colorado
0.2 mmcf/day
Heaters
Began recovering methane in
2003. Used for heating the
mine.
Horizontal and vertical
gob boreholes with
pumps
Cumberland
Mine
Pennsylvania
1.0 mmcf/day
Pipeline sales
Began recovering methane in
2005.
Vertical gob boreholes
with pumps
Bailey Mine
Pennsylvania
Small volumes
Pipeline sales
Vertical gob boreholes
with pumps
Buchanan
Mine #1
Virginia
53.8 mmcf/day
Pipeline sales,
onsite power
generation
This mine liberated
62.7 mmcf/day of gas in
2016.
Vertical gob boreholes;
horizontal pre-mine
boreholes; vertical pre-
mine boreholes
mmcf = million cubic feet.
www.epa.gov/cmop
2
-------
Table 1-2: Summary of Existing Methane Recovery and Use Projects in West Virginia
Mine
Approximate
Location
Amount of Gas
Methane Use
Oegasification
Mine Name
(State)
Used in 2015*
Option
Notes
System
Monongalia County
Mine (formerly
Blacksville #2 Mine)
Marion County Mine
(formerly Loveridge
No. 22)
West
Virginia
0.3 mmcf/day
Pipeline sales
The two mines liberated
22.4 mmcf/day in 2016.
Now owned by Murray
Energy, the prior
owner/operator CONSOL
Energy began reporting
methane recovered from
the two mines together in
2005.
Vertical gob boreholes
with pumps and
horizontal pre-
drainage wells
Pinnacle Mine
West
Virginia
0.2 mmcf/day
Pipeline sales
A unique, horizontal pre-
mine drainage program is
utilized using a pinnate
pattern.
Horizontal gob
boreholes with pumps
Marshall County
Mine (formerly
McEiroy Mine)
West
Virginia
2.4 mmcf/day
VAM
destruction
Largest commercial VAM
project to date; started in
2012 and use of drained
gas for pipeline sales
started in 2009
No drainage
Harrison County
Mine (formerly
Robinson Run Mine)
West
Virginia
0.3 mmcf/day
Pipeline sales
Started in 2015
Horizontal pre-
drainage wells
*For use of drained gas, the U.S. Environmental Protection Agency (EPA) only includes gas drained and used from wells that are
located within the coal mining plan, and only counts the gas as "coal mine methane" rather than coalbed methane once the well is
mined through.
www.epa.gov/cmop
3
-------
2. Mine Profiles Guide
Chapter 2 contains information that will assist
the reader in understanding and evaluating
the data presented in Chapters 3 and 4.
This report contains profiles of the 35 gassiest
U.S. coal mines (Chapter 4), and provides
details about ongoing recovery and use
projects at 13 of these mines. The profiled
mines were selected primarily based on their
annual methane liberation from ventilation
systems as recorded in quarterly U.S. Mine
Safety and Health Administration (MSHA)
inspections used for the U.S. Coal Mine
Methane Inventory found in the Inventory of
U.S. Greenhouse Gas Emissions and Sinks
1990-2016.
The mine profiles presented in this report are
designed to assist in identifying mines that
can sustain a profitable methane recovery
and use project. Each mine profile is
comprised of the following sections:
• Geographic data
• Corporate information
• Mine address
• General information regarding the mine
• Production, ventilation, and drainage data
Chapter 3 includes summary tables (Table
3-1 through Table 3-13) that list key data
elements shown in the mine profiles. The
individual mine profiles follow the summary
tables and are ordered alphabetically by
state, and arranged by mine name in Chapter
4. Below are explanations for each of the data
elements included in the mine profiles.
Mine Status
Each mine's operating status as of September
2018 is listed at the top left-hand corner of
each profile. The operating status may be
listed as described below.
Active: These mines are currently
producing coal.
Non-Producing: A mine that is open
but not currently producing coal.
Temporarily Idled: A mine that is open
but has temporarily ceased coal production.
All mines profiled in this version are classified
as either Active or Non-Producing. The
current operating status was determined by
reviewing the MSHA Mine Data Retrieval
System at
http://arlweb.msha.aov/drs/drshome.htm.
Drainage System
The presence of a drainage system is
indicated at the top right-hand corner of each
profile. If a drainage system is used at the
mine, "Yes" appears in the Drainage System
field.
Use Project
If a mine recovers (captures) and uses
methane, the type of utilization project is
designated in this field in the top left-hand
side of the profile under mine status. Use
projects include pipeline injection, electric
power, and heaters. If there is currently no
use project at the mine, "NA" (not available)
appears in the field.
MSHA ID
This field in the top right-hand side of the
profile under the drainage system contains
the mine's identification (ID) from MSHA.
Geographic Data
The first section of each profile gives the
geographic location of the mine, including the
state, county, coal basin where the mine is
located, and the coalbed(s) from which it
produces coal. The sources for this
information were MSHA (2018) and Coal Age
(2016).
State: Mines included in this report are
located in the following states - Alabama,
Colorado, Illinois, Indiana, New Mexico,
Oklahoma, Pennsylvania, Virginia, and West
www.epa.gov/cmop
4
-------
Virginia. Table 4-2 shows the mines listed by
state.
County: A relatively small number of counties
contain a majority of the gassy mines in the
entire U.S. Table 4-2 shows the mines listed
by state and county.
Basin: Mines are located in one of the major
coal producing regions: The Black Warrior
Basin, the Central Appalachian Basin, the
Northern Appalachian Basin, the Illinois Basin,
or one of the "Western basins" (Central
Rockies, San Juan, or Uinta Basin), which are
located in the states of Colorado, Utah, and
New Mexico. Major geological characteristics
of coal seams, including methane content,
sulfur content, depth, and permeability tend
to vary by basin and within a basin. Table 4-3
lists the mines by coal basin.
Corporate Information
Current Operator: Current operator refers to
the mining company that operates the mine.
Table 4-4 lists the mines by owner/parent
company. The source for this information was
the MSHA database (MSHA, 2018).
Owner/Parent Company: Many coal mines are
owned by a parent company. In addition to
showing the coal companies, Table 4-4 also
shows the parent corporation of the mining
company. This information was taken from
MSHA (2018), or based on industry
knowledge.
Previous Owner(s'): The names of previous
mine owners are useful due to the degree of
restructuring in the coal industry since 2008.
This information, along with the previous or
alternate name of the mine, is based on the
MSHA database (MSHA, 2018) and industry
knowledge.
Previous or Alternate Name of Mine: Mines
frequently undergo name changes,
particularly when they are purchased by a
new company. This section lists previous or
alternate mine names.
Mailing Address
This field includes the mailing address of the
mine. The principal source of this information
was MSHA (2018). The information in this
section is current as of September 2018.
General Information
Number of Employees at Mine: This field
shows the number of people employed by the
mine, as reported by the MSHA Mine Data
Retrieval System (MSHA, 2018). The total
number of employees during 2016 was used.
Year of Initial Production: This field indicates
the age of the mine. For mines appearing in
previous additions of the mine profiles, those
were used. Otherwise, the MSHA Mine Data
Retrieval System was used (MSHA, 2018).
Mining Method: Mines are classified as either
longwall or continuous (room-and-pillar),
based on Coal Age magazine's annual
longwall survey (Coal Age, 2016) and on
information in coal industry publications. The
mining method used is important for several
reasons. First, longwall mines tend to emit
more methane than room-and-pillar mines, as
the longwall technique tends to cause a more
extensive collapse and relaxation of the
methane-rich strata surrounding the coal
seam. Most of the high-emitting mines
profiled in this document use the longwall
mining method. Table 4-5 lists mines by
mining method.
Primary Coal Use: Coal may be used for
steam and/or metallurgical purposes. Steam
coal is used by utilities to produce electricity,
while metallurgical coal is used to produce
coke. The primary coal use is based on
information from annual Security and
Exchange Commission filings, parent
company annual reports, and industry
websites. Table 4-6 lists mines by primary
coal use.
www.epa.gov/cmop
2
-------
Production, Ventilation, and Drainage Data
This section presents the quantity of methane
emitted from, and the amount of coal
produced by the profiled mines for each year
from 2002 to 2016.
Coal Production: Annual coal production is an
important factor in determining a mine's
potential for profitable methane recovery.
Generally, larger mines will be better
candidates because they will have potential
for high methane production and they are
more likely to be able to finance capital
investments in methane recovery and
utilization projects. Coal production is derived
primarily from the MSHA database (MSHA,
2018). Table 3-7 lists the coal mines by the
amount of coal they produced in 2016.
Estimated Total Methane Liberated: Methane
liberation is the total volume of methane that
is removed from the mine by ventilation and
drainage. Liberation differs from emissions in
that the term emissions, as used in this
report, refers to methane that is not used and
is therefore emitted to the atmosphere. For
mines that do not use or sell any of their
methane, estimated total methane liberated
equals estimated methane emissions to the
atmosphere. Table 3-9 shows mines listed by
their estimated total daily methane liberation
for 2016.
Emissions from Ventilation Systems: Methane
released to the atmosphere from ventilation
systems is emitted in very low concentrations
(typically less than 1 percent in air). MSHA
field personnel test methane emission rates at
each coal mine on a quarterly basis. Testing
is performed underground at the same
location each time. However, MSHA does not
necessarily conduct the tests at precise three-
month intervals, nor are they always taken at
the same time of day. The ventilation
emissions data for a given year are therefore
averages of the four quarterly tests, and are
accurate to the extent that the data collected
at those four times are representative of
actual emissions. Table 3-10 lists the mines
by their 2016 ventilation emissions, as
reported by EPA's Greenhouse Gas (GHG)
Inventory (EPA, 2018).
Estimated Methane Drained: Mines that
employ degasification systems emit large
quantities of methane in high concentrations.
Table 3-11 lists mines according to the
estimated daily methane drained. Based on
information obtained from EPA's GHG
Inventory (EPA, 2018), EPA has developed a
list of 20 U.S. mines that have drainage
systems in place, and have active utilization
projects or a high potential for implementing
a utilization project.
Estimated specific Emissions: "Specific
emissions" refer to the total amount of
methane liberated per ton of coal that is
mined. Specific emissions are an important
indicator of whether a mine is a good
candidate for a methane recovery project. In
general, mines with higher specific emissions
tend to have stronger potential for methane
recovery. Table 3-12 shows a list of mines
ordered according to specific emissions in
2016. Note that the coal production and
methane liberation values shown in this
report have been rounded, whereas the data
actually used to calculate the specific
emissions values have not been rounded.
Therefore, the specific emissions data shown
in this report may differ from results that the
reader would obtain by dividing the methane
liberation values by the coal production
values. This difference is strictly due to
rounding, and does not reflect any error in
the calculation of the methane liberated.
Methane Used: Methane used refers to the
total amount of drained methane and
captured VAM that was put to productive use
(e.g., natural gas pipeline injection, fuel for
onsite power generation). Methane used does
not always equal methane drained as some
mines vent the methane liberated from
degasification systems to the atmosphere.
Table 3-13 shows a list of mines employing
methane recovery and use projects.
www.epa.gov/cmop
3
-------
Estimated Current Drainage Efficiency:
Drainage efficiency is the quantity of methane
produced by the gas drainage system divided
by the total quantity of methane released at
the mine by the mine's methane drainage and
mine ventilation systems. Expressed as a
percentage, it is a measure of the
effectiveness of the gas drainage system. It
also provides insight into the remaining
volumes of methane that could be potentially
extracted by gas drainage. Where a mine
employs only ventilation to remove gas from
the underground workings, there is no
drainage efficiency value.
Estimated Current Market Penetration: In
order to estimate the market penetration of
CMM utilization, this field represents the
percentage of drained methane that is used
rather than vented to the atmosphere. Mines
already draining methane that do not fully
utilize, or do not utilize at all, the methane
drained represent potential CMM project
opportunities.
Drainage System Used: 20 of the mines
profiled in this report used some type of
drainage (or degasification) system to capture
coal mine methane in 2016. One additional
mine had previously used methane drainage
but did not do so in 2016. Drainage systems
used include vertical pre-mine boreholes
(drilled in advance of mining), vertical gob
wells, long-hole horizontal pre-mine
boreholes, and horizontal pre-mine boreholes.
