fjUSDA
&EPA
United States Department
of Agriculture
United States Environmental
Protection Agency
Economics, Statistics, and
Cooperatives Service
Office of Environmental
Engineering and Technology
Technical Bulletin No. 1627
EPA-600/7-79-139
Research and Development
Western Energy:
The Interregional Coal
Analysis Model
Interagency
Energy/Environment
R&D Program
Report
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For sale by tho Superintendent of Documents, U.S. Government Printing Office, Washington, D.C. 20402
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WESTERN ENERGY: THE INTERREGIONAL COAL ANALYSIS MODEL, By John W. Green.
Natural Resource Economics Division; Economics, Statistics, and Cooperatives Service;
U.S. Department of Agriculture, Technical Bulletin No. 1627.
ABSTRACT
Electric utilities have already concluded contracts to obtain a major portion of
their long-term coal needs. Based on these contracts, coal production from Montana,
North Dakota, Wyoming, Colorado, Utah, Arizona, and New Mexico is projected to in-
crease from 65 million tons in 1975 to 286 million tons by 1985. Coal production in
northeastern Wyoming is projected to rise from 3.5 million tons in 1975 to 106 million
tons in 1985, by far the largest increase for any area of those seven States. Other
large increases will occur in Rosebud County, Montana, and the Four Corners area of
New Mexico—all strip-mined coal. By 1985, strip mining will be disturbing about
6,000 acres annually. Deep-mined coal from central Utah is projected to increase from
3 million tons in 1975 to 16 million in 1985. With a 3-year construction delay of
certain key electric power plants, Western coal output would rise to only 230 million
tons by 1985.
Keywords: Coal, Strip mining, Western States, Energy, Projections, Model
ACKNOWLEDGMENTS
Help and cooperation on this report came from many government agencies and pri-
vate industry. Special thanks is due to the Economics Department, Colorado State
University, for logistical, secretarial, and professional support. Special thanks
also are given to Melvin Skold, Professor of Economics, CSU, for his inspiration and
advice in beginning this work, and for his thorough and helpful review of the draft.
Thanks also go to my graduate assistants: Steve Lauck, John Kania, Mike Moffett, and
Norm Dalsted. Their research and programming help was essential as was the typing by
Maxine Rigdon. Project administration and manuscript review by Joseph Barse, ESCS/
Washington, is also acknowledged and appreciated.
Washington, D.C. 20250
August 1980
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FOREWORD
The research activities and results described in this report are part of a pro-
ject entitled "Integrated Assessment: Economic and Social Consequences of Coal and
Oil Shale Development." This project is supported jointly by the U.S. Department
of Agriculture (USDA) and the Environmental Protection Agency (EPA) as a component of
the Federal Interagency Energy/Environment Research and Development Program. The
overall project focuses on identifying and analyzing certain interrelationships be-
tween society's needs for energy, environmental quality, and agricultural production
and the impacts of alternative public policy strategies for dealing with these needs.
The Western States version of the Interregional Coal Analysis Model as described
in this report is not an adequate representation of the simulation model in its final
form. The final model will be national and interregional in coverage. However, the
western model does illustrate the basic logic and structure of the activity as cur-
rently envisioned. In this, as in most major modeling work, full application lags
development by a considerable time. Although the model is still in the development
stage, this report is being published in order to stimulate discussion of the basic
concepts and to solicit comments and suggestions. Colleagues in the energy modeling
field, as well as individuals actively involved in all kinds of related policy analy-
sis, are encouraged to send their comments to the author or to us.
Paul Schwengels, Project Officer
Office of Environmental Engineering
and Technology
Office of Research and
Development
U.S. Environmental Protection Agency
Joseph Barse
Natural Resource Economics Division
Economics, Statistics, and
Cooperatives Service
U.S. Department of Agriculture
11
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SUMMARY
Steam-electric coal production from Wyoming, Montana, North Dakota, New Mexico,
Utah, Colorado, and Arizona is projected to increase from the 65 million tons of 1975
to 286 million in 1985. The largest increase is occurring in northeastern Wyoming,
projected to rise from 3.5 million tons in 1975 to 106 million by 1985.
Other large increases are projected for Rosebud County, Montana, and the Four
Corners area of New Mexico—all strip-mined coal. Deep-mined coal from central Utah
is projected to increase from 3 million tons in 1975 to 16 million in 1985.
Electric utilities have already concluded contracts for a major portion of their
Western coal purchases through 1985. Such contracts are a good basis for projecting
1985 total demand for Western steam coal when supplemented by other demand information
and some policy assumptions. The simulation model described in this report recon-
structs the coal supply (origin and transportation) patterns to match projected de-
mand.
By 1985, strip mining will be disturbing about 5,800 acres of land annually under
this projection. At current tax rates, State severance taxes would yield $575 million
in total revenue to the seven-State region. Although the rapid buildup of strip
mining in the most active area, northeastern Wyoming, would have mined 400 million
tons of coal from that area during the 1975-84 decade, that part of Wyoming would
still have 20 billion tons of coal reserves left in 1985. Only 2 percent of north-
eastern Wyoming's rich reserves would be depleted by 1985, even with the sharp pro-
duction increase now foreseen.
However, alternative total demand projections for Western coal are also made
based on the assumption that completion of certain large new electric power plants
will be delayed. If 3-year construction delays were to occur in specified new power
plants, which would then come on line after 1985, total Western coal output and use
would rise to only 230 million tons instead of 286 million by 1985. These construc-
tion-delay projections illustrate how the simulation model will be used in its fully
developed interregional form. The objective will be to assess the effects of alter-
native public policies or market demand levels on coal supply and development pat-
terns.
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CONTENTS
INTRODUCTION 1
THE INTERREGIONAL COAL ANALYSIS MODEL 2
Supply Regions 2
Model Objectives 6
A Mathematical Programming Approach 7
Western States Model Structure 9
Model Limitations 11
DATA FOR THE 1975 WESTERN STATES MODEL 13
THE 1985 WESTERN STATES MODEL 29
Coal Supply 29
Coal Transportation 33
Electrical Generation Plants 41
Model Coefficients 43
Power Plant Conversions 43
Coal-Fired Electricity Demand 47
1985 RESULTS 54
1985 Base Scenario Resul ts 54
1-, 2-, and 3-Year Power Plant Construction Delay Scenarios... 63
REFERENCES 68
APPENDIX TABLES 70
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List of Tables
Page
1 U. S. power plant statistics, 1975 14
2 Coefficients for 1975 western region ICAM 16
3 Coal reserves balance for 1985 ICAM 30
4 Coal prices assumed in 1985 for strip and
underground mined coal 31
5 Heat val ue and sul fur content of western coal 32
6 Working table to provide 1985 coal yield and reclamation
ICAM input coefficients 34
7 Taxes computed for western CPAs 35
8 Projected 1985 ICAM coal prices, reclamation costs, and
tax payments 36
9 1975 and 1985 transportation costs 37
10 Characteristics of 1985 transportation links for new
power pi ants 38
11 Coal Btu-tonnage conversion coefficients for use in
monitoring capacity of transportation links 42
12 Power plant coefficients for 1985 model 44
13 Power plants greater than 100 MW converted to coal
by 1979 48
14 Power plants able to convert to coal with relative ease 51
15 Power plants able to convert to coal with difficulty 53
16 Industries issued preliminary prohibitioh orders
during May 1977 57
17 Industries issued preliminary construction orders
during May 1977 58
18 Western coal supply-demand balance, 1985
bO
19 Preliminary list of variables for household electricity
demand analysis 61
20 Base scenario results, 1975 and 1985 64
21 Data for 1-. 2-, and 3-year power plant construction
delay scenarios 55
22 Comparison of 1985 scenarios with 1975 and 1985 base solutions... 66
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Appendix Tables
Page
1 ICAM power plants, codes, and ownership, 1975 70
2 Power plants 100 MW or greater using coal, 1975 85
3 Reported additions to steam coal mining capacity,
by year 136
4 FERC Form 423 coal supply data for power plants
suppl ied by western coal 167
5 Additions to generation capacity: 1976-1990 174
6 Power plants with no expansion plans supplied by
western coal , 1985 235
7 New power plants and power plants with expansion
plans suppl ied by western coal , 1985 242
8 Standard Metropolitan Statistical Areas appearing
in the residential demand study 251
Li st of Figures
Page
1 Coal supply regions 3
2 Northern Great Plains coal supply areas (CPAs) 4
3 Rocky Mountain States coal supply areas (CPAs) 5
4 The analytical approach of the coal model 6
5 U.S. power plant statistics, 1975 13
6 Projected western coal production and remaining
reserves 55
7 Western coal production for large power plants 56
8 Projected 1985 coal prices, costs, and production
for large power plants 59
VI
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Western Energy: The Interregional Coal Analysis Model
John W. Green *
INTRODUCTION
Since the 1973 Middle East oil embargo the energy picture in the United States
has been constantly changing. Uncertainty over the Government's national energy
policy and the relative advantages of using different types of fuel have caused specu-
lation about the location and intensity of energy development. Development has al-
ready created serious problems in the Western United States where coal mining has
boomed in the last 5 years. The impacts on some rural communities have been severe.
This report describes a method for anticipating some of the impacts of coal de-
velopment under different policy options. The Interregional Coal Analysis Model
(ICAM) for the Western States, the subject of this report, projects the likely shifts
in the patterns of coal production, transportation, and utilization which might result
from alternative policy strategies. When completed, the national ICAM may be operated
in coordination with other major modeling activities in the Federal Interagency
Energy/Environment Integrated Assessment Program to provide a flexible and wide rang-
ing analytical system to support the policy analysis activities of that program.
This report describes the interregional competition model for the Western States.
It describes the structure of and the data in two models. The 1975 model describes
the coal mining-large electrical generation plant interactions which existed in 1975.
It develops a base solution against which alternative scenario solutions are compared.
The 1985 model portrays a reasonable reference case for 1985. It also develops a base
solution for use in comparing scenario analyses.
The results presented are preliminary. They were obtained by running the simu-
lation model using the best available coefficients, which are reported in this publi-
cation. However, many of those coefficients have been updated and will not be in the
national model. The Western model reported here is an accurate representation of the
structure and procedure we are utilizing in the development and use of the national
model.
The development of a third model for the year 2000 is under consideration. This
will require reliance on more hypothetical information. Considerable added effort
would be needed to modify the existing model.1 This added effort seems justified by
the need to deal with difficult policy questions and analysis of impacts over a much
longer time period—to 2000.
*John W. Green is a Regional Economist with the Economics, Statistics, and Cooper-
atives Service.
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THE INTERREGIONAL COAL ANALYSIS MODEL
The national I CAM, when completed, will be a large-scale simulation model in-
tended to assist in coal development planning and analysis. The model is being devel-
oped for major U.S. coal supply regions.
Supply Regions
There are six major U.S. coal supply regions: The Northern Great Plains, the
Rocky Mountain States, the Interior, the Appalachian Region, the Gulf States, and the
Pacific States (fig. 1). Regional profile reports are being developed for each of the
major coal supply regions (24, 25). _!_/ The information in these reports, plus other
data, are being used to develop the interregional model. This Western States report
deals with the model developed for the Northern Great Plains and Rocky Mountain States
The analysis described is an interregional analysis between the western coal pro-
ducing areas and the other four coal supply regions.
Coal production areas (CPAs) are multicounty supply areas defined within each of
the major coal supply regions. 2J The breakdown of each major coal supply region into
several coal production areas was necessary to make the model sensitive to the small
area problems being analyzed by this project. Figures 2 and 3 describe the CPAs with-
in the Northern Great Plains and Rocky Mountain coal supply regions, respectively.
The definition of several CPAs within the two western regions makes it possible
to use the model to perform a Western States intraregional analysis. Such an analysis
would consider only the CPAs within the Western States and perform an interregional
analysis among them.
J7The underscored numbers in parentheses refer to references listed at the end of
thTs report.
2J The boundaries of these CPAs, or coal supply regions, have been delineated by
the research staff of this project, and will be standard throughout all project re-
ports (24, 25). Boundaries are set along county lines, but no CPA crosses a State
line. "(TJata on coal reserves is classified on a county-by-county basis by the Bureau
of Mines; the county is the smallest geographic unit used in the Bureau's reserves
data). Only counties with reserves of at least 10 million tons are considered for in-
clusion in CPAs, thus excluding minor deposits. However, in the eight Western States
covered in this report, there are 90 counties with reserves of at least 10 million
tons each. Ninety supply regions would make the analysis unwieldy and would obscure
valid generalizations. Therefore, within a State, contiguous counties which contain
coal reserves of very similar characteristics are grouped into one CPA. The main
characteristics used are heat value and sulfur content. Appropriate county groupings
were usually obvious; for example the lignite of CPA MT05 is different from the sub-
bituminous coal of MT04. As a result of the county grouping process, 28 CPAs are
delineated in these eight Western States. Seven of these CPAs consist of only one
county, usually counties not adjacent to any other county with coal reserves. A South
Dakota CPA is defined, because of its coal reserves, although it has no active or pro-
jected production. Consequently, the model covers eight States, but production comes
from only seven.
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Figure 1
Coal Supply Regions
Northern Great Plains
Pacific
Legend
Bituminous
Coal Deposits
H Subbituminous
I Coal Deposits
}•".. Gulf Lignite
Deposits
Rocky Mountain
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Figure 2
Northern Great Plains Coal Supply Areas (CPAs)
North Dakota
Montana
Wyoming
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Figure 3
Rocky Mountain States Coal Supply Areas (CPAs)
Utah
Arizona
Colorado
New Mexico
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Model Objectives
The specific objectives for the model are to determine the economic and environ-
mental impacts of regional coal mining patterns triggered by changes in national demand
for coal. This includes both interregional and intraregional analyses as defined
above. The absolute level of demand for coal and its development implications for CPAs
will be examined using alternative objectives for each run of the model (fig. 4). Such
alternative objectives are:
1. (a) Examine effects of Federal, State, and local energy-
related policies on the location of coal mining and
the resulting impacts on rural resource use. Such
policies may include Federal and State air pollution
regulations, State taxation policies, and Federal
and State mined land reclamation laws.
(b) Examine effects of Federal and State resource policies
on the location of coal mining and the resulting impacts
on rural resource use. Such policies may include State
water resource regulations or State and Federal mine
siting and leasing regulations.
2. Examine effects of alternative locations of coal pro-
cessing facilities on the location of coal mining.
Figure 4
The Analytical Approach of the Coal Model
Impacts
. -v
Agricultural
>~<
(Environmental)
>-^C
Economic
^-<
Resource
Subregions and
interregional tradeoffs
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3. Examine shifts in regional coal production and re-
source use resulting from changes in consumer demand.
These changes in demand may be the result of coal and
other fuel price changes, consumer preferences, and
industrial production levels.
A Mathematical Programming Approach
One objective of this project is to evaluate the economics, relative efficiencies,
and certain impacts associated with delivering coal energy. The project attempts to
identify and analyze the impacts of coal development on environmental quality, agri-
cultural production potential, and rural communities. A large quantity of data, em-
phasizing total source-to-end-use systems, has been collected on the national coal
supply system. 3/ Various combinations of data representing different components of
the coal supply system are used as input to the computer model so that hypothetical
system economics and efficiencies can be compared. Concerns related to agriculture,
such as effects of reclamation requirements, water costs and availability, and mineral
taxes can also be considered. Technically, the problem is cast as a mathematical pro-
gramming problem; specifically, a simulation model.
Mathematical programming problems determine the optimal or preferred allocation
of limited resources to meet a given objective. More specifically, they deal with
conditions under which a set of resources in limited supply, such as materials, labor,
and machines are to be utilized to produce a number of products. Alternatively,
mathematical formulations can efficiently assess how varied assumptions about the
above factors can affect mining location. Local, State, and Federal policies designed
to regulate the provision of coal energy can be evaluated to assess their impact on
the spatial location of mining and conversion facilities. Mathematical formulation
allows for additional restrictions to be placed on the problem. These additional con-
ditions may be specific or follow broad categories such as the total amount of each
input available or the minimum quantity of each product desired. From all the pos-
sible allocations of scarce resources, mathematical programming allows identification
of those combinations which maximize or minimize a quantifiable function such as cost
or profit.
Linear programming deals with problems in which all relationships between the
variables may be cast as linear functions. Specifically, a number of constraints in
the form of linear inequalities are solved while maximizing or minimizing a linear
combination of these variables. The objective of our problem is to minimize the cost
of meeting coal energy requirements while insuring that certain constraints are satis-
f i ed.
The coal energy systems of the United States are described by a number of vari-
ables, each of which is linked to the others through a set of linear inequalities. An
additional linear function of these variables, the objective function, is then defined
and optimized. For the model described herein, the objective is to minimize the cost
of meeting coal-derived electricity demands. All other equations required to de-
fine the structure of the energy system constitute the linear constraint equations.
The model first simulates the coal supply system for large coal-fired electric gener-
ating plants and then optimizes the objective function for alternative sets of con-
straint equations.
The importance of the linear constraint equations should not be underemphasized.
These equations reflect externalities such as social issues, water policies, net
3/ The data files and the computer programs developed to manage them are described
~
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energy balances, and reclamation. Given the assumptions of certain scenarios, the
constraint equations may be much more important than the objective function.
Each variable or activity in the system is assigned a unit cost. The product of
the activity level and its unit cost is the total cost for that activity. The sum of
total costs for all activities is the objective function to be minimized. The basis
of the constraint equations are mass and energy balances, economic cost, regulatory
restraints, and thermal efficiencies. The linear programming model is demand driven.
Coal -generated electricity demands are met in a manner leading to lowest total cost.
If the specified electrical demands cannot be met, the associated scenario is not
technically feasible.
Model activities deal with the following general areas:
1. Production of coal.
2. Transportation of coal by various transportation modes.
3. Conversion of coal from one form into another including
synthetic liquids, gas, and electric power.
4. Distribution of those energy forms to meet national and
regional energy demands.
Two types of constraints may be present in the model: column constraints and row
constraints. Column constraints are activity bounds that force the level of a partic-
ular activity to be greater than, less than, or equal to a given value. Row con-
straints force the sum of a set of activities to be greater than, less than, or equal
to a defined value. For example, the total amount of coal that can be mined in a
region must be less than or equal to the mining capacity of the region. The row con-
straints in our model may include:
1. Coal reserve rows. These limit the production of coal in a region to be less
than or equal to the reserves of coal in that re.gion.
2. Coal production rows. These limit the production of coal in a region to the
mining capacity of the region.
3. Coal transshipment capacity rows. These insure that the flow of each coal
type between regions is less than or equal to the capacity of the particular
transshipment mode.
4. Coal-fired steam electric power generation rows. These limit the output of
coal-fired power generation plants to the coal-fired generation capacity of
each plant.
5. Sulfur dioxide (SOz) emission rows. These limit the amount of S02 per mil-
lion Btu that may be released in each region.
6. Coal conversion process capacity rows. These limit the conversion of coal
to liquids or gases to the capacity of such facilities.
7. Regional water availability rows. These limit the total quantity of water
consumed by all coal conversion processes in each region to the amount of
water available in each region.
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8. Coal-derived electric energy demand rows. These insure that the quantity of
coal-derived electrical energy available in each region is at least equal to
the demand for coal-derived electrical energy in that region.
9. Nonelectric coal energy demand rows. These insure that the quantity of syn-
thetic coal energy produced satisfies the demand for that energy in each
region.
10. Accounting rows. These are nonconstraining rows that facilitate arithmetic
calculations within the report writing programs and provide summaries of
variables for a quick overview of model results. For the purposes of our
model, these accounting rows may include land, labor, coal production (under-
ground and/or surface-mined), transportation, water, pollutants, health
characteristics, reclamation, ancillary energy use, or net energy balances.
In addition to the above constraint rows, all activities may be bounded.
Western States Model Structure
This section defines each of the detailed equations that form the basis of the
Western States model and places them in the context of the model as a whole. The
notation used below is subject to change as the specific model undergoes continuing
development.
Equation 1 is the objective function and represents the total cost of satisfying
coal-derived energy demands. It is the sum of four components.
Z = C.(PRO), + C (TRANS) + C.(CONV). + C.. (DIST).. (1)
I 1 'J ' J J J J K J K
where: first term cost of mining coal (underground or surface) in CPA i.
second term = cost of transporting coal from CPA i to conversion plant j.
third term = cost of producing energy at plant j.
fourth term - cost of distributing coal-derived energy from conversion
plant j to demand region k.
Constraining equations for the model are described in the following paragraphs.
All the constraint equations described are not operational in the western models des-
cribed later in this report.
Equation 2 limits the total production in CPAi to the coal mining capacity of
that area.
EPR01- <_ MCAP. (2)
Equation 3 limits the total quantity of coal mines in each CPA to the reserves of
coal available in that area. The 1976 to 1984 annual production has been deleted from
the reserves available for the 1985 model. Since we are analyzing 1985 scenarios, we
leed to subtract the coal mines each year to 1985 from the total coal reserves avail-
ible.
2PRO. £ RESit (3)
Equation 4 limits the total quantity of coal shipped via slurry pipeline between
3PA i and a destination plant j to the annual capacity of the slurry pipeline assumed
to exist.
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Z(SLUR). . < (SLCAP).. (4)
Equations 5, 6, and 7 limit the conversion of the coal entering each plant j into
electricity, gas, or oil. Each equation takes into account the efficiencies of the
respective conversion processes. Equation 5 limits the conversion of coal into elec-
tricity to the capacity of generation plant j. Equation 6 does the same for gasifi-
cation of coal and equation 7 for liquefaction of coal. It may be necessary to modify
these three equations to reflect various complements of pollution control equipment.
E(ELEC), l (ELCAP) (5)
J J
I(GAS), <_ (GASCAP). (6)
J J
E(LIQ) <_ (LIQCAP) (7)
J J
Equation 8 places a limit on the amount of sulfur dioxide that may be released
per million Btu of heat input.
£((TRANS)..(S).) £ Z((S02).(ELEC).) (8)
' j i j j
Equation 9 limits the total quantity of water consumed by all conversion plants
to the amount of water available at that plant.
E((CONV).(WTRUSE).) <_ (WATER). (9)
•JO U
The amount of electric energy produced by each plant, plus that imported, less
that exported must at least equal the demand for electric energy in the utility serv-
ice area to which the plant belongs.
E(ELEC).k l (ELECDEM)k (10)
The terms used in the 10 equations listed above are defined below.
T - the objective function to be minimized.
C.= the cost of mining coal in CPA i.
(PRO). = production level of coal in CPA i in thousands of tons.
C.. = cost of transporting coal from CPA i to conversion plant j.
(TRANS)-. = amount of coal transported from CPA i to conversion plant j.
C. = cost of producing a unit of output at conversion plant j.
J
(CONV). = output of conversion plant j (includes (ELEC)., (GAS)., and (LIQ).).
J J J J
C.. = distribution cost of energy from conversion plant j to demand region k.
J K
(MCAP). = mining capacity in CPA i.
(RES).. = reserves of coal available in CPA i in time frame t.
(SLUR).. = coal slurry transportation line from CPA i to conversion plant j.
(SLCAP)-• = annual transporting capacity of slurry pipeline ij.
(ELEC). = output of electrical generation plant j.
J
10
-------
(ELCAP). = annual output capacity of electrical generation plant j.
J
(GAS). = output of coal gasification plant j.
J
(GASCAP). = annual output capacity of coal gasification plant j.
J
(LIQ) • = output of coal liquefaction plant j.
J
(LIQCAP). = annual output capacity of coal liquefaction plant j.
J
(S). = sulfur content of coal from CPA i.
($02). = sulfur dioxide regulation in effect at conversion plant j.
J
(WTRUSE). water use rate at conversion plant j.
J
(WATER). = amount of water available at conversion plant j.
J
(ELECDEMV = demand for electricity in utility service area k.
Model Limitations
Model limitations derive specifically from at least three sources: input data,
systems structure, and appropriateness of the modeling methodology used. Specific
problems arising from available data can be divided into two major parts: (1) the un-
certain nature of some of the data, particularly that dealing with new energy systems
not yet commercially available, and (2) the problems of projecting historic data, how-
ever good, to future years. An important aspect of projecting cost data is the choice
of appropriate rates of escalation.
Problems with data in this simulation model application, as in all simulation
model applications, were many and varied. Specific selling prices for coal in each
CPA were not known, making it necessary to compute weighted averages or prices using
known or assumed prices for each mine. Specific costs, modes, and routes of trans-
portation were also unknown. Many shipments go entirely by rail while other ship-
ments use a combination of rail and barge routes. Neither the input-output ratios nor
the costs of generation were available for specific power plants in 1975. This made
the task of projecting input-output ratios and electrical generating costs to 1985
more difficult. Coal prices (FOB mine) and transportation costs were projected to
1985 using a simple 6-percent annual escalation rate. A more complete discussion of
these problems and assumptions follows in later sections.
There are several model structure limitations. These include the capability of
electric utilities to switch from gas and oil to coal use, assumptions concerning
intraregional electrical transmission costs and efficiencies, the blending of coal
types, and the mixing of transportation modes to supply coal to end users. Assump-
tions were made concerning the amount of coal used by each electrical generating
plant, ignoring the ability of these plants to switch back and forth between oil and
coal depending on competitive price structures. Intraregional electrical transmission
costs and efficiencies were ignored, assuming instead that the cost and efficiencies
of transmission were reflected in the operating costs of the plants. The blending of
coal types, given minimum attention in the development of this model, will be treated
more adequately in the national interregional model. The regulation of sulfur dioxide
emission levels may encourage coal blending activities to develop. Mixing of trans-
portation modes to supply coal to generation plants has also been ignored in this
model. Plans for the national model call for specific treatment of alternative modes
of transportation and their costs.
11
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The most important advantage of the mathematical programming structure is that it
allows the user to formulate rational economic choices based on the best available
technical and cost information. The methodology also has at least two important con-
ceptual drawbacks. The first is the simplifying assumption that all relationships be-
tween variables are linear. The second is that a linear programming model is never a
strictly accurate representation of the economic system with which it deals. It is
merely a method of conceptualization that allows the analyst to formalize the basic
strategic relationships controlling the described phenomenon and permitting manipu-
lation of the situation. The linearity assumption is particularly limiting in the
pricing of the various products or services essential to the coal supply and utili-
zation trajectory. The unit cost of any commodity varies with the quantity of that
commodity provided. It is possible to reflect this economic fact in a linear pro-
gramming model; this has not been done in the development of this model.
We minimized the representation problem in this simulation model by including
information for individual generating plants. We have attempted to look at data for
each mine in each coal producing area and at the specific power plants which those
mines supply. It has been necessary to aggregate the mines in each CPA to reflect
conditions for that CPA. (See footnote, p. 2). However, aggregation has not occurred
at the power plant level. We have also looked at the individual transportation links
which connect a mine with an individual power plant. Therefore, the aggregation prob-
lem should not be serious in the transportation or generation portions of this model.
Perhaps the area of greatest potential misrepresentation of the operating eco-
nomic system is demand. To formulate a demand for coal-derived electrical generation,
it was necessary to determine the total demand for electricity and then separate out
that portion of total electrical demand derived from coal. This involved certain
simplifying assumptions concerning utilization of coal and noncoal-fired electrical
generation plants. If certain of these assumptions prove to be inconsistent, it will
be possible to develop alternative scenarios modifying these assumptions. To address
the demand problem more satisfactorily, the ICAM can probably be linked to a very de-
tailed Utility Simulation Model (USM), which represents the national electric utility
industry and which has been developed as part of an EPA-funded study (15).
The development of operational policies or regulations using results of simu-
lation analyses should be done carefully. The linear relationships present within
linear programming models may cause dramatic shifts between regional activity levels.
This occurs because linear programming algorithms set up ratios between coefficients.
These ratios are constantly compared and if, as demand is met, their relative magni-
tudes switch, it may cause dramatic shifts in the levels of activities. This problem
can be clarified by performing sensitivity analyses. Sensitivity analysis enables the
analyst to define shift points and to temper the description of impacts to prevent
unwarranted reliance on shifts caused by linearity assumptions.
