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Coalbed Methane
Identifying Opportunities
for Methane Recovery at
U.S. Coal Mines:
Profiles of Selected Gassy
Underground Coal Mines
2007-2015

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Identifying Opportunities for Methane Recovery at
U.S. Coal Mines:
Profiles of Selected Gassy Underground Coal Mines
2007-2015
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United States Environmental Protection Agency
Office of Air and Radiation
1200 Pennsylvania Avenue, NW
Washington, DC 20460
January 2018
www.epa.gov

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Acknowledgements
The U.S. EPA would like to thank the U.S. Mine Safety and Health Administration for the ventilation
emissions data used in this document.

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Table of Contents
Page #
Acknowledgements	i
List of Figures	iv
List of Tables	iv
Frequently Used Terms	v
Frequently Used Abbreviations	vii
1.	Executive Summary
Methane Emissions and Recovery Opportunities	1-1
U.S. EPA	1-1
Coal Mine Methane (CMM) Recovery Opportunities	1-2
Opportunities for Methane Recovery Projects	1-3
Overview of Methane Liberation, Drainage, and Use at Profiled Mines	1-3
Summary of Opportunities for Project Development	1-3
2.	Introduction
Purpose of Report	2-1
Recent Developments in the Coal Mine Methane Industry	2-1
3.	Mine Profiles Guide
Mine Status	3-1
Drainage System	3-1
Use Project	3-2
MSHA ID	3-2
Geographic Data	3-2
Corporate Information	3-2
Mine Address	3-3
General Information	3-3
Production, Ventilation, and Drainage Data	3-3
4.	Mine Summary Tables
Table 1:	Mines Listed Alphabetically	4-1
Table 2:	Mines Listed by State and County	4-2
Table 3:	Mines Listed by Coal Basin	4-3
Table 4:	Mines Listed by Company	4-4
Table 5:	Mines Listed by Mining Method	4-5
Table 6:	Mines Listed by Primary Coal Use 	4-6
Table 7:	Mines Listed by 2015 Coal Production	4-7
Table 8:	Mines Employing Methane Drainage Systems	4-8
Table 9:	Mines Listed by Estimated Total Methane Liberated in 2015	4-9
Table 10:	Mines Listed by Daily Ventilation Emissions in 2015	4-10
Table 11:	Mines Listed by Estimated Daily Methane Drained in 2015	4-11
Table 12:	Mines Listed by Estimated Specific Emissions in 2015	4-12
Table 13:	Mines with CMM Use Projects	4-13
ii

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5. Profiled Mines
Data Summary
..5-1
..5-2
..5-7
5-11
5-13
5-15
5-21
5-23
5-25
Alabama	
Illinois	
Indiana	
New Mexico..
Pennsylvania
Utah	
Virginia	
West Virginia
Mine Profiles (profiles appear in alphabetical order by state)
Alabama Mines
No. 4 Mine
No. 7 Mine
Oak Grove
Shoal Creek
Illinois Mines
MC #1 Mine
New Future Mine
The American Coal Company New Era Mine
Indiana Mines
Oaktown Fuels #1
New Mexico Mines
San Juan Mine 1
Pennsylvania Mines
Bailey
Cumberland
Emerald Mine No 1
Enlow Fork
Harvey
Utah Mines
West Ridge Mine
Virginia Mines
Buchanan Mine #1
West Virginia Mines
Beckley Pocahontas	Ohio County Mine
Federal No. 2	Pinnacle
Harrison County Mine
Leer Mine
Marion County Mine
Marshall County Mine
Monongalia County
in

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6. References	6-1
List of Figures
Page #
Figure 2-1: Mines with Active Coal Mine Methane Recovery and Use Projects	2-2
Figure 2-2: Estimated Annual Use of Methane Recovered from U.S. Coal Mines	2-2
List of Tables
Table 2-1: Summary of Existing Methane Recovery and Use Projects	2-3
iv

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Frequently Used Terms
Coalbed methane (CBM): 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 unavoidable leakage of air into the 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 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. It is also referred to as mine degasification. A drainage system
may consist of only one well or borehole or multiple wells or boreholes.
Greenhouse Gas Reporting Program (GHGRP): The EPA's GHGRP collects and verifies annual
reports of greenhouse gas (GHG) data and other relevant information from large sources and
suppliers in the United States including underground coal mines that liberate at least 36.5 million
cubic feet per year of methane from ventilation and degasification systems. The purpose of the
program is to collect accurate and timely GHG data to inform future policy decisions; it does not
require GHG emission controls. Data for underground coal mines, including volumetric flow and CH4
concentration at all ventilation and degasification monitoring points has been collected since 2011.
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, etc.) or destroyed (e.g. flaring or oxidation).
v

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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.
vi

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Frequently Used Abbreviations
b (or B)	Billion (109)
Bcf	Billion cubic feet
Btu	British Thermal Unit
CBM	Coalbed Methane
cf	Cubic Feet
CH4	Methane
CO2	Carbon Dioxide
CMM	Coal Mine Methane
DOE	Department of Energy
EIA	Energy Information Administration
EPA	Environmental Protection Agency
IC	Internal Combustion
m (or M)	Thousand (103)
mm (or MM)	Million (106)
MMTCC>2e	Million metric tonnes CO2 equivalent
MSHA	Mine Safety and Health Administration
MW	Megawatt
NA	Not Available (as opposed to Not Applicable)
t (or T)	ton (short tons are used throughout this report when referring to coal
Production)
VAM	Ventilation air methane
vii

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Executive Summary

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1. Executive Summary
The purpose of this report is to provide information about specific opportunities to develop methane
recovery and use projects at large, underground coal mines in the United States. This report
contains profiles of 25 U.S. coal mines that may be potential candidates for methane recovery and
use projects, and provides details about ongoing recovery and use projects at 13 of these mines. The
United States 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 in order to determine whether the
development of a specific methane recovery and use project is both technically and economically
feasible.
Since the last version of this report was published in January 2009, total coal mine methane (CMM)
produced from gas drainage systems peaked at 59 Bcf in 2010, and has since declined to 41 Bcf in
2015. The amount of CMM recovered and used peaked at 49 Bcf in 2010, and has since declined to 33
Bcf in 2015. The decline in utilization is due to several factors including natural fluctuations in methane
production, a continued reduction in underground coal production, closure of mines, low natural gas
prices and low carbon prices for CMM projects before 2015.
Methane Emissions and Recovery Opportunities
Methane is a greenhouse gas with an atmospheric lifespan of approximately 9-15 years, that is 251
times more effective in trapping heat in the atmosphere than carbon dioxide over a 100-year period.
Methane is emitted from a variety of natural and human-influenced sources, including 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 also an important, relatively clean-burning energy
source. As a result, efforts to prevent or utilize methane emissions can provide significant energy,
economic, and environmental benefits.
U.S. EPA
U.S. industries, along with state and local governments, collaborate with the U.S. Environmental
Protection Agency (EPA) to implement several voluntary programs that promote profitable
opportunities for reducing methane emissions. These programs are designed to overcome a wide
range of informational, technical, and institutional barriers to reducing methane emissions, while
creating profitable activities for the coal, natural gas, petroleum, landfill, and agricultural industries.
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 into and
emitted from mines.
Coal Mine Methane (CMM) Recovery Opportunities
In the U.S., coal mines account for approximately 9% of all man-made methane emissions (EPA,
2017). Today, there are methane recovery and use projects at mines in Alabama, Colorado,
1 From IPCC, 2007: Climate Change 2007: Synthesis Report. Contribution of Working Groups I, II and III to the Fourth
Assessment Report of the Intergovernmental Panel on Climate Change [Core Writing Team, Pachauri, R.K and Reisinger,
A. (eds.)]. IPCC, Geneva, Switzerland, 104 pp. Used as the GWP for the EPA Greenhouse Gas Reporting Program and
Inventory of U.S. Greenhouse Gas Emissions & Sinks.	
1-1