Table 3-8 lists mines by drainage system
used.
www.epa.gov/cmop
4
-------
3. Mine Summary Tables
Chapter 3 contains data tables (Table 3-1 through Table 3-13) summarizing information for the
35gassiest U.S. mines.
Table 3-1: Mines Listed Alphabetically
Mine Name
State
American Eagle Mine
WV
The American Coal Company New Era Mine
IL
The American Coal Company New Future Mine
IL
Bailey Mine
PA
Beckley Pocahontas Mine
WV
Buchanan Mine #1
VA
Cumberland Mine
PA
Deep Mine 41
VA
Enlow Fork Mine
PA
Federal No. 2
WV
Gibson Mine
IN
Gibson South
IN
Hamilton County Coal Mine #1
IL
Harrison County Mine
WV
Harvey Mine
PA
Leer Mine
WV
Mach #1 Mine
IL
Marion County Mine
WV
Marshall County Mine
WV
MC #1 Mine
IL
Monongalia County Mine
WV
No. 4 Mine
AL
No. 7 Mine
AL
Oak Grove
AL
Oaktown Fuels Mine No. 1
IN
Oaktown Fuels Mine No. 2
IN
Ohio County Mine
WV
P8 North
OK
Pattiki Mine
IL
Pinnacle Mine
WV
San Juan Mine 1
NM
Sentinel Mine
WV
Shoal Creek
AL
Tunnel Ridge Mine
WV
West Elk Mine
CO
www.epa.gov/cmop
5
-------
Table 3-2: Mines Listed by State and County
Mine Name
State
County
Oak Grove
AL
Jefferson
Shoal Creek
AL
Jefferson
No. 4 Mine
AL
Tuscaloosa
No. 7 Mine
AL
Tuscaloosa
West Elk Mine
CO
Gunnison
MC #1 Mine
IL
Franklin
Hamilton County Coal Mine #1
IL
Hamilton
The American Coal Company New Era Mine
IL
Saline
The American Coal Company New Future Mine
IL
Saline
Pattiki Mine
IL
White
Mach #1 Mine
IL
Williamson
Gibson Mine
IN
Gibson
Gibson South
IN
Gibson
Oaktown Fuels Mine No. 1
IN
Knox
Oaktown Fuels Mine No. 2
IN
Knox
San Juan Mine 1
NM
San Juan
P8 North
OK
Le Flore
Bailey Mine
PA
Greene
Cumberland Mine
PA
Greene
Enlow Fork Mine
PA
Greene
Harvey Mine
PA
Greene
Buchanan Mine #1
VA
Buchanan
Deep Mine 41
VA
Dickenson
Sentinel Mine
WV
Barbour
American Eagle Mine
WV
Kanawha
Harrison County Mine
WV
Harrison
Marion County Mine
WV
Marion
Marshall County Mine
WV
Marshall
Ohio County Mine
WV
Marshall
Federal No. 2
WV
Monongalia
Monongalia County Mine
WV
Monongalia
Tunnel Ridge Mine
WV
Ohio
Beckley Pocahontas Mine
WV
Raleigh
Leer Mine
WV
Taylor
Pinnacle Mine
WV
Wyoming
www.epa.gov/cmop
6
-------
Table 3-3: Mines Listed by Coal Basin
Coal Basin/Mine Name
Black Warrior
No. 4 Mine
No. 7 Mine
Oak Grove
Shoal Creek
Central Appalachian
American Eagle Mine
Beckley Pocahontas Mine
Buchanan Mine #1
Deep Mine 41
Pinnacle Mine
Illinois
The American Coal Company New Era Mine
The American Coal Company New Future Mine
Gibson Mine
Gibson South
Hamilton County Coal Mine #1
Mach #1 Mine
MC #1 Mine
Oaktown Fuels Mine No. 1
Oaktown Fuels Mine No. 2
Pattiki Mine
Northern Appalachian
Bailey Mine
Cumberland Mine
Enlow Fork Mine
Federal No. 2
Harrison County Mine
Harvey Mine
Leer Mine
Marion County Mine
Marshall County Mine
Monongalia County Mine
Ohio County Mine
Sentinel Mine
Tunnel Ridge Mine
Western
San Juan Mine 1
West Elk Mine
Western Interior
P8 North
www.epa.gov/cmop
7
-------
Table 3-4: Mines Listed by Company
Owner/Parent
Operator
Mine Name
Arch Coal Inc.
ACI Tygart Valley
Leer Mine
ICG Beckley LLC
Beckley Pocahontas Mine
Mountain Coal Company, LLC
West Elk Mine
Wolf Run Mining LLC
Sentinel Mine
Westmoreland Coal Company
San Juan Coal Company
San Juan Mine 1
Seneca Coal Resources LLC
Oak Grove Resources LLC
Oak Grove Mine
Pinnacle Mining Company LLC
Pinnacle Mine
CONSOL Energy Inc.
CONSOL Pennsylvania Coal Company
Bailey Mine
CONSOL Pennsylvania Coal Company
Enlow Fork Mine
CONSOL Pennsylvania Coal Company
Harvey Mine
Coronado IV, LLC
Buchanan Minerals, LLC
Buchanan Mine #1
Drummond Company Inc.
Drummond Company Inc.
Shoal Creek
Contura Energy, Inc.
Cumberland Coal Resources LP
Cumberland Mine
Paramount Contura, LLC
Deep Mine 41
Murray Energy Corp
The American Coal Company
The American Coal Company New
Era Mine
The American Coal Company
The American Coal Company New
Future Mine
Marion County Coal Company
Marion County Mine
Harrison County Coal Company
Harrison County Mine
Ohio County Coal Company
Ohio County Mine
Marshall County Coal Company
Marshall County Mine
Monongalia County Coal Company
Monongalia County Mine
Virginia Conservation Legacy Fund, Inc.
ERP Federal Mining Complex LLC
Federal No. 2
Warrior Met Coal LLC
Warrior Met Coal Mining, LLC
No. 4 Mine
Warrior Met Coal Mining, LLC
No. 7 Mine
Foresight Energy
M-Class Mining LLC
MC #1 Mine
Mach Mining LLC
Mach #1 Mine
Hallador Energy Company
Sunrise Coal LLC
Oaktown Fuels Mine No. 1
Oaktown Fuels Mine No. 2
Alliance Resource Partners LP
Gibson County Coal LLC
Gibson Mine
Gibson County Coal LLC
Gibson South
Hamilton County Coal, LLC
Hamilton County Coal Mine #1
Tunnel Ridge, LLC
Tunnel Ridge Mine
White County Coal, LLC
Pattiki Mine
L. Keller Smith
Txoma Mining LLC
P8 North
Blackhawk Mining LLC
Panther Creek Mining LLC
American Eagle Mine
www.epa.gov/cmop
8
-------
Table 3-5: Mines Listed by Mining Method
Mine Name
Method
Beckley Pocahontas Mine
Continuous
American Eagle Mine
Longwal
Bailey Mine
Longwal
Buchanan Mine #1
Longwal
Cumberland Mine
Longwal
Deep Mine 41
Longwal
Enlow Fork Mine
Longwal
Federal No. 2
Longwal
Hamilton County Coal Mine #1
Longwal
Harrison County Mine
Longwal
Harvey Mine
Longwal
Leer Mine
Longwal
Mach #1 Mine
Longwal
Marion County Mine
Longwal
Marshall County Mine
Longwal
MC #1 Mine
Longwal
Monongalia County Mine
Longwal
No. 4 Mine
Longwal
No. 7 Mine
Longwal
Oak Grove
Longwal
Ohio County Mine
Longwal
P8 North
Longwal
Pinnacle Mine
Longwal
San Juan Mine 1
Longwal
Sentinel Mine
Longwal
Shoal Creek
Longwal
The American Coal Company New Era Mine
Longwal
The American Coal Company New Future Mine
Longwal
Tunnel Ridge Mine
Longwal
West Elk Mine
Longwal
Gibson Mine
Room and pillar
Gibson South
Room and pillar
Oaktown Fuels Mine No. 1
Room and pillar
Oaktown Fuels Mine No. 2
Room and pillar
Pattiki Mine
Room and pillar
www.epa.gov/cmop
9
-------
Table 3-6: Mines Listed by Primary Coal Use
Mine Name
Primary Use
Beckley Pocahontas Mine
Metallurgical
Leer Mine
Metallurgical
No. 4 Mine
Metallurgical
No. 7 Mine
Metallurgical
Pinnacle Mine
Metallurgical
Sentinel Mine
Metallurgical
West Elk Mine
Metallurgical
American Eagle Mine
Steam
Cumberland Mine
Steam
Deep Mine 41
Steam
Enlow Fork Mine
Steam
Federal No. 2
Steam
Gibson Mine
Steam
Gibson South
Steam
Harrison County Mine
Steam
Mach #1 Mine
Steam
Marion County Mine
Steam
Marshall County Mine
Steam
MC #1 Mine
Steam
Monongalia County Mine
Steam
Oaktown Fuels Mine No. 1
Steam
Oaktown Fuels Mine No. 2
Steam
Ohio County Mine
Steam
P8 North
Steam
Pattiki Mine
Steam
San Juan Mine 1
Steam
Shoal Creek
Steam
The American Coal Company New Era Mine
Steam
The American Coal Company New Future Mine
Steam
Tunnel Ridge Mine
Steam
Bailey Mine
Steam, metallurgical
Buchanan Mine #1
Steam, metallurgical
Hamilton County Coal Mine #1
Steam, metallurgical
Harvey Mine
Steam, metallurgical
Oak Grove
Steam, metallurgical
www.epa.gov/cmop
10
-------
Table 3-7: Mines Listed by 2016 Coal Production
Mine Name
Million Tons
Bailey Mine
12.1
MC #1 Mine
11.4
Marshall County Mine
10.5
Enlow Fork Mine
9.6
Cumberland Mine
7.0
Harrison County Mine
6.6
Tunnel Ridge Mine
6.6
Ohio County Mine
6.3
Mach #1 Mine
5.4
Buchanan Mine #1
5.0
Marion County Mine
4.4
San Juan Mine 1
4.3
West Elk Mine
4.2
Gibson South
3.9
Monongalia County Mine
3.9
Oaktown Fuels Mine No. 1
3.8
Leer Mine
3.6
No. 7 Mine
3.1
Hamilton County Coal Mine #1
3.0
Harvey Mine
3.0
Shoal Creek
2.3
American Eagle Mine
2.0
Oaktown Fuels Mine No. 2
1.9
Pattiki Mine
1.9
The American Coal Company New Era Mine
1.7
Deep Mine 41
1.5
Federal No. 2
1.5
Oak Grove
1.5
The American Coal Company New Future Mine
1.4
Beckley Pocahontas Mine
1.0
Sentinel Mine
1.0
Pinnacle Mine
0.9
P8 North
0.4
No. 4 Mine
0.3
Gibson Mine
-
www.epa.gov/cmop
11
-------
Table 3-8: Mines Employing Methane Drainage Systems
Estimated Current
Mine Name
Type of Drainage System
Drainage Efficiency
Buchanan Mine #1
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes; Vertical
Pre-Mine Boreholes
86%
Shoal Creek
Horizontal Gob Boreholes with Pumps
78%
No. 4 Mine
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes; Vertical
Pre-Mine Boreholes
69%
No. 7 Mine
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes; Vertical
Pre-Mine Boreholes
56%
Oak Grove
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes; Vertical
Pre-Mine Boreholes
44%
Harvey Mine
Vertical Gob Boreholes; In-mine Horizontal Gob Boreholes
39%
West Elk Mine
Horizontal & Vertical Gob Boreholes with Pumps
39%
Cumberland Mine
Vertical Gob Boreholes with Pumps
36%
Monogalia County Mine
Vertical Gob Boreholes with Pumps
33%
Bailey Mine
Vertical Gob Boreholes with Pumps
32%
Harrison County Mine
Horizontal pre-drainage wells
28%
Marshall County Mine
Vertical Gob Boreholes with Pumps
23%
San Juan Mine 1
Vertical Gob Boreholes with Pumps
15%
Oaktown Fuels Mine No. 1
Vertical Gob Boreholes
10%
Marion County Mine
Vertical Gob Boreholes with Pumps & Horizontal Pre-drainage wells
10%
Pinnacle Mine
Horizontal Gob Boreholes with Pumps
6%
Oaktown Fuels Mine No. 2
Vertical Gob Boreholes
4%
Beckley Pocahontas Mine
Horizontal pre-drainage wells
> 1%
Enlow Fork Mine
Horizontal pre-drainage wells
> 1%
Federal No 2
Vertical Gob Boreholes
> 1%
* Mines using methane drainage in 2016 but not represented among the 25-highest emitting mines were Emerald Mine No. 1
(MSHA ID 3605466), Road Fork #51 mine (MSHA ID 4601544), Bowie No. 2 Mine (MSHA ID 0504591), and Carlisle Mine (MSHA ID
1202349).