The user of simulation models results should also be aware of the inaccuracy of
specific numbers presented as output. Studies using simulation models should make
base analyses reflecting most probable situations. These base results should not be
interpreted as absolute levels expected to exist. Base results should be interpreted
to reflect a situation similar to one which may exist in the scenario year. Then the
results of alternative scenarios should be compared with the base results in a rela-
tive manner. (The results should be interpreted as an increase or a decrease of an
approximate magnitude rather than in absolute terms). For example, when we develop a
1985 base scenario, the level of coal mining in a CPA should be interpreted as the
level which may exist in 1985. The level of mining which will actually exist in 1985
may be lesser or greater than the level predicted using the model. The policymaker
should not assume that the absolute level projected by the model will actually exist.
12
-------
An acceptable way of presenting results of simulation model analyses is to show rela-
tive changes from a base line rather than absolute levels of activity which the model
has predicted will occur under alternative scenario assumptions.
The linearity assumption is particularly troublesome with respect to coal supply
pricing. The national coal model developed by the Department of Energy uses nonlinear
coal pricing parameters. This approach is preferred to our linear approach.
DATA FOR THE 1975 WESTERN STATES MODEL
This section describes the development of the data used in the 1975 Western
States model. 4/ Since this model is being designed to measure the impact of coal de-
velopment in the United States, and since the major market for coal is the electric-
ity utility industry, a reasonable beginning point for assessing the demand for coal
is to inventory all electric utility power plants which burn coal to generate elec-
tricity. There were 413 power plants in the United States which burned coal to gener-
ate some or all of their electricity in 1975 (table 1). The plants which burn coal to
generate electricity contributed 38 percent of the total generation capacity in the
United States. Because of the difficulty in obtaining information for individual
power plants, it seemed appropriate to investigate only a subset of the coal-fired
electrical generating plants. Therefore, the megawatt capacity of each coal-fired
power plant was examined and several cutoff levels analyzed. It was ultimately de-
cided to model only those coal-fired power plants with a nameplate generating capa-
city 5_/ of 100 megawatts or greater. This eliminates only 2 percent of the total
coal-fired nameplate generating capacity in the United States (table 1 and fig. 5).
Figure 5
U.S. Power Plant Statistics, 1975
529,000 MW (Megawatt)
capacity
2,709 Total
number
201,000 MW
38%
Small power
plants
-30%
413 12%
Of those coal-fired, most are large, 100 MW or over in size
291 plants of 100 MW or over account for 98% of coal-fired capacity
I/The Western States model will undergo continuing development.
5/ Nameplate capacity is the generation capacity which each power plant is designed
and built to produce. Operating conditions may prevent a plant from producing at
nameplate capacity.
13
-------
Table 1--U.S. power plant statistics, 1975 I/
Item
Power plants
Total capacity
Power plants using coal
Capacity of power plants using coal
Percentage of MW capacity from coal-fired
plants
Percentage of power plants using coal
Coal-fired power plants £ 100 MW
Capacity of power plants <_ 100 MW
Percentage of MW capacity from coal -fired
plants 1 100 MW
Percentage of coal -fired power plants
1 100 MW
Unit
No.
MW
No.
MW
Pet.
Pet.
No.
MW
Pet.
Pet.
Statistic
2,/09
528,647
413
201,383
38
15
103
4,010
1.99
25
I/ Includes 50 States and Puerto Rico.
Source: (16)
Nevertheless, the possibility of developing information on both smaller utility boil-
ers and coal utilization in industrial boilers is being considered in cooperation with
other related studies in EPA's Energy/Environment research and development program.
Smaller plants are usually older, less efficient plants which are likely to be retired
when larger, more efficient plants are built. The recent trend in new generating
capacity has been towards larger plants.
App. table 1 lists all the coal-fired plants included in the 1975 national ICAM
and describes each plant's ownership. There are 291 power plants greater than or
equal to 100 megawatts in nameplate generating capacity. This list includes all
plants supplied by western coal as well as all other coal-fired power plants in the
Nation. The percentage ownership shown is important in allocating the output of each
plant. The demand analysis will describe a demand for each utility service area. The
output of each plant going to meet demand in each utility service area will be defined
by the percentage ownership of that utility system in each plant.
App. table 2 lists all the power plants receiving coal from the Western States.
It identifies and codes each transportation link to each power plant, including the
CPA from which the coal was supplied and the amount of the shipment. From app. table
2, we can identify those CPAs which mined coal for use by each power plant. We can
also identify all power plants receiving western coal and then proceed to develop the
transportation links necessary for the analytical model. Therefore, we have three
vital pieces of information for the interregional linear programming model: (1) the
CPA which supplies the coal, (2) a transportation link from the CPA to the individual
power plant, and (3) the individual power plant identification. For example, we can
code the coal producing area (MNGSAZ01), the transportation link (AZ019014), and the
power plant (CEG 9014). In addition, app. table 2 provides the proportion of each
plant's input supplied by each transportation link. This number is in the form of a
coal input to electricity output ratio (million Btu/million kWh). Only Western States
coal sources are defined in detail (by CPA); the Interior, Appalachian, and Gulf major
coal producing region sources will be broken into individual CPAs as the model is ex-
panded to include those regions.
The first part of this section described how the number of power plants was re-
duced to a more manageable number and how the background information for these power
14
-------
plants and their western coal sources was developed. The tables described below will
list the exact coefficients entered into the simulation model.
The first portions of table 2 describe the model coefficients for the western
region strip and underground mining activities. The code for each CPA supplying util-
ity steam coal in 1975 is listed. As the model is expanded to include future sce-
narios, coefficients will be developed for vacant matrix intersections. Coefficients
describing coal tonnage-to-Btu conversion values were obtained from the Northern Great
Plains and Rocky Mountain regional reports (]_,2^,2S). Strip mining in the Western
States recovers approximately 90 percent of the coal in mined seams. Therefore, the
coefficient describing depletion from reserves becomes 1.1111 for all strip mining
activities. Moreover, underground mining in the Western States recovers approximately
50 percent of the coal. Therefore, the coefficient describing depletion of resources
for underground mining becomes 2.000 for all underground mining activities. Produc-
tion is described in both thousands of tons and in millions of Btu. The coefficient
describing the entry into the mining transportation transfer accounting row is de-
scribed in Btu because costs for transporting coal are expressed in dollars per mil-
lion Btu. Therefore, as can be seen from table 2, the conversion from thousands of
tons of production to millions of Btu of production is accomplished in the mining ac-
tivities.
Table 2 also describes the coefficients for the western region transportation ac-
tivities. Each transportation activity carries coal, expressed in Btu, from the CPA
to the power plant. Therefore, each transportation activity has a cost, an input from
the mining transfer row, an output to the power plant transfer row, and a coefficient
to account for the capacity of the movement. The conversion from tons to Btu of pro-
duction is accomplished in the mining activities. Therefore, the basic function of
these transportation activities is to transport 1 million Btu of coal at a cost. The
movement volume of the transportation activity is accumulated to accommodate future
scenarios which may impose capacity limitations on specific transportation links. The
transfer of coal through these transportation activities is assumed to be 99 percent
efficient. Therefore, the input coefficient in the mining transfer row is 1.00 while
the output coefficient in the power plant transfer row is 0.99. Transportation costs
for certain mine mouth power plants are zero; but, in some instances, these zero coef-
ficients have been modified to prevent cycling during problem solution.
Table 2 also describes the model coefficients for electrical generation plants
supplied by western coal. Each generation activity receives coal from each of its CPA
suppliers and converts those Btu of coal input to kilowatt hours of electricity out- ,
put. This is accomplished at a cost expressed in dollars per million kilowatt hours
of electrical production. The amount of electricity produced is accumulated and the
generation capacity of the electrical plant is constrained.
There is a major weakness in the model because it uses coal-fired generating
plants to meet both base- and intermediate-load electricity demand. The electrical
demand requirement which drives the simulation model does not accurately reflect the
base demand alone. That is, total electrical demand has not yet been reduced to re-
flect only the base-load portion intended to be met by coal-fired power plants. This
will be done by analyzing the utilization factors for coal-fired power plants. Gener-
ation capacity and utilization factors will determine the estimated base demand load
each plant is managed to meet. Output capacity for each power plant will be modified
depending upon the age of the power plant and the change in the utilization factor.
Table 2 also describes the model coefficients for the simulation model right-hand
side. Coefficients are shown only for those rows which have nonzero entries. Another
approach would employ the previously mentioned Utility Simulation Model (USM) to pro-
vide a greater level of detail for demand analysis.
15
-------
Table 2--Coefficients for 1975 western region ICAM I/
Activity
Strip mining:
MNGSMT01
MNGSMT02
MNGSMT03
MNGSMT04
MNGSMT05
MNGSND01
MNGSND02
MNGSND03
MNGSWY01
MNGSWY02
MNGSWY03
MNGSWY04
MNGSAZ01
MNGSNM01
MNGSNM02
MNGSC001
MNGSC002
MNGSC004
MNGSUT01
MNGSUT02
Underground m
MNGUNM01
MNGUNM02
MNGUNM03
MNGUNM04
MNGUC001
MNGUC002
MNGUC003
MNGUC004
MNGUC005
MNGUC006
MNGUC007
MNGUUT01
MNGUUT02
MNGUUT03
Transportatio
MT043001
MT043007
MT043014
MT043029
MT043086
MT045003
HT045004
MT045007
MT045011
MT045013
Cost :
Dols. per
1,000 tons
2/
2/
I/
5,510.26
2/
645.92
2,753.58
1,609.30
8,835.75
3,265.36
5,858.26
4,420.08
3,085.21
5,000.19
6,248.49
9,870.50
2/
2/
2/
I/
ning:
2/
2/
2/
I/
9,871.50
I/
2/
2/
2/
2/
8,411.43
11,801.20
2/
I/
n:Dols. per
mil. Btu
0.9241
0.8108
1.1463
0.5453
1.3466
0.6971
0.4793
0.4188
0.5454
0.4628
PROxxxxB
and
MNTRxxxx
Mil. Btu
CAPxxxxx : PTRxxxxx : Unit and Coefficient
: constraint
per
1,000 tons
17,200
13,100
12,600
12,300
19,300
16,200
19,300
22,700
20,700
23,100
22,300
23,100
23,100
18,000
25,200
1,000 tons
per mil . Btu
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
See footnotes at end of table.
Continued
16
-------
Table 2--Coefficients for 1975 western region ICAM--Continued
Activity
MT045014
MT045016
riT045017
MT045018
MT045022
MT045024
MT045025
MT045035
MT046002
MT046005
MT046007
HT046008
MT046010
MT046011
HT046012
MT046013
MT046016
MT046022
MT046023
MT046024
MT046028
MT046031
MT049020
ND026014
ND026003
ND026023
ND026025
ND036032
ND036009
WY016024
WY023002
WY023015
WY023027
WY023056
WY025009
WY025012
WY026019
WY026021
WY026022
C0013100
C0016015
UT016015
C001 6024
UT016001
C001 7014
UT017014
C001 6029
UT016017
AZ019003
Cost
0.6674
0.6664
0.2210
0.5146
0.4662
0.5789
0.5584
0.3935
0.3046
0.2473
0.2250
0.3271
0.3221
0.3375
0.3258
3/0.0000
0.4229
0.2767
0.1911
0.2484
0.4785
1.0349
0.0908
0.1073
0.0464
0.0434
0.3544
0.1562
0.2317
0.6723
0.7238
0.5637
0.6539
1.0172
0.4623
0.6664
0.6244
0.5495
0.4299
0.3854
0.2855
0.4474
0.6954
0.7010
0.2000
0.6680
0.4516
0.1655
0.0242
PROxxxxB : :
and CAPxxxxx PTRxxxxx: Unit and : Coefficient
MNTRxxxx : constraint :
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00008
0.00008
0.00008
0.00008
0.00008
0.00008
0.00005
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00006
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00005
See footnotes at end of table
Continued
17
-------
Table 2--Coefficients for 1975 western region ICAM--Continued
Activity
NM019001
NM019012
C0011007
C0011006
UT013020
UT013002
UT019018
UT019015
UT019010
Generation:
CEG 3001
MT04
APR
CEG 3002
WY02
UT01
INT
APR
CEG 3007
MT04
INT
APR
CEG 3014
MT04
APR
CEG 3015
WY02
INT
CEG 3027
WY02
INT
CEG 3029
MT04
WY03
INT
CEG 3050
WY03
INT
Cost :
3/0.0003
0.0529
1.2617
1.2618
1.4251
1.2930
0.0504
0.3059
1/0.0004
Dols. per
mil. kWh
826.99
435.00
752.99
847.99
932.99
614.99
2,246.99
1,197.99
PROxxxxB : : : :
and : CAPxxxxx : PTRxxxxx : Unit and : Coefficient
MNTRxxxx : : constraint :
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
0.00004
Mil . Btu per
mil. kWh
- 9,706.60
- 251.40
- 9,455.20
- 9,462.46
- 1,632.27
- 591.40
70.02
- 7,168.76
-10,263.30
- 338.69
- 9,202.10
722.54
- 9,827.34
- 2,911.84
- 6,915.50
- 9,084.39
- 498.73
- 8,585.65
- 9,802.99
37.25
- 9,765.74
-11,248.10
- 4,266.40
- 4,705.10
- 2,276.61
-10,167.90
- 9,937.06
- 230.81
See footnotes at end of table.
Continued
18
-------
Table 2--Coefficients for 1975 western region ICAM—Continued
Activity
CEG 3056
WY02
INT
CEG 3086
MT04
APR
CEG 5001
WY03
INT
CEG 5002
WY03
INT
CEG 5003
MT04
INT
CEG 5004
MT04
INT
CEG 5005
WY03
INT
APR
CEG 5007
MT04
INT
CEG 5009
WY02
INT
CEG 5011
MT04
WY03
INT
CEG 5012
WY02
INT
CEG 5013
MT04
INT
: PROxxxxB : :
Cost : and : CAPxxxxx PTRxxxxx Unit and : Coefficient
: MNTRxxxx : constraint :
1,896.99 - 9,572.35
- 278.56
- 9,293.80
3,105.99 -12,556.90
92.90
-12,464.00
1,091.99 - 9,942.65
- 123.00
- 9,769.65
498.00 - 9,353.60
182.40
- 9,171.20
1,239.99 -10,845.00
- 8,627.18
- 2,217.80
1,038.99 -10.545.10
- 794.05
- 9,751.06
2,034.99 - 9,966.57
- 2,364.10
- 7,404.17
198.34
1,706.99 -10,491.70
- 9,807.66
- 684.06
1,335.99 -10,250.10
26.65
-10,223.50
1,674.99 -10.667.90
- 678.48
- 8,458.56
- 1,530.84
1,759.99 -10,685.10
38.47
-10,646.60
699.99 - 9,667.92
- 3,188.48
- 6,479.44
See footnotes at end of table.
Continued
19
-------
Table 2--Coefficients for 1975 western region ICAM--Continued
Activity
CEG 5014
MT04
CEG 5016
MT04
CEG 5017
MT04
CEG 5018
MT04
WY03
com
UT01
INT
APP
CEG 5022
MT04
INT
APP
CEG 5024
MT04
INT
APP
CEG 5025
MT04
INT
CEG 5028
WY03
INT
APP
CEG 5035
MT04
INT
CEG 5036
WY03
UT01
INT
CEG 6001
WY03
UT01
GIF
PROxxxxB : : :
Cost : and CAPxxxxx : PTRxxxxx : Unit and : Coefficient
: MNTRxxxx : constraint :
1,812.99 -10,735.00
-10,735.00
4,907.99 -11,494.20
-11,494.20
799.99 -10,215.20
-10,215.20
1,833.99 -10,550.00
- 322.83
- 143.48
- 101.28
99.17
- 9,460.17
- 423.05
1,706.99 -11,676.20
- 1,387.13
- 5,561.36
- 4,727.68
1,006.99 -10,034.50
- 251.87
- 9,607.08
175.60
3,857.99 -11,589.20
- 6,909.51
- 4,679.74
6,666.99 -14,980.10
- 9,340.08
- 396.97
- 5,243.03
1,494.99 -11,287.10
- 290.08
-10,997.10
5,999.99 -12,293.60
- 1,852.64
540.92
- 9,900.00
688.99 - 9,809.08
- 9,743.36
34.33
31.39
See footnotes at end of table.
Continued
20
-------
Table 2--Coefficients for 1975 western region ICAM--Continued
Activity
CEG 6003
ND02
CEG 6004
WY03
CEG 6005
MT04
INT
CEG 6006
WY03
CEG 6007
MT04
CEG 6008
MT04
INT
CEG 6009
ND03
CEG 6010
MT04
INT
CEG 6011
MT04
CEG 6012
MT04
WY03
INT
APP
CEG 6013
MT04
CEG 6014
ND01
CEG 6016
MT04
INT
PROxxxxB : : :
Cost and : CAPxxxxx : PTRxxxxx Unit and : Coefficient
MNTRxxxx : : constraint :
1,017.99 -11,289.90
-11,289.90
932.99 -10,385.40
-10,385.40
911.99 - 9,738.33
- 3,030.57
- 6,707.76
688.99 -11,298.20
-11,298.20
1,176.99 -10,168.70
-10,168.70
1,335.99 -11,433.60
- 7,757.69
- 3,675.90
799.99 -11,711.10
-11,711.10
2,660.99 -11,512.60
- 9,809.88
- 1,702.71
1,907.99 -11,185.40
-11,185.40
1,441.99 - 9,490.71
- 1,228.10
- 1,634.30
- 6,594.14
34.17
799.99 -12,142.10
-12,142.10
667.99 -10,991.80
-10,991.80
1,144.99 -11,313.90
- 2,568.26
- 8,745.65
See footnotes at end of table.
Continued
21
-------
Table 2--Coefficients for 1975 western region ICAM--Continued
Activity
CEG 6017
WY03
UT01
GLF
CEG 6019
WY02
INT
CEG 6020
WY03
INT
CEG 6021
WY02
INT
CEG 6022
MT04
WY02
INT
APR
CEG 6023
MT04
ND02
CEG 6024
MT04
UY01
C001
INT
GLF
CEG 6025
ND02
CEG 6026
WY03
CEG 6028
MT04
CEG 6029
WY03
WY04
C001
PROxxxxB : : :
Cost and : CAPxxxxx : PTRxxxxx : Unit and Coefficient
MNTRxxxx : : constraint
1,356.99 -10,146.90
- 5,915.62
80.16
- 4,151.08
741.99 -10,504.60
- 302.53
-10,202.10
1,769.99 -12,772.70
- 430.44
-12,342.50
2,140.99 -13,394.60
- 4,138.92
- 9,255.65
1,557.99 -11,630.60
- 1,926.03
- 1,821.36
- 7,762.28
- 120.96
1,472.99 -11,764.40
- 2,661.12
- 9,103.33
911.99 -11,572.90
- 291.64
- 933.93
- 1,844.72
- 2,871.23
- 5,631.36
1,239.99 -11,985.90
-11,985.90
1,441.99 -11,140.20
-11,140.20
2,607.99 -13,202.50
-13,202.50
1,886.99 -12,639.90
- 4,573.11
- 965.69
- 7,101.09
See footnotes at end of table.
Continued
22
-------
Table 2—Coefficients for 1975 western region ICAM--Continued
Activity
CEG 6030
WY03
GLF
CEG 6031
MT04
CEG 6032
ND02
CEG 7001
WY03
GLF
CEG 7003
WY03
CEG 7004
WY03
GLF
CEG 7006
WY03
CEG 7013
WY03
GLF
CEG 7014
WY03
C001
UT01
GLF
CEG 9005
WY04
CEG 9006
WY02
C001
CEG 9007
WY03
CEG 9008
WY04
CEG 9011
WY02
: PROxxxxB
Cost : and
: MNTRxxxx
1,886.99
1,801.99
1,123.99
1,600.99
858.99
1,271.99
2,479.99
5,999.99
5,999.99
836.99
921.99
1,907.99
656.99
1,038.99
CAPxxxxx PTRxxxxx Unit and Coefficient
constraint
-12,630.10
- 5,364.02
- 7,266.12
-11,527.30
-11,527.30
-13,490.40
-13,490.40
-10,703.30
- 8,363.54
- 2,339.74
-10,621.80
-10,621.80
-11,301.40
63.29
-11,238.10
-12,500.40
-12,500.40
-18,219.90
- 368.04
-17,851.90
-12,486.90
- 4,487.80
- 315.92
103.64
- 7,579.55
-10,713.50
-10.713.50
-10,909.90
- 1,167.36
- 9,742.51
-10,412.00
-10,412.00
-10,479.40
-10,479.40
-10,807.20
-10,807.20
Continued
23
-------
Table 2—Coefficients for 1975 western region ICAM--Continued
Activity
CE6 9016
WY03
C001
C007
CEG 9019
WY03
C007
CEG 9020
MT04
CEG 9014
AZ01
NM02
UT01
CEG 9002
AZ01
NM01
UT01
CEG 9013
C001
CEG 9009
C001
CEG 3023
UT01
INT
APR
CEG 3100
C001
INT
APR
CEG 6015
C001
UT01
INT
GIF
CEG 9017
UT01
CEG 9003
AZ01
PROxxxxB : : :
Cost and : CAPxxxxx : PTRxxxxx : Unit and Coefficient
MNTRxxxx : : :constraint
1,345.99 -12,977.00
- 4,413.47
- 6,040.79
- 2,522.73
995.99 -11,647.40
-10,089.00
- 1,558.42
646.99 -10,033.00
-10,033.00
1,345.99 -10,138.70
- 362.96
- 9,136.98
- 638.74
964.99 -10,167.80
- 9,128.69
- 645.66
- 393.50
1,999.99 -10,990.80
-10,990.80
1,430.99 -10,607.80
-10,607.80
1 ,525.99 - 9,724.28
- 585.40
- 8,743.10
- 395.78
6,115.99 -12,968.40
85.59
- 1,267.92
- 203.60
1,759.99 -10,729.70
- 2,192.08
- 136.27
- 7,239.35
- 1,162.03
1,419.99 -11,000.40
-11,000.40
2,840.99 -11,293.00
-11,293.00
See footnotes at end of table.
Continued
24
-------
Table 2--Coefficients for 1975 western region ICAM—Continued
Activity
CEG 9001
NH01
CEG 9012
NM01
CEG 1007
C001
APR
CEG 1006
C001
APP
CEG 3020
UT01
APP
CEG 9018
UT01
CEG 9015
UT01
CEG 9010
UT01
Right hand
NRESMT01
NRESMT02
NRESMT03
NRESMT04
NRESMT05
NRESND01
NRESND02
NRESND03
NRESWY01
NRESWY02
NRESWY03
NRESWY04
NRESAZ01
NRESNM01
NRESNM02
NRESNM03
NRESNM04
NRESC001
NRESC002
PROxxxxB :
Cost and CAPxxxxx : PTRxxxxx
MNTRxxxx :
1,801.99 -10,329.50
-10,329.50
2,013.99 -10,201.20
-10,201.20
3,999.99 -11,175.10
- 226.85
-10,948.20
2,437.99 -10,716.90
19.30
-10,700.30
1,112.99 - 9,646.12
- 105.14
- 9,540.98
1,907.99 -11,020.20
-11,020.20
2,002.99 -12,473.90
-12,473.90
1,557.99 -10,192.80
-10,192.80
;ide (RHS001):
: Unit and
rconstraint
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
Coefficient
.48400+06
.35590+07
.13660+07
.18395+08
.42594+08
.38820+07
.64690+07
.56440+07
.92000+05
.20606+08
.10290+07
.21160+07
.35000+06
.25452+07
.41520+06
.13810+07
.27500+05
.66675+07
.95050+06
See footnotes at end of table.
Continued
25
-------
Table 2—Coefficients for 1975 western region I CAM—Continued
Activity
NRESC003
NRESC004
NRESC005
NRESC006
NRESC007
NRESUT01
NRESUT02
NRESUT03
MCAPMT01
MCAPHT02
MCAPMT03
MCAPMT04
MCAPMT05
MCAPND01
MCAPND02
MCAPND03
MCAPWY01
MCAPWY02
MCAPWY03
MCAPWY04
MCAPAZ01
MCAPNM01
MCAPNM02
MCAPNM03
MCAPNM04
MCAPC001
MCAPC002
MCAPC003
MCAPC004
MCAPC005
MCAPC006
MCAPC007
MCAPUT01
MCAPUT02
MCAPUT03
CAP 9016
CAP 9006
CAP 9011
CAP 9019
CAP 5013
CAP 5025
CAP 5016
CAP 5014
CAP 5036
CAP 5003
CAP 5004
CAP 5011
: PROxxxxB : :
Cost : and : CAPxxxxx PTRxxxxx Unit and : C
: MNTRxxxx : constraint :
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
1,000 tons-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
oefficient
.20660+06
.41005+07
.43330+06
.11103+07
.13679+07
.10064+07
.29905+07
.40300+05
.00000+00
.33000+03
.00000+00
.22000+05
.10000+01
.15250+04
.61410+04
.16120+04
.10230+04
.40510+04
.14000+05
.41910+04
.72250+04
.73180+04
.46800+03
.10160+04
. 00000+00
.44720+04
.00000+00
.00000+00
.21940+04
.00000+00
.63200+03
.17300+03
.93730+04
.00000+00
.00000+00
.10329+04
.41201+04
.18880+04
.32101+03
.33506+04
.73428+03
.21648+04
.23772+04
.33558+03
.53348+04
.55654+04
.33282+04
See footnotes at end of table.
Continued
26
-------
Table 2--Coefficients for 1975 western region ICAM--Continued
Activity
CAP 5007
CAP 5009
CAP 5018
CAP 5002
CAP 5028
CAP 3029
CAP 5017
CAP 5022
CAP 5035
CAP 9005
CAP 9007
CAP 9008
CAP 3056
CAP 3015
CAP 3050
CAP 3027
CAP 6016
CAP 6024
CAP 9001
CAP 9012
CAP 1007
CAP 1006
CAP 3020
CAP 9018
CAP 9015
CAP 9010
CAP 9003
CAP 9017
CAP 6015
CAP 3100
CAP 3023
CAP 9009
CAP 9013
CAP 9002
CAP 9014
CAP 5024
CAP 5005
CAP 6012
CAP 6022
CAP 6009
CAP 3002
CAP 6023
CAP 6032
CAP 6014
CAP 6003
CAP 6004
CAP 6017
CAP 6029
: PROxxxxB
Cost : and CAPxxxxx PTRxxxxx Unit and
: MNTRxxxx constraint
mil. kWh-L
mil. kWh-L
mil . kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
mil. kWh-L
Coefficient
.47987+04
.69070+04
.21119+04
.86080+04
.54430+03
.38632+04
.17186+04
.15196+04
.46195+03
.24861+04
.43636+04
.34021+04
.19970+04
.98700+04
.26221+04
. 54869+04
.10158+04
.27343+03
.10379+05
.24361+04
.40489+03
.11812+04
.49620+04
.91008+03
.78321+03
.25233+04
.75967+04
.11924+04
.49317+03
.38272+03
.47588+04
.12948+04
.81283+03
.80354+04
.79978+03
.14327+04
.64186+04
.16510+04
.86600+03
.14478+04
.12225+05
.84944+03
.44370+03
.17449+04
.16110+04
.16330+04
.42448+03
.33363+03
See footnotes at end of table
Continued
27
-------
Table 2—Coefficients for 1975 western region ICAM—Continued
Activity
CAP 9020
CAP 6013
CAP 5001
CAP 5012
CAP 7004
CAP 7001
CAP 7013
CAP 7014
CAP 6025
CAP 6011
CAP 6005
CAP 6010
CAP 6008
CAP 6007
CAP 6028
CAP 6031
CAP 3001
CAP 3014
CAP 3086
CAP 3007
CAP 7006
CAP 7003
CAP 6019
CAP 6021
CAP 6026
CAP 6006
CAP 6030
CAP 6001
CAP 6020
: PROxxxxB : : :
Cost : and : CAPxxxxx : PTRxxxxx : Unit and :
: MNTRxxxx : : :constraint :
mil .
mil .
mil .
mil .
mil .
mil .
mil .
mi 1 .
mil .
mil .
mil .
mil .
mil .
mil .
mi 1 .
mil .
mil .
mil .
mil .
mil .
mi 1 .
mil .
mil .
mi 1 .
mil .
mil .
mil .
mil .
mil .