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Pennsylvania, Utah, 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 sale of gas to pipelines or use
in applications ranging from electric power generation to industrial uses. In addition, indirect financial
and economic benefits may also be realized. Because of the large environmental benefits that may be
achieved, coal mine methane projects could serve as cost-effective alternatives for companies or
facilities seeking to offset their own emissions. For example, certain CMM projects may produce
emission offsets that can be sold via the California Cap-and-Trade program, generating a source of
revenue for the project in addition to gas sales into energy and industrial markets.
CMM projects also provide other benefits. Degasification systems prevent gas from escaping into mine
working areas, thereby increasing methane recovery, improving worker safety, and reducing ventilation
costs. Increased recovery also reduces methane-related mining delays. To learn about CMM capture
and use technologies, please visit the CMOP website at https://www.epa.gov/cmop.
Opportunities for Methane Recovery Projects
This report profiles 25 mines that are potential candidates for the development of CMM projects based
on 2015 emissions. The number of mines with gas drainage systems increased from 23 in 2006 to 26
in 2015. Twenty of these mines are profiled in this document. The number of mines with active methane
recovery and use projects increased from 14 in 2006 to 172 in 2015. At least 13 of these mines sell
recovered methane, and at least five mines consume methane onsite for power generation, to heat
mine ventilation air, flare CMM, or use produced gas as fuel in on-site vacuum pumps. Mines that have
installed drainage systems may be especially good candidates for the development of cost-effective
methane recovery and use projects.
For information on methane recovery projects at abandoned (closed) 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/cmop/coal-mine-methane-sources#abandonedUnderqroundMines
Surface mines may also be candidates for recovery and utilization projects. See U.S. Surface Coal
Mine Methane Recovery Project Opportunities, which is available on the CMOP website at
https://www.epa.gov/sites/production/files/2016-03/documents/cmm recovery opps surface.pdf
Overview of Methane Liberation, Drainage, and Use at Profiled Mines
This report profiles mines located in eight states. West Virginia has the largest number of profiled mines
with nine, followed by Pennsylvania with five, Alabama with four, Illinois with three, and Indiana, New
Mexico, Utah, and Virginia with one each. In 2015, the 25 mines profiled in this report liberated an
estimated 268 mmcf/d of methane, or about 98 Bcf/yr (78% of all methane liberated from underground
mines).
As of 2015, 20 of the profiled mines have installed drainage systems (although not all systems were
operational that year). West Virginia has the largest number with seven, followed by Pennsylvania with
five, Alabama with four, and Indiana, New Mexico, Utah, and Virginia with one each. In 2015, the 17
2 This document only profiles 13 out of the 17 mines with use projects. The four mines not included here are: 1) Road Fork
#51 Mine in West Virginia has a pipeline utilization project; 2) West Elk Mine in Colorado uses CMM for shaft heating, 3) Elk
Creek Mine in Colorado has a CMM power plant and flare, and 4) Bowie No. 2 mine in Colorado uses CMM in on-site
vacuum pumps.	
1-2

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mines operating drainage systems reported an estimated 109 mmcf/d of methane drained, or about
39.7 Bcf/yr. Table 8 in Chapter 4 shows mines that employ drainage systems, the type of drainage
system employed, and estimated drainage efficiency.
Summary of Opportunities for Project Development
Most of the more than 300 active underground coal mines in the U.S. do not recover and use methane.
However, the mines profiled in this report appear to be strong candidates for cost-effective recovery
projects.
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 3 mmcf/d to over 59 mmcf/d. Similarly,
specific emissions range from 235 cf/ton to approximately 4,850 cf/ton. Annual coal production ranges
from approximately 1.0 million tons at some mines to over 10 million tons per year at others. These
metrics affect each mine's potential as a project opportunity. Furthermore, as shown in the profiles
(Chapter 5), the candidate mines vary with respect to other important metrics, such as the distance from
the mine to a natural gas pipeline. 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.
1-3

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2. Introduction

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2. Introduction
Purpose of Report
This report provides information about specific opportunities to develop methane recovery and use
projects at large underground mines in the United States. 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 3 contains information that will assist
the reader in understanding and evaluating the data presented in Chapters 4 and 5. Chapter 4
contains data summary tables, and finally, Chapter 5 profiles individual underground coal mines that
appear to be good candidates for the development of methane recovery projects.
Recent Developments in the Coal Mine Methane Industry
The number of mines with gas drainage systems increased from 23 in 2006 to 26 in 2015. The
number of mines with active methane recovery and use projects increased from 14 in 2006 to 17 in
2015. However, total methane produced from gas drainage systems declined from 54 Bcf to 41 Bcf
following a peak in 2010 at 59 Bcf. The amount of methane recovered and used increased from 45
Bcf in 2006 to 49 Bcf in 2010, but has since decreased to 33 Bcf in 2015. The decline in utilization is
due to several factors including natural fluctuations in methane production, a continued reduction in
underground coal production, mine closures, low natural gas prices and the lack of a viable carbon
market before 2015.
Coal production from underground mines has decreased since 2010 and several gassy mines either
closed or were idled for significant periods of time reducing the volume of available gas. Low natural
gas prices resulting from the rapid growth in 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
drained methane was used, but in 2015 only 80 percent of available drained gas was utilized.
Despite these challenges, many promising developments are expected to encourage greater CMM
capture and use in future years. The U.S. saw implementation of the first two commercial VAM
projects during this period. The Biothermica VAM project operated at the Warrior Met Coal Blue
Creek Number 4 Mine from 2010-2013, and the Verdeo McElroy VAM Project began operation at the
Murray Energy Marshall County Mine in 2012, and remains in operation today. The success in
demonstrating both the technical and commercial viability of these projects suggests that many more
VAM projects could be deployed in coming years.
The second notable development was the California Air Resources Board (CARB) adoption of the
Mine Methane Capture (MMC) 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 Compliant Offsets (CCOs) including emission 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 LNG or CNG production.
CCO prices are attractive and capable of generating cash flow to make the projects economically
Introduction
2-1

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sustainable. Since the adoption of the Protocol, CCO prices have ranged from $9,00-12.00 per
metric ton of CO2 equivalent3.
Figure 2-1 shows the number of mines engaging in CMM recovery and use since 1994. Figure 2-2
shows the volume of gas recovered from CMM projects since 1990. Table 2-1 summarizes the
methane recovery and use projects.
Figure 2-1: Mines with Active Coal Mine Methane Recovery and Use Projects
Methane Recovery and Use Projects (by State)
Total
West Virginia
Virginia
Utah
Pennsylvania
New Mexico
Colorado
Alabama
201s
2006
2003
1997
1994
10
15
20
Number of Mines with Methane Recovery and Use Projects
(based on publicly available information)
Figure 2-2: Estimated Annual Use of Methane Recovered from U.S. Coal Mines
(Based on publicly available information)

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3California Carbon Info http://californiacarbon.info/
Introduction
2-2

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Table 2-1: Summary of Existing Methane Recovery and Use Projects
Mine Name
Mine
Location
(State)
Approximate
Amount of Gas
Used in 2015*
Methane Use
Option
Notes
Degasification
system
No. 4 Mine
No. 7 Mine
Alabama
23.8 mmcf/day
Pipeline Sales
The two mines
collectively
liberated 45.5
mmcf/d of gas in
2015.
Vertical Gob Boreholes;
Horizontal Pre-Mine
Boreholes; Vertical Pre-
Mine Boreholes
Oak Grove
Alabama
1.8 mmcf/day
Pipeline Sales
Most of the
production in the
Oak Grove Field is
beyond the limits of
the mine plan.
Vertical Gob Boreholes;
Horizontal Pre-Mine
Boreholes; Vertical Pre-
Mine Boreholes
Shoal Creek
Alabama
7.2 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
Cumberland
Emerald Mine No 1
Pennsylvania
1.9 mmcf/day
Pipeline Sales
Began recovering
methane in 2005.
Vertical Gob Boreholes
with Pumps
Bailey
Pennsylvania
small volumes
Pipeline sales

Vertical Gob Boreholes
with Pumps
Buchanan
Virginia
51.2 mmcf/day
Pipeline Sales
On-Site Use
Power
Generation
This mine
produced 58.5
mmcf/day of gas in
2015.
Vertical Gob Boreholes;
Horizontal Pre-Mine
Boreholes; Vertical Pre-
Mine Boreholes
Introduction
2-3

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Mine Name
Mine
Location
(State)
Approximate
Amount of Gas
Used in 2015*
Methane Use
Option
Notes
Degasification
system
Monongalia County
Mine (formerly
Blacksville #2 Mine)
Marion County
Mine (formerly
Loveridge No. 22)
West Virginia
0.2 mmcf/day
Pipeline Sales
The two mines
liberated 22.6
mmcf/d in 2015.
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 &
Horizontal Pre-drainage
wells
Pinnacle
West Virginia
0.8 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
McElroy Mine)
West Virginia
1.5 mmcf/day
Ventilation Air
Methane
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, 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.
Introduction
2-4

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3. Mine Profiles Guide

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3. Mine Profiles Guide
This report contains profiles of the 25 largest emitting coal mines that may be potential candidates for
development of methane recovery and use projects. The profiled mines were selected primarily on
the basis of 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 1990-2015.
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
The mine profiles are ordered alphabetically by state, and arranged by mine name. Following this
chapter are summary tables that list key data elements shown in the mine profiles. The individual
mine profiles follow the summary tables. Below are explanations for each of the data elements
included in the mine profiles.
Mine Status
Each mine's operating status as of May 2017 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.gov/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.
Guide
3-1