www.epa.gov/cmop
12
-------
Table 3-9: Mines Listed by Estimated Total Methane Liberated in 2016
Mine Name
MMCF/D
Buchanan Mine #1
62.7
No. 7 Mine
30.7
Marshall County Mine
15.9
Marion County Mine
13.5
No. 4 Mine
11.7
Cumberland Mine
11.5
Bailey Mine
11.3
Shoal Creek
10.2
Enlow Fork Mine
9.8
Harrison County Mine
9.5
Monogalia County Mine
8.9
Oak Grove
7.5
MC# 1 Mine
7.0
Harvey Mine
6.9
The American Coal Company New Future Mine
6.8
Pinnacle Mine
4.7
San Juan Mine 1
4.6
Leer Mine
4.5
Ohio County Mine
4.5
The American Coal Company New Era Mine
4.5
Deep Mine 41
4.2
Gibson Mine
4.2
Beckley Pocahontas Mine
3.6
Tunnel Ridge Mine
3.4
American Eagle Mine
3.0
Oaktown Fuels Mine No. 1
2.9
Mach #1 Mine
2.7
West Elk Mine
2.5
Oaktown Fuels Mine No. 2
2.5
Gibson South
2.5
Sentinel Mine
2.3
P8 North
2.2
Hamilton County Coal Mine #1
2.2
Federal No 2
2.1
Pattiki Mine
2.1
www.epa.gov/cmop
13
-------
Table 3-10: Mines Listed by Daily Ventilation Emissions in 2016
Mine Name
MMCF/D
No. 7 Mine
13.7
Marshall County Mine
12.2
Marion County Mine
12.1
Enlow Fork Mine
9.8
Buchanan Mine #1
8.9
Bailey Mine
7.8
Cumberland Mine
7.4
MC #1 Mine
7.0
Harrison County Mine
6.8
The American Coal Company New Future Mine
6.8
Monogalia County Mine
6.0
Leer Mine
4.5
Ohio County Mine
4.5
Pinnacle Mine
4.5
The American Coal Company New Era Mine
4.5
Harvey Mine
4.2
Deep Mine 41
4.2
Gibson Mine
4.2
Oak Grove
4.2
San Juan Mine 1
3.9
Beckley Pocahontas Mine
3.7
No. 4 Mine
3.6
Tunnel Ridge Mine
3.4
American Eagle Mine
3.0
Mach #1 Mine
2.7
Oaktown Fuels Mine No. 1
2.6
Gibson South
2.5
Oaktown Fuels Mine No. 2
2.4
Sentinel Mine
2.3
P8 North
2.2
Shoal Creek
2.2
Hamilton County Coal Mine #1
2.2
Federal No 2
2.1
Pattiki Mine
2.1
West Elk Mine
1.6
www.epa.gov/cmop
14
-------
Table 3-11: Mines Listed by Estimated Daily Methane Drained in 2016
Mine Name
MMCF/D
Buchanan Mine #1
53.8
No. 7 Mine
17.1
No. 4 Mine
8.0
Shoal Creek
8.0
Cumberland Mine
4.2
Marshall County Mine
3.7
Bailey Mine
3.6
Oak Grove
3.3
Monogalia County Mine
2.8
Harvey Mine
2.7
Harrison County Mine
2.7
Marion County Mine
1.4
West Elk Mine
1.0
San Juan Mine 1
0.7
Oaktown Fuels Mine No. 1
0.3
Pinnacle Mine
0.2
Oaktown Fuels Mine No. 2
0.1
Enlow Fork Mine
0.0
MC #1 Mine
-
The American Coal Company New Future Mine
-
Leer Mine
-
Ohio County Mine
-
The American Coal Company New Era Mine
-
Deep Mine 41
-
Gibson Mine
-
Beckley Pocahontas Mine
-
Tunnel Ridge Mine
-
American Eagle Mine
-
Mach #1 Mine
-
Gibson South
-
Sentinel Mine
-
P8 North
-
Hamilton County Coal Mine #1
-
Federal No 2
-
Pattiki Mine
-
www.epa.gov/cmop
15
-------
Table 3-12: Mines Listed by Estimated Specific Emissions in 2016
Mine Name
CF/Ton
No. 4 Mine
12,389
Buchanan Mine #1
4,626
No. 7 Mine
3,657
P8 North
2,008
Pinnacle Mine
1,870
Oak Grove
1,853
The American Coal Company New Future Mine
1,755
Shoal Creek
1,594
Beckley Pocahontas Mine
1,355
Marion County Mine
1,127
Deep Mine 41
1,022
The American Coal Company New Era Mine
941
Harvey Mine
852
Sentinel Mine
840
Monongalia County Mine
832
Cumberland Mine
605
Marshall County Mine
553
American Eagle Mine
548
Harrison County Mine
526
Federal No 2
505
Oaktown Fuels No. 2
480
Leer Mine
463
Pattiki Mine
403
San Juan Mine 1
389
Enlow Fork Mine
372
Bailey Mine
343
Oaktown Fuels No. 1
278
Hamilton County Coal Mine #1
268
Ohio County Mine
262
Gibson South
234
MC #1 Mine
222
Tunnel Ridge Mine
188
Mach #1 Mine
183
West Elk Mine
182
Gibson Mine
0
www.epa.gov/cmop
16
-------
Table 3-13: Mines with CMM Recovery and Use Projects
Type of
Estimated Current
Mine Name
Use Project
Market Penetration
Buchanan Mine #1
Pipeline/Power
100%
Oak Grove
Pipeline
99%
No. 4 Mine
Pipeline
91%
No. 7 Mine
Pipeline
90%
Shoal Creek
Pipeline
85%
Pinnacle Mine
Pipeline
81%
Marshall County Mine
VAM Destruction
64%
Cumberland Mine
Pipeline
24%
West Elk Mine
Heaters
21%
Harrison County Mine
Pipeline
11%
Marion County Mine
Pipeline
7%
Monongalia County Mine
Pipeline
4%
Bailey Mine
Pipeline
3%
www.epa.gov/cmop
17
-------
4. Profiled Mines
Chapter 4 profiles individual underground coal mines that appear to be good candidates for the
development of methane recovery projects. At least 13 of these mines already sell recovered methane,
and at least 3 mines consume methane onsitefor power generation, to heat mine ventilation air, flare
CMM, or use produced gas as fuel in onsite vacuum pumps.
Alabama Mines
No. 4 Mine
No. 7 Mine
Oak Grove Mine
Shoal Creek Mine
www.epa.gov/cmop
18
-------
Mine Status: Active
Use Project: Pipeline
NO. 4 MINE
Drainage System: Yes
MSHA ID: 0101247
Basin: Black Warrior
State: AL
Coalbed: Blue Creek / Mary Lee
County: Tuscaloosa
Current Operator: Warrior Met Coal Mining, LLC
Owner/Parent Company: Warrior Met Coal Mining LLC
Parent Company Website: http://www.warriormetcoal.com/
Previous Owner(s): Jim Walter Resources Inc.
Previous or Alternate Name of Mine: Blue Creek No. 4
Description of SurroundingTerrain: Open Hills/Open High Hills
Utility Electric Supplier: Alabama Power Co
Parent Corporation of Utility: Southern Co
Mailing Address: 14730 Lock 17 Rd, Brookwood,
AL 35444
Latitude/Longitude: 33.2615, -87.3115
Number of Employees at Mine: 143
Mining Method: Longwall
Year of Initial Production: 1976
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 1,900
Seam Thickness (ft.): 5.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan
Distance to Pipeline (miles): 5.3
Coal
Production
(million
short tons)
2.8
2.8
3.1
3
2.2
3.1
3.2
2.7
2.8
2.1
1.9
2.6
2.7
2.4
0.3
Emission
from
Ventilation
Systems
(MMCF/D)
11.7
8.7
8.2
6.3
6.4
9.7
10.7
12.2
13.2
9.8
9.2
9.3
10.9
6.5
3.6
Estimated
Methane
Drained
14.8
11.4
8.3
19.2
16.8
23.3
12.9
19.1
14
5.4
3.2
8.6
10.4
12.4
8.0
(MMCF/D)
Estimated
3,45
5
Specific
Emissions
2,620
1,943
3,103
3,849
3,886
2,692
4,231
3,546
2,642
2,382
2,513
2,879
2,874
12,389*
(CF/T)
Methane
Used
(MMCF/D)
14.8
11.4
8.3
19.2
16.8
23.3
12.9
19.5
14.5
5.8
3.4
8.6
10.4
12.5
7.3
Estimated
Current
Drainage
Efficiency
56%
57%
50%
75%
73%
71%
55%
61%
51%
36%
26%
48%
49%
66%
69%
Estimated
Current
Market
100%
100%
100%
100%
100%
100%
100%
102%
104%
107%
106%
100%
100%
101%
91%
Penetration
*2016 estimated specific emissions were higher than usual because the No. 4 Mine was idled for most of 2016 (Warrior, 2017).
Coal Production (million short tons)
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
^ ^ / / # / f ^ ^ ^
Emissions (MMCF/D)
25
20
15
10
5
0
^ ^ J?
ocP oE? is1 "fl? nv *G» 'V? "b»
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
19
-------
Mine Status: Active
Use Project: Pipeline
NO. 7 MINE
Drainage System: Yes
MSHA ID: 0101401
Basin: Black Warrior
State: AL
Coalbed: Blue Creek / Mary Lee
County: Tuscaloosa
Current Operator: Warrior Met Coal Mining, LLC
Owner/Parent Company: Warrior Met Coal Mining LLC
Parent Company Website: http://www.warriormetcoal.com/
Previous Owner(s): Jim Walter Resources Inc.