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
kWh-L
Coefficient
.99683+03
.27877+03
.12673+05
.41038+04
.26629+04
.25015+04
.15483+03
.23747+03
.79600+03
.14916+04
.30040+04
.12469+04
. 1 5444+04
.29610+04
.46400+03
.15072+02
.15503+05
.68707+04
.78963+03
.92220+04
.52475+03
.10575+04
.95604+03
.50398+03
.59063+03
.24174+03
.78312+02
.18275+04
.72248+03
J7 The following abbreviations are used in this table: PROxxxxB-coal production
by CPA in Btu per 1,000 tons; MNTRxxxx-mining transfer for each CPA; CAPxxxxx-mining
capacity in each CPA; PTRxxxxx-transfer for each power plant; MNGS-strip mining;
MNGU-underground mining
MT-Montana
ND-North Dakota
WY-Wyoming
AZ-Arizona
MNGSMT01 strip mining in CPA Montana 01
CEG 3001 electric generating plant 3001
INT-Interior region (Midwest)
APP-Appalachian region
2J There are no cost or Btu coefficients for these activities because
there was no utility steam coal production from these CPAs during 1975.
_3_/ These transportation activities have 0.0000 coefficients because the
associated electrical generation plant is a mine-mouth plant and the transpor-
tation charges are included in the cost of mining or the generation cost.
NM-New Mexico
UT-Utah
CO-Colorado
GIF-Gulf region
NRES-coal reserves
MCAP-mining capacity
L-lower limit
Source: Computer printouts prepared as part of this research.
28
-------
THE 1985 WESTERN STATES MODEL
The development of 1975 historical information for coal-fired power plants rated
at 100 megawatts and greater provided a clear picture of the coal-fired electrical
generation capacity supplied by western mines. The transportation links were also ac-
curately described. Once we had a clear picture of the 1975 demand-supply situation,
we could begin to think about how that situation would change in 1985, our initial
scenario year.
The analysis of the coal demand-supply trajectory in 1985 involves several sub-
analyses. We first must examine the coal supply (mining) situation and then the
electrical generation situation. To tie the demand and supply portions together, we
must develop the transportation links. Also involved in the assessment of the mining
situation is a determination of the requirements and costs of reclamation and taxa-
tion. The transportation links must deal with rail capacity and with additions to
capacity. They must also describe alternative modes of transportation such as coal
slurry pipelines. The electrical generation picture must include expansions of
existing capacity and plants built after 1975. In addition, the potential exists for
development of synthetic fuel plants using coal as a base stock. Therefore, this
section is divided into subsections describing coal supply, coal transportation, and
electrical generation. In addition, we discuss the demand for electricity and the
scenario input coefficients to the simulation model.
Coal Supply
The most important information describing the 1985 coal supply situation is a
summarization of additions to coal mining capacity (app. table 3). Additions to coal
mining capacity are described for the entire Nation. (Additions to western coal
mining capacity have not been separately summarized). The situation described in app.
table 3 constantly changes. Also, we are probably not aware of all the additions
planned. We constantly acquire information to keep app. table 3 current and accurate.
The table is organized by year, beginning with 1976 and extending beyond 1985. To de-
velop coal mining capacity for 1985, we use only those reported additions planned for
operation before the end of 1984. The company and mine location is listed with mine
type, capacity, seam thickness, and the source of the information. We have not in-
cluded mines being developed for the metallurgical coal market. If a mine is being
developed for both steam and metallurgical markets, we assign the entire output to the
steam market since we have no way of determining the portion of the output going into
each market.
A similar table (app. table 5) has been developed describing additions to coal-
fired electrical generation capacity. This table will be described in detail in the
electrical generation plant section. However, we have used this table to determine
the demand for coal from western CPAs between 1976 and 1984. We staged the additions
to electrical generation capacity and determined their coal use for each year. Then
we subtracted the 1976 to 1984 coal requirements from the coal reserves remaining in
each CPA at the end of 1975 (table 3). This process yields an estimate of the amount
of coal reserves available in each CPA for the 1985 model. The 1985 rate of use is
listed in table 3 and divided into the reserves available at the end of 1984 to deter-
mine the number of years of reserves remaining, assuming the 1985 rate of use. WY01
has the least number of years of reserves remaining with 17. NM03 has the greatest
with 2,760. The amount of economical reserves present in each CPA is highly uncertain
and constantly changing as exploration continues. In addition, the coal-fired gener-
ation capacity utilizing coal from each CPA is constantly changing. Generation plant
operating dates are delayed and synthetic fuel plant locations and fuel sources are
uncertain. In addition, we have assumed the 1985 rate of use to continue after 1985.
We may decide later to extend our scenarios beyond 1985 and will then modify the
29
-------
Table 3--Coal reserves balance for 1985 ICAM
CPA I/
: Reserves :
: remaining :
: after 1975 :
: model run :
Reserves :
needed :
1976-84 :
1 000
Reserves :
available :
for 1985 :
model runs :
1985
rate of
use
: Reserves
: remaining
: at 1985
: rate of use
AZ01
341,356
89,145 252,211
7,197
35
C001
C002
COOS
C004
C005
C006
C007
MT01
MT02
MT03
MT04
MT05
ND01
ND02
ND03
NM01
NM02
NM03
NM04
UT01
UT02
UT03
WY01
WY02
WY03
WY04
6,663,800
950,500
205,600
4,100,500
433,300
1,110,300
1,367,600
484,000
3,559,000
1,366,000
18,373,000
42,594,000
3,880,400
6,465,300
5,642,500
2,528,500
414,832
1,381,000
27,500
1,000,500
2,990,500
40,300
91,985
20,602,000
1,015,000
2,112,900
79,006
0
0
18,348
0
0
0
0
2,900
0
379,001
0
31,153
54,751
24,481
129,258
42,719
1,045
1,000
80,501
15,525
0
17,604
426,212
121,433
87,638
6,584,794
950,500
205,600
4,082,152
433,300
1,110,300
1,367,600
484,000
3,556,100
1,366,000
17,993,999
42,594,000
3,849,247
6,410,549
5,618,019
2,409,242
372,113
1,379,955
26,500
919,999
2,974,975
40,300
74,381
20,175,788
893,567
2,025,262
18,083
0
0
3,520
0
0
0
0
2,900
0
49,548
0
7,017
13,739
4,109
25,984
9,512
500
1,000
22,129
16,400
0
4,506
106,582
14,321
11,800
364
--
--
1,160
--
--
--
_-
1,226
—
363
--
549
467
1,367
93
39
2,760
26
42
181
--
17
189
62
172
-- = Not applicable
\J See footnote I/ to table 2 for explanation of abbreviations.
Source: Compiled from Bureau of Mines reserve data and from use rates of existing
and planned power plants. Summarized from data in app. table 5 (7_, 18, 21).
analysis described in table 3. The table does, however, give us a tentative picture of
the continuing viability of the coal mining industry in each western CPA.
The continued utilization of western coal heavily depends upon the price level of
western coal relative to coal available in other producing areas. One of the most
30
-------
important inputs to the simulation model in the coal supply area is the cost 6/
assumed for each CPA. Table 4 describes the 1985 coal prices assumed for strip and
underground mined coal. The selling prices reported in Coal Meek are for much broader
areas than our CPAs. This causes similarity of prices for several CPAs. We would ex-
pect minor differences in selling prices between adjacent CPAs. Therefore, a more in-
tensive analysis of these pricing differences will be performed as time permits. An-
other problem was how to price coal from the MT01, MT02, MT03, and MT05 CPAs. These
CPAs lie in eastern Montana and contain mostly lignite reserves. Therefore, the de-
cision was made to price these CPAs in a manner similar to the North Dakota CPAs.
This may be later modified because of the seemingly low prices attached to coal from
both North Dakota and eastern Montana.
Another important aspect of the coal supply situation is the characteristics
assumed to exist for coal mined in each CPA. Table 5 describes the heat value, sulfur
content, and pounds of sulfur per million Btu estimated for coal mines from each CPA.
The Btu per pound describe the heat value of the coal burned by each electrical gener-
ation plant. The percent sulfur per pound is translated into the number of pounds of
sulfur per million Btu using the Btu content described in the first column of table 5.
The sulfur content will be used for the sulfur dioxide constraints in the simulation
model.
The coal selling price assumed for each CPA includes the cost of reclamation and
the cost of taxes paid to various taxing authorities. We will treat reclamation and
taxation activities separately in our simulation model. Therefore, these costs must
6/ The model's present objective is to determine the cost of producing electricity,
not to minimize cost in the usual linear programming sense. Simulation of the real
world is improved by the use of selling prices rather than cost of production.
Table 4--Coal prices assumed in 1985 for strip and underground mined coal
CPA I/
Strip:
SAZ01
SCC01
SCC02
SCC04
SMT01
SMT02
SMT03
SMT04
SMT05
SND01
SND02
SND03
SNM01
SNM02
SUT01
SUT02
; Price
Dols. per ton
21.05
26.31
26.31
26.31
4.03
4.03
4.03
13.16
4.03
4.03
4.03
4.03
21.05
21.05
26.31
26.31
CPA IJ
Strip:
SWY01
SWY02
SWY03
SWY04
SC007
SNM03
SC005
; Price
Dols. per
10.15
10.15
23.31
23.31
26.31
21.05
26.31
: ; CPA \i
ton
Underground :
UC001
UC002
UC003
UC004
UC005
UC006
UC007
UNM01
UNM02
UNM03
UNM04
UUT01
UUT02
UUT03
UWY04
UWY03
; Price
Dols. per ton
26.31
26.31
26.31
26.31
26.31
26.31
26.31
21.05
21.05
21.05
32.05
26.31
26.31
26.31
26.31
26.31
I/See footnote \j to table 2 for explanation of abbreviation for the activity.
Source: Computed by inflating 1978 selling prices (as reported by Coal Week) by 6
percent annually.
31
-------
Table 5--Heat value and sulfur content of western coal
Activity and
CPA I/
MNGSAZ01
MNGSC001
MNGSC002
MNGSC004
MNGSC005
MNGSC007
MNGSMT01
MNGSMT02
MNGSMT03
MNGSMT04
MNGSMT05
MNGSND01
MNGSND02
MNGSND03
MNGSNM01
MNGSNM02
MNGSNM03
MNGSUT01
MNGSUT02
MNGSWY01
MNGSWY02
MNGSWY03
MNGSWY04
MNGUC001
MNGUC002
MNGUC003
MNGUC004
MNGUC005
MNGUC006
MNGUC007
MNGUNM01
MNGUNM02
MNGUNM03
MNGUNM04
MNGUUT01
MNGUUT02
MNGUUT03
MNGUWY03
MNGUWY04
Heat value
Btu per Ib.
10,350
11,538
10,120
11,657
12,950
9,000
6,350
6,500
7,635
9,025
7,698
6,750
6,767
6,128
11,560
11,164
12,560
12,591
9,780
9,300
8,040
9,570
8,852
11,538
10,120
10,874
11,657
12,944
12,460
11,609
11,560
11,164
12,560
12,760
12,591
9,780
10,740
9,650
11,350
Sulfur
Pet. per Ib. '
0.90
.50
.30
.50
1.20
.50
.30
.50
.50
.60
.46
.52
1.01
.78
.70
.60
.50
.40
1.10
.61
.49
.55
.52
.50
.30
.40
.50
1.20
.50
.30
.70
.60
.50
.60
.40
1.10
1.40
.90
1.00
content
Lbs. per mil . Btu
0.870
.433
.296
.429
.927
.556
.472
.769
.655
.665
.598
.770
1.493
1.273
.606
.537
.398
.318
1.125
.656
.609
.575
.587
.433
.296
.368
.432
.927
.401
.258
.606
.537
.398
.470
.318
1.125
1.304
.933
.881
I/ See footnote I/ to Table 2 for explanation of abbreviation for the activity.
Source: Compiled from Bureau of Mines data base on western coal reserves (7).
32
-------
be separated from the selling price of coal in each CPA. Table 6 describes the inputs
used to determine the reclamation costs per ton and per acre for each CPA. The table
describes the characteristics of the coal seams in each CPA and uses that information
to determine the reclamation yield in acres per 1,000 tons. These acres are accumu-
lated in the simulation model and reclaimed at the cost described in table 6. Many of
these reclamation costs were obtained from (10). The cost of reclamation for the
underground mining activities is highly questionable. A good analysis of underground
mine reclamation costs in the Western States does not exist. Therefore, we had to
impute values based on costs of underground mine reclamation in the Interior coal pro-
ducing region.
Another important part of the selling price of coal in each CPA is the cost of
taxes which the coal mining company must pay. ESCS has developed programs which can
compute the amount of taxes paid under alternative mining conditions. These mine tax
models used the prices described in table 4. The underground mine tax estimates are
based on a 4.9 million-tons-per-year mine. The strip mine tax estimates are based on
the 5 million-tons-per-year mine described in (13). All estimates are for a mine with
a preparation plant and a loading facility. These tax estimates are good basic esti-
mates of taxes paid by coal mines. They could be improved by using other mine sizes
and by using better price and tax assessment information. The most important factor,
however, is price. As a result, our questionable prices for North Dakota and Montana
lignite could influence results obtained using the Western States model. Table 7 de-
scribes the taxes computed for each western CPA. The assumed price is listed with the
taxes paid per ton for both strip and underground mines.
Table 8 summarizes the 1985 coal mine price, reclamation cost, and tax payment
situation. For each mine type in each CPA, the total mining cost is listed with the
reclamation cost and the tax payment. These latter two costs are subtracted from the
total mining cost to derive the actual cost of mining for each mine type in each CPA.
This cost is the input coefficient to the simulation model.
Coal Transportation
After the 1985 inventory of coal mines and electrical generation plants was de-
veloped, we could begin the development of transportation links to connect the coal
supply and demand points. We were able to determine the source of coal for each
electrical generation plant in almost all cases. These sources of supply are usually
in the form of long-term contracts and are announced concurrently with plans for the
construction of the generation facility. Therefore, we knew the transportation link
to specify. If, for example, an electrical generation plant in Illinois was to be
producing electricity in 1985 and getting its coal from MT04, we would simply set up
an MT04-Illinois power plant transportation link. TJ
For those cases where we did not know the source of coal for a power plant, we
determined whether the addition to generation capacity was part of an existing plant
or whether it was a new plant. If it was an addition to a plant existing in 1975, we
assumed that the addition to capacity would receive the same proportion of coal from
western CPAs as did the capacity existing in 1975. If the plant was a new one, we
looked at other plants in the same utility system and assumed the new plant would get
the same proportion of coal from western CPAs as did other plants in the system. If
we had no information indicating that plants in the system or the new plant received
western coal, we assumed no western coal transportation links to that plant. This
TJ This is an example of the deterministic nature of the ICAM. Rather than per-
mitting the Illinois power plant to be supplied by the least-cost CPA, current con-
tracts are used as a guide. The disadvantage of this procedure is that opportunity
costs are not evaluated.
33
-------
Table 6--Working table to provide 1985 coal yield and reclamation ICAM input coefficients
CPA
Strip
AZ01
C001
C002
C004
COO 5
C007
MT01
MT02
MT03
MT04
HT05
N001
ND02
ND03
NH01
NM02
NM03
UT01
UT02
WY01
WY02
WY03
WY04
Underc
C001
C004
C006
C007
NH03
UT01
UT02
WY03
WY04
Heat \J •
value :
Btu
per 1b.
ining:
10,350
11,538
10,120
11,657
12,950
9,000
6,350
6,500
7,635
9,025
7,698
6,750
6,767
6,128
11,560
11,164
12,460
12,491
9,780
9,300
8,040
9,570
8,852
ound mining:
11,538
11,657
12,460
11,609
12,560
12,491
9,780
9,650
22,350
Sulfur !_/ : Coal 2/ : Seam 3/
content : type : thickness
Pet.
0.90
.50
.30
.50
1.20
.50
.30
.50
.50
.60
.46
.52
1.01
.78
.70
.60
.50
.40
1.10
.61
.49
.55
.52
.50
.50
.50
.30
.50
.40
1.10
.90
1.00
Rank Feet
SUB N/A
BIT N/A
BIT 25
BIT 15
BIT 12
SUB 15
LIG 21
SUB
SUB 15
SUB
LIG 24
LIG
LIG N/A
LIG N/A
SUB N/A
BIT N/A
BIT 10
BIT 12
BIT 11
SUB N/A
SUB N/A
SUB N/A
SUB N/A
BIT 9
BIT 8
BIT 9
SUB 9
BIT 10
BIT 9
BIT 8
SUB 16
SUB 12
N/A = Not available
I/ Heat value and sulfur content were taken from table
2] Coal ranking and
: Coal 2/ : Coal :
: yielcT : yield :
Tonsjer Tons
acre foot per acre
N/A 4/ 41,429
N/A 4/ 14,444
1,440 5/ 36,000
1,440 V 21,600
1,440 5/ 17,280
1,416 5_/ 21,240
1,400 5/ 29,400
4/ 27,647
1,400 5/ 21,000
4/ 65,714
1,400 5/ 33,600
4/ 13,333
N/A 4/ 17,200
N/A 4/ 16,800
N/A 4/ 33,333
N/A 4/ 28,889
1,440 5/ 14,400
1,440 5/ 17,280
1,440 5/ 15,840
N/A 4/ 98,000
N/A 4/112,222
N/A 4/ 37,143
N/A 4/ 60,000
1,440 5/ 12,960
1,440 5/ 11,520
1,440 5/ 12,960
1,416 ^/ 23,744
1,440 5/ 14,400
1,440 5/ 23,960
1,440 5/ 11,520
1,416 5/ 22,656
1,416 5/ 16,992
5.
Reclamation
yield
Acres per
1,000 tons
I/
8/
1
-------
Table 7—Taxes computed for western CPAs
CPA
AZ01
C001
C002
COO 3
C004
COO 5
C006
C007
MT01
MT02
MT03
MT04
MT05
NM01
NM02
NM03
NM04
ND01
ND02
ND03
UT01
UT02
UT03
WY01
WY02
WY03
WY04
Assumed
price
21.05
26.31
26.31
I/
26.31
26.31
26.31
26.31
I/
4.03
I/
13.16
I/
21.05
21.05
21.05
I/
4.03
4.03
4.03
26.31
26.31
I/
10.15
10.15
23.31
23.31
:
: Strip
Dollars per ton
3.33
1.01
1.03
I/
1.08
1.10
2/
1.19
I/
0.98
I/
3.51
I/
0.75
0.73
0.70
I/
0.72
0.72
0.72
0.14
0.12
I/
1.75
1.67
3.82
4.18
Tax
: Underground
I/
0.87
2/
I/
0.94
2/
1.03
1.06
I/
2/
T/
2/
I/
2/
2/
0.85
I/
2/
2/
I/
0.35
0.31
I/
2/
2/
4.00
2/
I/ Taxes were not computed for these CPAs.
2J Taxes were not computed for this mine type in this CPA. If a number was needed
for the model, an estimate was made based on the nearest in-State CPA.
Source: (13, 14).
estimation procedure was necessary for only a few of the capacity additions. Alter-
native transportation scenarios involving different assumptions about transportation
costs will be developed later in the present research project.
The most important part of the transportation activities is the cpst of the trans-
portation link. For those power plants which existed in 1975 and which were planning
additions to capacity by 1985, we simply escalated the cost of transportation used in
the 1975 simulation model (table 9). This 1975 transportation cost was escalated 6
percent per year. Therefore, the inflation factor assumed from 1975 to 1985 became
35
-------
Table 8—Projected 1985 ICAM coal prices, reclamation costs, and tax payments
Mine type
and CPA
SAZ01
SC001
UC001
SC002
SC003
UC003
SC004
UC004
SC005
UC006
SC007
UC007
SMT01
SMT02
SMT03
SMT04
SMT05
SNM01
SNM02
SNM03
UNM03
SNM04
SND01
SND02
SND03
SUT01
UUT01
SUT02
UUT02
SUT03
SWY01
SWY02
SWY03
UWY03
SWY04
Total :
mining :
cost :
21.05
26.31
26.31
26.31
26.31
26.31
26.31
26.31
26.31
26.31
26.31
26.31
4.03
4.03
4.03
13.16
4.03
21.05
21.05
21.05
21.05
21.05
4.03
4.03
4.03
26.31
26.31
26.31
26.31
26.31
10.15
10.15
23.31
23.31
23.31
-- = Not applicable
I/ Not computed.
2/ Estimated using adjacent CPAs.
S = Strip mine
U = Underground mine
Reclamation
cost
Dollars
0.07
.07
.23
.08
.10
.24
.14
.26
.17
.23
.14
.24
.10
.17
.14
.07
.09
.09
.09
.21
.21
.20
.33
.25
.25
.21
.23
.19
.26
.20
.05
.03
.07
.13
.05
Tax
payment
per ton
3.33
1.01
.87
1.03
I/
I/
1.08
.94
1.10
1.03
1.19
1.06
I/
.98
V
3.51
I/
.75
.73
.70
.85
2/ .70
.72
.72
.72
.14
.35
.12
.31
V
1.75
1.67
3.82
4.00
4.18
: Actual
: cost of
: mining_____
17.65
25.23
25.21
25.20
--
—
25.09
25.11
25.04
25.05
24.98
25.01
--
2.88
--
9.58
—
20.21
20.23
20.14
19.99
20.15
2.98
3.06
3.06
25.96
25.73
26.00
25.74
-_
8.35
8.45
19.42
19.18
19.08
1.7908477. If a power plant was completely new, we furnished North Dakota State Uni-
versity specialists with the mine source and the power plant destination and they used
their transportation cost model to build a cost for that transportation link. Table 10
36
-------
Table 9—1975 and 1985 transportation costs
Link-7
C0019013
WY029006
C0019006
WY029011
MT045025
MT045016
MT045014
WY035036
UT015036
MT045003
MT045004
WY035011
MT045011
MT045007
WY025009
MT045024
WY035018
MT045018
C0015018
UT015018
WY035002
WY035028
WY033029
MT043029
WY023056
UT013023
WY023015
WY033050
C0013100
WY023027
MT046016
C0016015
UT016015
WY016024
MT046024
C0016024
WY036020
WY036030
UY026021
WY026019
WY037003
WY039016
C0079016
C0079019
1975 :
cost :
Dols. per
0.2656
.0757
.1113
.5623
.5584
.6664
.6674
.3353
.8733
.6971
.4793
.3915
.5454
.4188
.4623
.5789
.8611
.5146
.0753
.5167
.2917
.7851
.5495
.5453
1.0172
.8223
.5637
.5606
.3854
.6539
.4229
.2855
.4474
.6723
.2484
.6954
.2173
.1980
.5495
.6244
.5457
.1239
.0830
.0409
1985
cost
mil . Btu
0.4756
.1356
.1993
1.0070
1.000
1.1934
1.1952
.6005
1.5640
1.2484
.8584
.7011
.9767
.7500
.8279
1.0367
1.5421
.9216
1.9257
.9253
.5224
1.4060
.9841
.9765
1.8820
1.4726
1.0095
1.0039
.6902
1.1710
.7573
.5113
.8012
1.2040
.4448
1.2454
.3892
.3456
.9841
1.1182
.9773
.2219
.1486
.0732
Link^/
WY037006
MT043007
MT043086
MT043014
MT043001
MT046031
MT046028
MT046008
MT046010
MT046005
MT046011
ND026025
WY037014
C0017014
UT017014
WY037013
WY037001
WY037004
WY025012
WY035001
MT049020
WY036029
WY046029
C0016029
WY036017
UT016017
WY036004
AZ019003
NM019001
ND026003
ND016014
ND026032
ND026023
MT046023
UT019018
UT019015
WY036012
MT046012
WY035005
MT045002
WY039007
C0019016
WY039019
1975 :
cost :
Dols. per mi
0.5261
.8108
1.3466
1.4363
.9241
1.0349
.4785
.3271
.3221
.2473
.3375
.3544
.4915
.2000
.6680
.1873
.3595
.2382
.6664
.6846
.0908
.4401
.4714
.4516
1.1860
.1655
.3526
.0242
.0000
.0464
.1073
.1562
.0434
.1911
.0504
.3059
.3286
.3258
.3344
.4662
.0000
.1240
.2017
1985
cost
. Btu
0.9422
1.4520
2.4116
1.6549
1.6549
1.8533
.8569
.5858
.5768
.4429
.6044
.6347
.8802
.3582
1.1960
.3354
.6438
.4266
1.1934
1.2260
.1626
.7882
.8442
.8087
.3331
.1964
.6315
.0433
.0000
.0831
.1922
.2797
.0777
.3422
.0903
.5478
.5885
.5835
.5989
.8349
.0000
.2221
.3612
J7 The first four digits of the link are the CPA of origin for the coal;
the last four digits are the electric power plant code. See app. tables
2 and 5 for power plant names.
«
Source: 1975 costs obtained from published rates of the Interstate
Commerce Commission (_23). 1985 costs obtained by inflating 1975
costs by 6 percent annually.
37
-------
Table 10--Characteristies of 1985 transportation links for new power plants
Transportation
link I/
MT045043
UT019037
WY027016
WY027018
WY028004
WY028005
C0018006
MT048007
WY028013
NM018014
NM018016
NM018017
WY028018
NM018019
NMO 18020
MT048021
MT048022
UT019010
NM029014
UT019017
NM029021
UT019022
NM029025
UT019026
NM029026
NM039026
C0019027
WY029028
UT019029
WY029030
WY029031
UT019033
NM029035
C0019038
UT019039
NM049040
MT049042
WY023002
UT013020
C0043045
C0043104
WY023107
WY035002
MT045013
MT045017
MT045035
Cost y :
Dols. j?er
mil. Btu
0.808716
.535381
.901557
1.357790
1.536840
1.525090
1.014330
1.538350
1.045020
.960259
1.000000
.987023
1.525140
.980516
.940039
1.136113
1.379650
--
.078171
.278547
.105028
.066692
.363530
.252007
.040024
.319419
.242226
.638608
.291162
1.122090
.201024
.315486
.189903
.253085
.360083
.257286
.127491
1.119040
1.254360
.936621
.966019
1.227830
.890759
1.182760
.849432
.792209
One-way
distance
Miles
865
798
859
1,298
1,470
1,459
1,392
1,653
997
1,320
1,375
1,357
1,459
1,348
1,292
1,461
1,481
--
96
411
131
92
477
371
45
471
326
606
430
1,071
185
467
245
341
534
378
129
1,068
1,881
1,298
1,339
1,160
1,007
1,080
909
847
: Round-trip
: time
Hours
99.45
92.52
98.83
144.22
162.01
160.87
153.95
180.94
113.10
146.50
152.19
150.33
160.87
149.40
143.60
161.08
163.15
--
19.93
52.50
23.55
19.51
59.33
48.36
14.65
58.71
43.71
72.67
54.47
120.75
29.13
58.29
35.34
45.26
65.22
49.09
23.34
120.44
204.51
144.22
148.46
129.95
114.13
121.68
104.00
97.59
: Cost 3/
Dols. per ton
8.1549
7.5318
8.0989
12.1973
13.8058
13.7003
13.0763
15.5125
9.3877
12.4029
12.9166
12.7486
13.7007
12.6646
12.1417
13.7254
13.9121
__
0.9751
3.9186
1.3101
0.9382
4.5346
3.5453
0.4992
4.4826
3.1227
5.7368
4.0961
10.0800
1.8059
4.4383
2.3688
3.2627
5.0657
3.6106
1.2856
10.0526
17.6466
12.1991
12.5820
11.0299
9.5246
10.1731
8.5655
7.9885
See footnotes at end of table
Continued
38
-------
Table 10—Characteristics of 1985 transportation links for new power
plants—Continued
Transportation
linkl/
WY026001
MT046002
MT046007
ND036009
WY026022
MT046022
WY036026
MT046037
WY026038
WY026040
WY026041
MT046043
MT046045
ND026046
WY027022
WY029046
WY027021
UT014057
C0044057
WY027017
WY027019
WY027023
MT047025
WY027025
WY027026
WY017027
WY027028
WY027031
WY027033
WY027034
WY027037
WY027039
WY027040
MT043116
MT046013
ND026035
ND016039
AZ019002
WY049005
WY049008
NM019012
UT029034
ND026047
WY029043
C0019044
Cost 2J :
Dols. per
mil. Btu
0.606290
.608645
.650463
.491480
.965138
.822768
.543538
.488851
.396428
.684373
.628765
.575077
. 704085
. 054843
.906721
.717241
.805174
1.069610
1.011240
1.067830
1.117830
1.357710
1.420030
1.546920
1.078230
1.095680
1.573950
1.208190
1.161430
1.199170
1.312100
1.312100
1.647710
1.403040
—
—
__
--
—
—
—
—
—
--
--
One-way :
distance :
Miles
575
649
694
352
919
879
614
519
373
650
596
612
752
36
864
681
766
1,603
1,402
1,019
1,067
1,298
1,525
1,480
1,029
1,211
1,506
1,154
1,109
1,145
1,254
1,254
1,577
1,409
—
--
__
--
--
--
--
__
—
__
--
Round-trip
time
Hours
69.46
77.11
81.77
46.40
105.03
100.90
73.49
63.67
48.57
77.22
71.63
73.29
87.76
13.72
99.35
80.42
89.21
175.76
154.98
115.37
120.34
144.22
167.70
163.05
116.41
135.23
165.73
129.33
124.68
128.40
139.67
139.67
173.08
155.70
--
__
__
__
-_
__
-_
__
__
__
: Cost 3/
Dols. per ton
5.4465
6.1375
6.5591
3.3651
8.6701
8.2966
5.8119
4.9295
3.5612
6.1479
5.6484
5.7990
7.0999
.4147
8.1453
6.4432
7.2331
15.0475
13.1710
9.5926
10.0418
12.1966
14.3193
13.8963
9.6860
11.2853
14.1392
10.8535
10.4334
10.7724
11.7870
11.7870
14.8018
14.1480
-_
_-
__
__
__
_-
__
__
._
__
--
See footnotes at end of table.