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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, "none" 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 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 2017), (Coal Age 2016).
State: Mines included in this report are located in the following states - Alabama, Illinois, Indiana,
New Mexico, Pennsylvania, Virginia, and West Virginia. Summary Table 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.
Summary Table 2 shows the mines listed by state and by county.
Coal 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. Summary
Table 3 lists the mines by basin and 2015 estimated specific emissions per ton of coal mined for each
listed mine.
Corporate Information
Current Operator: Current operator refers to the mining company that operates the mine. Summary
Table 4 lists mines by mining company. The source for this information was the MSHA database
(MSHA, 2017).
Owner/Parent Company: Many coal mines are owned by a parent company. In addition to showing
the coal companies, Summary Table 4 also shows the parent corporation of the mining company.
This information was taken from MSHA (MSHA, 2017), 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, 2017) and industry knowledge.
Previous or Alternate Name: Mines frequently undergo name changes, particularly when they are
purchased by a new company. This section lists previous or alternate mine names.
Guide
3-2

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Mine Address
This section includes the mailing address of the mine. The principal source of this information was
MSHA (MSHA, 2017). The information in this section is current as of June 2017.
General Information
Number of Employees: This field shows the number of people employed by the mine, as reported by
the MSHA Mine Data Retrieval System (MSHA, 2017). The average number of employees for the
most recent quarter was used.
Year of Initial Production: Year of initial production 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, 2017).
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 of, 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. Summary Table 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 SEC filings, parent company annual reports, and industry
websites. Summary Table 6 lists mines by primary coal use.
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 of the years 2002 to 2015.
Coal Production: All of the mines profiled in this report have production exceeding one million tons
per year. 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, 2017). Summary Table 7 lists the coal mines by the amount of coal they produced
in 2015.
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. The volume of methane liberated
is shown for the years 2002-2015. Summary Table 9 shows mines listed by their estimated total daily
methane liberation for 2015.
Guide
3-3

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Emissions from Ventilation Systems: Methane released to the atmosphere from ventilation systems
is emitted in very low concentrations (typically less than 1% 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. Summary Table 10
lists the mines by their 2015 ventilation emissions, as reported by the EPA's GHG Inventory (EPA,
2017).
Estimated Methane Drained: Mines that employ degasification systems emit large quantities of
methane in high concentrations. Summary Table 11 lists mines according to the estimated methane
drained. Based on information obtained from EPA'S GHG Inventory (EPA, 2017), EPA has developed
a list of 20 U.S. mines that have drainage systems in place and have utilization projects or high
potential for implementing a utilization project.
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. Summary Table 12 shows a list of mines ordered
according to specific emissions. 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 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, etc.).
Methane used does not always equal methane drained as some mines vent the methane liberated
from degasification systems to the atmosphere. Table 13 shows a list of mines employing methane
use projects.
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 is 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: Twenty of the mines in this report had drainage systems, but only seventeen
had active drainage systems in place in 2015. Three additional mines had previously used methane
drainage but did not do so in 2015. 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. Summary Table 8 lists mines by drainage system used.
Guide
3-4

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4. Mine Summary Tables
List of Summary Tables:
Table 1:	Mines Listed Alphabetically
Table 2:	Mines Listed by State and County
Table 3:	Mines Listed by Coal Basin
Table 4:	Mines Listed by Company
Table 5:	Mines Listed by Mining Method
Table 6:	Mines Listed by Primary Coal Use
Table 7:	Mines Listed by 2015 Coal Production
Table 8:	Mines Employing Methane Drainage Systems
Table 9:	Mines Listed by Estimated Total Methane Liberated in 2015
Table 10:	Mines Listed by Daily Ventilation Emissions in 2015
Table 11:	Mines Listed by Daily Methane Drained in 2015
Table 12:	Mines Listed by Estimated Specific Emissions in 2015
Table 13:	Mines with CMM Use Projects

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Table 1: Mines Listed Alphabetically
Mine Name
State
Bailey Mine
PA
Beckley Pocahontas
WV
Buchanan Mine
VA
Cumberland
PA
Emerald Mine No 1
PA
Enlow Fork Mine
PA
Federal No. 2
WV
Harrison County Mine
WV
Harvey
PA
Leer Mine
WV
Marion County Mine
WV
Marshall County Mine
WV
MC #1 Mine
IL
Monongalia County Mine
WV
New Future Mine
IL
No. 4 Mine
AL
No. 7 Mine
AL
Oaktown Fuels #1
IN
Ohio County Mine
WV
Oak Grove Mine
AL
Pinnacle Mine
WV
San Juan Mine 1
NM
Shoal Creek
AL
The American Coal Company New Era Mine
IL
West Ridge Mine
UT
Mine Summary Tables
4-1

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Table 2: Mines Listed by State and County
Mine Name
State
County
Oak Grove Mine
AL
Jefferson
Shoal Creek
AL
Jefferson
No. 4 Mine
AL
Tuscaloosa
No. 7 Mine
AL
Tuscaloosa
MC #1 Mine
IL
Franklin
New Future Mine
IL
Saline
The American Coal Company New Era Mine
IL
Saline
Oaktown Fuels #1
IN
Knox
San Juan Mine 1
NM
San Juan
Bailey Mine
PA
Greene
Cumberland
PA
Greene
Enlow Fork Mine
PA
Greene
Emerald Mine No 1
PA
Greene
Harvey
PA
Greene
West Ridge Mine
UT
Carbon
Buchanan Mine
VA
Buchanan
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
Beckley Pocahontas Mine
WV
Raleigh
Leer Mine
WV
Taylor
Pinnacle Mine
WV
Wyoming
Mine Summary Tables
4-2

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Table 3: Mines Listed by Coal Basin
Coal Basin/
Mine Name
Black Warrior
No. 4 Mine
No. 7 Mine
Oak Grove Mine
Shoal Creek
Central Appalachian
Beckley Pocahontas Mine
Buchanan Mine
Pinnacle Mine
Illinois
The American Coal Company New Era Mine
MC #1 Mine
New Future Mine
Oaktown Fuels #1
Northern Appalachian
Bailey Mine
Cumberland
Emerald Mine No. 1
Enlow Fork Mine
Federal No. 2
Harrison County Mine
Harvey
Leer Mine
Marion County Mine
Marshall County Mine
Monongalia County Mine
Ohio County Mine
San Juan
San Juan Mine 1
Uinta
West Ridge Mine
Mine Summary Tables
4-3

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Table 4: Mines Listed by Company
Owner/Parent
Operator
Arch Coal Inc.
ACI Tygart Valley
ICG Beckley LLC
Westmoreland
San Juan Coal Company
Seneca Coal Resources LLC
Oak Grove Resources LLC
Pinnacle Mining Company LLC
CONSOL Energy Inc.
CONSOL Pennsylvania Coal Company
CONSOL Pennsylvania Coal Company
CONSOL Pennsylvania Coal Company
Coronado IV, LLC
Buchanan Minerals, LLC
Drummond Company Inc.
Drummond Company Inc.
Contura Energy, Inc.
Cumberland Coal Resources LP
Emerald Coal Resources LP
Murray Energy Corp
Virginia Conservation Legacy
Fund, Inc.
Warrior Met Coal LLC
Foresight Energy
The American Coal Company
Marion County Coal Company
Harrison County Coal Company
Ohio County Coal Company
Marshall County Coal Company
Monongalia County Coal Company
The American Coal Company
West Ridge Resources Inc.
ERP Federal Mining Complex LLC
Warrior Met Coal Mining, LLC
Warrior Met Coal Mining, LLC
M-Class Mining LLC
Hallador Energy Company	Sunrise Coal LLC
Mine Name
Leer Mine
Beckley Pocahontas Mine
San Juan Mine 1
Oak Grove Mine
Pinnacle Mine
Bailey Mine
Enlow Fork Mine
Harvey Mine
Buchanan Mine #1
Shoal Creek
Cumberland
Emerald Mine No 1
The American Coal
Company New Era Mine
Marion County Mine
Harrison County Mine
Ohio County Mine
Marshall County Mine
Monongalia County Mine
New Future Mine
West Ridge Mine
Federal No. 2
No. 4 Mine
No. 7 Mine
MC #1 Mine
Oaktown Fuels #1
Mine Summary Tables
4-4

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Table 5: Mines Listed by Mining Method
Mine Name
Method
Beckley Pocahontas Mine
Continuous
Bailey Mine
Longwall
Buchanan Mine
Longwall
Cumberland
Longwall
Emerald Mine No 1
Longwall
Enlow Fork Mine
Longwall
Federal No. 2
Longwall
Leer Mine
Longwall
Marion County Mine
Longwall
Marshall County Mine
Longwall
Monongalia County Mine
Longwall
No. 4 Mine
Longwall
No. 7 Mine
Longwall
Oak Grove Mine
Longwall
Pinnacle Mine
Longwall
Harrison County Mine
Longwall
San Juan Mine 1
Longwall
Shoal Creek
Longwall
Ohio County Mine
Longwall
The American Coal Company New Era Mine
Longwall
Harvey Mine
Longwall
New Future Mine
Longwall
MC #1 Mine
Longwall
West Ridge Mine
Longwall
Oaktown Fuels #1
Room & Pillar
Mine Summary Tables
4-5