Previous or Alternate Name of Mine: Blue Creek No. 7
Description of SurroundingTerrain: Open Hills/Open High Hills
Utility Electric Supplier: Alabama Power Co
Parent Corporation of Utility: Southern Co
Mailing Address: 18069 Hannah Creek Rd, Brookwood,
AL 35444
Latitude/Longitude: 33.2615, -87.3115
Number of Employees at Mine: 539
Mining Method: Longwall
Year of Initial Production: 1978
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 1,900
Seam Thickness (ft.): 6.4
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan
Distance to Pipeline (miles): 5.1
Coal
Production
(million short
tons)
2
1.9
2.3
2
2.6
2.7
2.9
3.3
3.9
3.6
4.8
5.4
5.2
3.0
3.1
Emission
from
Ventilation
Systems
(MMCF/D)
11
9.8
7.9
7.8
8.7
12.7
21.3
29
23.5
22.9
26.2
22.5
20.4
15.2
13.7
Estimated
Methane
Drained
14
12.8
8
24
22.9
11.5
13.4
11
21.2
18.1
15.9
16.8
10.1
11.3
17.1
(MMCF/D)
Estimated
4,56
3
Specific
Emissions
4,342
2,523
5,804
4,436
3,273
4,367
4,424
4,184
4,157
3,201
2,656
2,141
3,224
3,657
(CF/T)
Methane
Used
(MMCF/D)
14
12.8
8
24
22.9
11.5
13.4
11
21.2
18.1
15.9
16.8
10.1
11.3
15.3
Estimated
Current
Drainage
Efficiency
56%
57%
50%
75%
73%
48%
39%
28%
47%
44%
38%
43%
33%
43%
56%
Estimated
Current
Market
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
90%
Penetration
Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0
^ ^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
35
30
25
20
15
10
5
0
# ^ ^ ^ ^ ^
<•$ /A- A «> A *So
# -&• & -s? &
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
20
-------
Mine Status:
Use Project:
Active
Pipeline
tffflfcfehWJMIIh
Drainage System: Yes
MSHA ID: 0100851
Basin: Black Warrior
State: AL
Coalbed: Blue Creek
County: Jefferson
Current Operator: Oak Grove Resources LLC
Owner/Parent Company: Seneca Coal Resources
Parent Company Website: http://www.erpfuels.com/
Previous Owner(s): Cliffs Natural Resources, US Steel Mining Co LLC
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Hills/Open High Hills
Utility Electric Supplier: Alabama Power Co
Parent Corporation of Utility: Southern Co
Mailing Address: 8800 Oak Grove Mine Rd, Adger, AL
35006
Latitude/Longitude: 33.45075, -87.03723
Number of Employees at Mine: 303
Mining Method: Longwall
Year of Initial Production: 1981
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 1,000
Seam Thickness (ft.): 5.2
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan
Distance to Pipeline (miles): 3.7
e&ei
Eml
Coal
Production
(million
short tons)
1.9
1.7
1.5
1.7
1.4
1
0.9
0.8
0.9
0.5
2.2
2.3
2.3
2.0
1.5
Emission
from
Ventilation
Systems
(MMCF/D)
5.1
8.5
10
7.3
6.7
7.5
6.9
7.5
7.3
7.3
4.2
5.2
6.1
6.3
4.2
Estimated
Methane
Drained
9.7
5.9
2.1
2.5
0.7
1.1
2.5
0
3.7
2.1
2.6
2.5
3.9
1.8
3.3
(MMCF/D)
Estimated
Specific
Emissions
2,843
3,092
2,944
2,104
1,929
3,139
3,812
3,423
4,461
6,862
1,128
1,222
1,571
1,478
1,853
(CF/T)
Methane
Used
(MMCF/D)
9.7
5.9
2.1
1.7
0.7
0.8
1
2.9
2.2
2.1
2.3
2.2
3.9
1.8
3.3
Estimated
Current
Drainage
Efficiency
66%
41%
17%
26%
10%
13%
27%
0%
33%
22%
38%
32%
39%
22%
44%
Estimated
Current
Market
100%
100%
100%
68%
100%
72%
40%
-
59%
100%
88%
88%
100%
100%
99%
Penetration
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
Coal Production (million short tons)
2.5
2.0
1.5
1.0
0.5
0.0
^ ^ ^ ^ ^ ^ ^ JSP ^ ^ ^
www. e pa. g o v/cm o p
21
-------
Mine Status: Active
Use Project: Pipeline
SHOALCREEK MINE
Drainage System: Yes
MSHA ID: 0102901
Basin: Black Warrior
State: AL
Coalbed: Blue Creek / Mary Lee
County: Walker
Current Operator: Drummond Company Inc.
Former Owner/Parent Company: Drummond Company Inc.;
Current Owner/Parent Company: Peabody Energy, Inc.
Parent Company Website: www.drummondco.com
Previous Owner(s): None in last 10 years
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Hills/High Hills
Utility Electric Supplier: Alabama Power Co
Parent Corporation of Utility: Southern Co
Mailing Address: 8488 Nancy Ann Bend Road Adger,
AL35006
Latitude/Longitude: 33.51314, -87.27675
Number of Employees at Mine: 419
Mining Method: Longwall
Year of Initial Production: 1994
Primary Coal Use: Steam
Depth to Seam (ft.): 1,150
Seam Thickness (ft.): 7.0-11.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: El Paso Corp/Kinder Morgan
Distance to Pipeline (miles): 1.3
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
4
3.8
3.8
2.2
0.8
1.3
2.1
1.6
1.7
1.8
1.3
1.5
1.8
2.0
2.3
Emission
from
Ventilation
Systems
(MMCF/D)
6.7
8.2
11.4
8.3
4.5
6.2
7.3
7.6
5.9
3.5
3
2.7
1.6
2.4
2.2
Estimated
Methane
Drained
0.7
0.5
1.8
2
0.1
1.3
2.1
2.7
7.1
7.8
15.8
5.4
3.2
8.5
8.0
(MMCF/D)
Estimated
Specific
Emissions
675
836
1,268
1,709
2,090
2,106
1,634
2,350
2,791
2,291
5,279
1,971
973
1,989
1,594
(CF/T)
Methane
Used
(MMCF/D)
0.7
0.5
0.6
0.1
0.1
0.6
1.4
2.7
7.1
7.4
15.4
3.4
1.1
3.2
6.8
Estimated
Current
Drainage
Efficiency
9%
6%
14%
19%
2%
17%
22%
26%
55%
69%
84%
67%
67%
78%
78%
Estimated
Current
Market
100%
100%
33%
5%
100%
46%
67%
100%
100%
95%
97%
63%
34%
38%
85%
Penetration
Coal Production (million short tons)
4.5
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
cO' e
<$" ^ ^ ^ ^
Emissions (MMCF/D)
20
15
10
5
0
^ ^ J? ^ ^ ^ ^ 4^ 4? ¦$? J?
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
22
-------
Colorado Mine
West Elk Mine
Drainage System: Yes
MSHA ID: 0503672
WEST ELK MINE
Mine Status: Active
Use Project: Heaters
Basin: Western
State: CO
Coalbed: B Seam
County: Gunnison
Current Operator: Mountain Coal Company, LLC
Owner/Parent Company: Arch Coal Inc.
Parent Company Website: http://www.archcoal.com/
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Hilly/Mountainous
Utility Electric Supplier: Delta-Montrose Electric Association
Parent Corporation of Utility: Touchstone Energy Cooperatives
Mailing Address: 5174 Highway 133 Somerset, CO
81434
Latitude/Longitude: 38.927032,-107.463917
Number of Employees at Mine: 261
Mining Method: Longwall
Year of Initial Production: 1983
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 1,000-2,000
Seam Thickness (ft.): 12
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan Inc
Distance to Pipeline (miles): 26
Coal
Production
(million short
6.6
6.5
6.5
5.6
6.0
6.9
5.9
4.5
4.8
5.9
6.9
5.8
6.2
5.1
4.2
tons)
Emission
from
Ventilation
Systems
(MMCF/D)
9.9
13.6
10.4
11.4
9.1
10.8
8.8
5.0
5.5
5.6
4.1
3.0
2.2
1.7
1.6
Estimated
Methane
Drained
9.9
13.6
10.5
11.4
9.1
3.6
2.9
1.7
1.8
1.9
2.8
2.0
1.5
1.0
1.0
(MMCF/D)
Estimated
Specific
Emissions
1,095
1,527
1,174
1,486
1,107
762
724
543
555
464
365
315
219
193
182
(CF/T)
Methane
Used
(MMCF/D)
-
0.1
0.5
0.5
0.5
0.5
0.5
0.5
0.5
-
0.1
0.2
0.2
0.2
0.2
Estimated
Current
Drainage
Efficiency
60%
50%
50%
50%
5-%
25%
25%
25%
25%
25%
41%
40%
41%
37%
38%
Estimated
Current
Market
-
1%
5%
4%
5%
14%
17%
29%
28%
0%
4%
10%
13%
20%
21%
Penetration
Coal Production (million short tons)
8.0
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
www.epa.gov/cmop
23
-------
Illinois Mines
The American Coal Company New Era Mine
The American Coal Company New Future Mine
Hamilton County Coal Mine #1
Mach #1 Mine
MC #1 Mine
Pattiki Mine
www.epa.gov/cmop
24
-------
Mine Status: Active
Use Project: NA
THE AMERICAN COAL COMPANY NEW ERA MINE
Drainage System: No
MSHA ID: 1102752
Basin: Illinois
State: IL
Coalbed: Springfield No. 5
County: Saline
Current Operator: The American Coal Company
Owner/Parent Company: Murray Energy Corp
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): Kerr-McGee Coal Corp
Previous or Alternate Name of Mine: Galatia No. 56, Galatia
Description of SurroundingTerrain: Open Hills/Irregular Plains
Utility Electric Supplier: AmrenCIPS
Parent Corporation of Utility: Ameren Corp.
Mailing Address: 9085 Highway 34 North Galatia, IL
62935
Latitude/Longitude: 37.86433, -88.6145
Number of Employees at Mine: 202
Mining Method: Longwall
Year of Initial Production: 1983
Primary Coal Use: Steam
Depth to Seam (ft.): 600-830
Seam Thickness (ft.): 5.0-6.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Atmos Energy
Distance to Pipeline (miles): 0.1
e&ei
Eml
Coal
Production
(million
short tons)
6.3
6
6.5
5.9
7.2
7
5.3
6.3
5.8
4.9
5.6
4.4
5.5
3.1
1.7
Emission
from
Ventilation
Systems
(MMCF/D)
6.1
3.9
5.6
7.5
8.5
6.9
9.9
8.2
8.6
6.5
8.2
5.1
4.2
6.5
4.5
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
353
237
315
464
431
360
682
475
541
484
535
423
279
765
941
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
8.0
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
Emissions (MMCF/D)
12
10
8
6
4
2
0
# ^ ^ ^
?
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
25
-------
Mine Status: Active
Use Project: NA
THE AMERICAN COAL COMPANY NEW FUTURE MINE
Drainage System: No
MSHA ID: 1103232
Basin: Illinois
State:IL
Coalbed: Herrin No. 6
County: Saline
Current Operator: The American Coal Company
Owner/Parent Company: Murray Energy Corp
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Hills/Irregular
Utility Electric Supplier: AmrenCIPS
Parent Corporation of Utility: Ameren Corp.
Mailing Address: 9085 Highway 34 North Galatia, IL
62935
Latitude/Longitude: 37.82967, -88.63985
Number of Employees at Mine: 132
Mining Method: Longwall
Year of Initial Production: 2010
Primary Coal Use: Steam
Depth to Seam (ft.): 600-900
Seam Thickness (ft.): NA
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Atmos Energy
Distance to Pipeline (miles): NA
E££]
Coal
Production
(million
short tons)
-
-
-
-
-
-
0.6
1.8
3.6
5.5
5.7
5.2
1.4
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
4.4
3.4
3.5
4.8
5.1
3.9
6.8
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
0
0
0
0
0
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
2,677
689
355
319
327
274
1,755
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
0%
0%
0%
0%
0%
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0
cf? c5^ & of? n"? ^ ^ jf? -.-J* ^
Emissions (MMCF/D)
Emission from Ventilation Systems 1 Estimated Methane D rained
www.epa.gov/cmop
26
-------
Mine Status: Active
Use Project: NA
HAMILTON COUNTY COAL MINE #1
Drainage System: No
MSHA ID: 1103203
Basin: Illinois
State:IL
Coalbed: Herrin No. 6
County: Hamilton
Current Operator: Hamilton County Coal, LLC
Owner/Parent Company: Alliance Resource Partners LP
Parent Company Website: http://www.arlp.com/
Previous Owner(s): White Oak LLC
Previous or Alternate Name of Mine: White Oak Mine No. 1
Description of SurroundingTerrain: Flat
Utility Electric Supplier: NA
Parent Corporation of Utility: NA
Mailing Address: 18033 County Rd. 500 East
Dahlgreen, IL 62828
Latitude/Longitude: 37.170524, -88.614144
Number of Employees at Mine: 214
Mining Method: Longwall
Year of Initial Production: 2013
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 1,000
Seam Thickness (ft.): 6
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
E££]
Coal
Production
(million
short tons)
-
-
-
-
-
-
-
-
-
0.19
1.7
5.8
3.0
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
0.0
0.3
2.2
2.2
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
-
-
-
19
64
138
268
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
7.0 -I
6.0 -
5.0 -
4.0
3.0
2.0
1.0
0.0
Coal Production (million short tons)
/\
A* ^
i? <•£ ^
Emissions (MMCF/D)
3 -I
2
2
1 -
1
^ / / /
-------
Mine Status: Active
Use Project: NA
MACH #1 MINE
Drainage System: No
MSHA ID: 1103141
Basin: Illinois
State: IL
Coalbed: Herrin No. 6
County: Williamson
Current Operator: Mach Mining LLC
Owner/Parent Company: Foresight Energy Labor LLC
Parent Company Website: http://www.foresight.com/
Previous Owner(s): None
Previous or Alternate Name of Mine: Pond Creek Mine
Description of SurroundingTerrain: Flat
Utility Electric Supplier: NA
Parent Corporation of Utility: NA
Mailing Address: 11525 N. Thompsonville Road
Macedonia, IL 62860
Latitude/Longitude: 37.84, -88.8300018311
Number of Employees at Mine: 216
Mining Method: Longwall
Year of Initial Production: 2006
Primary Coal Use: Steam
Depth to Seam (ft.): 6
Seam Thickness (ft.): 500
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
E££]
eeh
Coal
Production
(million
short tons)
0.1
1.1
5.5
5.9
5.8
7.2
7.5
6.7
6.5
5.6
5.4
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
0.2
0.2
1.4
1.6
2.8
2.3
2.8
2.4
2.6
2.9
2.7
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
-
-
-
-
730
730
93
99
176
117
136
131
146
189
183
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
8.0
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
. -J?" ^ ^ c??