Continued
39
-------
Table lO—Characteristics of 1985 transportation links for new power
plants—Continued
Transportation
link I/
MT029045
WY019047
C001 9009
WY029023
C0019024
UT029032
UT029036
Cost 2/ : One-way :
: distance :
Dols. per
mil . Btu Miles
„
__
.-
—
-_
—
~.. —
Round-trip : Cost 3/
time :
Hours Dols. per ton
__
__
—
__
__
—
"
= Not applicable. Link is mine-mouth plant.
_!_/ See table 9, footnote _!/', for explanation of link coding.
2/ 1985 dollars.
3/ 1975 dollars.
Source: (5). Computer printouts also provided by the authors of (5).
describes those transportation costs developed by North Dakota State University
(NDSU). 8/ Zero transportation costs were assumed for mine-mouth power plants.
Several new railroad links were assumed to be operating by 1985. One such link
will be the line being built from the coal fields south of Gillette, Wyoming, to con-
nect with the existing rail line running through Douglas, Wyoming.
Coal slurry pipelines may also be used to move coal in 1985. Costs and other
Information for coal slurry pipelines are being developed by NDSU. We will use coal
slurry pipelines as alternative scenarios in our national coal model. We will not
analyze the use of coal slurry pipelines in this report because adequate information
1s not yet available.
NDSU specialists are also developing rail link capacities to be used in our
modeling effort. They will determine the carrying capacity of each rail link and
then the model will accumulate coal shipments over those links up to the capacity of
those links. Then, costs for expanding the capacity of various critical links will
be developed and we will examine changes in the location of coal mining resulting
from those investments in expanded rail capacity. In order to accumulate shipments
of coal over specific rail links, we have converted the number of Btu per thousand
tons of coal into a coefficient which describes thousands of tons of coal per million
Btu. This is necessary because the cost of moving coal is expressed in dollars per
million Btu (the model transports 1 million Btu at a specific cost). However, rail-
road carrying capacity is described in thousands of tons or number of cars per unit
of time. Therefore, it is necessary to monitor our transportation coal movements in
terms of thousands of tons. This is done by using the thousands of tons per million
8/ For this report, we simply list the transportation costs developed by the
authors of (5). An explanation of the model methodology used to develop these costs
is available in the cited report.
40
-------
Btu coefficient described above. Table 11 describes both the million Btu per thousand
tons and the thousand tons per million Btu coefficients used in both the 1975 and 1985
models.
NDSU engineers and economists are developing transportation costs for use in this
western model. They have approached this problem from an engineering cost standpoint
by developing a model which examines the equipment needed to transport coal and cal-
culates a cost of that movement. They are also examining the railroad capacity prob-
lem and analyzing the cost of coal movements by slurry pipeline and barge.
Electrical Generation Plants
The coal supply-demand trajectory also involves electrical generation plants. In
the western model, we consider only coal used by electrical generation plants. One
source used to inventory electrical generation plants using western coal in 1985 was
the 1975 list of power plants. This involved an analysis of changes in their annual
coal use. This information is available from FERC (Federal Energy Regulatory Commis-
sion) Form 423. We used the 1976 Form 423 data to add or delete power plants which
added or discontinued coal use in 1976. We intend to do the same with the 1977 Form
423. We plan to continue this analysis annually to maintain a current picture of
power plants receiving western coal. App. table 4 shows how the 1975 western coal-
fired electrical generation situation changed from 1975 to 1978.
The next step in identifying likely 1985 plants was a synthesis of construction
plans for new coal-fired electrical generation facilities for 1985. Many government
agencies and other sources have compiled lists of planned additions to electrical
generation capacity year-by-year up to and beyond 1985. In addition, industry news-
letters and newspapers report daily on the plans for new additions to capacity. These
and many sources were scrutinized and app. table 5 was developed synthesizing the
information. App. table 5 describes yearly additions to coal-fired electrical gener-
ation capacity. This table is used for scenario development. Since we are interested
in a 1985 scenario, we incorporate into the model all of the proposed additions to
electrical generation capacity from 1976 through 1985. In those cases where captive
reserves 9/ supply the power plant, or where supply contracts have been determined,
we force those linkages into the solution.
We developed two tables to summarize information about power plants demanding
western coal in 1985. The first of these tables (app. table 6) lists power plants
receiving western coal in 1975 which have no expansion plans from 1976 through 1985.
These plants were assumed to obtain the same amount of coal in 1985 as they obtained
in 1975. The CPA source of this coal does not change nor does the percentage of coal
received. There are 64 of these power plants.
The second table (app. table 7) lists new power plants planned for completion by
1985 and power plants with expansion plans supplied by western coal. There are 94 of
these power plants. In those cases where the power plant existed in 1975, we assumed
that its expansion plans would utilize the same portion of western coal as in 1975.
We had information on the western source of coal for almost all of the new plants.
For those plants for which we had no information concerning their source of coal, we
examined other power plants in the utility system or, in a very few instances, made an
educated guess of where they would obtain their western coal.
9_/ "Captive reserves" describes the vertically integrated situation in which the
utility controlling the power plant also owns or controls the coal supply source (the
mine). The utility may also own the rolling stock (usually railroad cars) in which
the coal is transported.
41
-------
Table ll--Coal Btu-tonnage conversion coefficients for use in
monitoring capacity of transportation links
CPA
Strip mining:
AZ01
C001
C002
C004
C005
C007
MT01
MT02
MT03
MT04
MT05
ND01
ND02
ND03
NM01
NM02
NM03
UT01
UT02
WY01
WY02
WY03
WY04
Underground m
C001
C002
C003
C004
COOS
C006
C007
NM01
NH02
NM03
NM04
UT01
UT02
UT03
WY03
WY04
Coefficients
Mil. Btu
per 1,000 tons
20,700
23,076
20,240
23,314
25,900
18,000
12,700
13,000
15,270
18,050
15,396
13,500
13,534
12,256
23,120
22,328
25,120
25,182
19,560
18,600
16,080
19,140
17,704
ning:
23,076
20,240
21,748
27,320
25,888
24,920
23,218
23,120
22,328
25,120
25,520
25,182
19,560
21,480
19,300
22,700
1,000 tons
per mil . Btu
0.0000483092
.0000432900
.0000495050
.0000429185
.0000386100
.0000555560
.0000839433
.0000746269
.0000653595
.0000537634
.0000649351
.0000763359
.0000793651
.0000813008
.0000432900
.0000448430
.0000398406
.0000396825
.0000510204
.0000518135
.0000617284
.0000518135
.0000440529
.0000432937
.0000495050
.0000460829
.0000429185
.0000386100
.0000401606
.0000431034
.0000432900
.0000448430
.0000398406
.0000392157
.0000396825
.0000510204
.0000465116
.0000518135
.0000440529
Source: (7).
42
-------
Model Coefficients
The linear programming input data required for each power plant includes the net
generation capacity expressed in million kilowatt hours, the input-output ratio ex-
pressed in million Btu per million kilowatt hours, and the operating cost expressed in
dollars per million kilowatt hours (table 12). To obtain these 1985 inputs for each
power plant, we examined historical information for existing power plants (19). Be-
cause of time constraints, a simple visual examination of the data from 1965 through
1974 was used to formulate 1985 coefficients. For instance, a power plant receiving
western coal in 1975 would be examined and its net generation each year from 1965
through 1974 used to determine its net generation for 1985. If the plant was old and
its net generation declining, this decline was continued to 1985. If the plant was
new and maintaining a constant high level of generation output, this high level of
net generation output was modified only slightly for 1985. Next, the input-output
ratios for each plant were examined for the 1965 through 1974 period and an estimate
made of the input-output ratio for the plant in 1985. The same procedure was followed
for the operating cost for each plant. 10/ The 1965-74 historical data were also used
to make estimates concerning the retirement of some power plants. The power plants
estimated to be retired from production are indicated in table 12.
Power Plant Conversions
The 1975 inventory of coal-fired power plants can be expanded by adding those
plants which have been or can be converted to coal use. The addition of these plants
to the analysis of 1985 scenarios is necessary to obtain accurate estimates of large
power plant coal use.
There are three major categories into which the conversion data can be divided.
The first is a list of power plants greater than 100 megawatts which were converted
to coal by mid-1979 (table 13). Between 1975 and 1979, 47,633 megawatts of capacity
in the United States were switched to coal. Many of the generating units which were
converted were located at power plants which already burned coal in other units of
the same plant; therefore, many of the site locations are not new, but show increased
coal-fired capacity at a location already existing in the model. Historical data are
used to make estimates of coal requirements for those units converted through 1985.
The second major category of conversion data describes oil and gas-fired gener-
ating units which can be converted to coal firing with relative ease from a technical
standpoint (table 14). These plants may have burned coal in the past or have boilers
designed to burn coal. There is some coal handling equipment present and an area
exists which could be or is being used for a coal stockpile. Table 14 indicates that
this group of units and plants total 16,347 megawatts and that most are oil-fired.
A third group includes units at power plant sites which do not presently use coal
as a boiler fuel and which could convert to coal use only with difficulty (table 15).
This difficulty usually occurs because of substantial engineering and site problems
10/ We have developed hypotheses concerning a statistical model which may be used
to provide these input coefficients for the linear programming model. We have had
tentative discussions with an engineer concerning the feasibility of developing
statistical models of this type and believe that they are potentially reliable. We
will be pursuing the development of these models using historical 1965 through 1975
information. We hope to have an operational model available for use in defining 1985
power plant input characteristics for our national interregional model. We are also
investigating the possibility of using existing models available through EPA's Energy/
Environment R & D Program and through the Department of Energy for this purpose.
43
-------
Table 12--Power plant coefficients for 1985 model
I CAM
code
3002
3020
3045
3104
3107
4057
5002
5013
5017
5035
5043
6001
6002
6006
6007
6009
6013
6022
6026
6035
6037
6038
6039
6040
6041
6043
6045
6046
7016
7017
7018
7019
7022
7023
7025
7026
7027
7028
7031
7033
7034
7037
7039
7040
8004
8005
8006
8007
Power plant
Gavin
Cardinal
Bailly
Schahfer
Sull ivan
Jackson Co.
Baldwin
Edwards
Columbia
Weston
Pleasant Prairie
George Neal
Sherburne Co.
Neal #3
Boswell
Big Stone
Col strip
Alma
Council Bluffs
Square Butte
Sioux Falls
Gentleman
Coal Creek
Nebraska City
Heartland
Basin
Brookston
Antelope Valley
Harrington
Muskogee
Welsh
Fl int Creek
Jeffrey
White Bluff
Big Cajun
Sooner
Northeastern
Rodemacher
Unsited
Unsited
CRS Joint
Unsited
Unsited
Nelson
Deely, J.T.
Parish
Coleto Creek
Fayette
Net
generation
Mil. kWh
15,000
14,000
3,500
6,000
15,000
6,000
15,000
7,500
6,000
2,000
7,000
9,000
22,000
6,500
6,000
5,000
8,000
3,000
4,500
2,000
1,000
7,000
2,500
3,500
1,000
900
5,000
2,500
6,000
6,000
9,500
3,000
15,000
15,000
10,000
6,000
5,500
6,000
4,000
4,000
1,500
4,000
4,000
3,300
5,500
15,000
3,300
6,500
Input-
output
ratio
Mil. Btu
per mil . kWh
10,000
9,500
9,500
10,000
10,000
10,000
10,000
10,000
9,500
10,500
10,000
10,000
9,500
10,000
10,500
10,500
10,000
10,500
11,000
10,500
10,500
10,000
10,500
10,500
10,500
10,500
10,000
10,500
10,000
10,000
9,500
10,500
9,500
9,500
9,500
10,000
10,000
10,000
10,000
10,000
10,500
10,000
10,000
10,000
10,000
9,500
10,000
10,000
Operating
cost
Dols. per
Mil. kWh
850
1,800
1,000
900
850
900
850
1,100
900
1,400
900
1,100
850
900
1,500
1,000
950
2,000
1,800
1,000
1,000
900
1,000
1,000
1,000
1,000
950
1,000
950
950
900
1,000
850
850
900
950
950
950
1,000
1,000
1,000
1,000
1,000
950
950
850
950
950
1985
capacity
MW
2,600
2,410
616
1,020
2,600
1,000
2,528
1,280
1,038
435
1,160
1,621
3,680
1,060
1,015
880
1,363
537
781
400
200
1,200
450
575
200
150
800
450
1,037
1,030
1,584
528
2,880
2,800
1,620
1,015
900
1,020
700
700
280
700
700
540
894
2,968
550
1,100
Continued
-------
Table 12--Power plant coefficients for 1985 model--Continued
I CAM
code
8013
8014
8016
8017
8018
8019
8020
8021
8022
9002
9005
9008
9009
9010
9012
9014
9017
9021
9022
9023
9024
9025
9026
9027
9028
9029
9030
9031
9032
9033
9034
9035
9036
9037
9038
9039
9040
6047
3116
7021
9013
9006
9011
5025
5016
5014
5036
5003
Power plant
South Plains
Sandow
Unsited
Unsited
Unnamed
Unsited
Unsited
Unnamed
Unnamed
Navajo
Jim Bridger
Naughton
Hayden
Huntington Canyon
San Juan
Choi la
Gardner
Snowflake
Emery
Wyodak
Craig
Apache
Coronado
Nixon
Pawnee
North Valmy
Boardman
Laramie River
Warner Valley
Allen
Garfield
Plains
Intermountain
Unsited
Future
Pioneer
Springville
Coyote
Belle River
Nearmen Creek
Drake
Cherokee
Comanche
Wai lace
risk
Crawford
Dixon
Joliet
Net
generation
Mil. kWh
5,500
3,500
4,500
4,500
4,500
4,500
4,500
1,000
1,000
14,000
15,000
9,000
4,000
5,000
10,000
7,000
2,000
800
5,000
2,000
9,000
2,000
6,000
4,500
6,000
3,000
3,000
9,000
3,000
12,000
6,000
2,000
13,500
5,000
6,000
3,000
2,000
2,500
8,000
3,500
1,000
4,500
2,500
—
—
1,500
300
7,000
: Input-
: output
: ratio
Mil. Btu
per mil . kWh
10,000
10,500
10,000
10,000
10,000
10,000
10,000
10,500
10,500
9,500
9,500
10,000
10,000
10,000
9,500
10,000
10,500
10,500
10,000
10,500
9,500
10,500
10,000
10,000
10,000
10,500
10,500
10,000
10,500
9,500
9,500
10,500
9,500
10,000
10,000
10,500
10,500
10,500
10,000
10,500
13,000
12,000
11,000
—
-_
12,500
13,000
12,000
: Operating
: cost
Dols. per
Mil. kWh
950
1,000
950
950
950
950
950
1,000
1,000
900
900
950
1,000
950
950
1,600
1,000
1,100
950
1,100
950
1,000
950
1,000
950
1,000
1,000
950
1,000
900
900
1,000
900
950
950
1,000
1,000
1,000
950
1,000
2,550
1,650
1,850
__
__
3,250
3,250
2,200
1985
capacity
MW
950
575
750
750
750
750
750
200
200
2,303
2,508
1,541
680
800
1,669
1,104
345
125
800
330
1,520
350
1,050
750
1,000
500
500
1,500
500
2,000
1,000
350
2,250
800
1,000
500
330
410
1,350
566
257
802
383
_ _
702
119
1,787
Continued
45
-------
Table 12--Power plant coefficients for 1985 model--Continued
I CAM
code
5004
5011
5007
5009
5024
5018
5028
3029
3056
3023
3015
3050
3100
3027
6016
6015
6024
6020
6030
6021
6019
7003
7006
3007
3086
3014
3001
6031
6028
6008
6010
6005
6011
6025
7014
7013
7001
7004
5012
5001
9020
6029
6017
6004
9003
9001
6003
6014
6032
Power plant
Powerton
Waukegan
Will County
Joppa
Hennepin
lAlood River
Venice 2
State Line
Breed
Tanners Creek
Clifty Creek
Mitchell
Edwardsport
Cayuga
Kapp
Prairie Creek
Sutherland
Riverside
Maynard
Des Moines 2
Burl ing ton
Lawrence
Tecumseh
Shawnee
Marysvil le
St. Clair
Monroe
Fox Lake
Aurora
Black Dog
High Bridge
King
Riverside
Hoot Lake
Blue Valley
Grand Ave.
Hawthorne
Montrose
Meremec
Labadie
Corette
Kramer
Sheldon
North Omaha
Mohave
Four Corners
Leland Olds
Young
Heskett
Net
generation
Mil . kWh
6,000
2,000
5,000
6,000
1,200
1,500
—
4,000
2,000
5,000
7,500
2,500
--
6,000
1,000
1,000
800
1,000
200
1 ,000
1,000
2,500
500
9,000
500
9,500
18,500
200
300
2,000
1,000
3,000
1,500
700
400
-_
4,000
3,000
4,000
15,000
1,000
500
1,300
3,000
8,500
12,000
1,500
1,500
500
Input-
output
ratio
Mil. Btu
per mil . kWh
11,000
13,000
11,000
11,000
11,000
12,000
--
11,000
10,500
10,000
9,500
10,500
--
10,000
11,000
12,000
12,000
12,500
15,000
14,000
10,500
11,500
14,500
10,500
13,500
10,000
10,000
13,500
14,000
11,500
12,500
10,000
12,000
12,500
13,000
__
11,000
11,000
11,000
10,000
11,000
13,000
11,000
10,500
11,500
10,500
11,500
11,500
13,500
Operating
cost
Dols. per
Mil . kWh
1,700
3,000
3,050
2,400
1,800
3,300
-_
3,500
2,800
2,700
1,650
2,000
--
1,100
1,900
2,650
1,600
3,100
3,400
3,800
1,350
1,550
4,400
1,350
5,550
1,500
1,400
3,250
4,650
2,400
4,750
1,650
3,400
2,200
3,000
—
2,850
2,200
3,150
1,800
1,100
3,350
1,750
1,650
5,100
2,200
1,800
1,200
2,100
1985
capacity
MW
1,743
932
1,269
1,098
306
501
--
972
496
1,101
1,350
529
--
1,062
237
245
158
203
105
189
212
613
346
1,750
200
1,435
3,173
105
116
488
398
598
384
137
115
_ _
909
564
924
2,484
173
114
229
646
1,510
2,170
700
257
100
Continued
46
-------
Table 12--Power plant coefficients for 1985 model—Continued
I CAM
code
6023
9018
9015
6012
5005
5022
9007
9016
9019
Power plant
Stan ton
Carbon
Gads by
Genoa 3
Oak Creek
Pul 1 iam
Dave Johnston
Arapahoe
Valinont
Net
generation
Mil. kWh
1,000
900
900
2,000
8,500
2,000
5,000
1,000
1,000
Input-
output
ratio
Mil. Btu
per mil . kWh
11,500
11,500
11,500
10,000
10,000
12,000
11,000
13,000
12,000
: Operating
: cost
Dols. per
Mi 1 . kWh
2,650
3,050
3,150
2,450
3,600
3,000
3,000
2,400
1,800
1985
capacity
MW
172
189
252
346
1,692
373
788
251
180
-- = Plant retired.
Source: Summarized from app. tables 2, 4, 5, 6, and 7 which are based on
sources shown in those tables. Input-output ratios and operating costs were
subjectively developed using historical data published by the Federal Energy
Regulatory Commission (19). One goal is to develop a reliable regression model
to estimate input-output ratios and operating costs.
including need for major modifications, lack of coal handling equipment, or insuf-
ficient space for coal unloading equipment and stockpiles. This group of units
totals 17,012 megawatts. Most are oil-fired units.
Yet another future market for coal is in private industry. Some units which
presently exist may be ordered to switch to coal or new industrial units may be
built with coal-fired capability. Table 16 describes industries which were issued
preliminary prohibition orders in May, 1977. Table 17 lists industries issued pre-
liminary construction orders in May, 1977. These industries, according to the
order, will be prohibited from burning fuels other than coal as of some future date.
These orders have changed substantially since they were issued because of changing
governmental and judicial viewpoints. Coal supply information for private industry
will not be included in scenario runs of this model. Further investigation of in-
dustrial coal use is underway. If an accurate data base can be developed, industrial
coal will be included in later scenario runs of the national model.
Coal-Fired Electricity Demand
The analysis of the demand for coal-fired electrical generation is being per-
formed by John McKean in the Economics Department at Colorado State University. His
work is accompanying the development of the simulation model. A preliminary econo-
metric approach to the problem has been defined and data essential for the analysis
collected. The demand analysis will use historical data for major U.S. Standard
Metropolitan Statistical Areas (SMSAs). l\J These SMSAs are correlated with util-
ity service areas owning the power plants defined in our 1975 and 1985 models.
ll/ An SMSA is a specified area surrounding and including a major metropolitan
ceTiTer. There are about 285 of the SMSAs in the U.S. They are defined by the U.S.
Office of Management and Budget in cooperation with the Bureau of the Census.
47
-------
Table 13--Power plants greater than 100 MW
converted to coal by 1979
State and power plant
Colorado:
Drake
Arapahoe
Cherokee
Valmont
Delaware:
Delaware City
Florida:
Crystal River
Crist
Gannon
Georgia:
McDonough
Yates
Port Wentworth
11 1 inois:
Hutsonville
Wai lace
Crawford
Fisk
Jol iet
Waukegan
Hennepin
Lakeside
Havana
Wood River
Indiana:
Michigan City
Ba i 1 ey
Mitchell
Stout
Pritchard
State Line
Iowa:
Sutherland
M.L. Kapp
Riverside
Council Bluffs
Des Moines
George Neal
Muscatine
Kansas:
Kaw
Quindaro
Lawrence
Tecumseh
Riverton
Kentucky:
Paddy's Run
Cane Run
Units
Identifying
number
5-7
1-4
1-4
5
1-3
1,2
4-7
5,6
1,2
1-7
1-4
3,4
3-7
7,8
19,20
6-8
6-8
1,2
1-7
6
4,5
2,3,12
7,8
4-6,11
5-7
3-6
3,4
1-3
1,2
3-5
1-3
6,7
1-3
5-8
1-3
1,2
4,5
7,8
7,8
1-6
1-6
: Capacity
MW
264
252
767
180
120
964
1054
552
458
1394
333
150
271
538
495
1196
774
310
161
450
503
540
590
472
651
283
536
158
237
100
781
189
987
125
171
218
553
229
91
302
983
Continued
48
-------
Table 13—Power plants greater than 100 MW
converted to coal by 1979--Continued
State and power plant
Maryland:
Wagner
Morgantown
Chalk Point
Michigan:
Weadock
Karn
St. Clair
River Rouge
Conners Creek
Trenton Channel
Minnesota:
High Bridge
Riverside
Black Dog
Aurora
Clay Boswell
Mississippi :
Daniel/Jackson Cnt.
Missouri :
Hawthorne
Blue Valley
Meramec
Lake Rd.
Nebraska:
Fremont 2
Sheldon
Kramer
North Omaha
Nevada:
Reid Gardner
Mo have
New Jersey:
BL England
Mercer
New Mexico:
San Juan
North Carolina:
Sutton
North Dakota:
Young
Heskett
Ohio:
Miami Fort
Tait
Hamil ton
Toronto
Cardinal
Units :
Identifying
number
3
1,2
1,2
7,8
1,2
1-4,6,7
2,3
15,16
7,8,9A
3-6
1,2,6-8
1-4
1,2
1-3
1
1-5
1-3
1-4
2,4
6-8
1.2
1-3
1-5
1-3
1,2
1,2
1,2
1,2
1-3
1,2
1,2
5-8
4,5
3,8,9
5-7
1-3
Capacity
MW
359
1148
788
326
550
1382
558
300
778
363
358
488
116
515
500
969
102
880
124
135
216
114
646
330
1608
299
606
656
588
648
100
1254
278
80
172
1800
Continued
49
-------
Table 13--Power plants greater than 100 MW
converted to coal by 1979--Continued
State and power plant
Oklahoma:
Muskogee
Pennsylvania:
Seward
Cromby
South Carolina:
Robinson
Canadys
McMeekin
Urquhart
Jefferies
Tennesee:
Allen
Texas:
Deely
Utah:
Gadsby
Virginia:
Chesterfield
Glen Lyn
Wisconsin:
Pul 1 iam
Weston
N. Oak Creek
S. Oak Creek
Total MW
Units :
Identifying
number
4,5
2-5
•i
1
1-3
1,2
1-3
3,4
1-3
1,2
1-3
5,6
5,6
3-8
1,2
1-4
5-8
Capacity
MW
1030
243
150
174
422
252
250
300
879
836
252
991
335
380
148
442
1034
47,633
Sources:(8).Also app. table 5.
Table 18 compares the coal supply and demand situation. The strip and under-
ground mining capacity for each CPA is listed and totaled. Also listed and totaled
is the amount of coal demanded by electrical generation plants from strip and under-
ground mines. Based upon the information in, table 18, the coal mining capacity will
be inadequate in only four CPAs: MT02, ND01, NM04, and WY01. For purposes of the
1985 base model runs, we have increased the mining capacity in these four CPAs to
meet the demand for coal from them.
Demand for coal can be divided into two major parts. The first and largest is
the coal demand of coal-fired electrical generation plants. A smaller demand for coal
is by private industry. Coal demanded by private industry will not be treated in this
study.
The demand for coal-fired electrical generation depends on total demand for elec-
tricity. The demand analysis will examine the residential demand for electricity by
formulating an econometric model which forecasts electricity demanded by residential
households to 1985. As described above, this research is based on data collected for
SMSAs. We consider a second equation to estimate demand for electricity in rural
50
-------
Table 14--Power plants able to convert
to coal with relative ease
State and power plant
Connecticut:
Devon
Monville
Norwal k Harbor
Middle town
Bridgeport Harbor
Delaware:
Edgemoor \J
Georgia:
McManus I/
Effingham _!/
11 1 inois:
Havana I/
Crane _!_/
Wagner _!/
Massachusetts:
Bray ton Point \J
Salem Harbor I/
Mt. Tom I/
Michigan:
St. Clair I/
River Rouge _!/
Minnesota:
Fox Lake I/
New Hampshire:
Schiller \J
New Jersey:
Bergen
Burl ington
Hudson
Deep water
New York:
Danskammer I/
Albany _!/
Port Jefferson I/
Arthur Kill
Astoria
Ravenswood
Lovett
Far Roc ka way
Glenwood
Oklahoma:
Mustang \J
Pennsylvania:
Southwark
Springdale
Cromby
Unit :
Identifying
number
7,8
1-5
1,2
1-3
1-3
3,4
1,2
1
1-5
1,2
1,2
1-3
1-3
1
5
1
1-3
3-6
1,2
6,7
1
1,5-7
1-4
1-4
1-4
2,3
1-5
1-3
1-5
4
4,5
1,2
1,2
7,8
2
Capacity
MW
214
182
333
420
675
249
131
163
260
384
271
1152
310
140
300
199
108
179
570
300
383
207
468
400
477
826
1438
1778
496
114
227
106
356
223
201
Present
primary
fuel
Oil
Oil
Oil
Oil
Oil
Gas
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Gas
Oil
Oil
Oil
Continued
51
-------
Table 14--Power plants able to convert
to coal with relative ease—Continued
State and power plant
Delaware
Virginia:
Chesterfield If
Portsmouth _!/
Possum Point _!/
Yorktown _!/
Total MW
Unit :
Identifying
number
7,8
2,4
3,4
1-4
1,2
--
Capacity :
MW
250
234
376
437
310
16,347
Present
primary
fuel
Oil
Oil
Oil
Oil
Oil
--
If These plants have emission limitations of 1.2 Ib. S02 per
mil. Btu or more.