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Table 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
Cumberland
Steam
Enlow Fork Mine
Steam
Federal No. 2
Steam
Harrison County Mine
Steam
Marion County Mine
Steam
Marshall County Mine
Steam
MC #1 Mine
Steam
Monongalia County Mine
Steam
The American Coal Company New Era Mine
Steam
New Future Mine
Steam
Ohio County Mine
Steam
San Juan Mine 1
Steam
Shoal Creek
Steam
West Ridge Mine
Steam
Bailey Mine
Steam, Metallurgical
Buchanan Mine
Steam, Metallurgical
Emerald Mine No 1
Steam, Metallurgical
Oak Grove Mine
Steam, Metallurgical
Harvey Mine
Steam, Metallurgical
Mine Summary Tables
4-6

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Table 7: Mines Listed by 2015 Coal Production
Mine Name
Million Tons
MC #1 Mine
10.6
Marshall County Mine
10.3
Bailey Mine
10.2
Enlow Fork Mine
9.0
Cumberland
7.5
Harrison County Mine
7.1
Marion County Mine
6.5
San Juan Mine 1
6.5
Ohio County Mine
6.1
New Future Mine
5.2
Buchanan Mine
4.4
Harvey Mine
3.6
Oaktown Fuels #1
3.5
Leer Mine
3.4
Monongalia County Mine
3.3
The American Coal Company New Era Mine
3.1
No. 7 Mine
3.0
Federal No. 2
2.4
No. 4 Mine
2.4
Pinnacle Mine
2.4
Oak Grove Mine
2.0
Shoal Creek
2.0
Emerald Mine No 1
1.7
West Ridge Mine
1.6
Beckley Pocahontas Mine
0.9
Mine Summary Tables
4-7

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Table 8: Mines Employing Methane Drainage Systems
Mine Name
Buchanan Mine
Shoal Creek
No. 4 Mine
Cumberland
West Ridge Mine
No. 7 Mine
Emerald Mine No 1
Bailey Mine
San Juan Mine 1
Harrison County Mine
Monongalia County Mine
Oak Grove Mine
Harvey Mine
Marion County Mine
Pinnacle Mine
Enlow Fork Mine
Oaktown Fuels No 1
Beckley Pocahontas Mine
Federal No. 2
Marshall County Mine
Type of Drainage System
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes;
Vertical Pre-Mine Boreholes
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes;
Vertical Pre-Mine Boreholes
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes;
Vertical Pre-Mine Boreholes
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes;
Vertical Pre-Mine Boreholes
Vertical Gob Boreholes; In-mine Horizontal Gob Boreholes
Vertical Gob Boreholes with Pumps
Vertical Gob Boreholes; Horizontal Pre-Mine Boreholes
Horizontal Pre-Drainage Wells
Vertical Gob Boreholes
Horizontal Pre-Drainage Wells
Vertical Gob Boreholes
Vertical Gob Boreholes with Pumps
Estimated Current
Drainage Efficiency
88%
77%
66%
46%
45%
43%
42%
30%
28%
27%
26%
22%
19%
12%
12%
3%
3%
0%
0%
0%4
*Mines using methane drainage in 2015 but not represented among the 25 highest emitting mines were: the Elk
Creek Mine (MSHA ID 0504674), Bowie No. 2 Mine (MSHA ID 0504591), West Elk Mine (MSHA ID 0503672),
Oaktown Fuels Mine No. 2 (MSHA ID 1202418), and the Carlisle Mine (MSHA ID 1202349).
4 Drainage efficiency in 2014 was 11%, but no drainage was recorded in 2015
Mine Summary Tables
4-8

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Table 9: Mines Listed by Estimated Total Methane Liberated in 2015
Mine Name
MMCF/D
Buchanan Mine
58.5
No. 7 Mine
26.5
No. 4 Mine
19.0
Marion County Mine
13.4
Marshall County Mine
12.8
Cumberland
11.9
Harrison County Mine
11.5
Enlow Fork Mine
11.0
Shoal Creek
10.9
Bailey Mine
10.4
Monongalia County Mine
9.2
Oak Grove Mine
8.1
Pinnacle Mine
7.0
MC #1 Mine
6.8
The American Coal Company New Era Mine
6.5
Harvey
6.3
San Juan Mine 1
6.2
Emerald Mine No 1
5.5
Ohio County Mine
5.0
Leer Mine
4.1
Federal No. 2
4.0
New Future Mine
3.9
Beckley Pocahontas Mine
3.3
West Ridge Mine
3.1
Oaktown Fuels No 1
3.0
Mine Summary Tables
4-9

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Table 10: Mines Listed by Daily Ventilation Emissions in 2015
Mine Name
MMCF/D
No. 7 Mine
15.2
Marshall County Mine
12.8
Marion County Mine
11.8
Enlow Fork Mine
10.7
Harrison County Mine
8.4
Bailey Mine
7.4
Buchanan Mine
7.3
Monongalia County Mine
6.8
MC #1 Mine
6.8
No. 4 Mine
6.5
The American Coal Company New Era Mine
6.5
Cumberland
6.4
Oak Grove Mine
6.3
Pinnacle Mine
6.2
Harvey Mine
5.0
Ohio County Mine
5.0
San Juan Mine 1
4.4
Leer Mine
4.1
Federal No. 2
4.0
New Future Mine
3.9
Beckley Pocahontas Mine
3.3
Emerald Mine No 1
3.2
Oaktown Fuels No 1
2.8
Shoal Creek
2.4
West Ridge Mine
1.7
Mine Summary Tables
4-10

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Table 11: Mines Listed by Estimated Daily Methane Drained in 2015
Mine Name	MMCF/D
Buchanan Mine	51.2
No. 4 Mine	12.5
No. 7 Mine	11.3
Shoal Creek	8.5
Cumberland	5.5
Harrison County Mine	3.1
Bailey Mine	3.1
Monongalia County Mine	2.4
Emerald Mine No 1	2.3
Oak Grove Mine	1.8
San Juan Mine 1	1.7
Marion County Mine	1.6
West Ridge Mine	1.4
Harvey Mine	1.2
Pinnacle Mine	0.8
Enlow Fork Mine	0.3
Oaktown Fuels #1	0.1
Federal No.2	0
Marshall County Mine	0
MC #1 Mine	0
New Future Mine	0
Ohio County Mine	0
The American Coal Company New Era Mine	0
Leer Mine	0
Beckley Pocahontas Mine	0
Mine Summary Tables
4-11

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Table 12: Mines Listed by Estimated Specific Emissions in 2015
Mine Name
CF/Ton
Buchanan Mine
4,850
No. 7 Mine
3,223
No. 4 Mine
2,889
Shoal Creek
1,991
Oak Grove Mine
1,484
Beckley Pocahontas Mine
1,356
Emerald Mine No 1
1,180
Pinnacle Mine
1,067
Monongalia County Mine
1,019
The American Coal Company New Era Mine
763
Marion County Mine
754
West Ridge Mine
696
Harvey Mine
634
Federal No. 2
608
Harrison County Mine
593
Cumberland
578
Marshall County Mine
452
Enlow Fork Mine
445
Leer Mine
440
Bailey Mine
374
San Juan Mine 1
346
Oaktown Fuels No. 1
310
Ohio County Mine
300
New Future Mine
271
MC #1 Mine
235
Mine Summary Tables
4-12

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Table 13: Mines with CMM Use Projects
Mine Name	Type of Use Project Estimated Current Market
Penetration
Buchanan Mine
Pipeline, Electricity
100%
No. 4 Mine
Pipeline
100%
No. 7 Mine
Pipeline
100%
Oak Grove Mine
Pipeline
100%
Pinnacle Mine
Pipeline
100%
Shoal Creek
Pipeline
85%
Emerald Mine No 1
Pipeline
30%
Cumberland
Pipeline
22%
Marshall County Mine
VAM Destruction
12%
Harrison County Mine
Pipeline
10%
Marion County Mine
Pipeline
6%
Monongalia Mine
Pipeline
4%
Bailey Mine
Pipeline
0%
Mine Summary Tables
4-13

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5. Profiled Mines
States with Candidate and Utilizing Mines:
Alabama
Illinois
Indiana
New Mexico
Pennsylvania
Utah
Virginia
West Virginia
Profiled Mines Summary
5-1

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5. Profiled Mines
Alabama Mines
No. 4 Mine
No. 7 Mine
Oak Grove
Shoal Creek
Profiled Mines Summary
5-2