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
www.epa.gov/cmop
28
-------
Mine Status:
Use Project:
Active
NA
Drainage System: No
MSHA ID: 1103189
Basin: Illinois
State: IL
Coalbed: Herrin No. 6
County: Franklin
Current Operator: M-Class Mining LLC
Owner/Parent Company: Foresight Energy
Parent Company Website: www.foresight.com
Previous Owner(s): None
Previous or Alternate Name of Mine: Sugar Camp
Description of SurroundingTerrain: Open Hills/Irregular
Utility Electric Supplier: Central Illinois Public Services Co
Parent Corporation of Utility: Ameren Corp.
MC #1 MINE
Mailing Address: 11525 N. Thompsonville Road
Macedonia, IL 62860
Latitude/Longitude: 39.9705, -80.4141
Number of Employees at Mine: 410
Mining Method: Longwall
Year of Initial Production: 2008
Primary Coal Use: Steam
Depth to Seam (ft.): 600-900
Seam Thickness (ft.): NA
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
E££]
Coal
Production
(million
short tons)
-
-
-
-
-
-
0.3
0.9
4.7
6.5
9.1
10.6
11.4
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
0.2
0.4
2.2
2.6
4.4
6.8
7.0
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
243
162
171
146
177
234
222
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
12.0
10.0
8.0
6.0
4.0
2.0
0.0
^ ^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
s
7
-
6
5
/
4
/
3
2
1
^ ^ ^ ^ ^ ^ ^ ^ ^
Emission from Ventilation Systems ^^^Estimated Methane Drained
www.epa.gov/cmop
29
-------
Mine Status:
Use Project:
Non-Producing
NA
PATTIKI MINE
Drainage System: No
MSHA ID: 1103058
Basin: Illinois
State:IL
Coalbed: Herrin No. 6
County: White
Current Operator: White County Coal, LLC
Owner/Parent Company: Alliance Resource Partners LP
Parent Company Website: http://www.arlp.com/
Previous Owner(s): MAPCO Coal Inc
Previous or Alternate Name of Mine: Galatia Mine No. 56-1
Description of SurroundingTerrain: Irregular Plains
Utility Electric Supplier: Wayne-White Counties Electric Coop
Parent Corporation of Utility: NA
Mailing Address: 1525 County Rd 1300 N
Carmi, IL 62835
Latitude/Longitude: 38.064818, -88.089559
Number of Employees at Mine: 219
Mining Method: Room and Pillar
Year of Initial Production: 1980
Primary Coal Use: Steam
Depth to Seam (ft.): NA
Seam Thickness (ft.): NA
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Texas Eastern Transmission Co.
Distance to Pipeline (miles): 3.3
e&ei
Eml
Coal
Production
(million
short tons)
1.8
0.3
2.4
2.6
2.5
2.9
2.7
2.5
1.7
2.2
2.4
2.6
2.6
2.4
1.9
Emission
from
Ventilation
Systems
(MMCF/D)
1.9
0.6
1.1
1.7
2.0
1.9
2.7
2.2
1.8
1.9
2.1
1.7
1.9
0.3
2.1
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
371
704
167
238
297
239
365
321
387
315
319
239
267
46
403
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
3
3
2
2
1
1
0
# # J" J? J? J* # J* J J
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
30
-------
Indiana Mines
Gibson Mine
Gibson South
Oaktown Fuels No. 1
Oaktown Fuels No. 2
www.epa.gov/cmop
31
-------
Mine Status:
Use Project:
Active
NA
Drainage System: No
MSHA ID: 1202215
Basin: Illinois
State: IN
Coalbed: Springfield No. 5
County: Gibson
Current Operator: Gibson County Coal LLC
Owner/Parent Company: Alliance Resource Partners LP
Parent Company Website: http://www.arlp.com/
Previous Owner(s): Alliance Resources Holdings
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Flat
Utility Electric Supplier: Duke Energy Indiana Inc.
Parent Corporation of Utility: Duke Energy Corp
GIBSON MINE
Mailing Address: RR #3
Princeton, IN 47670
Latitude/Longitude: 38.362943,-87.582192
Number of Employees at Mine: 43
Mining Method: Room and Pillar
Year of Initial Production: 2000
Primary Coal Use: Steam
Depth to Seam (ft.): NA
Seam Thickness (ft.): 0.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Vectren Corporation
Distance to Pipeline (miles): 0.7
E££]
eeh
Coal
Production
(million
short tons)
1.9
2.4
3.0
3.4
3.6
3.2
3.8
3.4
3.1
3.4
3.4
3.9
3.8
2.2
-
Emission
from
Ventilation
Systems
(MMCF/D)
2.2
2.4
2.2
2.6
3.1
3.5
4.7
4.6
4.2
4.3
4.5
3.4
4.7
2.5
4.2
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
423
365
268
279
314
399
451
494
495
462
483
318
451
415
-
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
www.epa.gov/cmop
32
-------
Mine Status: Active
Use Project: NA
GIBSON SOUTH
Drainage System: No
MSHA ID: 1202388
Basin: Illinois
State: IN
Coalbed: Springfield No. 5
County: Gibson
Current Operator: Gibson County Coal LLC
Owner/Parent Company: Alliance Resource Partners LP
Parent Company Website: http://www.arlp.com/
Previous Owner(s): Alliance Resources Holdings
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Flat
Utility Electric Supplier: Duke Energy Indiana
Parent Corporation of Utility: Duke Energy Corp
Mailing Address: RR #3
Princeton, IN 47670
Latitude/Longitude: 38.362943,-87.582192
Number of Employees at Mine: 278
Mining Method: Room and Pillar
Year of Initial Production: 2014
Primary Coal Use: Steam
Depth to Seam (ft.): NA
Seam Thickness (ft.): 0.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Vectren Corporation
Distance to Pipeline (miles): 0.7
E&U
Coal
Production
(million
short tons)
-
-
-
-
-
-
-
-
-
-
0.8
2.9
3.9
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
2.6
2.5
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
-
-
-
-
-
327
234
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
4.5 -I
4.0 -
3.5 -
3.0
2.5
2.0
1.5
1.0
0.5
0.0 -
Coal Production (million short tons)
/
& j# J? .<&
¦nP
Emissions (MMCF/D)
tC' cJ> pf1 pj" ^ c8> <§) iS> \V
CN° CV5 CV° _CVJ _CS° _CV> _CV> CN* _C\> _C\*
^ J?
-Emission from Ventilation Systems
-Estimated Methane Drained
www.epa.gov/cmop
33
-------
Mine Status: Active
Use Project: NA
OAKTOWN FUELS NO. 1
Drainage System: Yes
MSHA ID: 1202394
Basin: Illinois
State: IN
Coalbed: Springfield No. 5
County: Knox
Current Operator: Sunrise Coal LLC
Owner/Parent Company: Hallador Energy Company
Parent Company Website: www.halladorenergy.com
Previous Owner(s): Black Panther Mining LLC
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Flat farmland
Utility Electric Supplier: Duke Energy Indiana Inc.
Parent Corporation of Utility: Duke Energy Corp
Mailing Address: 12661 North Agri Care Road
Oaktown, IN 47561
Latitude/Longitude: 38.94575, -87.38421
Number of Employees at Mine: 367
Mining Method: Room and Pillar
Year of Initial Production: 2007
Primary Coal Use: Steam
Depth to Seam (ft.): 350-450
Seam Thickness (ft.): 0.5
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Coal
Production
(million short
tons/year)
-
-
-
-
-
-
0.0
0.05
1.0
2.7
2.8
3.4
3.4
3.5
3.8
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
0.3
0.7
1.6
2.7
2.2
2.7
2.8
2.6
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
0.05
0.1
0.3
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
1,190
256
216
352
236
295
302
278
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
2%
3%
10%
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
Emissions from Ventilation System
Estimated Methane Drained
www.epa.gov/cmop
34
-------
Mine Status: Active
Use Project: NA
OAKTOWN FUELS NO. 2
Drainage System: Yes
MSHA ID: 1202418
Basin: Illinois
State: IN
Coalbed: Springfield No. 5
County: Knox
Current Operator: Sunrise Coal LLC
Owner/Parent Company: Hallador Energy Company
Parent Company Website: www.halladorenergy.com
Previous Owner(s): Black Panther Mining LLC
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Flat farmland
Utility Electric Supplier: Duke Energy Indiana Inc.
Parent Corporation of Utility: Duke Energy Corp
Mailing Address: 12661 North Agri Care Road
Oaktown, IN 47561
Latitude/Longitude: 38.862499, -87.428433
Number of Employees at Mine: 240
Mining Method: Room and Pillar
Year of Initial Production: 2013
Primary Coal Use: Steam
Depth to Seam (ft.): 350-450
Seam Thickness (ft.): 0.5
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Coal
Production
(million short
tons/year)
-
-
-
-
-
-
-
-
-
-
-
1.0
2.1
2.2
1.9
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
0.1
1.0
1.7
2.0
2.4
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
0.1
0.1
0.1
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
-
-
-
183
313
348
480
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
6%
5%
4%
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
2.5
2.0
1.5
/
1.0
/
0.5
0.0
/ . . ,
^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
3
3
2
2
1
1
0 -I 1 1 1 1 1
# ^ J? J* J
? J* f
# #
Emissions from Ventilation System Estimated Methane Drained
www.epa.gov/cmop
35
-------
New Mexico Mine
San Juan Mine 1
Drainage System: Yes
MSHA ID: 2902170
SAN JUAN MINE 1
Mine Status: Active
Use Project: NA
Basin: San Juan
State: NM
Coal bed: No. 9/ No. 8
County: San Juan
Current Operator: San Juan Coal Company
Owner/Parent Company: Westmoreland Coal Company
Parent Company Website: www.westmoreland.com
Previous Owner(s): BHP Billiton
Previous or Alternate Name of Mine: San Juan South
Description of SurroundingTerrain: Flat arid terrain
Utility Electric Supplier: Jemez Mountains Electric Coop Inc.
Parent Corporation of Utility: NA
Mailing Address: PO Box 561, Waterflow, NM 87421
Latitude/Longitude: 39.919613, -80.471824
Number of Employees at Mine: 404
Mining Method: Longwall
Year of Initial Production: 1997
Primary Coal Use: Steam
Depth to Seam (ft.): 400-900
Seam Thickness (ft.): 10.0-13.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Western Gas Resources
Inc.