Sources: (4.), May 12, 1975, and July 12 and Dec. 12, 1976;
(8); also, app. tables 5 and 7.
areas using Rural Electrification Administration data. The OBERS (joint USDA-Depart-
ment of Commerce projections) population and income data are used for both SMSAs and
rural areas.
The medium-run demand for electricity 12/ by households may be described as an
equation which relates the quantity demanded to variables such as the age of the
housing stock, the fuel used by household equipment, prices shown on typical electric
bills, climatological data, and household characteristics. Dummy variables are used
to represent other characteristics of the housing stock, the appliance stock, and the
population. If we assume that appliance stocks cannot be adjusted instanteously, a
lagged model is appropriate. Since we are applying the model to cross-section data,
serial correlation is not a problem. Fortunately the distributed lag formulation does
not expect serial correlation; therefore, the estimation process does not create it.
Other models do, in fact, create serial correlation if the data do not reflect the
serial correlation implied by the model.
Table 19 describes a preliminary list of variables for the household electricity
demand analysis. The number of customers by income class and distribution parameters
will also be included. The distribution of appliances by fuel type will be converted
into percentages within the statistical analysis program. Prices and quantities of
electricity are shown from three sources: (1) American Gas Association (AGA) data
which provide electricity prices as well as substitute fuel prices for 1975 and other
years; (2) prices computed from FERC ratios of revenues and customers; and (3) prices
estimated from typical electric bill data obtainable from the FERC. Other data on
marginal prices will be tested when it is received.
SMSAs appearing in the residential demand analysis are listed in app. table 8. A
reduced list of SMSAs is used because of data limitations. It may be possible to ex-
pand this list to cover States and utility service areas not currently represented.
App. table 8 also describes the representation of utility service areas by the SMSAs.
12/ Medium run implies that the appliance stock is fixed.
52
-------
Table 15--Power plants able to convert
to coal with difficulty
State and power plant
Arkansas:
Ritchie J./
Moses \j
Colorado:
Zuni J7
Connecticut:
Devon
Delaware:
Edgemoor \J
District of Columbia:
Benning
11 1 inois:
Collins I/
Ridgeland _!/
Wood River I/
Venice #2 \J
Maine:
Mason _!_/
Maryland:
Gould St. \J
Riverside \J
Bradon Shores _!_/
Westport \]
Massachusetts:
Somerset _!_/
West Springfield \J
Canal \J
Mystic
New Boston
Michigan:
Weadock I/
Karn \J
Morrow I/
Del ray I/
Conners Creek _!/
New Jersey:
Deepwater
Kearney
Sewaren
Sayrev i 11 e
Gilbert
New York:
Oswego I/
Northport JL/
Waterside
Unit :
Identifying
number
1,2
1,2
1,2
1,3-6
1,2
10-14
4,5
1-4
1,2,3
1-6
1-5
3
1-5
1,2
1,3,4
5,6
1-3
1
4,5,6
1,2
4-6
3,4
1-4
11-16
8-10,
12-14
3,4
7,8
1-4
1-5
1-3
1-4
1-4
4-9,
14,15
Capacity
MW
812
126
107
258
140
162
1,010
582
150
460
117
103
321
1,220
145
196
209
572
442
738
206
1,163
180
411
299
107
288
446
376
127
375
1,535
345
: Present
: primary
: fuel
Oil
Oil
Gas
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
Oil
See footnote at end of table.
Continued
53
-------
Table 15--Power plants able to convert
to coal with difficulty
State and power plant
East River
74th Street
Hudson Ave
Barrett
Ohio:
Ta i t I/
Oklahoma:
Horseshoe Lake I/
Mustang _!/
Muskogee \J
Pennsylvania:
Chester
Schuykill
Rhode Island:
Manchester
Virginia:
Chesterfield
Portsmouth
Total MW
Unit :
Identifying
number
5,6,7
3,9-11
5-8,10
1,2
1-3,7,8
4-6
3,4
3
5,6
1,3,9
9-11
1,3
1,2
JY Plants with emission limitations
Capacity
MW
426
219
459
380
148
192
387
185
124
249
139
160
216
17,012
of 1.2 Ib.
Present
primary
fuel
Oil
Oil
Oil
Oil
Oil
Gas
Gas
Gas
Oil
Oil
Oil
Oil
Oil
S00 per mil .
Btu or more.
Sources: (8j ; also app. table 5.
The demand analysis is currently in an elementary stage of development. The
residential demand analysis will be completed shortly. Future work in estimating de-
mand for coal-fired electricity generation will attempt to make use of existing models
and studies to the greatest possible degree.
1985 RESULTS
This section describes results of analyses of 1985 scenarios.
scenarios analyzed is limited because of lack of data.
The number of
1985 Base Scenario Results
The 1985 base scenario includes power plants scheduled for operation by the end
of 1985. We were able to determine the coal sources for most of these power plants
(figs. 6 and 7). The 1985 base run forces those links into the model. _13/ Therefore,
the 1985 base scenario can be described as a forced solution very similar to the 1975
13/ Strict linkage of power plant coal demands to predetermined supplies prevents
the model from reflecting opportunity costs for other supply regions.
54
-------
Figure 6
Projected Western Coal Production and Remaining Reserves
Coal
production
areas
Cumulative production 1976-1984
Billion tons
.1
.2
I
.3
I
.4
I
.5
Reserves remaining in 1985
Billion tons
10
20
30
I
40
50
I
WY2
MT4
NM1
WY3
AZ1
WY4
I
UT1
C01
ND2
NM2
ND1
ND3
C04 UT2 WY1
MT2 NM3
and 4
MT5and
others
MT (Montana)
ND (North Dakota)
1r
WY (Wyoming)
UT (Utah)
(Colorado)
AZ (Arizona)
Production data for large power plants only.
NM (New Mexico)
55
-------
Figure 7
Western Coal Production for Large Power Plants
North Dakota
1985 Projected
286 million tons
1975
65!
million
tons
Total
Arizona
56
-------
Table 16—Industries issued preliminary prohibition orders during May 1977
Name
International Paper
Fraser Paper
Chesapeake Corp.
Continental Forest Industries
E.I. DuPont deNemours
Allied Chemical
Union Carbide
Scott Paper
FMC Corp.
Avtex Fibers
Union Camp
Scott Paper
International Paper
Continental Forest Industries
Weyerhaeuser
Monsanto
Bowater
Westvaco
Brown Company
A.E. Staley Manufacturing
Marathon
International Paper
International Paper
Kennecott Copper
Location :
Jay, ME
Madawaske, ME
West Point, VA
Hopewel 1 , VA
Seaford, DE
Hopewel 1, VA
Institute, WV
Chester, PA
Fredericksburg, VA
Front Royal , VA
Savannah, GA
Mobile, AL
Vicksburg, MS
Port Wentworth, GA
Plymouth, NC
Pensacola, FL
Calhoun, TN
Charleston, SC
Parchment, MI
Decatur, IL
Robinson, IL
Texarkana, TX
Pine Bluff, AR
Salt Lake City, UT
Number of units
2
2
1
2
2
1
1
2
5
3
1
2
1
4
2
6
5
2
2
3
3
1
2
4
Source: (T), May 16, 1977.
base run. The major difference between the 1975 and the 1985 base runs is the addi-
tional power plants announced for completion before the end of 1985.
The differences between the 1975 and 1985 base solutions are described in table
20. The greatest increase in coal mining will occur in Wyoming and Utah. Coal pro-
ducing area WY01 will increase production from only 13,000 tons in 1975 to over 3
million tons in 1985. The area around Gillette (Wyo.) will increase production from
3.4 million tons in 1975 to nearly 106 million tons in 1985. The coal producing
areas in Utah will increase production from nearly 3 million tons in 1975 to nearly
26 million tons in 1985. Coal producing area UT02 increases from no production in
1975 to 9.5 million tons in 1985. Coal producing area MT04, which is the area
around Colstrip, nearly triples its production from 1975 to 1985. Total production
from all the western CPAs is projected to increase by 438 percent between 1975 and
1985. Individual CPAs which are likely to experience social and economic adjustment
problems because of the large amount of new mine development between 1975 and 1985
include C001, C004, MT04, NM01, NM02, UT01, UT02, WY02, and WY04.
57
-------
Table 17--Industries issued preliminary construction orders during May 1977
Name
Dartmouth College
Anheuser-Busch
Bellefield Boiler Plant
The Boeing Company
United States Steel
International Paper
Shell Oil
Goodyear Tire and Rubber
J. P. Stevens
Kimberly-Clark
Phillip Morris
B. F. Goodrich
Federal Paper Board
General Motors
The Upjohn Company
Anheuser-Busch
United States Steel
Republ ic Steel
United States Steel
General Motors
E.I. DuPont deNernours
Texaco
Exxon
Shell Oil
Shell Oil
Shell Oil
Fort Howard Paper
Shell Oil
Shell Oil
Standard Oil
Location :
Hanover, NH
Will iamsburg, VA
Pittsburg, PA
Ridley Township, PA
Fairfield, AL
Georgetown, SC
Mobile, AL
Gadsden, AL
Wallace, SC
Memphis, TN
Eden, NC
Louisville, KY
Riegelwood, NC
Undesignated
Kalamazoo, MI
Moor head, MN
Gary, IN
Grand River, OH
Mt. Iron, MN
Oklahoma City, OK
Deer Park, TX
Port Neches, TX
Baton Rouge, LA
Geismar, LA
Norco, LA
Deer Park, TX
Muskogee, OK
Fellows, CA
Bakersfield, CA
Oildale, CA
Number
of units
1
2
1
1
2
1
1
1
1
1
3
1
1
3
1
2
2
2
2
3
2
1
3
1
3
2
1
2
2
4
Source: (4), May 16, 1977.
Information on the amount of land disturbed is not available for the 1975 base run
because this capability is not programmed into the 1975 model. Data for 1985 are
shown in table 20. The same situation exists for tax payments. If development occurs
according to the structure of our 1985 base scenario, there will be nearly 6,000 acres
of land disturbed by coal mining in 1985. The disturbance of 6,000 acres will produce
286 million tons of coal and generate $575 million in tax revenues. The greatest
amount of land will be disturbed in Wyoming, but North Dakota, Montana, and Colorado
will also have large amounts of land disturbance. The greatest amounts of tax revenue
will be generated in Wyoming and Montana because of their larger tax rates per ton of
coal mined (fig. 8).
58
-------
Figure 8
Projected 1985 Coal Prices, Costs, and Production for Large Power Plants
(1975 Dollars)
$/ton
25
20
15
10
170
70 »* 901
-Reclamation cost
-Tax
-Extraction cost
30
330i
Utah, Colorado WY3,4
41 30
Arizona New Mexico
8 28
MT4
54
WY1.2
109
North Dakota
16
Production (Mil. tons)
-------
Table 18--Western coal supply-demand balance, 1985
CPA
AZ01
C001
C002
COOS
C004
COOS
C006
C007
MT01
MT02 I/
MT03
MT04
MT05
ND01 I/
ND02
ND03
NM01
NM02
NM03
NM04 I/
UT01
UT02
UT03
WY01 I/
WY02
UY03
WY04
Total
Mining capacity :
Strip
19,986
26,092
3,000
0
603
250
0
11,000
0
300
3,000
90,933
0
6,364
45,689
5,057
83,618
9,968
500
0
500
11,500
0
2,787
126,775
26,330
25,895
500,047
: Underground
1
0
7,080
0
0
15,139
0
3,232
363
0
0
0
0
0
0
0
0
0
0
1,716
0
32,904
17,400
0
0
0
2,500
1,600
81,934
: Total :
,000 tons
19,986
33,172
3,000
0
15,742
250
3,232
11,363
0
300
3,000
90,933
0
6,264
45,689
5,057
83,618
9,968
2,216
0
33,404
28,900
0
2,787
126,775
28,830
27,495
581,981
Strip
7,197
13,252
0
0
0
0
0
0
0
2,900
0
49,548
0
7,017
13,739
4,109
25,984
9,512
500
1,000
500
0
0
4,506
106,582
14,321
11,800
272,467
Coal demanded
: Underground
0
4,831
0
0
3,520
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
21,629
16,400
0
0
0
0
0
46,380
: Total
7,197
18,083
0
0
3,520
0
0
0
0
2,900
0
49,548
0
7,017
13,739
4,109
25,984
9,512
500
1,000
22,129
16,400
0
4,506
106,582
14,321
11,800
318.847
T7Announced capacity expansions for these CPAs are not adequate to
meet announced or assumed demand.
Source: App. table 5, also (18).
There were 246,650 million kilowatt-hours of electricity generated by power plants
using western coal in 1975. This output includes kilowatt-hours generated using non-
western coal in those power plants using both western and nonwestern coal. The output
in 1985, using the same assumption, increased 296 percent over the 1975 output to
729,000 million kilowatt-hours of electricity.
The cost of producing 246,650 million kilowatt-hours of electricity in 1975 was
$1.0183 billion. This cost includes the total cost of operation and maintenance at
each power plant and the cost of western coal as fuel. The cost of supplying
60
-------
Table 19--Preliminary list of variables for household electricity
demand analysis
Variable
AGAGP
AGAPP
AGAEP
AGA02P
AGA01 P
AGACP
POPSM
MEDAGE
MED INC
HUM75
HDD75
CDD75
AVHDD
SSPC
AVDB
AVWB
ELEV
GP60
02P60
01P60
BCP60
ACP60
CKP60
BP60
PP60
KP60
EP60
NTOT60
NGHF60
NOHF60
NCHF60
NEHF60
NPHF60
NOTHF60
NONEHF60
NGWHF60
NEWHF60
NCWHF60
NPWHF60
NOWHF60
NOTWHF60
NONEWHF6
NGCF60
NECP60
NPCF60
NOCH60
NCCF60
NOTCF60
NONECF60
NWR160
Description of variable
Gas price from AGA (household), 1975: dollars per million Btu
Propane price from AGA (household), 1975: dollars per million Btu
Electricity price from AGA (household), 1975: dollars per million
#2 fuel oil price from AGA (household), 1975: dollars per million
#1 fuel oil price from AGA (household), 1975: dollars per million
Coal price from AGA (household), 1975: dollars per million Btu
Population/square mile (possible index of apartments with
commercial rates)
Median age: years
Median income: dollars
Average humidity at 1 am for 1975: percent
Total heating degree days for 1975: days
Total cooling degree days for 1975: days
Average heating degree days for 1941-1970: days
Percent of possible sunshine in 1975: percent
Temperature exceeded 5% of the time (dry bulb thermometer): Fahr.
Temperature exceeded 5% of the time (wet bulb thermometer): Fahr.
Elevation: feet
Gas price from AGA (household), 1960: cents per therm
#2 fuel oil price from AGA (household), 1960: cents per gallon
#1 fuel oil price from AGA (household), 1960: cents per gallon
Bituminous coal price from AGA, 1960: dollars per ton
Anthracite coal price from AGA, 1960: dollars per ton
Coke price from AGA, 1960: dollars per ton
Butane price from AGA, 1960: cents per gallon
Propane price from AGA, 1960: cents per gallon
Kerosene price from AGA, 1960: cents per gallon
Electricity price from AGA, 1960: mills per kWh
Total occupied housing units, 1960
Number of houses with gas heat, 1960
Number of houses with oil or kerosene heat, 1960
Number of houses with coal or coke heat, 1960
Number of houses with electric heat, 1960
Number of houses with propane heat, 1960
Number of houses with wood or other heat, 1960
Number of houses with no heat, 1960
Number of houses with gas water heat, 1960
Number of houses with electricity water heat, 1960
Number of houses with coal or coke water heat, 1960
Number of houses with propane water heat, 1960
Number of houses with oil or kerosene water heat, 1960
Number of houses with wood or other water heating fuel, 1960
Number of houses with no water heating fuel, 1960
Number of houses with gas cooking fuel, 1960
Number of houses with electricity cooking fuel, 1960
Number of houses with propane heating fuel, 1960
Number of houses with oil or kerosene cooking fuel, 1960
Number of houses with coal or coke cooking fuel, 1960
Number of houses with wood or other cooking fuel, 1960
Number of houses with no cooking fuel, 1960
Number of houses with wringer washer, 1960
Continued
Btu
Btu
Btu
61
-------
Table 19--Preliminary list of variables for household electricity
demand analysis—Continued
Variable
Description of variable
NAUT60
NWD60
NONEW60
NGD60
NED60
NONED60
NFF60
NONEFF60
N1AC60
N2AC60
NCAC60
NONEAC60
N1TV60
N2TV60
NONETV60
TRIND75
MUNI 75
TEB50075
TEB75075
TEB10007
NDTOT70
NAC170
NAC270
NACC70
MEDR70
NRES175
NCOM75
NIND75
KWHRES75
KWHCOM75
KWHIND75
TRRES175
TRCOM75
NDWELTOT
B6970
B6568
B6064
B5059
B4049
BEARLY
NTOT70
NGHF70
NOHF70
NCHF70
NWHF70
NEHF70
NPHF70
NOTHF70
NONEHF70
NGWHF70
NOWHF70
NCWHF70
Number of houses with automatic washer, 1960
Number of houses with washer-dryer combination, 1960
Number of houses with no washer, 1960
Number of houses with gas heated clothes dryer, 1960
Number of houses with electric heated clothes dryer, 1960
Number of houses with no clothes dryer, 1960
Number of houses with one or more food freezers, 1960
Number of houses with no food freezers, 1960
Number of houses with one airconditioner, 1960
Number of houses with 2 or more airconditioners, 1960
Number of houses with central air conditioning, 1960
Number of houses with no air conditioning, 1960
Number of houses with 1 television set, 1960
Number of houses with 2 or more television sets, 1960
Number of houses with no television sets, 1960
Revenue large industrial customers, 1975 (FERC electricity)
Dummy indicating municipal retailer of electricity
Typical electric bill for 500 kWh, 1975
Typical electric bill for 750 kWh, 1975
Typical electric bill for 1000 kWh, 1975
Total number of dwellings, 1970
Number of dwellings with air conditioning in 1 room, 1970
Number of dwellings with air conditioning in 2 or more rooms, 1970
Number of dwellings with central air conditioning
Median rent
Number of residential customers, 1975 FERC
Number of commercial customers, 1975 FERC
Number of industrial customers, 1975 FERC
Residential electric consumption, 1975 FERC: 1,000 kWh
Commercial electric consumption, 1975 FERC: 1,000 kWh
Industrial electric consumption, 1975 FERC: 1,000 kWh
Revenue residential customers, 1975 (FERC electricity)
Revenue commercial customers, 1975 (FERC electricity)
Total dwellings, 1970
Dwellings constructed 1969-March 1970
Dwellings constructed 1965-1968
Dwellings constructed 1960-1964
Dwellings constructed 1950-1959
Dwellings constructed 1940-1949
Dwellings constructed 1930 or earlier
Total occupied housing units, 1970
Number of houses with gas heat, 1970
Number of houses with oil or kerosene heat, 1970
Number of houses with coal or coke heat, 1970
Number of houses with wood heat, 1970
Number of houses with electric heat, 1970
Number of houses with propane heat, 1970
Number of houses with other heat, 1970
Number of houses with no heat, 1970
Number of houses with gas water heating fuel, 1970
Number of houses with oil or kerosene water heating fuel, 1970
Number of houses with coal or coke water heating fuel, 1970
Continued
62
-------
Table 19--Preliminary list of variables for household electricity
demand analysis—Continued
Variable
Description of variable
NWWHF70 Number of houses with wood water heating fuel, 1970
NEWHF70 Number of houses with electricity water heating fuel, 1970
NPWHF70 Number of houses with propane water heating fuel, 1970
NOTWHF70 Number of houses with other water heating fuel, 1970
NONEWHF7 Number of houses with no water heating fuel, 1970
NCCF70 Number of houses with gas cooking fuel, 1970
NECF70 Number of houses with electricity cooking fuel, 1970
NPCF70 Number of houses with propane cooking fuel, 1970
NOCF70 Number of houses with oil or kerosene cooking fuel, 1970
NCCF70 Number of houses with coal or coke cooking fuel, 1970
NWCF70 Number of houses with wood cooking fuel, 1970
NOTCF70 Number of houses with other cooking fuel, 1970
NONECF70 Number of houses with no cooking fuel, 1970
NWR70 Number of houses with wringer washer, 1970
NAUT70 Number of houses with automatic washer, 1970
NONEW70 Number of houses with no washer, 1970
NGD70 Number of houses with gas heated clothes dryer, 1970
NED70 Number of houses with electricity heated clothes dryer, 1970
NONED70 Number of houses with no clothes dryer, 1970
NDW70 Number of houses with dishwasher, 1970
NONEDW70 Number of houses with no dishwasher, 1970
NFF70 Number of houses with food freezer, 1970
NONEFF70 Number of houses with no food freezer, 1970
N1TV70 Number of houses with 1 television set, 1970
N2TV70 Number of houses with 2 or more television sets, 1970
NONETV70 Number of houses with no television sets, 1970
S21 through S68 State dummies
48 dummy variables indicating State of residence
Source: (11).
nonwestern coal is not included and therefore the total cost is understated. The
national model, when completed, will include operation and maintenance costs and the
costs of supplying all coal regardless of its region of origin. Following the same
western model assumption (free nonwestern coal), the cost of producing 729,000 million
kilowatt-hours of electricity for the base 1985 scenario was $8.8203 billion, an in-
crease of 866 percent over 1975.
The 1975 base data reflect what actually happened and the 1985 base scenario re-
flects the model's initial projection based on best available information. Alternative
scenarios developed for 1985 will be compared with 1985 base solutions.
1-. 2-, and 3-Year Power Plant Construction Delay Scenarios
It is likely that all power plants announced for operation by the end of 1985 will
not be on schedule. However, it is unlikely that they will all be delayed by the same
amount of time. But since it is impossible to separate those which will be delayed
from those which will not be delayed, we will assume an equal delay for all plants.
We have arbitrarily assumed 1-, 2-, and 3-year construction delays in plant operation.
53
-------
Table 20—Base scenario results, 1975 and 1985
CPA
AZ01
C001
C002
C003
C004
C005
C006
C007
CO total
MT01
MT02
MT03
MT04
MT05
MT total
ND01
ND02
ND03
ND total
NM01
NM02
ND03
NM04
NM total
UT01
UT02
UT03
UT total
WY01
WY02
WY03
WY04
WY total
Total
Coal production
to steam plants
MOO MW
1975 : 1985
1,000 tons
7,780 8,377
3,211 12,352
0 0
0 0
0 2,865
0 0
0 0
174 333
3,385 15,550
0 0
0 0
0 0
19,893 53,716
0 0
19,893 53,716
1,479 3,255
3,323 8,593
1,392 4,327
6,194 16,175
6,002 20,043
331 7,256
0 268
0 0
6,333 27,567
2,943 16,329
0 9,567
0 0
2,943 25,896
13 3,003
3,438 105,820
12,638 17,019
2,786 13,293
18,875 139,135
65,403 286,416
1975-1985 :
Change :
*
Percent
108
385
0
0
+
0
0
191
459
0
0
0
270
0
270
220
259
311
261
334
2,192
+
0
435
555
+
0
880
23,100
3,078
135
477
737
438
H . t 7=
Land
disturbed
1985
Acres
201
689
0
0
57
0
0
6
752
0
0
0
806
0
806
244
498
260
1,002
601
254
18
0
873
317
191
0
508
30
952
460
226
1,668
5,809
: Tax
: payments
: 1985
Mil. Dols.
27.9
12.0
0
0
3.2
0
0
0.4
15.6
0
0
0
188.5
0
188.5
2.3
6.2
3.1
11.6
15.0
5.3
0.2
0
20.5
5.6
3.0
0
8.6
5.3
176.7
65.0
55.6
302.6
575.3
64
-------
The first alternative scenario assumes that all plants scheduled to begin oper-
ation in 1985 will be delayed 1 year. The additions which they are scheduled to make
to electrical generation capacity will be assumed not to occur- The specific power
plants which are assumed not to become operational by 1985 are shown in table 21.
Table 22 describes the results of this 1-year delay and compares it with the 1975
and 1985 base runs described earlier. Delaying the construction of 1985 plants 1 year
causes a decrease in coal production in C001, MT04, ND02, UT01, UT02, and WY02. The
decreases in production levels are most noticeable in ND02 and UT02. Production in
ND02 will be approximately 25 percent less than the 1985 base scenario. Production in
UT02 will be approximately 33 percent less under the 1-year construction delay
Table 21--Data for 1-, 2-, and 3-year power plant construction
delay scenarios
I CAR
code
6002
6045
6046
7022
7023
7025
7028
7037
7039
7040
8013
8016
8017
8018
8019
9037
8020
9038
8021
9039
8022
9040
9027
6047
9029
9031
9033
9034
9036
: Power plants —
;
Sherburne Co.
Brookston
Antelope Valley
Jeffrey Energy Ctr
White Bluff
Big Cajun
Rodemacher
Unsited
Unsited
Nel son
South Plains
Unsited
Unsited
Unnamed
Unsited
Unsited
Unsited
Future
Unnamed
Pioneer
Unnamed
Springville
Nixon
Coyote
North Valmy
Laramie River
Allen
Garfield
Intermountain Power
MN
MN
ND
KS
AK
LA
LA
AK
AK
LA
TX
TX
TX
TX
TX
CA
TX
CO
TX
ID
TX
AZ
CO
MT
NV
WY
NV
UT
UT
Total
capacity
1985
3,680
800
450
2,880
2,800
1,620
1,020
700
700
540
950
750
750
750
750
800
750
1,000
200
500
200
330
750 '
410
500
1,500
2,000
1,000
2,250
Scheduled
1985 :
—
—
—
-- '
—
540
--
700
540
—
—
—
—
—
—
--
500
—
—
200
—
200
410
—
—
500
500
750
Operation
1984
MW
800
—
450
720
--
--
--
—
—
__
475
—
—
—
750
—
--
—
200
—
—
330
—
—
--
—
500
—
750
date
: 1983
__
800
--
--
700
--
510
700
—
-_
—
750
750
750
—
800
750
500
—
500
--
--
350
--
250
500
500
—
750
-- = Not applicable
\J Subject to delay past scheduled operating date.
Source: Calculated from app. tables 5 and 7.