-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 0101247
NO 4 MINE
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 Surrounding Terrain: 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: 551
Mining Method: Longwall
Year of Initial Production: 1976
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 1900
Seam Thickness (ft.): 5.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan
Distance to Pipeline (miles): 5.3

2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














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
12.5
(MMCF/D)














Estimated














Specific
Emissions
3,455
2,620
1,943
3,103
3,849
3,886
2,692
4,231
3,546
2,642
2,382
2,513
2,879
2,889
(CF/T)














Methane














Used
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
(MMCF/D)














Estimated














Current
Drainage
56%
57%
50%
75%
73%
71%
55%
61%
51%
36%
26%
48%
49%
66%
Efficiency














Estimated














Current
Market
100%
100%
100%
100%
100%
100%
100%
102%
104%
107%
106%
100%
100%
100%
Penetration














3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
Coal Production (million short tons)
^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
# / # / / # J?	V* <{?
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-3

-------
Mine Status: Active Drainage System: Yes
Use Project:	Pipeline	MSHA ID: 0101401
NO 7 MINE
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 Surrounding Terrain: 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: 811
Mining Method: Longwall
Year of Initial Production: 1978
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 1900
Seam Thickness (ft.): 6.4
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan
Distance to Pipeline (miles): 5.1
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
14
12.8
8
24
22.9
11.5
13.4
11
21.2
18.1
15.9
16.8
10.1
11.3
(MMCF/D)














Estimated














Specific
4,563
4,342
2,523
5,804
4,436
3,273
4,367
4,424
4,184
4,157
3,201
2,656
2,141
3,223
(CF/T)














Methane














Used
14
12.8
8
24
22.9
11.5
13.4
11
21.2
18.1
15.9
16.8
10.1
11.3
(MMCF/D)














Estimated














Current
Drainage
56%
57%
50%
75%
73%
48%
39%
28%
47%
44%
38%
43%
33%
43%
Efficiency














Estimated














Current
Market
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
Penetration














Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0 -I	
ftl' o
^ ^ ^ ^ ^
Emissions (MMCF/D)
35
30
25
20
15
10
5
0
^ ^ ^ ^
x? G oy "v? oc? W? nv ocP *?	ofp -v? oc? ofp
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-4

-------
Mine Status: Active Drainage System: Yes
Use Project:	Pipeline	MSHA ID: 0100851
OAK GROVE MINE
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 Surrounding Terrain: 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: 339
Mining Method: Longwall
Year of Initial Production: 1981
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 1000
Seam Thickness (ft.): 5.2
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Kinder Morgan
Distance to Pipeline (miles): 3.7
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
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
(MMCF/D)














Estimated














Specific
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
1,484
(CF/T)














Methane














Used
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
(MMCF/D)














Estimated














Current
Drainage
66%
41%
17%
26%
10%
13%
27%
0%
33%
22%
38%
32%
39%
22%
Efficiency














Estimated














Current
Market
100%
100%
100%
68%
100%
72%
40%
-
59%
100%
88%
88%
100%
100%
Penetration














Coal Production (million short tons)
2.5
2.0
1.5
1.0
0.5
0.0 -I	
& c
Emissions (MMCF/D)
12
10
8
6
4
2
0
f # #
^ -ff -s? 4? -G? ^ ^
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-5

-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 0102901
SHOAL CREEK MINE
Basin: Black Warrior
State:AL
Coalbed: Blue Creek / Mary Lee
County: Jefferson
Current Operator: Drummond Company Inc.
Owner/Parent Company: Drummond Company Inc.
Parent Company Website: www.drummondco.com
Previous Owner(s): None in last 10 years
Previous or Alternate Name of Mine: None
Description of Surrounding Terrain: Open Hills/High Hills
Utility Electric Supplier: Alabama Power Co
Parent Corporation of Utility: Southern Co
Mailing Address: 8488 Nancy Ann Bend Road Adger,
AL 35006
Latitude/Longitude: 33.51314, -87.27675
Number of Employees at Mine: 455
Mining Method: Longwall
Year of Initial Production: 1994
Primary Coal Use: Steam
Depth to Seam (ft.): 1150
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
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














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
(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
1,991
(CF/T)














Methane














Used
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
7.2
(MMCF/D)














Estimated














Current
Drainage
9%
6%
14%
19%
2%
17%
22%
26%
55%
69%
84%
67%
67%
77%
Efficiency














Estimated














Current
Market
100%
100%
33%
5%
100%
46%
67%
100%
100%
95%
97%
63%
34%
85%
Penetration














Coal Production (million short tons)
^ ^ ^ ^ ^ ^ $
Emissions (MMCF/D)
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-6

-------
5. Profiled Mines (continued)
Illinois Mines
The American Coal Company New Era Mine
New Future Mine
MC #1 Mine
Profiled Mines
5-7

-------
Mine Status:
Use Project:
Active
NA
Drainage System: No
MSHA ID: 1102752
THE AMERICAN COAL COMPANY NEW ERA MINE
Basin: Illinois
State: IN
Coalbed: Springfield No. 5
County: Saline
Current Operator: The American Coal Company
Owner/Parent Company: Murray Energy Corp
Parent Company Website: www.murrayenergycorp.com
Previous Owner(s): Kerr-McGee Coal Corp
Previous or Alternate Name of Mine: Galatia No. 56, Galatia
Description of Surrounding Terrain: 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: 381
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
Coal
Production
(million
short tons)
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
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
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
Estimated
Methane
Drained
(MMCF/D)
Estimated
Specific
Emissions
(CF/T)
353
237 315 464 431 360
682 475 541 484 535 423 279 763
Methane
Used
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
Coal Production (million short tons)
Emissions (MMCF/D)
8.0
7.0
6.0
1.0
0.0

.Cv^ _C$ jd> * _cC^ .ft1** _c&	-Ov*" _c&
Jf

- Emission from Ventilation Systems
-Estimated Methane Drained
Profiled Mines
5-8

-------
Mine Status:
Use Project:
Active
NA
Drainage System: NA
MSHA ID: 1103232
NEW FUTURE MINE
Basin: Illinois
State: IN
Coalbed: Herrin No.6
County: Saline
Current Operator: The American Coal Company
Owner/Parent Company: Murray Energy Corp
Parent Company Website: www.murrayenergycorp.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of Surrounding Terrain: 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: 318
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
2002
2003 2004 2005 2006 2007 2008 2009 2010
2011
2012
2013
2014
2015
Coal






Production
(million
0.6
1.8
3.6
5.5
5.7
5.2
short tons)






Emission






from






Ventilation
4.4
3.4
3.5
4.8
5.1
3.9
Systems






(MMCF/D)






Estimated






Methane
Drained
o
0
0
0
0
-
(MMCF/D)






Estimated






Specific
Emissions
2,677
689
355
319
327
271
(CF/T)






Methane






Used
.
-
-
-
-
-
(MMCF/D)






Estimated






Current
Drainage
o
0
0
0
0%
-
Efficiency






Estimated






Current






Market






Penetration






Coal Production (million short tons)
# # # # / # / # ^
Emissions (MMCF/D)
/ ^ ^ ^
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-9

-------
Mine Status: Active Drainage System: NA
Use Project:	NA	MSHA ID: 1103189
MC #1 MINE
Basin: Illinois
State: IN
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 Surrounding Terrain: Open Hills/Irregular
Utility Electric Supplier: Central Illinois Public Services Co
Parent Corporation of Utility: Ameren Corp.
2002 2003 2004 2005 2006 2007
Mailing Address: 11525 N. Thompsonville Road
Macedonia, IL 62860
Latitude/Longitude: 39.9705, -80.4141
Number of Employees at Mine: 404
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
2008 2009 2010 2011 2012 2013 2014 2015
Coal
Production ........ 0.3 0.9 4.7 6.5 9.1 10.6
(million
short tons)
Emission
from
Ventilation ........ o.2 0.4 2.2 2.6 4.4 6.J
Systems
(MMCF/D)	
Estimated
Methane
Drained
(MMCF/D)
Estimated
peClf'C	-------- 243 162 171 146 177 235
Emissions
(CF/T)	
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)
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-10

-------
5. Profiled Mines (continued)
Indiana Mines
Oaktown Fuels No. 1
Profiled Mines
5-11