Distance to Pipeline (miles): NA
Coal
Production
(million short
tons)
1.8
5.9
7.7
7.9
7
6.9
7
6.5
4.9
3.9
4.9
6
8.8
6.5
4.3
Emission
from
Ventilation
Systems
(MMCF/D)
1.5
1.3
1.6
3.9
3.9
3.5
4.8
5.5
5.8
6.2
3.5
2.9
2.7
4.4
3.9
Estimated
Methane
Drained
(MMCF/D)
0.5
2.3
2.5
2.6
2.6
2.3
3.2
3.7
3.9
4.2
1.2
1.9
2.1
1.7
0.7
Estimated
Specific
Emissions
(CF/T)
406
223
194
300
339
307
417
517
723
973
350
292
199
343
389
Methane
Used
(MMCF/D)
-
0
0.2
0
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
25%
64%
61%
40%
40%
40%
40%
40%
40%
40%
26%
40%
44%
28%
15%
Estimated
Current
Market
Penetration
-
>1%
8%
>1%
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
www.epa.gov/cmop
36
-------
Oklahoma Mine
P8 North
Mine Status:
Use Project:
Active
NA
Basin: Western Interior
State: OK
Coal bed: NA
County: Le Flore
Current Operator: Txoma Mining LLC
Owner/Parent Company: L. Keller Smith
Parent Company Website: NA
Previous Owner(s): South Central Coal Company, Inc.
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Hilly
Utility Electric Supplier: NA
Parent Corporation of Utility: NA
Drainage System: No
MSHA ID: 3402080
Mailing Address: 22279 US Highway 271
Spiro, OK 74959
Latitude/Longitude: 35.238143, -94.642531
Number of Employees at Mine: 76
Mining Method: Longwall
Year of Initial Production: 2010
Primary Coal Use: Steam
Depth to Seam (ft.): NA
Seam Thickness (ft.): NA
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
-
-
-
-
-
-
-
-
0.2
0.4
0.3
0.4
0.4
0.4
0.4
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
0.5
0.6
1.0
0.8
-
1.8
2.2
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
913
548
1,217
730
-
1,643
2,008
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
0.5
0.4
0.4
0.3
0.3
0.2
0.2
0.1
0.1
0.0
^ ^ ^ ^ ^
Emissions (MMCF/D)
3
2
2
1
1
0
J" J- J? J- 4> J?
Emissions from Ventilation System Estimated Methane Drained
www.epa.gov/cmop
37
-------
Pennsylvania Mines
Bailey Mine
Cumberland Mine
Enlow Fork Mine
Harvey Mine
www.epa.gov/cmop
38
-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 3607230
BAILEY MINE
Basin: Northern Appalachian
State: PA
Coalbed: Pittsburgh No. 8
County: Greene
Current Operator: Consol Pennsylvania Coal Company LLC
Owner/Parent Company: CONSOL Energy Inc.
Parent Company Website: www.consolenergy.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: High Hills/Open High Hills
Utility Electric Supplier: West Penn Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 192 Crabapple Road Wind Ridge,
PA 15380
Latitude/Longitude: 39.919613, -80.471824
Number of Employees at Mine: 683
Mining Method: Longwall
Year of Initial Production: 1984
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 600-1000
Seam Thickness (ft.): 5.2-6.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: National Fuel Gas Supply Corp
Distance to Pipeline (miles): < 0.1
E££]
eeh
Coal
Production
(million
short tons)
9.7
9.4
10.1
11.1
10.2
9.8
10
10.2
10.6
10.8
10.1
11.3
12.3
10.2
12.1
Emission
from
Ventilation
7.1
5.7
8.4
6.9
7.5
8.6
9.8
10.5
14.2
11.3
9.2
15.6
10.4
7.4
7.8
Systems
(MMCF/D)
Estimated
Methane
Drained
0.1
-
-
2.9
3.2
1.5
1.7
1.8
2.5
1.1
1.2
1.5
1.8
3.1
3.6
(MMCF/D)
Estimated
Specific
Emissions
271
221
304
322
383
376
420
440
575
419
376
552
362
376
343
(CF/T)
Methane
Used
-
-
-
-
-
-
-
-
-
-
-
-
1.8
-
0.1
(MMCF/D)
Estimated
Current
Drainage
Efficiency
1%
-
-
30%
30%
15%
15%
15%
15%
9%
12%
9%
15%
30%
32%
Estimated
Current
Market
-
-
-
-
-
-
-
-
-
-
-
-
100%
>1%
3%
Penetration
Coal Production (million short tons)
Emissions (MMCF/D)
20
15
10
5
0 -I 1 <—i 1 ,
# # J' J? J? J> J
# n?S ¦*>* n?S
Emission from Ventilation Systems 1 Estimated Methane D rained
www.epa.gov/cmop
39
-------
Mine Status: Active
Use Project: Pipeline
CUMBERLAND MINE
Drainage System: Yes
MSHA ID: 3605018
Basin: Northern Appalachian
State: PA
Coalbed: Pittsburgh No. 8
County: Greene
Current Operator: Cumberland Coal Resources LP
Owner/Parent Company: Contura Energy, Inc.
Parent Company Website: www.conturaenergy.com
Previous Owner(s): Alpha Natural Resources
Previous or Alternate Name of Mine: RAG Cumberland
Description of SurroundingTerrain: High Hills
Utility Electric Supplier: West Penn Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 576 Maple Run Rd, Waynesburg, PA
15370
Latitude/Longitude: 39.79547, -80.16442
Number of Employees at Mine: 709
Mining Method: Longwall
Year of Initial Production: 1972
Primary Coal Use: Steam
Depth to Seam (ft.): 400-1000
Seam Thickness (ft.): 6.5-7.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 0.4
e&ei
Eml
Coal
Production
(million
short tons)
6.6
6.2
5.2
7.1
7.5
7.3
7.3
6.8
5.8
6.2
6.4
5.6
7.4
7.5
7.0
Emission
from
Ventilation
Systems
(MMCF/D)
9.6
9.9
7.2
7.2
6.7
7.8
8.9
13
11.5
7.3
8.6
7.2
6.4
6.4
7.4
Estimated
Methane
Drained
1.5
4.4
3.4
3.7
3.4
3.8
3.9
4
4
4
5.1
6.4
6.7
5.5
4.2
(MMCF/D)
Estimated
Specific
Emissions
614
842
744
560
492
580
640
913
975
665
781
886
646
579
605
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
3.2
3.4
2.6
3.2
3.7
3.7
3.7
1.7
1.7
1.4
1.2
1.0
Estimated
Current
Drainage
Efficiency
14%
31%
32%
34%
34%
33%
30%
24%
26%
35%
37%
47%
51%
46%
36%
Estimated
Current
Market
-
-
-
86%
100%
68%
82%
93%
93%
93%
33%
27%
20%
22%
24%
Penetration
Coal Production (million short tons)
3.0
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
1 1 1 1 1 1 1 1 1 i 1 1 1 1
# $ $ $ $ $ $ 4^ 4* 4^ 4? 4? 4* 4^
Emissions (MMCF/D)
14
12
10
8
6
4
2
0
^ -6^ 4^ ^ 4* 4^ 4? 4? 4? 4? 4^ 4^ 4?
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
40
-------
Mine Status: Active
Use Project: NA
Drainage System: Yes
MSHA ID: 3607416
ENLOW FORK MINE
Basin: Northern Appalachian
State: PA
Coalbed: Pittsburgh No. 8
County: Washington
Current Operator: Consol Pennsylvania Coal Company
Owner/Parent Company: CONSOL Energy Inc.
Parent Company Website: www.consolenergy.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Hills/Open High Hills
Utility Electric Supplier: West Penn Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 2041 Pleasant Grove Road, Claysville,
PA 15323
Latitude/Longitude: 40.076034, -80.35271
Number of Employees at Mine: 606
Mining Method: Longwall
Year of Initial Production: 1990
Primary Coal Use: Steam
Depth to Seam (ft.): 600-1,000
Seam Thickness (ft.): 5.2-6.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: National Fuel Gas Supply Corp
Distance to Pipeline (miles): 1.2
E££]
eeh
Coal
Production
(million
short tons)
9.6
9.9
10.2
9.8
10.7
11.2
11.1
11.1
9.9
10.2
9.5
10.1
10.6
9.0
9.6
Emission
from
Ventilation
9
10.3
11
9.6
10.1
10.6
11.4
14.3
14.8
12.3
10.3
11.2
10.6
10.7
9.8
Systems
(MMCF/D)
Estimated
Methane
Drained
0.1
-
-
-
-
-
-
-
0.1
0.1
-
-
-
0.3
0.0
(MMCF/D)
Estimated
Specific
Emissions
346
380
394
358
345
345
375
470
549
444
396
405
365
446
372
(CF/T)
Methane
Used
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
(MMCF/D)
Estimated
Current
Drainage
Efficiency
1%
-
-
-
-
"
-
-
0%
0%
-
-
-
3%
0%
Estimated
Current
Market
Penetration
Coal Production (million short tons)
Emissions (MMCF/D)
10 -
c?> <$¦ cfr cfc c?»cP ^ ^ -D- ^ ^
js8 jh* js8 .or .er jcS* .cv .cv .cv .cv .cv
Emission from Ventilation Systems 1 Estimated Methane D rained
www.epa.gov/cmop
41
-------
Mine Status: Active
Use Project: NA
HARVEY MINE
Drainage System: Yes
MSHA ID: 3610045
Basin: Northern Appalachian
State: PA
Coalbed: Pittsburgh No. 8
County: Greene
Current Operator: Consol Pennsylvania Coal Company
Owner/Parent Company: CONSOL Energy Inc.
Parent Company Website: www.consolenergy.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Hills/Open High Hills
Utility Electric Supplier: West Penn Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 685 Patterson Creek Road Sycamore,
PA 15364
Latitude/Longitude: 39.9705, -80.4141
Number of Employees at Mine: 178
Mining Method: Longwall
Year of Initial Production: 2015
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 600-1,000
Seam Thickness (ft.): 5.2-6.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
-
-
-
-
-
-
-
-
-
-
-
-
3.2
3.6
3.0
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
4.5
5
4.2
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
1.2
2.7
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
-
-
-
-
513
629
852
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
19%
39%
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
6
5
4
3
2
1
0
# J3 J* JP J3
S* J3
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
42
-------
Virginia Mines
Buchanan Mine #1
Deep Mine 41
www.epa.gov/cmop
43
-------
Mine Status:
Use Project:
Active
Pipeline, Power
Drainage System: Yes
MSHA ID: 4404856
BUCHANAN MINE#1
Basin: Central Appalachian
State: VA
Coalbed: Pocahontas No. 3
County: Buchanan
Current Operator: Buchanan Minerals, LLC
Owner/Parent Company: Coronado IV LLC
Parent Company Website: www.coronadocoal.com
Previous Owner(s): CONSOL Buchanan Mining Company LLC and
Consolidation Coal Company
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Low Mountains/Low Mountains
Utility Electric Supplier: Appalachian Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
MailingAddress: Rte 680, Keen Mountain, VA 24624
Latitude/Longitude: 37.207886, -81.916612
Number of Employees at Mine: 469
Mining Method: Longwall
Year of Initial Production: 1983
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 1,400-2,000
Seam Thickness (ft.): 5.4
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Dominion
Distance to Pipeline (miles): 4.2
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
4.1
4.7
4.4
1.7
5
2.8
3.5
2.8
4.7
5.7
3.5
4.8
4.0
4.4
5.0
Emission
from
Ventilation
Systems
(MMCF/D)
9.5
7.3
7.5
6.4
8.4
9
8.5
6.2
9.7
10.2
8
10.3
7.9
7.3
8.9
Estimated
Methane
Drained
38.7
35.3
35.8
30.6
63.9
52.3
67.9
60.8
75.4
72.2
62.7
67.4
67.7
51.2
53.8
(MMCF/D)
Estimated
Specific
Emissions
4,291
3,308
3,592
7,944
5,278
7,991
7,967
8,734
6,609
5,277
7,373
5,908
6,899
4,853
4,626
(CF/T)
Methane
Used
(MMCF/D)
38.7
34
35.7
30.6
51.3
52.3
67.9
60.8
75.4
72.2
62.7
67.4
52.1
51.2
53.8
Estimated
Current
Drainage
Efficiency
80%
83%
83%
83%
88%
85%
89%
90%
89%
88%
89%
87%
90%
88%
86%
Estimated
Current
Market
100%
96%
99%
100%
80%
100%
100%
100%
100%
100%
100%
100%
77%
100%
100%
Penetration
Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0
Emissions (MMCF/D)
70
40
30
10 .
s3 -cy5 -cv •Cv3 .cv° .cv .cv .cv .cv ja* .cs* .o*
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
44
-------
Mine Status: Active
Use Project: NA
DEEP MINE 41
Drainage System: No
MSHA ID: 4407223
Basin: Central Appalachian
State: VA
Coal bed: NA
County: Dickenson
Current Operator: Paramount Contura, LLC
Owner/Parent Company: Contura Energy Inc
Parent Company Website: http://conturaenergy.com/
Previous Owner(s): Alpha Natural Resources Inc.