65
-------
Table 22—Comparison of 1985 scenarios with 1975 and 1985 base solutions
CPA
AZ01
C001
C002
COOS
C004
C005
C006
C007
CO total
MT01
MT02
MT03
MT04
MT05
MT total
ND01
ND02
ND03
ND total
NM01
NM02
NM03
NM04
NM total
UT01
UT02
UT03
UT total
WY01
WY02
WY03
WY04
WY total
Total
1975 base :
7,780
3,211
0
0
0
0
0
174
3,385
0
0
0
19,893
0
19,893
1,479
3,323
1,392
6,194
6,002
331
0
0
6,333
2,943
0
0
2,943
13
3,438
12,638
2,786
18,875
65,403
Cost (bil. dols.) 1.0183
Output (mil. kWh) 246,650
Coal
1985 base :
1,
8,377
12,352
0
0
2,865
0
0
333
15,500
0
0
0
53,716
0
53,716
3,255
8,593
4,327
16,175
20,043
7,256
268
0
27,567
16,329
9,567
0
25,896
3,003
105,820
17,019
13,293
139,135
286,416
8.8203
729,900
production
1
000 tons
8,377
10,514
0
0
2,865
0
0
333
13,712
0
0
0
52,833
0
52,833
3,255
6,634
4,327
14,216
20,043
7,256
268
0
27,567
15,186
5,909
0
21,095
3,003
99,908
17,019
13,293
133,223
271,023
8.3560
701,111
Scenario
: 2
8,377
10,514
0
0
2,865
0
0
333
13,712
0
0
0
49,693
0
49,693
3,255
4,675
4,327
12,257
15,193
7,256
268
0
22,717
14,043
3,655
0
17,698
3,003
97,115
17,019
13,293
130,430
254,884
7.8652
667,716
: 3
8,377
8,280
0
0
2,865
0
0
333
11,478
0
0
0
46,895
0
46,895
3,255
4,675
4,327
12,257
11,261
7,256
268
0
18,785
10,233
1,472
0
11,705
3,003
86,837
17,019
13,293
120,152
229,649
6.9791
615,116
Source: Computer printouts from project.
66
-------
scenario. Electricity output decreases to 701,111 million kilowatt-hours. Total cost
decreases approximately one-half billion dollars.
The second alternative scenario assumes that all plants scheduled to begin oper-
ation in 1984 and 1985 will be delayed 2 years. The additions which they are sched-
uled to make to electrical generation capacity are deleted from the 1985 calculations.
The specific power plants assumed not to become operational by 1985 are shown in
table 21. Table 22 describes the results of this 2-year delay and compares it with
the 1975 and 1985 base runs. Delaying the construction of scheduled 1984 and 1985
plants by 2 years causes a decrease of coal production in MT04, ND02, NM01, UT01,
UT02, and WY02. These decreases are in addition to decreases caused by the 1-year
delay scenario. The decreases in coal production will be most noticeable in North
Dakota and Utah. Production in ND02 will decrease approximately 33 percent and pro-
duction in Utah will decrease approximately 20 percent with most of the decrease
coming in UT02. Electricity output decreases to 667,716 million kilowatt-hours.
Total cost decreases approximately $1 billion from the 1985 base scenario.
The third alternative scenario assumes that all plants scheduled to begin oper-
ation in 1983, 1984, and 1985 will be delayed 3 years. The additions which they are
scheduled to make to electrical generation capacity are deleted from 1985 calcula-
tions. The specific power plants assumed not to become operational by 1985 are shown
in table 21. Table 22 describes the results of this 3-year delay and compares it
with the 1975 and 1985 base runs. Delaying the construction of scheduled 1983, 1984,
and 1985 plants by 3 years causes a decrease in coal production in C001, MT04, NM01,
UT01, UT02, and WY02. These decreases are in addition to decreases caused by the 2-
year delay scenario. The decreases in coal production will be most noticeable in New
Mexico and Utah, but especially in Utah where production drops from 17.7 million tons
under the 2-year delay scenario to 11.7 million tons under the 3-year delay scenario.
Arizona and North Dakota are unaffected by this 3-year delay scenario. The CPA WY02
loses 10 million tons of production, but it is from a level which is high enough that
the decrease may not be noticeable. Electricity output decreases to 615,116 million
kilowatt-hours. Total cost decreases approximately $1 billion from the 2-year delay
scenario.
67
-------
REFERENCES
(1) Ayres, Ronald F. Coal: New Markets/New Prices. Prepared by Battelle Columbus
Laboratories for McGraw-Hill Publishing Co., 1977.
(2) Coal Age. Feb. 1978. McGraw-Hill Publishing Co.
(3) Coal Outlook. Various issues 1976-79. Pasha Publications.
(4) Coal Week. Various issues 1976-79. McGraw-Hill Publishing Co.
(5) Ebeling, Kenneth and Norman Dalsted. Assessment of Costs of Various Inter-
regional Energy Transportation Systems, Phase I Progress Report. Agri-
cultural and Engineering Experiment Stations, North Dakota State University,
1978. Also, data tapes and other data supplied by Ebeling concerning coal
transportation and costs. This data based on sources cited in the above report.
(Unpublished manuscript)
(6) Electrical World. Various issues. McGraw-Hill Publishing Co.
(7) Hamilton, Patrick A., D. H. White, Jr., and Thomas K. Matson. The Reserve
Base of U.S. Coals by Sulfur Content. Part 2, The Western States. U.S.
Department of the Interior, Bureau of Mines, Information Circular 8703, 1976.
(8) ICF, Inc., Memorandum, Aug. 30, 1979, "Preliminary List of Plants Which Could
Reconvert to Coal." Memorandum transmitted to the President's Coal Commission.
(9) Kania, John J., and John W. Green. User Guide to ESCS Coal Data File and
Retrieval System. U.S. Department of Agriculture; Economics Statistics, and
Cooperatives Service; August 1977. (Unpublished manuscript)
(10) Leathers, Kenneth. Costs of Strip Mine Reclamation in the West. U.S. Depart-
ment of Agriculture; Economics, Statistics, and Cooperatives Service; Rural
Development Research Report No. 19, 1980.
(11) McKean, John R. Modelling the Residential Demand for Electricity. Colorado
State University, 1978.(Unpublished manuscript)
(12) National Coal Association. Steam Electric Plant Factors. Annual issues.
(13) Stinson, Thomas F., and Stanley W. Voelker. Coal Development in the Northern
Great Plains: The Impact on Revenues of State and Local Government. U.S.
Department of Agriculture; Economics, Statistics, and Cooperatives Service;
Agricultural Economic Report No. 394, Jan. 1978.
(14) Stinson, Thomas F. State Taxation of Mineral Deposits and Production. U.S.
Department of Agriculture; Economics, Statistics, and Cooperatives Service;
Rural Development Research Report No. 2, Sept. 1978.
(15) Teknekron, Inc. An Integrated Technology Assessment of Electric Utility Energy
System. (Unpublished manuscript)
(16) U.S. Department of Energy (formerly Federal Energy Administration). Trends
In Power Plant Capacity and Utilization—Inventory of the Power Plants in the
U.S. Dec. 1976.
68
-------
(17) U.S. Department of Energy, Federal Energy Regulatory Commission (formerly
Federal Power Commission). Data tapes from Form 423 reports (and Form 423
reports themselves) submitted by electric utilities. For 1975 and 1976.
(18) U.S. Department of Energy, Federal Energy Regulatory Commission (formerly
Federal Power Commission). Status of Coal Supply Contracts for New Electric
Generating Units. Annual issues, 1976 and 1977.
(19) U.S. Department of Energy, Federal Energy Regulatory Commission (formerly
Federal Power Commission). Steam Electric Plant Construction Costs and Annual
Production Expenses. Issues from 1965 through 1974.
(20) U.S. Department of the Interior, Bureau of Mines. Methods and Costs of Coal
Refuse Disposal and Reclamation. Information Circular 8576, 1973.
(21) U.S. Department of the Interior, Bureau of Mines. Projects to Expand Fuel
Sources in Western States. Information Circular 8719, May 1976.
(22) U.S. Department of the Interior, Bureau of Mines. Projects to Expand
Fuel Sources in Eastern States. Information Circular 8725. June 1976.
(23) U.S. Interstate Commerce Commission. Coal Tariffs.
(24) Whetzel, Virgil, and others. Northern Great Plains Resources and Coal Develop-
ment. U.S. Department of Agriculture; Economics, Statistics, and Cooperatives
Service; Working Paper No. 29, Apr. 1977. (Unpublished manuscript)
(25) Whetzel, Virgil, and others. Resources of Rocky Mountain States and Coal
Development. U.S. Department of Agriculture; Economics Statistics, and Co-
operatives Service; Apr. 1978. (Unpublished manuscript)
69
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975
I CAM
code
4006
4052
4014
4014
4053
4054
4011
4030
4005
4005
9014
9002
9016
9006
9011
9013
9009
FERC
code
004500-0200
004500-0400
477000-0900
477000-0905
004500-0500
004500-0450
004500-0600
004500-0800
477000-3800
477000-3805
017000-0200
433000-0750
406000-0200
406000-0600
406000-0650
108000-0100
108500-0100
State and plant name
Alabama
Barry
Chickasaw
Colbert A
Colbert B
Gadsden
Gaston
Gorgas
Greene County
Widows Creek A
Widows Creek B
Arizona
Choi la
Navajo 1-3
Colorado
Arapahoe
Cherokee
Comanche
Drake
Hayden
beginning 1976
Ownership
share
Percent
100.0
100.0
100.0
100.0
100.0
73.6
26.4
100.0
60.0
40.0
100.0
100.0
100.0
21.7
24.3
21.2
14.0
11.3
7.5
100.0
100.0
100.0
100.0
100.0
47.3
52.7
Owning
utility system
Alabama Power Company
Alabama Power Company
Tennessee Valley Authority
Tennessee Valley Authority
Alabama Power Company
Alabama Power Company
Georgia Power Company
Alabama Power Company
Alabama Power Company
Mississippi Power Company
Tennessee Valley Authority
Tennessee Valley Authority
Arizona Public Service
Salt River Project
Bureau of Reclamation
Los Angeles Dept. of
Water and Power
Arizona Public Service
Nevada Power Company
Tucson Gas and Electric
Public Service of Colorado
Public Service of Colorado
Public Service of Colorado
Colorado Springs Dept. of
of Public Utilities
Colorado-Ute Electric Assn.
Salt River Project
Colorado-Ute Electric Assn.
Continued
-------
Appendix table 1—ICAM power plants, codes, and ownership, 1975--Continued
ICAM
code
9019
2014
4023
4032
4022
4041
4040
4001
4019
4007
4029
4047
4020
4012
5002
5010
5014
5032
5034
5036
5013
5016
FERC
code
406000-1200
120500-0300
474000-0300
195000-0100
474000-0100
195000-0300
179000-0100
179000-2800
179000-0900
179000-1000
179000-0200
179000-2500
179000-2550
179000-2600
222500-0800
078500-0100
111500-3000
457000-0100
457000-0200
111500-0400
079000-0100
111500-0100
State and plant name
Col orado-continued
Valmont
Delaware
Indian River
Florida
Big Bend
Crist
Gannon
Smith
Georgia
Arkwright
Bowen
Hammond
Harllee Branch
McDonough-Atkinson
Mitchell
Wansley
Yates
Illinois
Baldwin
Coffeen
Crawford
Oallman
Lakeside
Di xon
Edwards
Fisk
Ownership
share
Percent
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
Owning
utility system
Public Service of Colorado
Delmarva Power and Light
Tampa Electric
Gulf Power
Tampa Electric
Gulf Power
Georgia Power
Georgia Power
Georgia Power
Georgia Power
Georgia Power
Georgia Power
Georgia Power
Georgia Power
Illinois Power
Central Illinois Public
Commonwealth Edison
Springfield Water Light
Springfield Water Light
Commonwealth Edison
Central Illinois Light
Commonwealth Edison
Continued
Service
and Power
and Power
-------
Appendix table 1--ICAM power plants, codes, and ownership, i975--Continued
I CAM
code
5030
5024
5027
5003
5009
5006
5023
5004
5028
5031
5025
5011
5007
5018
3045
3056
3027
3015
3061
3100
3047
3043
3046
3050
3102
3034
3073
3083
FERC
code
078500-0200
222500-0300
078500-0300
111500-1000
145500-0100
111500-1100
078500-0400
111500-1300
512500-1100
222500-0600
079500-0400
111500-1600
111500-1700
222500-0700
345500-0100
225000-0200
404500-0900
225500-0100
452000-0100
404500-0200
404500-0600
404500-0250
345500-0400
345500-0300
404500-0500
226000-0500
226000-0200
216800-0100
State and plant name
Illinois-continued
Grand Tower
Hennepin
Hutsonvil le
Jol iet
Joppa
Kincaid
Meredosia
Power ton
Venice #2
Vermil ion
Wallace
Waukegan
Will County
Wood River
Indiana
Bailly
Breed
Cayuga
Clifty Creek
Culley
Ed ward sport
Gal lagher
Gibson Station
Michigan City
Mitchell
Noblesville
Petersburg
Pritchard
Ratts
Ownership
share
Percent
100.0
100.0
100.0
100.0
20.0
20.0
40.0
20.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
Owning
utility system
Central Illinois Public Service
Illinois Power
Central Illinois Public Service
Commonwealth Edison
Illinois Power
Kentucky Utilities Company
Union Electric
Central Illinois Public Service
Commonwealth Edison
Central Illinois Public Service
Commonwealth Edison
Union Electric
Illinois Po.wer
Central Illinois Light
Commonwealth Edison
Commonwealth Edison
Illinois Power
Northern Indiana Public Service
Indiana and Michigan Electric
Public Service of Indiana
Ohio Valley Electric Corp.
Southern Indiana Gas and Electric
Public Service of Indiana
Public Service of Indiana
Public Service of Indiana
Northern Indiana Public Service
Northern Indiana Public Service
Public Service of Indiana
Indianapolis Power and Light
Indianapolis Power and Light
Indiana Statewide Rural Elec. Coop
Continued
-------
Appendix table 1—ICAM power plants, codes, and ownership, l975--Continued
ICAM
code
3029
3037
3023
3030
3033
6019
6026
6021
6001
6016
6030
6027
6015
6020
6024
7010
7002
7003
7011
FERC
code
111000-0100
226000-0100
225000-0700
404500-0800
452000-0500
230500-0200
230000-0100
230000-0200
229500-0800
227000-0800
229500-1300
326000-0100
228500-2100
229000-0300
228500-2600
242000-0100
241500-0250
484500-0500
149000-0300
State and plant name
Indiana-continued
State Line
Stout
Tanners Creek
Uabash River
Warrick
Iowa
Burl ington
Council Bluffs
Des Moines #2
George Neal
projected 79
Kapp
Maynard
Muscatine
Prairie Creek
Riverside
Sutherland
Kansas
Kaw River
LaCygne 1 & 2
Lawrence
Riverton
Ownership
share
Percent
100.0
100.0
100.0
100.0
23.4
76.6
100.0
100.0
100.0
15.2
14.7
12.1
58.0
48.2
17.4
8.7
25.7
100.0
100.0
100.0
100.0
100.0
100.0
100.0
50.0
50.0
100.0
100.0
Owning
utility system
Commonwealth Edison
Indianapolis Power and Light
Indiana and Michigan Electric
Public Service of Indiana
Southern Indiana Gas and Electric
Aluminum Company of America
Iowa Southern Utilities
Iowa Power and Light
Iowa Power and Light
Iowa-Illinois Gas and Electric
Iowa Southern Utilities
Iowa Power and Light
Iowa Public Service
Iowa Public Service
Interstate Power
Northwestern Public Service
Several small Iowa Cooperatives
Interstate Power
Iowa Public Service
Muscatine Power and Water
Iowa Electric Light and Power
Iowa-Illinois Gas and Electric
Iowa Electric Light and Power
Kansas City Bd. of Public Utilities
Kansas Gas and Electric Co.
Kansas City Power and Light
Kansas Power and Light
Empire District Electric
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975--Continued
ICAM
code
FERC
code
State and plant name
Ownership
share
Owning
utility system
Percent
7006 483500-0700
3024
3038
3028
3057
3067
3089
3052
3080
3040
3068
3003
3007
3062
3097
2005
3051
2004
3088
2013
1001
1012
1015
245000-0100
245500-0200
275500-0200
041000-0050
141500-0100
141500-0200
245500-0250
245500-0300
275500-0600
275500-0400
477000-3000
477000-3200
367000-0100
245500-0600
041000-0100
394500-0300
394500-0400
394500-0600
386500-0300
026500-0300
334000-0200
314000-0100
334000-1200
Kansas-continued
Tecumseh 100.0
Kentucky
Big Sandy 100.0
Brown, E.W. 100.0
Cane Run 100.0
Coleman 100.0
Cooper 100.0
Dale 100.0
Ghent 1 100.0
Green River 100.0
Mill Creek 100.0
Paddys Run 100.0
Paradise 100.0
Shawnee 100.0
Smith 100.0
Tyrone 100.0
Reid, Robert (Station II) 18.9
81.1
Maryland
Chalk Point 100.0
Dickerson 100.0
Morgantown 100.0
Smith 100.0
Wagner 100.0
Massachusetts
Brayton Point 100.0
Somerset 100.0
Salem Harbor 100.0
Kansas Power and Light
Kentucky Power
Kentucky Utilities
Louisville Gas and Electric
Big Rivers Rural Electric Coop.
East Kentucky Power Coop., Inc.
East Kentucky Power Coop., Inc.
Kentucky Utilities
Kentucky Utilities
Louisville Gas and Electric
Louisville Gas and Electric
Tennessee Valley Authority
Tennessee Valley Authority
Owensboro Municipal Utilities
Kentucky Utilities
Big Rivers Rural Electric Coop.
Henderson Municipal Light Dept.
Potomac Electric Power
Potomac Electric Power
Potomac Electric Power
Potomac Edison
Baltimore Gas and Electric
New England Electric System
Montaup Electric Company
New England Electric System
Continued
-------
Appendix table 1—ICAM power plants, codes, and ownership, 1975--Continued
ICAM
code
3041
3055
3054
3065
3094
3099
6024
6028
6008
6007
6031
6010
6025
6005
6011
FERC
code
114500-1900
1 14500-0400
482000-0200
260500-0100
260500-0100
482000-0700
228500-2600
307000-0100
347000-0300
307000-0300
227000-0400
347000-1300
365000-1400
347000-1400
347000-2700
State and plant name
Michigan
Campbel 1
Cobb
Conners Creek
Eckert
Erickson 1
Harbor Beach
Sutherland
Minnesota
Aurora (Syl La skin)
Black Dog
Boswel 1
Fox Lake
High Bridge
Hoot Lake
King
Riverside
Ownership
share
Percent
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
Owning
utility system
Consumers Power
Consumers Power
Detroit Edison
Lansing Board of Water and Light
Lansing Board of Water and Light
Detroit Edison
Iowa Electric Light and Power
Minnesota Power and Light
Northern States Power
Minnesota Power and Light
Interstate Power
Northern States Power
Otter Tail Power
Northern States Power
Northern States Power
4015 308000-0400
7008
7014
5037
7013
7001
5019
7007
5001
7012
149000-
099500-
109000-
241500-
241500-
021000-
101000-
512500-
460000-
0400
0100
0100
0100
0200
0100
0100
1200
0200
Mississippi
Watson
Missouri
As bury
Blue Valley
Columbia
Grand Avenue
Hawthorne
Thomas Hill
James River
Labadie
Lake Road
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
Mississippi Power
Empire District Electric
Independence Power and Light
Columbia Water and Light
Kansas City Power and Light
Kansas City Power and Light
Associated Electric Coop.
Springfield City Utilities
Union Electric
St. Joseph Light and Power
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975--Continued
I CAM
code
5012
7004
5015
7005
5008
9020
6013
6029
6004
6017
9017
9003
FERC
code
512500-0400
241500-0300
021000-0200
309500-0700
512500-0700
484500-0700
484500-0250
331500-0400
357000-0200
331500-1100
333000-0300
450500-4500
State and plant name
Missouri-continued
Meramec
Montrose
New Madrid 1 & 2
Sibley
Sioux
Montana
Corette
Col strip
projected 1981
Nebraska
Kramer
North Omaha
Sheldon
Nevada
Gardner
Mohave
Ownership
share
Percent
100.0
100.0
100.0
100.0
100.0
100.0
50.0
50.0
30.0
20.0
20.0
15.0
10.0
5.0
100.0
100.0
100.0
100.0
56.0
20.0
14.0
10.0
Owning
utility system
Union Electric
Kansas City Power and Light
New Madrid Municipal Light
and Power Dept.
Missouri Public Service
Union Electric
Montana Power
Montana Power
Puget Sound Power and Light
Montana Power
Puget Sound Power and Light
Portland General Electric
Washington Water Power
Pacific Power and Light
Uncommitted
Nebraska Public Power District
Omaha Public Power District
Nebraska Public Power District
Nevada Power
Southern California Edison
Los Angeles Dept. of Water and Power
Nevada Power
Salt River Project
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975--Continued
ICAM
code
FERC
code
State and plant name
Ownership
share
Owning
utility system
1004 405000-1100
2016
2006
9001
9012
1003
1009
1008
1002
1005
1007
1006
4016
4036
022000-0100
405500-0500
2007 405500-1100
017000-0300
403500-0350
341000-
339000-
339000-
341000-
339000-
422000-
422000-
8000
0600
0700
7900
1400
•0500
•0700
129500-0200
072000-0100
New Hampshire
Merrimack
New Jersey
England
Hudson
Mercer
New Mexico
Four Corners
San Juan
New York
Dunkirk
Goudey
Greenidge
Huntley
Mil liken
Rochester 3 (Beebee)
Rochester 7 (Russell)
North Carolina
Allen
Asheville
Percent
100.0
100.0
100.0
100.0
38.8
9.4
5.0
5.0
7.2
34.6
50.0
50.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
Public Service of New Hampshire
Atlantic City Electric
New Jersey Public Service
Electric and Gas
New Jersey Public Service
Electric and Gas
Arizona Public Service
Public Service of New Mexico
El Paso Electric
Tucson Gas and Electric
Salt River Project
Southern California Edison
Public Service of New Mexico
Tucson Gas and Electric
Niagara Mohawk Power
New York State Electric and Gas
New York State Electric and Gas
Niagara Mohawk Power
New York State Electric and Gas
Rochester Gas and Electric
Rochester Gas and Electric
Duke Power
Carolina Power and Light
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975 —Continued
I CAM
code
4003
4033
4037
4025
4043
4035
4004
4028
4008
4027
4050
6032
6003
6023
6014
3079
3058
3026
3042
3019
3049
3017
3020
FERC
code
339500-0250
139500-0500
072000-0300
139500-0800
139500-1000
072000-0500
139500-2200
139500-2600
072000-0900
072000-1000
072000-1300
313000-0500
031000-0100
513500-0100
307500-0550
488000-0100
104000-0100
104000-0200
488000-0200
480500-0300
354500-0500
109500-0200
070000-0100
State and plant name
North Carolina-continued
Belews Creek 1 & 2
Buck
Cape Fear
Cliff side
Dan River
Lee
Marshall
Riverbend
Roxboro
Sutton
Weatherspoon
North Dakota
Heskett
Lei and Olds
Stanton
Young, Milton
Ohio
Acme
Ashtabula
Avon Lake
Bay Shore
Beckjord
Burger
Conesville
Cardinal
Ownership
share
Percent
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
76.4
18.9
4.7
100.0
28.7
60.4
10.9
50.0
Owning
utility system
Duke Power
Duke Power
Carolina Power and Light
Duke Power
Duke Power
Carolina Power and Light
Duke Power
Duke Power
Carolina Power and Light
Carolina Power and Light
Carolina Power and Light
Montana-Dakota Utilities
Basin Electric Power Coop
United Power Association
Minnkota Power Coop
Toledo Edison
Cleveland Electric Illuminating
Cleveland Electric Illuminating
Toledo Edison
Cincinnati Gas and Electric
Dayton Power and Light
Columbus and South Ohio Electric
Ohio Edison
Columbus and Southern Ohio Electric
Cincinnati Gas and Electric
Dayton Power and Light
Ohio Power Company
Continued
-------
Appendix table 1—ICAM power plants, codes, and ownership, 1975—Continued
•vj
vo
ICAM
code
3018
3087
3002
3064
3025
3095
3053
3032
3013
3081
3075
3092
3084
3005
3004
3077
3085
3090
3101
3066
2002
3048
3010
FERC
code
104000-0300
354500-0100
354575-0500
481500-0300
356000-0100
103500-0200
104000-0400
480500-0200
355000-0200
354500-0400
355000-0300
109500-0500
109500-0600
354500-0700
481500-0400
481500-0200
355000-0400
354500-0600
362000-0100
542000-0100
380000-0200
140000-0600
379500-1500
State and plant name
Ohio-continued
East Lake
Edgewater
Gavin
Hutch ings
Kyger Creek
Lake Road
Lake Shore
Miami Fort
Muskingum River
Niles
Philo
Picway
Poston
Sammis
Stuart
Tait
Tidd
Toronto
Vine Street
Pennsylvania
Armstrong
Brunner Island
Cheswick
Conemaugh
Ownership
share
Percent
50.0
83.1
16.9
100.0
100.0
100.0
100.0
100.0
100.0
21.1
78.9
100.0
100.0
100.0
100.0
100.0
86.8
7.9
5.3
39.0
35.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
16.5
22.5
Owning
utility system
Buckeye Power Coop., Inc.
Cleveland Electric Illuminating
Duquesne Light Company
Ohio Edison
Ohio Electric
Dayton Power and Light
Ohio Valley Electric Coop.
Cleveland Division of Light and Power
Cleveland Electric Illuminating
Dayton Power and Light
Cincinnati Gas and Electric
Ohio Power
Ohio Edison
Ohio Power
Columbus and Southern Ohio Electric
Columbus and Southern Ohio Electric
Ohio Edison
Duquesne Light Company
Pennsylvania Power
Cincinnati Gas and Electric
Dayton Power and Light
Dayton Power and Light
Ohio Power
Ohio Edison
Orrville Municipal Utilities
West Penn Power
Pennsylvania Power and Light
Duquesne Light
Metropolitan Edison
New Jersey Public Service Electric
and Gas
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975--Continued
oo
o
ICAM
code
2020
2018
2008
3060
2019
3008
3016
2001
2015
3076
2003
2009
3071
2012
3098
3044
2010
FERC
code
303500-0100
384000-0300
384000-0500
140000-0200
379500-0300
542000-0600
379500-0350
379500-0400
380000-0800
542000-0400
380000-1300
380500-0100
140000-0300
303500-0300
379500-1000
379500-1100
380000-1000
State and plant name
Pennsylvania-continued
Crawford
Cromby
Eddystone
El rama
Front Street
Ha tfi eld's Ferry
Homer City
Keystone
Martins Creek
Mitchell
Montour
New Castle
Phillips
Portland
Sewa rd
Shawville
Sunbury
Ownership
share
Percent
11.4
20.7
3.8
10.6
3.7
1.1
9.7
100.0
100.0
100.0
100.0
100.0
20.0
27.5
52.5
50.0
50.0
22.8
21.0
12.4
16.7
2.4
21.0
3.7
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
Owning
utility system
Pennsylvania Power and Light
Philadelphia Electric Co.
Atlantic City Electric
Baltimore Gas and Electric
Oelmarva Power and Light
UGI Corporation
Potomac Electric Power
Metropolitan Edison
Philadelphia Electric
Philadelphia Electric
Duquesne Light
Pennsylvania Electric
The Potomac Edison Co.
Monongahela Power Co.
West Penn Power
New York State Electric and Gas Corp
Pennsylvania Electric
New Jersey Public Service Electric
and Gas
Philadelphia Electric Co.