-------
Mine Status: Active Drainage System: Yes
Use Project:	NA	MSHA ID: 1202394
OAKTOWN FUELS NO. 1
Basin: Illinois
State: IN
Coalbed: Springfield No. 5
County: Sullivan
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 Surrounding Terrain: Flat farmland
Utility Electric Supplier: Duke Energy Indiana Inc.
Parent Corporation of Utility: Duke Energy Corp
2002 2003 2004 2005 2006 2007
Mailing Address: 1183 East Canvasback Drive
Terre Haute, IN 47802
Latitude/Longitude: 38.94575, -87.38421
Number of Employees at Mine: 333
Mining Method: Room and Pillar
Year of Initial Production: 2006
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
2008 2009 2010 2011 2012 2013 2014 2015
0.05 0.1
Coal
Production
(million	______	o.O 0.05 1.0 2.7 2.8 3.4 3.4 3.5
short
tons/year)	
Emission
from
Ventilation -	-	-	-	-	-	-	0.3 0.7 1.6 2.7 2.2 2.7 2.8
Systems
(MMCF/D)	
Estimated
Methane
Drained
(MMCF/D)	
Estimated
Spe.Clf.'C	_______ 1 190 256 216 352 236 295 310
Emissions
(CF/T)	
Methane
Used	______________
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
2% 3%
Coal Production (million short tons)
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0 4
Emissions (MMCF/D)
3
3
2
2
l
l
0
^ nS5 &	"P ^

-------
5. Profiled Mines (continued)
New Mexico Mines
San Juan Mine 1
Profiled Mines
5-13

-------
Mine Status: Active Drainage System: Yes
Use Project:	None	MSHA ID: 2902170
SAN JUAN MINE 1
Basin: San Juan
State: NM
Coalbed: 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 Surrounding Terrain: 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: 483
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

2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal














Production
(million
1.8
5.9
7.7
7.9
7
6.9
7
6.5
4.9
3.9
4.9
6
00
00
6.5
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
Drained
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
(MMCF/D)














Estimated














Specific
Emissions
406
223
194
300
339
307
417
517
723
973
350
292
199
346
(CF/T)














Methane














Used
-
0
0.2
0
-
-
-
-
-
-
-
-
-
-
(MMCF/D)














Estimated














Current
Drainage
25%
64%
61%
40%
40%
40%
40%
40%
40%
40%
26%
40%
44%
28%
Efficiency














Estimated














Current
Market
-
>1%
8%
>1%
-
-
-
-
-
-
-
-
-
-
Penetration














Coal Production (million short tons)
Emissions (MMCF/D)
7
e
5
4
3
2
1
0
^ ^ ^ ^ ^ ^ ff' -G? ^ ^
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-14

-------
5. Profiled Mines (continued)
Pennsylvania Mines
Bailey
Cumberland
Emerald Mine No 1
Enlow Fork
Harvey Mine
Profiled Mines
5-15

-------
Mine Status: Active Drainage System: Yes
Use Project:	Power	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 Surrounding Terrain: 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: 726
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
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
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
Emission
from
Ventilation
Systems
(MMCF/D)
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
Estimated
Methane
Drained
(MMCF/D)
0.1
2.9 3.2 1.5 1.7 1.8 2.5 1.1 1.2 1.5 1.8 3.1
Estimated
Specific
Emissions
(CF/T)
271 221 304 322 383 376 420 440 575 419 376 552 362 374
Methane
Used
(MMCF/D)
1.8
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
1%
30% 30% 15% 15% 15% 15% 9% 12% 9% 15% 30%
100%
Coal Production (million short tons)
Emissions (MMCF/D)
20
15
10
5
0
J> Jr J1 J*
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-16

-------
Mine Status: Active
Use Project:	Pipeline
Drainage System: Yes
MSHA ID: 3605018
CUMBERLAND MINE
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 Surrounding Terrain: 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: 696
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

2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














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
(MMCF/D)














Estimated














Specific
Emissions
614
842
744
560
492
580
640
913
975
665
781
886
646
578
(CF/T)














Methane














Used
-
-
-
3.2
3.4
2.6
3.2
3.7
3.7
3.7
1.7
1.7
1.4
1.2
(MMCF/D)














Estimated














Current
Drainage
14%
31%
32%
34%
34%
33%
30%
24%
26%
35%
37%
47%
51%
46%
Efficiency














Estimated














Current
Market
-
-
-
86%
100%
68%
82%
93%
93%
93%
33%
27%
20%
22%
Penetration














Emissions (MMCF/D)
Coal Production (million short tons)
8.0
7.0
10
6.0
5.0
4.0
3.0
2.0
1.0
0.0 -I	1	1	1	1	1	1	1	1	1	1	1	1	
^ ^ ^ ^ ^ -p* -e? -v? ^ <$
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-17

-------
Mine Status: Active Drainage System: Yes
Use Project:	Pipeline	MSHA ID: 3605466
EMERALD MINE NO 1
Basin: Northern Appalachian
State: PA
Coalbed: Pittsburgh No. 8
County: Greene
Current Operator: Emerald 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 Emerald, Emerald No.
Description of Surrounding Terrain: High Hills/Open High Hills
Utility Electric Supplier: West Penn Power Co
Parent Corporation of Utility: FirstEnergy
Mailing Address: 212 Mine Rd. Waynesburg, PA 15370
Latitude/Longitude: 39.8875, -80.1935
Number of Employees at Mine: 275
Mining Method: Longwall
Year of Initial Production: 1977
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 400-1000
Seam Thickness (ft.): 6.5-7.0
1 Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 0.23

2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal














Production
(million
6.6
6.6
5.8
6.3
5.9
5.7
6.3
5.6
4.9
3.7
4.4
3.6
3.9
1.7
short tons)














Emission














from














Ventilation
6.6
7.4
4.9
4.7
5.2
5.5
7
6.6
5.4
3.5
3.7
5.2
3.9
3.2
Systems














(MMCF/D)














Estimated














Methane
Drained
2.5
2
2.3
2
2.3
2.1
2.2
2.2
2.2
2.2
1.9
2.9
2.2
2.3
(MMCF/D)














Estimated














Specific
Emissions
503
520
453
388
464
487
533
574
566
562
465
821
571
1,180
(CF/T)














Methane














Used
-
-
-
1.8
2.3
1.4
1.8
2
2
2
1
2
1.1
0.7
(MMCF/D)














Estimated














Current
Drainage
27%
21%
32%
26%
30%
28%
24%
25%
29%
39%
34%
36%
36%
42%
Efficiency














Estimated














Current
Market
-
-
-
90%
100%
67%
82%
91%
91%
91%
53%
69%
50%
30%
Penetration














Coal Production (million short tons)
4.0
3.0
1.0
0.0
-P
cn<
tC?

Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
Profiled Mines
5-18

-------
Mine Status: Active Drainage System: No
Use Project:	None	MSHA ID: 3607416
Enlow Fork
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 Surrounding Terrain: 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: 604
Mining Method: Longwall
Year of Initial Production: 1990
Primary Coal Use: Steam
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): 1.2
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
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
Emission
from
Ventilation
Systems
(MMCF/D)
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
Estimated
Methane
Drained
(MMCF/D)
0.1
0.1 0.1
0.3
Estimated
Specific
Emissions
(CF/T)
346 380 394 358 345 345 375 470 549 444 396 405 365 445
Methane
Used
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
1%
0% 0%
3%
12.0
10.0
Coal Production (million short tons)

6.0
4.0
# ^ # # / # -f	^ /
Emissions (MMCF/D)
12
10
-c& .c& Jr


-Emission from Ventilation Systems
-Estimated Methane Drained
Profiled Mines
5-19

-------
Mine Status: Active
Use Project:	NA
Drainage System: NA
MSHA ID: 3610045
Harvey Mine
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 Surrounding Terrain: 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: 343
Mining Method: Longwall
Year of Initial Production: 2015
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: NA
Distance to Pipeline (miles): NA
2002
2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014
2015
Coal


Production
3.2
3.6
(million
short tons)


Emission


from


Ventilation
4.5
5
Systems


(MMCF/D)


Estimated


Methane

1 1
Drained

l.Z
(MMCF/D)


Estimated


Specific
513
634
Emissions
(CF/T)


Methane


Used
.
-
(MMCF/D)


Estimated


Current

19%
------------
Drainage

Efficiency


Estimated


Current


Market


Penetration


Emissions (MMCF/D)
Coal Production (million short tons)
6
4.0
5
3.5
3.0
4
2.5
3
2.0
2
1.5
1
1.0
0	

-------
5. Profiled Mines (continued)
Utah Mines
West Ridge Mine
Profiled Mines
5-21