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Mountainous
Utility Electric Supplier: NA
Parent Corporation of Utility: NA
Mailing Address: 5703 Crutchfield Drive
Norton, VA 24273
Latitude/Longitude: 36.971027, -82.604644
Number of Employees at Mine: 325
Mining Method: NA
Year of Initial Production: 2010
Primary Coal Use: Steam
Depth to Seam (ft.): NA
Seam Thickness (ft.): NA
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Coal
Production
(million short
tons)
-
-
-
-
-
-
-
-
0.2
0.3
0.5
0.7
1.0
1.3
1.5
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
0.4
0.6
1.4
2.4
2.8
2.7
4.2
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
730
730
1,022
1,251
1,022
758
1,022
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
1.6
1.4
1.2
1.0
0.3
0.6
0.4
0.2
0.0
fS3*
-f ^ ^ ^ ^ ^
Emissions (MMCF/D)
5
4
3
2
1
0 -I 1 1 1 1 1
# ^ J? J* J
? J* f
# #
Emissions from Ventilation System Estimated Methane Drained
www.epa.gov/cmop
45
-------
West Virginia Mines
American Eagle Mine
Beckley Pocahontas Mine
Federal No. 2
Harrison County Mine
Leer Mine
Marion County Mine
Marshall County Mine
Monongalia County Mine
Ohio County Mine
Pinnacle Mine
Sentinel Mine
Tunnel Ridge Mine
www.epa.gov/cmop
46
-------
Mine Status: Active
Use Project: NA
AMERICAN EAGLE MINE
Drainage System: No
MSHA ID: 4605437
Basin: Central Appalachian
State: WV
Coalbed: Eagle/Big Eagle
County: Kanawha
Current Operator: Panther Creek Mining LLC
Owner/Parent Company: Blackhawk Mining LLC
Parent Company Website: http://www.blackhawkmining.com/
Previous Owner(s): Patriot Coal Corporation, Speed Mining Inc,
Appalachian Eagle Inc
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Mountainous
Utility Electric Supplier: Appalachian Power Co
Parent Corporation of Utility: American Electric Power Co Inc
Mailing Address: 903 Dawes Hollow
Dawes, WV 25054
Latitude/Longitude: 38.136332, -81.466969
Number of Employees at Mine: 252
Mining Method: Longwall
Year of Initial Production: 1977
Primary Coal Use: Steam
Depth to Seam (ft.): 600-1,000
Seam Thickness (ft.): 4.2
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): 0.93
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
3.3
4.1
4.1
3.5
2.4
1.8
2.3
2.1
1.9
1.8
2.3
2.4
2.7
1.9
2.0
Emission
from
Ventilation
Systems
(MMCF/D)
2.5
4.9
3.5
3.8
3.0
2.0
1.8
3.0
2.4
2.9
3.5
3.1
3.3
2.9
3.0
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
2.0
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
277
436
312
396
760
406
286
521
461
588
555
472
446
557
548
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
4.5 n
4.0
3.5
3.0
2.5
2.0
1.5 -
1.0
0.5 -
0.0
Coal Production (million short tons)
J? Jp
-CV5 _CN* -CN* _C\» -C\* .CNy
Emissions (MMCF/D)
&
'V 'V V V V T? T*
-Emissions from Ventilation System
^ .c&
f V f f T f
Estimated Methane Drained
www.epa.gov/cmop
47
-------
Mine Status:
Use Project:
Active
NA
Drainage System: Yes
MSHA ID: 4605252
BECKLEY POCAHONTAS MINE
Basin: Central Appalachian Basin
State: WV
Coalbed: Pocahontas No. 3
County: Raleigh
Current Operator: ICG BeckleyLLC
Owner/Parent Company: Arch Coal Inc
Parent Company Website: www.archcoal.com
Previous Owner(s): International Coal Group and Westmoreland Coal Company
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: High Hills/Hills
Utility Electric Supplier: Appalachian Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
Mailing Address: 279 Wolf Run Road Eccles, WV
25836
Latitude/Longitude: 37.7795, -81.2678
Number of Employees at Mine: 233
Mining Method: Continuous
Year of Initial Production: 2006
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 600-1,300
Seam Thickness (ft.): 4.2
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
-
-
-
-
-
0
0.4
0.7
1
1.1
1.1
1.1
1
0.9
1.0
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
0.3
1.2
4
4.5
2.9
3.1
2.9
3.3
3.3
3.7
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
1,095
2,086
1,643
962
1,029
962
1,205
1,338
1,355
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
1.2
1.0
0.8
0.6
0.4
0.2
0.0
^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
5
4
3
2
1
0
# J3 J* JP J3
S* J3
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
48
-------
Mine Status: Active
Use Project: NA
Drainage System: Yes
MSHA ID: 4601456
FEDERAL NO. 2
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Monongalia
Current Operator: ERP Federal Mining Complex, LLC
Owner/Parent Company: Virginia Conservation Energy Fund, Inc.
Parent Company Website: http://virginiaconservationlegacvfund.org/
Previous Owner(s): Peabody Energy Corp, Patriot Coal Corporation
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Low Mountains/High Hills
Utility Electric Supplier: Monongahela Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 1044 Miracle Run Road Fairview,
WV 26570
Latitude/Longitude: 39.67, -80.25
Number of Employees at Mine: 312
Mining Method: Longwall
Year of Initial Production: 1983
Primary Coal Use: Steam
Depth to Seam (ft.): 800-1,250
Seam Thickness (ft.): 7.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 0.7
E££]
Coal
Production
(million
short tons)
5
4.4
4.9
4.1
4.6
4
3.1
3.8
3.7
3.7
4
3.4
2.9
2.4
1.5
Emission
from
Ventilation
Systems
(MMCF/D)
10.6
7.6
4.6
5.6
5.7
7.6
6.2
5.9
7.8
7.8
6.8
6.5
4.3
4
2.1
Estimated
Methane
Drained
(MMCF/D)
1.4
1.1
1.1
1
1
1
1.1
1
0.2
0.1
0
0.1
0
0
-
Estimated
Specific
Emissions
(CF/T)
876
722
425
588
532
785
860
663
789
779
621
709
541
608
505
Methane
Used
(MMCF/D)
0.4
0.1
0
0.2
0.2
0.4
0.6
0.5
0.2
0.1
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
12%
13%
19%
15%
15%
12%
15%
14%
3%
1%
0%
2%
0%
0%
-
Estimated
Current
Market
Penetration
29%
9%
0%
20%
23%
40%
55%
50%
100%
100%
-
-
-
-
-
Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0
Emissions (MMCF/D)
12
10
8
6
4
2
0
"P "6*
^ ^
5 I? "P 'V
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
49
-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 4601318
HARRISON COUNTY MINE
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Harrison
Current Operator: The Harrison County Coal Company
Owner/Parent Company: Murray Energy
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Robinson Run No. 95
Description of SurroundingTerrain: Open Low Mountains
Utility Electric Supplier: Monongahela Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 79 Camp Run Rd, Mannington, WV
26582
Latitude/Longitude: 39.5158, -80. 444
Number of Employees at Mine: 397
Mining Method: Longwall
Year of Initial Production: 1968
Primary Coal Use: Steam
Depth to Seam (ft.): 700
Seam Thickness (ft.): 6.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Dominion
Distance to Pipeline (miles): 0.6
E££]
eeh
Coal
Production
(million
short tons)
5
5.7
6.2
6.1
5.7
6.4
5.6
5.5
5.5
5.9
5
5.7
6.7
7.1
6.6
Emission
from
Ventilation
Systems
(MMCF/D)
4.5
4
4.6
4.1
4
4.6
5.4
7.3
6.9
7.7
7
7.3
7.1
8.4
6.8
Estimated
Methane
Drained
1.1
1
2
1.7
1.7
0
0
0
0
0
1.3
1.3
6.3
3.1
2.7
(MMCF/D)
Estimated
Specific
Emissions
409
320
389
347
365
262
352
485
458
476
606
551
730
591
526
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
3.4
0.3
0.3
Estimated
Current
Drainage
Efficiency
20%
20%
30%
29%
30%
0%
0%
0%
0%
0%
16%
15%
47%
27%
28%
Estimated
Current
Market
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
10%
11%
Penetration
Coal Production (million short tons)
8.0
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
cf? c5^ & of? n"? ^ ^ jf? -.-J* ^
Emissions (MMCF/D)
10
8
6
4
2
0 -I , , , ,—>
# # J' J? J? J> J
# ^ 4?
Emission from Ventilation Systems 1 Estimated Methane D rained
www.epa.gov/cmop
50
-------
Mine Status:
Use Project:
Active
NA
Drainage System: No
MSHA ID: 4609192
Basin: Northern Appalachian
State: WV
Coal bed: Lower Kittanning
County: Taylor
Current Operator: ACI Tygart Valley
Owner/Parent Company: Arch Coal Inc.
Parent Company Website: www.archcoal.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Open Low Mountains
Utility Electric Supplier: MonPower Co.
Parent Corporation of Utility: FirstEnergy
LEER MINE
Mailing Address: 1200 Tygart Dr., Grafton, WV
26354
Latitude/Longitude: 39.3417, -79.9759
Number of Employees at Mine: 426
Mining Method: Longwall
Year of Initial Production: 2011
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 700
Seam Thickness (ft.): 6.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): 12.5
E££]
Coal
Production
(million
short tons)
-
-
-
-
-
-
-
0.01
0.6
0.6
2.7
3.4
3.6
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
0.9
2.6
4.1
4.5
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
-
-
-
548
351
440
463
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
fS3*
-f ^ ^ ^ ^ ^
Emissions (MMCF/D)
5
4
3
2
1
0 -I 1 1 1 1 1
# ^ J? J* J
? J* f
# #
Emission from Ventilation Systems Estimated Methane Drained
www.epa.gov/cmop
51
-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 4601433
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Marion
Current Operator: The Marion County Coal Company
Owner/Parent Company: Murray Energy
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Loveridge #22
Description of SurroundingTerrain: Open Low Mountains/High Hills
Utility Electric Supplier: Monongahela Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: PO Box 40, Fairview, WV, 26570
Latitude/Longitude: 39.58567, -80.36233
Number of Employees at Mine: 446
Mining Method: Longwall
Year of Initial Production: 1953
Primary Coal Use: Steam
Depth to Seam (ft.): 800-1,250
Seam Thickness (ft.): 7.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 1.4
E££]
eeh
Coal
Production
(million
short tons)
0.3
5
6.4
6.4
6.6
5.2
6
5.9
5.6
5.9
5.3
6.6
6.5
4.4
Emission
from
Ventilation
Systems
(MMCF/D)
2
0.9
3.7
4.1
5.3
5.3
6
10.6
9.1
10.7
9
11.3
12.8
11.8
12.1
Estimated
Methane
Drained
1.3
4.4
1.6
1.7
1.8
2.1
1.8
1.2
1.1
0.9
0.9
1.8
4.3
1.6
1.4
(MMCF/D)
Estimated
Specific
Emissions
-
6,448
387
331
405
409
548
718
631
756
613
902
946
752
1,127
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
1.7
1.8
2.1
1.8
1.2
1.1
0.9
0.9
0.9
3.1
0.1
0.1
Estimated
Current
Drainage
Efficiency
39%
83%
30%
29%
25%
28%
23%
10%
11%
8%
9%
14%
25%
12%
10%
Estimated
Current
Market
-
-
-
100%
100%
100%
100%
100%
100%
100%
100%
50%
72%
6%
7%
Penetration
Coal Production (million short tons)
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
cf? c5^ of? n"? ^ ^ ^
Emissions (MMCF/D)