Pennsylvania Power and Light
Jersey Central Power and Light
Atlantic City Electric
Baltimore Gas and Electric
Delmarva Power and Light
Pennsylvania Power and Light
West Penn Power
Pennsylvania Power and Light
Pennsylvania Power Company
Duquesne Light
Metropolitan Edison
Pennsylvania Electric
Pennsylvania Electric
Pennsylvania Power and Light
Continued
-------
Appendix table 1—ICAM power plants, codes, and ownership, 1975--Continued
ICAM
code
FERC
code
State and plant name
Ownership
share
Owning
utility system
2017 303500-0400
00
4043
4051
4040
4038
4039
4048
4045
4025
4042
6009
4018
4021
4002
4010
4013
4009
4024
4046
8001
447500-0400
448000-0100
448000-0200
139500-1900
447500-0900
072000-0400
447500-1600
447500-1700
448000-0075
365500-0250
477000-
477000-
477000-
477000-
477000-
477000-
477000-
477000-
0100
0500
4100
1400
1900
•2100
•1800
•3600
Pennsylvania-continued
Titus
South Carolina
Canadys
Grainger
Jefferies
Lee
McMeekin
Robinson
Urquhart
Wateree
Winyah (Georgetown)
South Dakota
478500-0250
Big Stone
Tennessee
Allen
Bull Run
Cumberland
Gal latin
Johnsonville
Kingston
Sevier
Watts Bar
Texas
Big Brown
Percent
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
47.5
32.5
20.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
33.3
Metropolitan Edison
South Carolina
South Carolina
South Carolina
Duke Power
South Carolina
Carolina Power
South Carolina
South Carolina
South Carolina
Electric and Gas
Public Service Authority
Public Service Authority
Electric and Gas
and Light
Electric and Gas
Electric and Gas
Public Service Authority
Otter Tail Power Company
Northwestern Public Service
Montana-Dakota Utilities
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Valley
Valley
Valley
Valley
Valley
Valley
Valley
Valley
Authority
Authority
Authority
Authority
Authority
Authority
Authority
Authority
Dallas Power and Light
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975--Continued
OO
ho
I CAM
code
5002
9018
9015
9010
4044
4017
3035
3069
4031
9004
FERC
code
478500-0575
517000-0500
517000-1000
517000-1450
525000-0200
525000-0300
014000-0500
014000-0600
394500-0500
370500-0450
State and plant name
Texas-continued
Monticello
projected 1978
Utah
Carbon
Gadsby
Huntington Canyon
Virginia
Bremo Bluff
Chesterfield
Cl inch River
Glen Lyn
Potomac River
Washington
Central i a
Ownership
share
Percent
33.3
33.3
20.0
50.0
30.0
50.0
50.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
47.5
15.0
8.0
7.0
2.5
8.0
8.0
4.0
Owning
utility system
Texas Power and Light
Texas Electric Service
Dallas Power and Light
Texas Power and Light
Texas Electric Service
Texas Power and Light
Texas Electric Service
Utah Power and Light
Utah Power and Light
Utah Power and Light
Virginia Electric and Power
Virginia Electric and Power
Appalachian Power
Appalachian Power
Potomac Electric Power
Pacific Power and Light
Washington Water Power
Seattle Dept. of Lighting
Puget Sound Power and Light
Portland General Electric Co.
City of Tacoma
Snohomish Co. Public Utility
District
Grays Harbor Co. Public Utility
District
Continued
-------
Appendix table 1—ICAM power plants, codes, and ownership, 1975--Continued
00
ICAM
code
3072
3011
3093
3022
3006
3036
3059
3012
3009
3021
3096
3082
6022
5029
5017
5020
6012
6018
5005
FERC
code
311000-0100
014000-1200
014000-0300
311000-0200
311000-0500
355000-0100
014000-0700
355000-0600
525000-0700
081000-0100
311000-0300
311000-0400
126000-0100
283500-0100
554000-0250
554000-0300
126000-0450
554000-0600
553000-0400
State and plant name
West Virginia
Albright
Amos
Cabin Creek
Fort Martin
Harrison
Kammer
Kanawha River
Mitchell-Captina
Mount Storm
P. Sporn
Rivesville
Willow Island
Wisconsin
Alma
Blount
Columbia
projected 1978
Edgewater
Genoa 3
Mel son Dewey
Oak Creek, North
Ownership
share
Percent
24.8
75.2
29.6
70.4
100.0
50.0
25.0
25.0
25.0
50.0
25.0
100.0
100.0
100.0
100.0
71.2
28.8
100.0
100.0
100.0
100.0
38.9
39.3
21.8
39.3
60.7
23.4
76.6
100.0
100.0
100.0
Owning
utility system
Potomac Edison Co.
Monogahela Power
Ohio Power Company
Appalachian Power
Appalachian Power
West Penn Power
Monongahela Power
Potomac Edison Co.
Monongahela Power
West Penn Power Co.
Potomac Edison Co.
Ohio Power
Appalachian Power
Ohio Power
Virginia Electric and Power
Ohio Power Co.
Appalachian Power
Monongahela Power
Monongahela Power
Dairyland Power Coop.
Madison Gas and Electric
Wisconsin Public Service
Wisconsin Power and Light
Madison Gas and Electric
Wisconsin Power and Light
Wisconsin Public Service Corp
Wisconsin Public Service Corp
Wisconsin Power and Light
Dairyland Power Coop.
Wisconsin Power and Light
Wisconsin Electric Power
Continued
-------
Appendix table 1--ICAM power plants, codes, and ownership, 1975--Continued
I CAM
code
5005
5021
5022
5033
5026
5035
9005
9007
9008
Total
FERC
code
553000-0600
553000-0500
554500-1500
554000-0900
553000-0700
554500-2000
370500-1105
370500-1200
517000-2000
= 291 coal -fired
State and plant name
West Virginia-continued
Oak Creek, South
Port Washington
Pul liam
Rock River
Valley
We s ton
Wyoming
Jim Bridger
Johnston
Naughton
power plants
Ownership
share
Percent
100.0
100.0
100.0
100.0
100.0
100.0
67.0
33.0
100.0
100.0
Owning
utility system
Wisconsin Electric Power
Wisconsin Electric Power
Wisconsin Public Service
Wisconsin Power and Light
Wisconsin Electric Power
Wisconsin Public Service
Pacific Power and Light
Idaho Power Company
Pacific Power and Light
Utah Power and Light
Source:(6, 16).
-------
Appendix table 2--Power plants 100 MW or greater using coal, 1975
ICAM
code
4006
4052
4054
4053
4011
4030
4014
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Barry Mobile 1,904,588 1,771
Bucks
Al abama
Chickasaw Mobile 65,586 138
Chickasaw
Alabama
Gaston Shelby 4,222,683 952
Wilsonville
Alabama
Gadsden Etowah 183,760 138
Gadsden
Alabama
Gorgas Walker 4,472,056 1,546
Gorgas
Alabama
Greene County Greene 1,244,569 568
Demopolis
Alabama
Colbert A & B Colbert 2,788,167 1,396
Pride
ICAM
link
A
Mine
Blue Creek 13
Mary Lee #1
71 ' \l
CPA^' Coal transport-'
AL1
Tons
1,517,430
Pet.
79.67
Chetopa & Warrior
B
C
D
A
A
B
C
D
E
A
B
C
D
E
A
A
B
A
B
Maxine
Eagle #2
Alston #4
Australia
Blue Creek #3
Maxine
Mary Lee #1
N. River
Warrior
Chetopa
Cobb
B.G. & M. 114
Justus
Ma thews
Homestead
Blue Creek #3
Mary Lee 1
Chetopa
Maxine
Premel e
Interstate 127
Harlan 1
H & B 1
Mary Lee #1
Cobb
Maxine
Warrior
Eagle
Jane Ann #10
Providence #1
IL6
KYI
3503
AL1
AL1
KY3
KY6
TNI
KYI
AL1
KY4
KY3
KY5
TNI
AL1
AL1
IL6
WV5
KYI
295,893
54,572
36,693
65,586
3,473,156
59,088
59,088
117,655
513,816
120,823
35,268
6,858
6,857
13,944
4,472,056
1,173,266
71,303
481
2,774,186
15.54
2.87
1.93
100.00
82.25
1.40
1.40
2.78
12.17
65.75
19.19
3.74
3.73
7.59
100.00
94.27
5.73
.02
99.50
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
4014
4005
9014
9002
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
(continued) Alabama
Widow's Creek Jackson 4,479,011 1,978
A & B Bridgeport &
Stevenson
Alabama
Choi la Navajo 377,400 114
Joseph City
Arizona
Navajo Coconino 3,377,000 1,606
Page
Arizona
ICAM
link
C
A
B
C
0
E
A
B
C
D
A
B
C
Mine CPA^7
Martwick
Drake #3
Dotiki
Ziegler #9
Ohio
Homestead
South Hopkins
Ranch River 3,5,6
Ayer Pit & Russel
!/
Buckhorn
S. Hopkins
Ayrgem
Fies
LCM Evans
Perfect Circle
Colonial
Dotiki
Sinclair-Slope
Pyro #2
Debco
Island #9
Ziegler #9
Pull Tight
V.H.R.
Fabius 1,2
Wai den Ridge #1
Kayenta
McKinley/King
Plateau & Star Pt
Swisher & Gordon
Navajo
Kayenta
Navajo
Convulsion Canyon
IN3
KYO
KY3
KYI
AL1
TN2
AZ1
NM2
UT1
NM1
AZ1
NM1
UT1
Coal transport—
Tons
13,500
747
224,653
3,136,527
816,397
300,687
13,500
170,050
23,800
170,050
2,991,500
239,500
146,000
Pet.
.48
.01
5.02
70.03
18.23
6.71
3.58
45.06
6.30
45.06
88.58
7.09
4.32
See footnotes at end of table.
Continued
-------
Appendix table 2«Power plants 100 MW or greater using coal, 1975--Continued
ICAM
code Plant name
9013 Drake
9009 Hayden
9016 Arapahoe
9006 Cherokee
9011 Comanche
9019 Valmont
County, town, Total coal Nameplate
& state used capacity
Tons MW
El Paso 458,500 277
Colorado Springs
Colorado
Routt 645,100 164
Hayden
Col orado
Denver 575,200 250
Denver
Colorado
Adams 2,517,500 801
Denver
Col orado
Pueblo 1,607,500 778
Pueblo
Col orado
Boulder 230,900 282
Boulder
ICAM
link Mine
A
B
A
A
B
C
A
B
C
D
E
A
B
C
D
E
F
G
A
B
Wise Hill 5
Edna
Eagle 5,6,7,9
Corley S & A
Seneca
Rosebud
Eagle
Edna/Energy
Belle Ayr
Energy
Eagle
Rosebud
Big Horn
Belle Ayr
Eagle Butte
I/
I/
I/
I/
I/
I/
Rosebud
Eagle
CPAi/
C01
C03
C01
WY3
C07
C01
WY2
C01
C07
WY3
WY1
WY2
AR1
OK2
C06
C04
UT1
NM3
WY3
C07
Coal transport-
Tons
450,680
7,820
645,100
195,600
111,800
267,800
94,156
2,071,849
176,251
93,212
82,032
1,591,582
1,034
704
11,467
1,299
497
917
200,000
30,900
Pet.
98.30
1.70
100.00
34.00
19.44
46.56
3.74
82.30
7.00
3.70
3.26
99.01
.07
.04
.71
.08
.03
.06
86.62
13.38
Colorado
2014 Indian River Sussex 971,000 340
Millsboro
Delaware
2026 Delaware City New Castle 2,000 120
Delaware City
Delaware
Sullivan, RaynePA2
Local
Coke
971,000 100.00
2,000 100.00
See footnotes at end of table.
Continued
-------
Appendix table 2--Power plants 100 MW or greater using coal, 1975 --Continued
00
00
ICAM County, town, Total coal Nameplate
code Plant name & state used capacity
4019 Hammond
4007 Harllee Branch
4047 Mitchell
4020 Wans ley
Tons MW
Floyd 1,804,000 953
Coosa
Georgia
Putnam 2,989,000 1,746
Milledgeville
Georgia
Dougherty 410,000 218
AT bany
Georgia
Heard 209,000 865
Roopville
Georgia
ICAM
link
B
C
A
B
C
D
E
F
G
H
A
B
C
D
E
A
B
C
D
A
B
Mine
Me Dowel 1
Volunteer
Little Joe
Shamrock
Alston 3,4
Corona
Short Creek 480
James Spur 7,9,
Buckhorn Mining
Interstate Coal
Justus
!/
High Top
Blackfoot 5
Premele Siding
H & S Coal
McDowell
Sigmon Prep
Mountain Dive 1
Tesoro 13
Creech
Matthews
I/
Volunteer
Roaring Fork
Harlan 1
Mountain Drive
Ben ham
Bushy Mtn
Interstate Coal
H & B 1
Corbin, Premele
Blackfoot 5
Alston 3 & 4
CPA^/
KY3
KYI
All
10KY5
4KY3
Co.
KY6
KYI
TNI
INS
KY4
KY3
KY5
TNI
VA1
KYI
KY5
1
KY3
TNI
KY4
INS
KYI
Coal transport-
Tons
209,489
192,004
746,309
127,691
136,377
20,154
187,369
5,000
21,000
460,000
100,000
708,147
1,300,000
917,000
2,000
61,853
295,080
104,920
3,000
7,000
148,265
60,735
Pet.
19.20
17.77
41.37
7.08
7.56
1.12
10.39
.28
1.16
25.50
5.54
23.69
43.49
30.68
.07
2.07
71.97
25.59
.73
1.71
70.94
29.06
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975 --Continued
00
\0
ICAM County, town, Total coal Nameplate ICAM
code Plant name & state used capacity link
Tons MM
4012 Yates Coweta 3,033,000 1,488 A
Newman
Georgia
B
C
D
E
F
G
H
Mine CPA^
Maxine AL1
Mary Lee #1
Chetopa
Corona
Nickel
Os borne VA1
Blackfoot 5 IN3
Corbin KY4
Premel e
Bevins Branch
Elkhorn Creek 2C
MKM
Lena
Gem Coal 1 KY3
Margin 17-20
Buckhorn 4
Interstate Coal #127
& McDowell
61 1 way Fuels, Inc. & F1es
J. L. Thacker 1 KY5
Bushy Mtn.
Slgmon Prep.
Benham
James Spur, 7,9,10
Creech
Sandy Fork
MB 1
Roaring Fork
Green Brook 1
Harlan 1
Stoney Fork
Nally & Hayden 1
Lyles Coal Co.
Turner Coal Mines 1 & 2
Justus KY6
D. H. Campbell 1
Little Joe KYI
Bennett
Coal transport-
Tons Pet.
581,000 19.16
96,000 3.16
22,000 .73
80,540 2.66
367,559 12.12
900,000 29.67
340,712 11.23
274,583 9.05
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975--Continued
ICAM
code Plant name
4001 Bowen
5010 Coffeen
5030 Grand Tower
5027 Hutsonville
5023 Meredosia
County, town, Total coal Nameplate
& state used capacity
Tons MW
Bartow 5,379,000 3,499
Taylorsvil le
Georgia
Montgomery 2,258,700 1,006
Coffeen
Illinois
Jackson 536,300 195
Grand Tower
Illinois
Crawford 370,400 200
Hutsonville
Illinois
Morgan 738,800 564
Meredosia
Illinois
ICAM
link
I
J
K
L
A
B
C
A
B
C
A
B
A
B
A
B
Mine CPA^
Captain
Lewis
Overton 2
0 & H 1
Winfield
Margo
Spradlin
Eagle
Boyd Co. 6
Sigmon Prep.
Mountain Drive 1
Creech
Stoney Fork
Harlan 1
Tesoro
Interstate Coal
Little Joe
Alston 3,4
Volunteer
Shamrock
Captain
Hillsboro
Carbon Coal 10
Sunspot
Delta
Central Prep.
Fidelity 11
Captain
Will Scarlet
Central Prep.
Delta
Minnehaha
Sunspot
Baldwin 2,3,4
Captain
IL5
TNI
IL6
KY2
KY5
KY3
KYI
IL5
IL3
IL1
IL6
IL5
IL6
IN2
IL1
IL5
Coal transport-
Tons
9,000
349,000
2,000
10,606
1,531,206
454,794
3,393,000
97,124
2,100,000
61,576
104,203
432,097
144,000
226,400
408,778
330,022
Pet.
.30
11.51
.07
.35
28.47
8.45
63.08
4.30
92.97
2.73
19.43
80.57
48.88
58.12
55.33
44.67
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975
ICAM
code Plant name
2002 Benning
4032 Crist
4041 Smith
4022 Gannon
4023 Big Bend
4049 Arkwright
County, town, Total coal Nameplate
& state used capacity
Tons MW
Washington 104,000 718
District of
Columbia
Escambia 1,202,300 1,229
Pensacola
Florida
Palm Beach 698,500 340
Lynn Haven
Florida
Hillsborough 1,904,014 1,270
Tampa
Florida
Hillsborough 1,767,856 891
Tampa
Florida
Bibb 276,999 181
Macon
Georgia
ICAM ?/
link Mine CPPF-'
A
B
C
A
B
C
D
E
A
B
C
D
A
A
A
B
C
D
Kopper Tipple
Martwick
Os borne
Eagle
Little Joe
Martwick
Vogue
Tiger
Warrior
Maxine
South Africa
Canada
Eagle
Little Joe
South Africa
Australia
Little Joe,
Vol unteer
Shamrock/Retiki/
Gibraltar
Pardee
Glammorgan
Harl an/Stoney
Fork
Ikerd & Bandy
High Top
WV2
KYI
VA1
IL6
KYI
AL1
3003
4003
IL6
KYI
3003
3505
KYI
KYI
VA1
KY5
KY3
TNI
Coal transport—
Tons
3,000
79,000
22,000
698,500
342,600
126,100
1,400
33,700
214,700
187,800
257,700
33,000
1,904,014
1,767,856
58,000
7,147
35,853
175,000
Pet.
2.89
75.96
21.15
58.10
28.50
10.49
.12
2.80
30.74
26.89
4.72
.76
100.00
100.00
21.01
2.59
12.99
63.41
4029 McDonough- Cobb
Atkinson Smyrna
Georgia
1,086,000 856
Sigmon Prep.
Plant
Harlan 1
Stoney Fork
Mountain Drive 1
Creech
Tesoro 13
KY5
684,506 63.03
See footnotes at end of table.
Continued
-------
Appendix table 2—-Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
5013 Edwards
5025 Wallace
5016 Fisk
5014 Crawford
5036 Dixon
5003 Joliet
5006 Kincaid
5004 Powerton
County, town, Total coal Nameplate
& state used capacity
Tons MW
Peoria 1,739,800 780
Bartonville
Illinois
Tazewell 508,200 351
Pekin
Illinois
Cook 1,338,300 547
Chicago
Illinois
Cook 1,369,000 702
Chicago
Illinois
Lee 227,500 119
Dixon
Illinois
Will 3,707,000 1,787
Joliet
Illinois
Christian 2,526,000 1,319
Kincaid
Illinois
Tazewell 3,029,000 1,786
Pekin
Illinois
ICAM
link
A
B
C
D
A
B
C
D
A
A
A
B
C
D
A
B
C
A
A
B
C
Mine CPA^/
Sarpy Creek
Buckheart
Morris
Burning Star 2,4
Hawk's Nest
Sarpy Creek
Buckheart
Norn's
Burning Star 2,3
Hawk's Nest
Decker
Decker
Senrinoe
Sufco/Utah 2
Carbon Coal 10
H & S Coal
Col strip/Decker
Carbon Coal 10
Monterey-Carter
Captain
Carbon Coal 10
Decker
Monterey-Carter
Captain
MT4
IL1
IL5
C04
MT4
III
IL5
C04
MT4
MT4
WY3
UT1
IL3
KY4
MT4
IL3
IL5
IL3
MT4
IL3
IL5
Coal transport-
Tons
713,318
939,492
86,990
303,000
141,588
63,612
1,338,300
1,369,000
34,300
10,000
174,000
9,200
2,949,000
137,046
620,954
2,526,000
228,000
2,765,000
36,000
Pet.
41.00
54.00
5.00
60.00
27.00
13.00
100.00
100.00
15.07
4.40
76.48
4.04
79.55
3.70
16.75
100.00
7.53
91.28
1.19
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Contlnued
VO
u>
ICAM
code Plant name
5011 Waukegan
5007 Will County
5009 Joppa
5024 Hennepin
County, town, Total coal Nameplate
& state used capacity
Tons MW
Lake 1,903,100 933
Waukegan
Illinois
Will 2,543,900 1,269
Joliet
Illinois
Massac 3,424,000 1,100
Joppa
Illinois
Putnam 716,064 306
Hennepin
Illinois
ICAM
link
A
B
C
A
B
C
A
B
C
D
E
A
B
C
D
E
F
G
H
I
Mine C
Seminoe
Decker
Carbon Coal 10
Monterey-Carter
Decker
Carbon Coal 10
Captain
Belle Ayr
Blackfoot 5
Roberts Tipple
Martwick
Weskol 6
Gibraltar
South Wind
Shamrock
Kentucky Minerals
St. Charles
Orient 4
Central Prep.
Jader
Delta
Old Ben 21, 26
Ziegler 11
Fidelity 11
Burning Star 3
Savage
Streamline
21 \l
PA— Coal transport—
WY3
MT4
IL3
MT4
IL3
IL5
WY2
IN3
KYI
(Rick)
IL6
IL5
MT2
IL5
Roberts, MartwickKYl
Ayrcoe
Powhatan
Miller Tipple 2
Will Scarlet
Mecco
Processed
INS
OH1
KY4
IL6
IL1
—
Tons
1,509,000
121,000
273,100
2,378,000
32,300
133,600
9,000
129,000
882,000
1,626,306
777,694
17,962
432,841
117,968
2,875
9,104
3,459
33,000
95,000
3,855
Pet.
79.29
6.36
14.35
93.48
1.27
5.25
.26
3.77
25.76
47.50
22.71
2.51
60.45
16.47
.40
1.27
.48
4.61
31.27
.54
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
5031 Vermilion
5018 Wood River
5002 Baldwin
5032 Dal 1 man
5034 Lakeside
5028 Venice #2
County, town, Total coal Nameplate
& state used capacity
Tons MW
Vermilion 462,378 182
Oakwood
Illinois
Madison 1,063,546 650
East Alton
Illinois
Randolph 4,168,346 1,892
Baldwin
Illinois
Sangamon 498,200 160
Springfield
Illinois
Sangamon 186,300 156
Springfield
Illinois
Madison 340,000 500
Venice
Illinois
ICAM
link
A
B
A
B
C
D
E
F
G
H
A
B
C
D
A
B
C
D
E
F
G
A
B
C
D
E
F
G
H
A
B
C
Mine
Ayrcoe
Streaml ine
Seminoe
Decker
Energy
Carbon Helper
Fidelity
Old Ben
Blue Diamond
Ayrcoe
Hanna Basin
Carbon Fuel Mine
Old Ben
Fidelity
Pea body 10
Murdock
Sunspot
Captain
Baldwin 2,3,4
I/
Orient 3,6
Jader/Blue Flame
Paradise
Pea body 10
Murdock/Ziegler
Sunspot
Orient 3,6
Capt. /Baldwin 2,3
I/
!/
i/
Hanna Mine
Carbon Coal 10
Ayrcoe
CP&
IN3
IL5
WY3
MT4
C01
UT1
IL5
IL6
KY5
IN3
WY3
UT1
IL6
IL5
IL3
IL4
111
IL5
TN2
IL6
KYI
IL3
IL4
III
IL6
,4IL5
KYI
IN3
OKI
WY3
IL3
IN3
Coal transport-
Tons
12,088
450,290
14,461
32,571
10,251
10,003
936,883
12,500
42,613
4,264
81,251
4,864
691,122
3,391,109
239,414
78,420
69,570
69,228
3,000
32,268
6,300
85,295
38,918
21,424
16,214
20,949
1,500
1,700
300
212,000
9,000
119,000
Pet.
2.61
97.39
1.36
3.06
.96
.94
88.09
1.18
4.01
.40
1.95
.12
16.58
81.35
48.06
15.74
13.96
13.90
.60
6.48
1.26
45.78
20.90
11.50
8.70
11.24
.81
.91
.16
62.35
2.65
35.00
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
vo
In
1C AM
code
3029
3083
3056
3023
3015
3037
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
State Line Lake 2,159,000 972
Hammond
Indiana
Ratts Pike 676,200 232
Pike
Indiana
Breed Sullivan 1,017,500 496
,
Tanners Creek Dearborn 2,163,900 1,100
Lawrenceburg
Indiana
Clifty Creek Jefferson 4,204,000 1,304
Mad i son
Indiana
Stout Marion 1,722,000 852
Indianapolis
Indiana
ICAM
link
A
B
C
D
A
A
B
C
A
B
C
D
E
F
G
A
B
C
D
E
A
B
C
D
E
F
Mine
Seminoe I/Medicine
Bow
Decker
Captain
Pea body 10
Ayrcoe
Belle Ayr
Ayrcoe
Chinook
Carbon Helper
River Queen
McDowell
Homestead
Unit Coal
I/
T/
I/
Belle Ayr
Wright
!/
Gibral tar/Mi n Dora
I/
Unit Coal
I/
!/
Minnehaha
Center Point
Lynnville
Old Ben 2
Hawthorn
Hampton Div
CP&
WY3
MT4
IL5
IL3
IN3
WY2
IN3
IN2
UT1
KYI
KY3
KY4
WV5
VA1
WV6
WY2
IN3
I NO
KYI
KYO
KY4
VA1
WV6
IN2
IN3
WV5
Coal transport-
Tons
903,000
819,000
90,590
346,410
676,200
29,600
63,818
924,082
130,300
1,945,600
30,850
30,850
6,700
19,000
600
231 ,000
1,725,365
15,635
2,204,317
27,683
24,375
1,896
1,729
1,036,559
657,441
Pet.
41.83
37.93
4.20
16.04
100.00
2.91
6.27
90.82
6.02
89.91
1.43
1.43
.31
.87
.03
5.49
41.04
.37
52.43
.67
1.42
.11
.10
60.20
38.17
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—-Continued
ICAM
code
3073
3034
3045
3050
3046
3100
3043
County, town, Total coal
Plant name & state used
Tons
Pritchard Morgan 726,000
Martinsville
Indiana
Petersburg Pike 1,800,000
Petersburg
Indiana
Bailly Porter 1,290,160
Chesterton
Indiana
Mitchell Lake 1,706,430
Gary
Indiana
Michigan City Laporte 1,593,550
Michigan City
Indiana
Edwardsport Knox 242,600
Edwardsport
Indiana
Gibson Station Gibson 942,500
Mt. Carmel
Indiana
Nameplate
capacity
MW
394
724
616
539
740
133
668
ICAM
link
A
A
B
A
B
C
D
E
A
B
C
A
B
C
A
B
C
D
E
F
A
B
C
Mine
Hawthorn West
Lynnville
R & H
Old Ben 2
Center Point
Dixon & Present
I/
I/
V
River King
Ayrcoe
Medicine Bow
Streamline Mine,
Leahy
Orchard Valley
(as of 6/77)
Ayrcoe
Ziegler
Streamline
Leahy
Energy
Lemmon
Reliable
Minnehaha
Universal
Delta Coal
Rowland Mine
Old Ben 2
Wabash
Captain
2/ I/
CPA^ Coal transport-
IMS
IN3
IN2
PA2
PA1
WV6
IL5
IN3
WY3
IL5
C04
IN3
IL4
IL5
C01
IN3
IN2
INI
KYI
WV6
IN3
IL6
IL5
Tons
726,000
1,744,100
55,900
4,708
8,745
346
209,890
1,066,471
1,667,720
38,710
88,630
1,106,718
398,202
1,600
18,241
199,604
19,355
2,700
1,100
9,980
702,840
229,680
Pet.
100.00
96.90
3.10
.36
.68
.03
16.27
82.66
97.73
2.27
5.56
69.45
24.99
.66
7.52
82.29
7.98
1.11
.45
1.06
74.56
24.37
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—-Continued
I CAM
code Plant name
3102 Noblesville
3047 Gallagher
3030 Wabash River
3027 Cayuga
3061 Culley
3033 Warrick
3105 Dresser
6016 Kapp
County, town, Total coal Nameplate
& state used capacity
Tons MW
Hamilton 133,100 100
Noblesville
Indiana
Floyd 1,610,200 600
New Albany
Indiana
Vigo 1,942,800 908
Terre Haute
Indiana
Vermilion 2,628,900 1,062
Cayuga
Indiana
Warrick 1,161,372 415
Newburg
Indiana
Warrick 2,371,618 812
Yanks town
Indiana
Vigo 49,000 150
Terre Haute
Indiana
Clinton 603,900 237
Clinton
Iowa
I CAM
link
A
B
C
D
A
B
C
D
A
B
C
D
E
F
A
B
C
A
A
A
A
B
C
Mine
Ikerd & Bandy
Universal
Minnehaha
Wabash
Ayrshire
Delta Coal
Stoney Fork
Kempton 2
Kempton 2
I/
I/
Hawthorn & Latta
Minnehaha
Universal
Belle Ayr
Minnehaha
Universal
Wright
Lynnville
Squaw Creek
Lynnville
Minnehaha
Chinook
Rosebud
Baldwin 2,3,4
Burning Star 2
Captain
I/
CPA^/
KY3
INI
IN2
IL6
INS
KYI
KY5
WV6
WV6
KY4
KY5
IN3
IN2
INI
WY2
IN2
INI
INS
INS
IN2
MT4
IL5
III
Coal transport-
Tons
3,800
90,705
36,995
1,600
895,600
653,500
37,800
23,300
40,800
8,609
15,891
1,383,905
478,199
15,395
10,100
33,521
2,585,279
1,161,372
2,371,618
49,000
137,100
460,825
5,975
Pet.