-------
Mine Status: Non-Producing Drainage System: Yes
Use Project:	Power, Flaring, Heating	MSHA ID: 4202233
WEST RIDGE MINE
Basin: Uinta
State: Utah
Coalbed: Lower Sunnyside
County: Carbon
Current Operator: West Ridge Resources Inc.
Owner/Parent Company: Murray Energy Corp
Parent Company Website: www.murrayenergycorp.com
Previous Owner(s): None
Previous or Alternate Name of Mine: None
Description of Surrounding Terrain: Hilly/Mountainous
Utility Electric Supplier: Rocky Mountain Power
Parent Corporation of Utility: PacifiCorp
Mailing Address: 794 North C Canyon Rd. East Carbon,
UT 84520
Latitude/Longitude: 39.62, -110.44
Number of Employees at Mine: 126
Mining Method: Longwall
Year of Initial Production: 1999
Primary Coal Use: Steam
Depth to Seam (ft.): 156
Seam Thickness (ft.): Unknown
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: Questar Pipeline Corp.
Distance to Pipeline (miles): < 5
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
Coal
Production
(million
short
tons/year)
Emission
from
Ventilation
Systems
(MMCF/D)
Estimated
Methane
Drained
(MMCF/D)
Estimated
Specific
Emissions
(CF/T)
Methane
Used
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
2.8 3.0 2.3 2.6 3.0 4.3 3.8 3.1 3.3 3.6 2.4 2.6 2.5 1.6
2.5 3.6 3.5 2.5 3.6 3.2 3.9 4.8 8.0 4.2 5.1 2.3 1.8 1.7
1.3 1.6 1.6 1.4 2.3 2.0 0.9 1.4
326 438 555 351 438 272 499 754 1,062 568 1,125 604 394 796
25% 25% 17% 25% 31% 47% 33% 45%
Coal Production (million short tons)
Emissions (MMCF/D)
10
s
6
4
2
0
rSi1 0 cS? r&	rd &
P iP
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-22

-------
5. Profiled Mines (continued)
Virginia Mines
Buchanan Mine #1
Profiled Mines
5-23

-------
Mine Status: Active Drainage System: Yes
Use Project:	Pipeline, Power	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 Surrounding Terrain: Open Low Mountains/Low
Mountains
Utility Electric Supplier: Appalachian Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
Mailing Address: Rte 680, Keen Mountain, VA 24624
Latitude/Longitude: 37.207886, -81.916612
Number of Employees at Mine: 434
Mining Method: Longwall
Year of Initial Production: 1983
Primary Coal Use: Steam, Metallurgical
Depth to Seam (ft.): 1400 - 2000
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
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
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
(MMCF/D)














Estimated














Specific
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
4,850
(CF/T)














Methane














Used
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
(MMCF/D)














Estimated














Current
Drainage
80%
83%
83%
83%
88%
85%
89%
90%
89%
88%
89%
87%
90%
88%
Efficiency














Estimated














Current
Market
100%
96%
99%
100%
80%
100%
100%
100%
100%
100%
100%
100%
77%
100%
Penetration














Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0 											r		
^ ,/ ^ ^ / ./ / 4? 4?	/
Emissions (MMCF/D)
Emission from Ventilation Systems
Estimated Methane Drained
Profiled Mines
5-24

-------
5. Profiled Mines (continued)
West Virginia Mines
Beckley Pocahontas Mine
Federal No. 2
Harrison County Mine
Leer Mine
Marion County Mine
Marshall County Mine
Monongalia County Mine
Ohio County Mine
Pinnacle
Profiled Mines
5-25

-------
Mine Status:
Use Project:
Active
Pipeline
Drainage System: Yes
MSHA ID: 4605252
Beckley Pocahontas Mine
Basin: Central Appalachian Basin
State: WV
Coalbed: Pocahontas No. 3
County: Raleigh
Current Operator: ICG Beckley LLC
Owner/Parent Company: Arch Coal
Parent Company Website: www.archcoal.com
Previous Owner(s): International Coal Group
Previous or Alternate Name of Mine: None
Description of Surrounding Terrain: 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: 242
Mining Method: Continuous
Year of Initial Production: 2007
Primary Coal Use: Coking
Depth to Seam (ft.): 600-1300
Seam Thickness (ft.): 4.2
Transmission Pipeline in County?: NA
Owner of Nearest Pipeline: NA
Distance to Pipeline (miles): NA
Coal
Production
(million
short tons)
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
0 0.4 0.7 1 1.1 1.1 1.1 1 0.9
Emission
from
Ventilation
Systems
(MMCF/D)
0.3 1.2 4 4.5 2.9 3.1 2.9 3.3 3.3
Estimated
Methane
Drained
(MMCF/D)
Estimated
Specific
Emissions
(CF/T)
1,095 2,086 1,643 962 1,029 962 1,205 1,356
Methane
Used
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
Coal Production (million short tons)
^ Jp
& & ^
V" -CV* -CV* .	A O*
-CV3 -CV" -C\V .CS* -CS*
 Estimated Methane Drained
Profiled Mines
5-26

-------
Mine Status: Active	Drainage System: Yes
Use Project:	Pipeline	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: N/A
Previous Owner(s): Peabody Energy Corp, Patriot Coal Corporation
Previous or Alternate Name of Mine: None
Description of Surrounding Terrain: 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: 456
Mining Method: Longwall
Year of Initial Production: 1968
Primary Coal Use: Steam
Depth to Seam (ft.): 800 - 1250
Seam Thickness (ft.): 7.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 0.7
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
1.4
1.1
1.1
1
1
1
1.1
1
0.2
0.1
0
0.1
0
-
(MMCF/D)














Estimated














Specific
876
722
425
588
532
785
860
663
789
779
621
709
541
608
(CF/T)














Methane














Used
0.4
0.1
0
0.2
0.2
0.4
0.6
0.5
0.2
0.1
-
-
-
-
(MMCF/D)














Estimated














Current
Drainage
12%
13%
19%
15%
15%
12%
15%
14%
3%
1%
0%
2%
0%
-
Efficiency














Estimated














Current
Market
29%
9%
0%
20%
23%
40%
55%
50%
100%
100%
-
-
-
-
Penetration














Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0
^ ^	^ ^ ^ r^3
^	J? /
Emissions (MMCF/D)
12
10
8
6
4
2
0
# ^ ^ ^ ^ ^ ^ ^
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-27

-------
Mine Status:
Use Project:
Active
None
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.murrayenergycorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Robinson Run No. 95
Description of Surrounding Terrain: 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: 561
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

2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
Drained
1.1
1
2
1.7
1.7
0
0
0
0
0
1.3
1.3
6.3
3.1
(MMCF/D)














Estimated














Specific
Emissions
409
320
389
347
365
262
352
485
458
476
606
551
730
593
(CF/T)














Methane














Used
-
-
-
-
-
-
-
-
-
-
-
-
3.4
0.3
(MMCF/D)














Estimated














Current
Drainage
20%
20%
30%
29%
30%
0%
0%
0%
0%
0%
16%
15%
47%
27%
Efficiency














Estimated














Current
Market
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
0%
10%
Penetration














3.0
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0
Coal Production (million short tons)
^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
0s?	^ <$
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-28

-------
Mine Status: Active	Drainage System: No
Use Project:	None	MSHA ID: 4609192
Leer Mine
Basin: Northern Appalachian
State: WV
Coalbed: 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 Surrounding Terrain: Open Low Mountains
Utility Electric Supplier: MonPower Co.
Parent Corporation of Utility: FirstEnergy
Mailing Address: 1200 Tygart Dr., Grafton, WV
26354
Latitude/Longitude: 39.3417, -79.9759
Number of Employees at Mine: 561
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: N/A
Distance to Pipeline (miles): 12.5
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
Coal
Production
(million
short tons)
Emission
from
Ventilation
Systems
(MMCF/D)
Estimated
Methane
Drained
(MMCF/D)
Estimated
Specific
Emissions
(CF/T)
Methane
Used
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
0.01 0.6 0.6 2.7 3.4
0.9 2.6 4.1
548 351 440
Coal Production (million short tons)
4.0
3.5
3.0
2.5
2.0
1.5
1.0
0.5
0.0
#	JP J* .c# -cf? .cC>
Emissions (MMCF/D)
^ oSJ5 < r$?

f>v	f>v	-pv
-Emission from Ventilation Systems
-Estimated Methane Drained
Profiled Mines
5-29

-------
Mine Status: Active Drainage System: Yes
Use Project:	Pipeline	MSHA ID: 4601433
Marion County Mine
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.murrayenergycorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Loveridge #22
Description of Surrounding Terrain: 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: 606
Mining Method: Longwall
Year of Initial Production: 1953
Primary Coal Use: Steam
Depth to Seam (ft.): 800-1250
Seam Thickness (ft.): 7.0
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EQT
Distance to Pipeline (miles): 1.4
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
Coal














Production
(million
-
0.3
5
6.4
6.4
6.6
5.2
6
5.9
5.6
5.9
5.3
6.6
6.5
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
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
(MMCF/D)














Estimated














Specific
-
6,448
387
331
405
409
548
718
631
756
613
902
946
754
(CF/T)














Methane














Used
-
-
-
1.7
1.8
2.1
1.8
1.2
1.1
0.9
0.9
0.9
3.1
0.1
(MMCF/D)














Estimated














Current
Drainage
39%
83%
30%
29%
25%
28%
23%
10%
11%
8%
9%
14%
25%
12%
Efficiency














Estimated














Current
Market
-
-
-
100%
100%
100%
100%
100%
100%
100%
100%
50%
72%
6%
Penetration