14
12
10
8
6
4
2
0 -I , , , , ,
# # J' J? J? J> J
# ^ J?
Emission from Ventilation Systems Estimated Methane D rained
www.epa.gov/cmop
52
-------
Mine Status: Active
Use Project: VAM Destruction
Drainage System: Yes
MSHA ID: 4601437
MARSHALL COUNTY MINE
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Marshall
Current Operator: The Marshall County Coal Company
Owner/Parent Company: Murray Energy
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: McElroy Mine
Description of SurroundingTerrain: High Hills/Hills
Utility Electric Supplier: Wheeling Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
Mailing Address: 57 Goshorn Woods Road, Cameron,
WV 26033
Latitude/Longitude: 39.8038, -80.5883
Number of Employees at Mine: 724
Mining Method: Longwall
Year of Initial Production: 1968
Primary Coal Use: Steam
Depth to Seam (ft.): 600-1,200
Seam Thickness (ft.): 5.0-5.4
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Spectra Energy Corp
Distance to Pipeline (miles): 1.5
E££]
eeh
Coal
Production
(million
short tons)
4.8
6.8
8.4
10.4
10.5
9.7
9.6
9.8
10.1
9.3
9.4
9.4
10.4
10.3
10.5
Emission
from
Ventilation
Systems
(MMCF/D)
7.4
1.6
8.2
11.3
12.8
13.4
13.6
12.6
15.1
14.2
13.2
12.8
12.7
12.8
12.2
Estimated
Methane
Drained
_
_
_
2.0
2.3
1.8
2.4
2.2
1
0.9
0.5
0.8
1.6
_
3.7
(MMCF/D)
Estimated
Specific
Emissions
563
86
356
467
525
572
608
551
582
593
532
528
502
454
553
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
0.1
0.1
0.1
0.7
1.9
1.8
1.5
2.4
Estimated
Current
Drainage
Efficiency
-
-
-
15%
15%
12%
15%
15%
6%
6%
4%
6%
11%
-
23%
Estimated
Current
Market
0%
0%
0%
0%
0%
0%
0%
5%
10%
11%
140%
226%
113%
12%
64%
Penetration
Coal Production (million short tons)
12.0
10.0
0.0
Emissions (MMCF/D)
10 -
& .cP -cr .cv5 -cv" _
-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 4601968
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Monongalia
Current Operator: The Monongalia County Coal Company
Owner/Parent Company: Murray Energy
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Blacksville No. 2
Description of SurroundingTerrain: Open Low Mountains/High Hills
Utility Electric Supplier: Monongahela Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 701 Oak Forest Road
Holbrook, PA 15341
Latitude/Longitude: 39.7634, -80.2822
Number of Employees at Mine: 279
Mining Method: Longwall
Year of Initial Production: 1971
Primary Coal Use: Steam
Depth to Seam (ft.): 800-1,150
Seam Thickness (ft.): 7.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 1.2
§
I
K±!&l
Coal
Production
(million
4.8
5.4
5.7
5.3
5
5.2
5.6
3.8
4.5
4.3
3.2
3.1
4.6
3.3
3.9
short tons)
Emission
from
Ventilation
Systems
(MMCF/D)
5.7
4.7
6.4
6.4
7.2
6.9
8.4
9.5
9.1
7.6
5.9
5.1
8.1
6.8
6.0
Estimated
Methane
Drained
3.3
1.4
1.4
1.6
2.5
1.9
1.7
1.7
1.4
1.3
1.1
2
1.5
2.4
2.9
(MMCF/D)
Estimated
Specific
Emissions
684
412
500
551
708
618
658
1,076
852
756
798
836
762
1,018
832
(CF/T)
Methane
Used
(MMCF/D)
3.3
1.4
1.4
1.6
2.5
1.9
1.7
1.7
1.4
1.3
1.1
1.5
0.2
0.1
0.1
Estimated
Current
Drainage
Efficiency
37%
23%
18%
20%
25%
22%
17%
15%
13%
15%
16%
28%
16%
4%
33%
Estimated
Current
Market
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
75%
13%
26%
4%
Penetration
Emissions (MMCF/D)
10
8
6
4
2
0
^ # 4# J? J? J" J> J? J> J> J-
Emission from Ventilation Systems Estimated Methane Drained
Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0
www.epa.gov/cmop
54
-------
Mine Status:
Use Project:
Active
NA
Drainage System: No
MSHA ID: 4601436
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Marshall
Current Operator: The Ohio County Coal Company
Owner/Parent Company: Murray Energy
Parent Company Website: www.murravenergvcorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Shoemaker Mine
Description of SurroundingTerrain: High Hills/Hills
Utility Electric Supplier: Wheeling Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
Mailing Address: 1107 Golden Ridge Road
Dallas, WV 26036
Latitude/Longitude: 39.9705, -80.4141
Number of Employees at Mine: 457
Mining Method: Longwall
Year of Initial Production: 1983
Primary Coal Use: Steam
Depth to Seam (ft.): 650
Seam Thickness (ft.): 5.0-5.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): 1.4
e&ei
Eml
Coal
Production
(million
short tons)
3.4
3.8
3.7
3.5
1
0.1
1.1
0.3
3.8
5.1
5.3
5.6
6.6
6.1
6.3
Emission
from
Ventilation
2.9
1.8
3.3
3.6
3.1
2.6
7.8
2.8
3.8
3.7
2.8
3.49
4.4
5.0
4.5
Systems
(MMCF/D)
Estimated
Methane
Drained
0.5
0.3
0.6
0.6
-
-
-
-
-
-
-
-
-
-
-
(MMCF/D)
Estimated
Specific
Emissions
365
202
385
438
1,132
9,490
2,588
3,407
365
265
193
228
243
299
262
(CF/T)
Methane
Used
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
(MMCF/D)
Estimated
Current
Drainage
Efficiency
15%
14%
15%
14%
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
Coal Production (million short tons)
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
cf? c5^ of? n"? ^ ^ ^
Emissions (MMCF/D)
10
8
6
4
2
o I 7 i i ***»! 1
# # J' J? J? J> J
# ^ 4? J?
Emission from Ventilation Systems 1 Estimated Methane D rained
www.epa.gov/cmop
55
-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 4601816
Basin: Central Appalachian
State: WV
Coalbed: Pocahontas No. 3
County: Wyoming
Current Operator: Pinnacle Mining Company
Owner/Parent Company: Seneca Coal Resources LLC
Parent Company Website: http://www.erpfuels.com/
Previous Owner(s): Cliffs Natural Resources, U.S. Steel Minin
Previous or Alternate Name of Mine: Pinnacle No. 50, Gary
No. 50, US Steel No. 50
Description of SurroundingTerrain: Low Mountains
Utility Electric Supplier: Appalachian Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
MailingAddress: Route 16 South, Welch Pineville Road
229, Welch, WV 24801
Latitude/Longitude: 37.54722, -81.49917
Number of Employees at Mine: 263
Mining Method: Longwall
Year of Initial Production: 1969
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 600-1,300
Seam Thickness (ft.): 4.2
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): 0.3
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
Coal
Production
(million
short tons)
3.5
2.5
1.8
2.6
2
1.4
2.1
0.5
1.1
1.2
2.4
2.8
2.7
2.4
0.9
Emission
from
Ventilation
Systems
(MMCF/D)
8
9.8
8
6.5
5.2
5.3
5.4
5.8
5.5
3.4
6
8.3
9
6.2
4.5
Estimated
Methane
Drained
5.6
2
3.1
9.7
4.6
3.4
2.3
5.7
4.6
4.6
1.5
3.6
1.1
0.8
0.2
(MMCF/D)
Estimated
Specific
Emissions
1,418
1,723
2,251
2,274
1,789
2,268
1,338
8,395
3,351
2,433
1,141
1,551
1,365
1,065
1,870
(CF/T)
Methane
Used
(MMCF/D)
5.6
2
3.1
9.7
4.6
2.4
1.3
4.7
4.6
4.3
-
2.9
0.4
-
0.2
Estimated
Current
Drainage
Efficiency
41%
17%
28%
60%
47%
40%
30%
50%
46%
58%
20%
30%
11%
12%
6%
Estimated
Current
Market
100%
100%
100%
100%
100%
71%
57%
82%
100%
93%
-
81%
36%
100%
81%
Penetration
Coal Production (million short tons)
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
www.epa.gov/cmop
56
-------
Mine Status: Active
Use Project: NA
SENTINEL MINE
Drainage System: No
MSHA ID: 4604168
Basin: Northern Appalachian
State: WV
Coal bed: NA
County: Barbour
Current Operator: Wolf Run Mining LLC
Owner/Parent Company: Arch Coal Inc
Parent Company Website: http://www.archcoal.com/
Previous Owner(s): International Coal Group
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Mountainous
Utility Electric Supplier: NA
Parent Corporation of Utility: NA
Mailing Address: 21550 Barbour County Highway
Philippi, WV 26416
Latitude/Longitude: 39.199293, -80.052064
Number of Employees at Mine: 239
Mining Method: Longwall
Year of Initial Production: 1973
Primary Coal Use: Metallurgical
Depth to Seam (ft.): NA
Seam Thickness (ft.): NA
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
e&ei
Eml
Coal
Production
(million
short tons)
0.3
0.3
0.3
0.1
0.1
0.8
1.0
1.3
1.3
1.2
1.1
1.0
1.0
1.0
1.0
Emission
from
Ventilation
Systems
(MMCF/D)
0.6
2.0
2.8
4.0
3.7
2.7
2.5
2.1
1.9
2.3
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
274
730
787
1,123
1,125
896
913
767
694
840
(CF/T)
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
1.4
1.2
1.0
0.8
0.6
0.4
0.2
0.0
fS3*
^ ^ ^ ^ ^ jS*
www.epa.gov/cmop
57
-------
Mine Status: Active
Use Project: NA
TUNNEL RIDGE MINE
Drainage System: No
MSHA ID: 4608864
Basin: Northern Appalachian
State: WV
Coalbed: Pittsburgh No. 8
County: Ohio
Current Operator: Tunnel Ridge, LLC
Owner/Parent Company: Alliance Resource Partners
Parent Company Website: http://www.arlp.com/
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of SurroundingTerrain: Mountainous
Utility Electric Supplier: NA
Parent Corporation of Utility: NA
Mailing Address:
Latitude/Longitude: 40.1500716, -80.7031356
Number of Employees at Mine: 436
Mining Method: Longwall
Year of Initial Production: 2010
Primary Coal Use: Steam
Depth to Seam (ft.): 400
Seam Thickness (ft.): 5.2-6.0
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Coal
Production
(million short
tons)
-
-
-
-
-
-
-
-
0.2
0.3
2.0
3.7
5.6
6.0
6.6
Emission
from
Ventilation
Systems
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
0.3
1.1
2.6
2.8
3.4
Estimated
Methane
Drained
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Specific
Emissions
(CF/T)
-
-
-
-
-
-
-
-
-
-
55
109
170
170
188
Methane
Used
(MMCF/D)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Drainage
Efficiency
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Estimated
Current
Market
Penetration
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Coal Production (million short tons)
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
Emissions from Ventilation System Estimated Methane Drained
www.epa.gov/cmop
58
-------
5. References
Coal Age. 2016. U.S. Longwall Census. Coal Age Magazine February: 18-22.
EPA. 2018. Inventory of U.S. Greenhouse Gas Emissions and Sinks 1990-2016. EPA 430-P-17-001.
U.S. Environmental Protection Agency, Office of Atmospheric Programs April 15.
MSHA. 2018. Mine Data Retrieval System. Mine Safety and Health Administration Department of
Labor. Available: httDs://arlweb.msha.aov/drs/drshome.htm . Accessed 6/6/2019.
Warrior. 2017. Securities and Exchange Commission Form 10-Q. Filed May 18, 2017 (period:
March 31, 2017).
www.epa.gov/cmop
59
------- |