Coal Production (million short tons)
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0 4-^
^ ^ ^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
14
12
10
8
6
4
2
0
/ J J ^ ^ J* J?
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-30

-------
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.murrayenergycorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: McElroy Mine
Description of Surrounding Terrain: 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: 954
Mining Method: Longwall
Year of Initial Production: 1968
Primary Coal Use: Steam
Depth to Seam (ft.): 600-1200
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

2002
2003 2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal













Production
(million
4.8
cn
00
00
4^
10.4
10.5
9.7
9.6
9.8
10.1
9.3
9.4
9.4
10.4
10.3
short tons)













Emission













from













Ventilation
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
Systems













(MMCF/D)













Estimated













Methane
Drained
-
-
2.0
2.3
1.8
2.4
2.2
1
0.9
0.5
0.8
1.6
-
(MMCF/D)













Estimated













Specific
Emissions
563
86 356
467
525
572
608
551
582
593
532
528
502
452
(CF/T)













Methane













Used
-
-
-
-
-
-
0.1
0.1
0.1
0.7
1.9
1.8
1.5
(MMCF/D)













Estimated













Current
Drainage
-
-
15%
15%
12%
15%
15%
6%
6%
4%
6%
11%
-
Efficiency













Estimated













Current
Market
0%
0% 0%
0%
0%
0%
0%
5%
10%
11%
140%
226%
113%
12%
Penetration













12.0
10.0
3.0
6.0
4.0
2.0
0.0
Coal Production (million short tons)
# # # # # / # / J?	^
Emissions (MMCF/D)
# # # / / / / ^	V* #
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-31

-------
Mine Status: Active Drainage System: Yes
Use Project:	Pipeline	MSHA ID: 4601968
Monongalia County Mine
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.murrayenergycorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Blacksville No. 2
Description of Surrounding Terrain: 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: 425
Mining Method: Longwall
Year of Initial Production: 1971
Primary Coal Use: Steam
Depth to Seam (ft.): 800-1150
Seam Thickness (ft.): 7.5
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: EOT
Distance to Pipeline (miles): 1.2
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
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
short tons)














Emission














from














Ventilation
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
Systems














(MMCF/D)














Estimated














Methane
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
(MMCF/D)














Estimated














Specific
684
412
500
551
708
618
658
1,076
852
756
798
836
762
1,019
(CF/T)














Methane














Used
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
(MMCF/D)














Estimated














Current
Drainage
37%
23%
18%
20%
25%
22%
17%
15%
13%
15%
16%
28%
16%
26%
Efficiency














Estimated














Current
Market
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
100%
75%
13%
4%
Penetration














Coal Production (million short tons)
6.0
5.0
4.0
3.0
2.0
1.0
0.0 -I	
c
# i?
^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
10
8
6
4
2

-v*	Jp
^^^Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-32

-------
Mine Status: Active	Drainage System: No
Use Project:	None	MSHA ID: 4601436
Ohio County Mine
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.murrayenergycorp.com
Previous Owner(s): CONSOL Energy Inc.
Previous or Alternate Name of Mine: Shoemaker Mine
Description of Surrounding Terrain: High Hills/Hills
Utility Electric Supplier: Wheeling Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
2002 2003 2004 2005 2006 2007
Mailing Address: 1107 Golden Ridge Road
Dallas, WV 26036
Latitude/Longitude: 39.9705, -80.4141
Number of Employees at Mine: 614
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: NiSource
Distance to Pipeline (miles): 1.4
2008 2009 2010 2011 2012 2013 2014 2015
Coal
Production
,	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
(million
short tons)
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
Systems
(MMCF/D)	
Estimated
Methane
Drained
(MMCF/D)
Estimated
Specific
Emissions
(CF/T)
0.5 0.3 0.6 0.6
365 202 385 438 1,132 9,490 2,588 3,407 365 265 193 228 243 300
Methane
Used
(MMCF/D)
Estimated
Current
Drainage
Efficiency
Estimated
Current
Market
Penetration
15% 14% 15% 14%
Coal Production (million short tons)
7.0
6.0
5.0
4.0
3.0
2.0
1.0
0.0	
c
^ ^ ^ ^ ^ ^ ^
Emissions (MMCF/D)
10
8
6
4
2
0
# A J? J? J> J> {> s> o * ~
Emission from Ventilation Systems	Estimated Methane Drained
Profiled Mines
5-33

-------
Mine Status: Active
Use Project:	Pipeline
Drainage System: Yes
MSHA ID: 4601816
PINNACLE MINE
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 Mining
Company
Previous or Alternate Name of Mine: Pinnacle No. 50, Gary
No. 50, US Steel No. 50
Description of Surrounding Terrain: Low Mountains
Utility Electric Supplier: Appalachian Power Co
Parent Corporation of Utility: American Electric Power Co Inc.
Mailing Address: Route 16 South, Welch Pineville Road
229, Welch, WV 24801
Latitude/Longitude: 37.54722, -81.49917
Number of Employees at Mine: 428
Mining Method: Longwall
Year of Initial Production: 1969
Primary Coal Use: Metallurgical
Depth to Seam (ft.): 600-1300
Seam Thickness (ft.): 4.2
Transmission Pipeline in County?: Yes
Owner of Nearest Pipeline: NiSource
Distance to Pipeline (miles): 0.3

2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Coal














Production
(million
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
short tons)














Emission














from














Ventilation
8
9.8
8
6.5
5.2
5.3
5.4
5.8
5.5
3.4
6
8.3
9
6.2
Systems














(MMCF/D)














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
(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
1,067
(CF/T)














Methane














Used
5.6
2
3.1
9.7
4.6
2.4
1.3
4.7
4.6
4.3
-
2.9
0.4
0.8
(MMCF/D)














Estimated














Current
Drainage
41%
17%
28%
60%
47%
40%
30%
50%
46%
58%
20%
30%
11%
12%
Efficiency














Estimated














Current
Market
100%
100%
100%
100%
100%
71%
57%
82%
100%
93%
-
81%
36%
100%
Penetration














Emissions (MMCF/D)
Coal Production (million short tons)
12
4.0
3.5
10
3.0
3
2.5
6
2.0
4
1.5
2
1.0
0	
# -V*
0.5
JF <> ^ ^ ^	v ^ ^ ^
0.0
Emission from Ventilation Systems
Estimated Methane Drained
Profiled Mines
5-34

-------
6. References
Alliance Resources (2016). Form 10-K. Filed February 26, 2016 (period: December 31, 2015).
Arch Coal (2016). Form 10-K. Filed March 15, 2016 (period: December 31, 2015).
BHP Billiton (2015). Resourcing global growth Annual Report 2015. Retrieved from
http://www.bhpbilliton.eom/~/media/bhp/documents/investors/annual-reports
California Carbon (2016). California Carbon Info. Retrieved from http://californiacarbon.info/
Cliff Natural Resources (2016). Form 10-K. Filed February 25, 2016 (period: December 31, 2015).
Coal Age (2016). U.S Longwall Census, Coal Age Magazine, February 2016. Pg.18-22.
CONSOL Energy (2016). Form 10-K Filed February 5, 2016 (period: December 31, 2015).
CONSOL Energy (2013). Form 10-K. Filed February 7, 2014 (period: December 31, 2012).
Drummond (2017). Shoal Creek. Retrieved from http://www.drummondco.com/our-
products/coal/m ines/
Hallador Energy Company (2016). Form 10-K. Filed on March 11, 2016 (period: December 31, 2015).
IPCC (2007). Climate Change 2007: Synthesis Report, prepared by Working Groups I, II and III to
the Fourth Assessment Report of the Intergovernmental Panel on Climate Change, Pachauri,
R.Kand Reisinger, A. (eds.). IPCC, Geneva, Switzerland, 104 pp., Eggleston H.S., Buendia
L., Miwa K., Ngara T. and Tanabe K. (eds). Published: IGES, Japan.
MSHA (2017). Mine Safety and Health Administration: Mine Data Retrieval System, Available at
http://arlweb.msha.gov/drs/drshome.htm
Platts (2016). Murray Energy's New Era thermal coal mine to remain in production until October.
Retrieved from http://www.platts.com/latest-news/coal/louisville-kentuckv/murrav-enerqys-
new-era-thermal-coal-mine-to-remain-21799047
EPA (U.S. Environmental Protection Agency) (2017). Inventory of U.S. Greenhouse Gas Emissions
and Sinks 1990-2015, Office of Atmospheric Programs, EPA 430-P-17-001. April, 15 2017.
EPA (2009). Identifying Opportunities for Methane Recovery at U.S Coal Mines: Profiles of Selected
Gassy Underground Coal Mines 2002-2006, EPA 430-K-04-003. January 2009.
EPA. Greenhouse Gas Reporting Program, https://www.epa.qov/qhqreportinq
References
6-1

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