2.85
68.15
27.80
1.20
55.62
40.59
2.35
1.45
2.10
.44
.82
71.23
24.61
.79
.38
1.28
98.34
100.00
100.00
100.00
22.70
76.31
.99
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
ICAM " C
code Plant name
6015 Prairie Creek
6024 Sutherland
6020 Riverside
6001 George Neal
6030 Maynard
•ounty, town, Total coal Name~pl a te
& state used capacity
Tons MW
Linn 470,900 244
Cedar Rapids
Iowa
Marshall 198,300 157
Marshall town
Iowa
Scott 475,000 222
Bettendorf
Iowa
Woodbury 1,158,576 1,046
Salix
Iowa
Blackhawk 44,389 97
Waterloo
Iowa
ICAM
link
A
B
C
D
E
F
A
B
C
D
E
F
A
B
C
A
B
C
A
B
• •
Mine
Wise Hill 5
Eagle 5,6,7,9
King
Central Prep.
Mecco
Allendale
Ziegler 11
Lexington Seam
Big Horn
Rosebud
Eagle 5,6,7,9
Big Ben 1
Lovilia
Lexington Seam
I/
Seminoe 1
Harrisburg
Mecco
Allendale
Buckheart
Vanguard/Medicine
Seminoe
Vanguard & Rimrock
Rosebud
Bow/Rosebud
I/
Rosebud
Volunteer
CPA?/
C01
UT1
IL6
IL1
IL5
M01
WY1
MT4
C01
IA1
M01
MOO
WY3
IL6
IL1
WY3
UT1
M01
WY3
KYI
Coal transport-
Tons
98,200
6,000
6,900
270,800
39,000
51,000
16,000
5,000
31,600
43,581
94,841
1,659
16,000
43,907
415,093
1,142,049
3,455
3,072
18,851
24,538
Pet.
20.85
1.27
1.47
57.51
8.28
10.83
8.07
3.63
14.74
21.98
47.83
.85
3.37
9.24
87.39
99.43
0.30
0.27
42.47
57.53
6026 Council Bluffs Pottawattomie 301,600
Council Bluffs
Iowa
131
Rosebud
WY3
301,600 100.00
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
vo
vo
ICAM
code Plant name
6021 Des Moines
6019 Burlington
6027 Muscatine
7011 Riverton
7002 LaCygne
7010 Kaw
7003 Lawrence
7006 Tecumseh
County, town, Total coal Nameplate
& state used capacity
Tons MW
Polk 433,160 270
Des Moines
Iowa
Des Moines 523,700 212
Burlington
Iowa
Muscatine 291,602 120
Muscatine
Iowa
Cherokee 165,010 145
Riverton
Iowa
Linn 1,475,100 893
LaCygne
Iowa
Wyandotte 142,869 161
Kansas City
Kansas
Douglas 798,800 613
Lawrence
Kansas
Shawnee 338,800 346
Tecumseh
Kansas
ICAM
link
A
B
A
B
C
A
B
A
B
A
A
B
C
D
E
A
A
Mine
Belle Ayr
Eagle Butte
Lovil ia
Belle Ayr
Eagle Butte
Lovilia
Mecco
Buckheart
Buckheart
Fidelity 11
Clemen's Coal22,25
Leon's Mine 1
Midway
Welch
Chelsea Tipple
Garland
I/
Clemens 22,25
Seminoe
Lovil ia
Medicine Bow
Medicine Bow
CPA— Coal transport—
WY2
IA2
WY2
IA1
IL1
IL1
IL5
KS3
OKI
M05
OKI
AR1
KS3
WY3
IA2
WY3
WY3
Tons
133,835
299,325
15,100
44,400
464,200
203,597
88,005
31,459
133,551
1,475,100
86,361
97
55,698
565
148
798,800
338,800
Pet.
30.90
69.10
2.88
8.48
88.64
69.82
30.18
19.06
80.95
100.00
60.45
.07
38.98
.40
.10
100.00
100.00
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
o
o
ICAM
code
7009
3057
3067
3089
3024
3038
3052
3080
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Quindaro #2,3 Wyandotte 309,481 327
Kansas City
Kansas
Coleman Hancock 1,490,500 521
Hawesville
Kentucky
Cooper Pulaski 750,930 344
Burnside
Kentucky
Dale Clark 358,460 196
Ford
Kentucky
Big Sandy Lawrence 2,214,800 1,097
Louisa
Kentucky
Brown Mercer 1,435,913 740
Burg in
Kentucky
Ghent Carroll 1,321,550 557
Ghent
Kentucky
Green River Muhlenburg 548,777 264
Central City
Kentucky
ICAM
link
A
B
C
D
A
B
C
A
B
C
A
B
C
D
A
B
C
D
A
B
C
D
E
F
A
B
A
B
Mine
Seminoe
Chelsea Porum
Clemens 22,25
Spadra
Homestead
Ohio Pit
Rough River
Martwick
Reti ki
Ikerd and Bandy
Ayrshire
Rush Creek
Green Mountain 1
Clear Creek 2
Ikerd and Bandy
I/
Jerry Lynn
Rush Creek
Add ing ton
Ridgeway 1
Unit Coal
i/
Tejay
Highland
Unit Coal
Ikerd and Bandy
Justus
Camp Mines
Ayrshire
Ayrshire
Warrick
!/
River Process 21
Highland
Ohio Energy
CPA^ Coal transport—
WY3
OKI
KS3
AR1
KYI
KY3
IN3
WV5
KY6
TNI
KY3
KY4
KY5
WV5
KY3
KY2
KY4
VA1
KY5
KY4
KY3
KY6
KYI
IN3
IN3
KY3
.22KY5
KYI
Tons
106,618
72,487
119,941
10,435
1,370,300
22,700
97,500
27,700
620,930
102,300
6,440
1,971
343,509
6,540
756,660
131,978
1,325,762
300
961,319
7,377
123,267
115,219
134,131
94,600
1,317,214
4,336
100,647
300,130
See footnotes at end of table.
Pet.
34.45
23,42
38.76
3.37
91.94
1.52
6.54
3.69
82.69
13.62
1.80
.55
95.83
1.82
34.16
5.96
59.87
.01
66.95
.51
8.59
8.02
9.34
6.59
99.67
.33
18.34
54.69
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
3080 (continued)
3097 Tyrone
3028 Cane Run
3068 Paddy's Run
3040 Mill Creek
3062 Smith
3003 Paradise
3007 Shawnee
County, town, Total coal Nameplate
& state used capacity
Tons MW
Woodford 52,692 137
Versailles
Kentucky
Jefferson 1,722,400 1,017
Louisville
Kentucky
Jefferson 20,700 338
Louisville
Kentucky
Jefferson 1,580,900 711
Kosmosdale
Kentucky
Daviess 1,014,495 416
Owensboro
Kentucky
Muhlenberg 6,546,826 2,558
Drakesboro
Kentucky
McCracken 5,146,050 1,750
Paducah
Kentucky
ICAM
link
C
D
A
B
C
A
A
A
A
B
A
A
B
C
Mine
Paradise
Newol d
Rough River 3,5,6
Ikerd and Bandy 1,
Green Mountain 1
Rough River
Drakes Creek
Mies
Sassafras
Riverview
Star
Roberts Tipple
Roberts Tipple
Star/Vogue
Chinook
Pleasant Hill
Sinclair
Ayrgem
Rosebud
Eads
Old Ben 21,24,26
Eads
Drake 3,4
Caney Creek
Colonial
Vogue
CPA^
KY3
6
KY6
KY3
KY4
KY5
KYI
KYI
KYI
INS
KYI
KYI
MT4
IL6
KYI
Coal transport-
Tons
81,000
67,000
21,082
3,077
28,533
1,722,400
20,700
1,580,900
18,000
996,495
6,546,826
169,900
1,969,032
2,644,856
Pet.
14.76
21.21
40.01
5.84
54.15
100.00
100.00
100.00
1.77
98.23
100.00
3.30
38.26
51.40
See footnotes at end of table.
Continued
-------
Appendix table 2--Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
3007 (continued)
3104 Robert Reid
2011 Crane
2013 Wagner
2005 Chalk Point
3051 Dickerson
2004 Morgantown
3088 Smith
County, town, Total coal Nameplate
& state used capacity
Tons MW
Webster 1,167,500 442
Sebree
Kentucky
Baltimore 9,000 400
Bal timore
Maryland
Anne Arundel 656,000 1,043
Baltimore
Maryland
Prince Georges 830,000 1,387
Aquasco
Maryland
Montgomery 1,029,000 586
Dickerson
Maryland
Charles 925,000 1,251
Newbu rg
Maryland
Washington 238,100 110
Williamsport
Maryland
ICAM
link
D
A
A
B
C
D
A
A
B
A
B
C
D
E
A
B
C
A
B
C
D
E
F
Mine
Ken
Perfect Circle
Rough River
Homestead
Retiki
Martwick
Sugarhill
Champion
Bridgeview
I/
Beaver
K & J mine
Bos torn' a
I/
Eagle Mine
Miller & McKnight
Loveridge
Romesburg
Allegheny Mining
I/
Laurel
Allegheny Strip
Bessemer
Premier
Jon tee
Romesburg
Laurel
!/
Allegheny Strip
CPA^/
KY3
KYI
PA2
PA1
MD1
WV3
WV6
PA
PA2
MD1
PA2
PA1
WV2
MD1
WV3
KY3
PA2
WV3
MD1
VA1
WV4
M01
PA2
VAO
WV3
Coal transport-
Tons
362,262
1,167,500
8,520
160
268
52
656,000
822,000
8,000
726,000
93,000
186,000
214,000
16,000
8,000
811,000
19,000
95,000
4,400
14,300
216,300
2,500
600
100
Pet.
7.04
100.00
94.66
1.78
2.98
.58
100.00
99.04
.96
70.56
9.04
18.06
1.55
.78
87.68
2.05
10.27
1.85
5.96
90.84
1.05
.25
.04
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
o
U)
I CAM
code
1001
1015
1012
3031
3041
3055
3103
3070
3091
See
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Brayton Point Bristol 476,000 1,600
Somerset
Massachusetts
Salem Harbor Essex 82,100 805
Salem
Massachusetts
Somerset Bristol 16,700 329
Somerset
Massachusetts
Karn Bay 712,500 530
Essexville
Michigan
Campbell Ottawa 1,675,300 650
West Olive
Michigan
Cobb Muskegon 1,362,900 510
Muskeg on
Michigan
Weadock Bay 1,532,500 614
Essexville
Michigan
Whiting Monroe 893,500 325
Erie
Michigan
Mistersky Wayne 209,682 174
Detroit
Michigan
footnotes at end of table.
ICAM
link
A
B
C
D
A
A
A
B
C
A
B
A
B
C
D
E
A
B
A
B
A
Mine
River Queen
Poland
So. Africa
Australia
Poland
Pol and
Williams
Carson/Powhatan
Sigmon
Warner/Crown City
i/
Valley Strip 1
Valley Camp 3
Ken
Fidelity
Ayrcoe
CPA!/
KYI
2503
3003
3503
2503
2503
WV2
OH1
KY5
OH1
WV1
OH1
WV1
KYI
IL5
IN3
Williams WV2
Powhatan 3,4/CarsonOHl
Hazard
Kenmont
Hazard
KY4
KY5
KY4
Coal transport-
Tons
288,000
123,000
36,000
29,000
82,100
16,700
33,200
668,700
10,600
1,675,200
100
137,000
137,000
932,600
73,500
82,200
179,300
1,353,200
622,323
271,177
209,682
Pet.
60.50
25.84
7.56
6.09
100.00
100.00
4.66
93.85
1.49
99.99
.01
10.05
10.10
68.43
5.39
6.03
11.70
88.30
69.65
30.35
100.00
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
3065
3094
3054
3099
3086
3078
3014
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Eckert Ingham 520,400 386
Lansing
Michigan
Erickson Ingham 436,300 160
Lansing
Michigan
Conner s Creek Wayne 592,000 540
Detroit
Michigan
Harbor Beach Huron 286,000 121
Harbor Beach
Michigan
Marysville St. Clair 544,000 200
Marysville
Michigan
River Rouge Wayne 62,000 933
Detroit
Michigan
St. Clair St. Clair 2,983,000 1,905
Belle River
Michigan
ICAM
link
A
A
A
B
C
D
A
B
C
D
A
B
C
D
E
A
B
C
D
A
B
C
D
E
F
G
Mine
Powhatan 1,3,5
Crown City
Consol 20
I/
Sands/Betsy
Majestic
Tateville
Consol 20
Powhatan 1,3,4
McGregor
Decker
Wharton
Nelms #2
Powhatan #5
Cravat Coal
S. Fork Haddix
Lorentz
Bell/King Knob
C and K Piney Run
Cravat Coal
Champion
Decker
Century 1 and 2
Cravat Coal
S. Fork Haddix
Champion
i/
McGregor
CPA^/
OH1
OH1
WV2
PA1
OH1
KY4
KY4
WV2
OH1
WV5
MT4
WV5
OH1
KY3
WV2
WV2
PA2
OH1
PA1
MT4
KY3
OH1
KY3
PA1
WV6
WV5
Coal transport-
Tons
520,400
436,300
30,000
3,000
70,000
489,000
17,000
85,000
137,000
47,000
4,000
15,000
89,000
386,000
50,000
18,000
1,000
35,000
8,000
884,000
655,000
781,000
537,000
48,000
2,000
76,000
Pet.
100.00
100.00
5.07
.51
11.82
82.60
5.94
29.72
47.90
16.43
.74
2.76
16.36
70.95
9.19
29.03
1.61
56.45
12.90
29.63
21.96
26.18
18.00
1.61
.07
2.55
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
3039 Trenton
Channel
3001 Monroe
3063 Presque Isle
6031 Fox Lake
6028 Aurora
6007 Boswell
6008 Black Oog
County, town, Total coal Nameplate
& state used capacity
Tons MW
Wayne 1,417,000 776
Trenton
Michigan
Monroe 6,484,000 3,280
Monroe
Michigan
Marquette 839,000 358
Marquette
Michigan
Sherburn 42,500 105
Sherburn
Minnesota
St. Louis 388,700 226
Aurora
Minnesota
Itasca 2,070,900 514
Cohasset
Minnesota
Dakota 1,042,000 487
Minneapolis
ICAM
link
A
B
C
D
E
A
B
C
0
E
F
A
B
C
D
A
A
B
C
D
E
F
A
A
B
Mine
Federal
C & K Piney Run
Powhatan #5
Georgetown
Egypt Valley
S. Fork Haddix
Champion
Decker
Federal #2
Blacksville 1,2
Georgetown
S. Fork Haddix
Carbon Fuel
Poseytown Prep
Glacial
Dotiki/Leeco
Smith Coal
Warwick
Benjamin
Hepburnia
Big Sky
Big Sky
!/
I/
I/
I/
I/
Big Sky
Rosebud
River King
CPA^/
WV2
PA2
OH1
KY3
PA1
MT4
WV2
OH1
KY3
WV5
PA2
KYI
KY4
PA1
PA2
MT4
MT4
WY1
UT1
MNO
WV6
KY4
MT4
MT4
IL5
Coal transport-
Tons
73,000
11,000
260,000
1,018,000
55,000
168,000
193,000
2,174,000
130,000
3,510,000
309,000
372,860
228,140
17,898
220,102
42,500
388,700
test firings
2,070,900
707,000
335,000
Pet.
5.15
.78
18.35
71.84
3.88
2.59
2.98
33.53
2.00
54.13
4.77
44.44
27.19
2.13
26.24
100.00
100.00
100.00
67.85
32.15
Minnesota
See footnotes at end of table.
Continued
-------
Appendix table 2-Power plants 100 MW or greater using coal, 1975-Continued
ICAM ~
code Plant name
6010 High Bridge
6005 King
6011 Riverside
6025 Hoot Lake
4015 Watson
5019 Thomas Hill
5015 New Madrid
7014 Blue Valley
wunty town, Total coal Nameplate
— g-. state. used capac i ty
Tons MW
Ramsey 886,000 397
St. Paul
Minnesota
Washington 1,668,000 598
Stillwater
Minnesota
Hennepin 952,000 455
Minneapolis
Minnesota
Ottertail 679,400 137
Fergus Falls
Minnesota
Harrison 1,531,000 1,174
Handsboro
Mississippi
Randolph 1,288,000 470
Moberly
Missouri
New Madrid 1,374,456 650
New Madrid
Missouri
Jackson 193,930 115
Independence
Missouri
ICAM"
link
A
B
C
A
B
C
A
B
A
A
B
C
A
A
B
A
B
C
D
E
F
G
Mine
Rosebud
I/
River King
Rosebud
Ziegler 9
River King
Rosebud
I/
Beulah
Eagle
Haddix(Falcon
• _ .
CPA^7 Coal transport*/
MT4
KYI
IL5
MT4
KYI
IL5
MT4
WY1
ND2
IL6
Coal)KY3
Don Bow Processed KYI
Prairie Hill
Bee Veer Mine
Baldwin 2,3,4
Homestead
Seminoe 2
Wise Hill 5
Belina 1 and 2
McNabb
United Coal
United Coal
Ft. Scott
Lexington Seam
M03
IL5
KYI
WY3
C01
UT1
OKI
OK3
KS3
M01
Tons
755,000
8,000
123,000
519,000
66,000
1,083,000
948,908
3,092
679,400
893,400
180,700
427,400
1,288,000
1,251,956
89,000
69,700
4,900
1,600
109,730
4,400
1,700
1,900
Pet.
85.21
.90
13.88
31.11
3.96
64.93
99.67
.33
100.00
58.35
11.80
27.92
100.00
91.09
6.48
35.94
2.53
.82
56.58
2.27
.88
.98
7007 James River Greene
Springfield
Missouri
178,975 253
Ft. Scott
KS3
178,975 100.00
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
5037
7008
7013
7001
7004
7005
7012
5012
See
Plant name
Columbia
As bury
Grand Avenue
Hawthorne
Montrose
Sibley
Lake Road
Meramec
County, town,
& state
Boone
Columbia
Missouri
Jasper
As bury
Missouri
Jackson
Kansas City
Missouri
Jackson
Kansas City
Missouri
Henry
Cl inton
Missouri
Jackson
Sibley
Missouri
Buchanan
St. Joseph
Missouri
St. Louis
St. Louis
Missouri
Total coal Nameplate
used capacity
Tons MW
83,910 107
654,599 213
172,900 126
1,032,100 908
1,793,800 563
849,000 518
157,250 125
1,936,000 923
ICAM
link
A
B
C
A
B
C
A
B
C
D
E
A
B
C
D
E
A
B
C
A
A
B
C
A
B
C
D
Mine
Fidelity 11
Orient 3,4,6
Lexington Seam
Clemens 22,25
Empire
Midway
United Coal
Medicine Bow
Chelsea Tipple
Ft. Scott
Lexington Seam
Panama #1
Seminoe 1
Rogers 1
Ft. Scott
Lexington Seam
!/
Seminoe 1
Power
Tebo
Rogers 1
Rogers, 1,2
Lexington Seam
Ft. Scott
Porum
Belle Ayr
Old Ben 1
Porum
Southwind
Fies
Burning Star 4,2,3
Captain
CPA^' Coal transport-
IL5
IL6
M01
KS3
M05
OKI
WY3
OKI
KS3
M01
OK2
WY3
OKI
KS3
M01
—
WY3
M04
OKI
OKI
M01
KS3
OKI
WY2
IN3
KYI
IL5
Tons
20,531
60,623
2,756
87,065
563,095
4,399
3,500
136,000
25,500
7,900
3,400
806,500
212,500
10,500
1,200
1,000
10,000
1,777,800
11,000
849,000
106,500
14,500
36,250
7,000
120,000
210,000
775,835
footnotes at end of table.
Pet.
24.47
72.25
3.28
13.30
86.03
.67
2.02
78.66
14.75
4.57
1.97
78.14
20.59
1.05
.12
.10
.56
98.83
.61
100.00
67.73
9.22
23.05
.36
6.20
10.85
40.07
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—-Continued
o
00
ICAM
code Plant name
5012 (continued)
5008 Sioux
5001 Labadie
6013 Col strip
9020 Corette
6029 Kramer
6017 Sheldon
County, town, Total coal Nameplate
& state used capacity
Tons MW
St. Charles 2,246,000 1,100
West Alton
Missouri
Franklin 5,804,000 2,482
Labadie
Missouri
Rosebud 197,000 358
Col strip
Montana
Yellowstone 700,000 173
Billings
Montana
Sarpy 239,400 113
Bellevue
Nebraska
Lancaster 254,200 229
Hal lam
Nebraska
ICAM
link
E
A
B
C
D
E
A
B
A
A
A
B
C
A
B
C
D
Mine
Old Ben 24
Eagle
Orient 3,6
Delta
Porum, Fies
Old Ben 1
Burning Star 4
Captain
Baldwin 2,3,4
Eagle
Orient 3,6
Old Ben 24
Monterey 1
Hanna Mine
Leahy
Burning Star 2,3,4
Captain
Fidelity 11
Rosebud
Rosebud
Rosebud
Sorensen
Eagle 5,6,7,9
Seminoe 1 & 2
Utah #2
Clemens 22,25
McNabb
Porum
CPA^' Coal transport—
IL6
KYI
IN3
IL5
IL6
IL3
WY3
IL5
MT4
MT4
WY3
WY4
C01
WY3
UT1
KS3
OKI
Tons
823,165
16,000
267,000
210,000
772,048
823,165
101,000
5,703,000
197,000
700,000
86,600
18,300
134,500
148,200
2,000
48,300
55,700
Pet.
42.52
.71
11.89
10.85
34.37
42.52
1.74
98.26
100.00
100.00
36.18
7.64
56.18
58.30
.70
19.00
21.91
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
I CAM
code Plant name
6004 North Omaha
9017 Gardner
9003 Mohave
1004 Merrimack
2016 England
2006 Hudson
2007 Mercer
County, town, Total coal Nameplate
& state used capacity
Tons MW
Douglas 956,000 645
Omaha
Nebraska
Clark 655,800 227
Moapa
Nevada
Clark 3,820,000 1,636
Laugh! in
Nevada
Merrimack 977,200 459
Concord Bow
New Hampshire
Cape May 744,633 475
Marmora
New Jersey
Hudson 558,100 1,114
Jersey City
New Jersey
Mercer 1,029,020 653
Hamilton
New Jersey
ICAM
link
A
A
A
A
B
C
D
E
A
B
C
A
B
C
D
A
B
C
D
E
F
Mine
Seminoe 2
Hanna Area
Deer Creek
Swisher and Gordon
Black Hawk
Plateau and Star Pt
Utah 2
King
Black Mesa
Champion
Mt. Carmel
Loveridge
North Branch
Rich Gap
Cowen
O'Dennell #20
I/
CPA^
WY3
UT1
f
AZ1
PA1
PA2
WV2
WV3
KY5
WV4
WV2
ILO
Eagle/Ringold/SugarPA2
King Knob/Barbour
Glamorgan Tipple
I/
Horner/Badger
Cross Brook
North Branch
McArthur/Iselin
Fox/Washington
Harlan
WV2
VA1
WV4
WV2
VA1
WV3
PA2
PA1
KY5
Coal transport-
Tons
965,000
655,800
3,820,000
15,700
30,700
865,500
64,900
400
29,156
712,727
2,750
278,700
198,100
77,600
3,700
400,400
313,600
27,100
115,720
74,000
98,200
Pet.
100.00
100.00
100.00
1.61
3.14
88.57
6.64
.04
3.92
95.71
.37
49.94
35.50
13.90
.66
38.91
30.48
2.63
11.25
7.19
9.54
9001 Four Corners San Juan
Fruitland
New Mexico
5,941,600
2,270
Navajo
NM1
5,941,600 100.00
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—-Continued
ICAM
code Plant name
9012 San Juan
1009 Goudey
1008 Greenridge
1005 Mil liken
1002 Huntley
1003 Dunkirk
County, town, Total coal Nameplate
& state used capacity
Tons MW
San Juan 1,253,300 329
Water flow
New Mexico
Broome 387,300 161
Johnson City
New York
Yates 540,800 198
Dresden
New York
Tompkins 832,300 310
Ithaca
New York
Erie 1,548,000 828
Tonawanda
New York
Chataque 1,194,000 628
Dunkirk
New York
ICAM
link
A
A
B
C
A
B
C
A
B
C
D
E
A
B
C
D
E
F
G
H
I
A
B
Mine
San Juan
Pevler Mine
Various
Champion
McArthur
I/
Affinity
Champion
McArthur
Northeast Surface
Romesburg
Gauley
Sull ivan
Champion
O'Donnel #20
King Knob 37
Love Ridge
Williams
Lorentz
Cowen
Wharton
Keystone
Smith Coal
Johnson Constr.
Blue Gem
Deby
Golden Glow
Renwood
Thacker
Champion
Mt. Carmel
CPA^/
NM1
KY4
PA2
PA1
PA2
PA1
WV6
PA1
PA2
WV2
MD1
WV6
PA2
PA1
WV2
WV4
WV5
WV6
KY4
KY3
KY5
PA1
PA2
Coal transport-
Tons
1,243,300
2,100
359,705
23,400
529,700
1,500
9,600
22,700
779,200
8,900
10,500
10,900
266,000
210,000
393,747
43,033
161,013
60,207
126,436
57,132
230,432
396,000
681 ,000
Pet.
100.00
.54
92.88
6.04
97.95
.28
1.77
2.73
93.63
1.07
1.26
1.31
17.18
13.57
25.44
2.78
10.40
3.89
8.17
3.69
14.88
33.17
57.04
Bel fast-Shal e-Shane
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM County, town, Total coal Nameplate
code Plant name & state used capacity
Tons MW
1003 (continued)
ICAM
link
Mine
Bark Camp
CPA!/
Coal transport-
Tons
Pet.
Eagle-Ringsgold-Sugar
1007 Rochester 3 Monroe 196,700 196
Rochester
New York
1006 Rochester 7 Monroe 542,600 252
Rochester
New York
4036 Asheville Buncombe 890,800 414
Skyland
North Carolina
C
D
A
B
C
D
E
F
A
B
C
D
E
A
B
C
0
Blue Gem
Love Ridge
O'Donnel 20
Nucla
Sugarhill
Champion
Love Ridge
Williams
Greenbrook
Ayrcoe
Nucla
Champion
Sugarhill
Love Ridge
Williams
Greenbrook
Knox Prep and Dock
Cross Brook Cane
Glamorgan Tipple
Porter
Lena
Kathryn
Blue Ribbon
Totz
Mari 1,2
Margin 17-20
Blue Gem 3,4
Point Stone
Gill is Way
J. L. Thacker 1
Bledsoe
Round Mtn.
Terry Glen
Golden Glow
West Tipple
KY3
WV2
C01
PA2
PA1
WV2
KY5
IN3
C01
PA1
PA2
WV2
KY5
VA1
KY4
KY3
KY5
91,000
26,000
4,000
88,378
64,600
30,100
6,700
2,922
1,000
220,100
215,100
96,200
10,200
126,400
20,644
135,714
332,119
7.62
2.18
2.03
44.93
32.84
15.30
3.41
1.49
.18
40.56
39.64
17.73
1.88
14.19
2.32
15.24
37.28
See footnotes at end of table.
Continued
-------
Appendix table 2—-Power plants 100 MW or greater using coal, 1975—Continued
ICAM County, town, Total coal Nameplate ICAM
code Plant name & state used capacity link
Tons MW
4036 (continued)
E
F
G
H
I
4037 Cape Fear Chatham 733,700 421 A
Moncure
North Carolina
B
C
D
E
F
G
Mine CPA-'
Lyle
Justus KY6
Kent-Ivydell TNI
Sam 1
Premium 1
Daugherty 3,9
and Tipple 1-1
Aytes #1
Amer-Lee WV6
Jane Ann 10 WV5
Renwood Tipple TN2
Race Fork VA1
Glamorgan Tipple
Porter
Premier
Banner
Norton
Virginia Pocahontas
Mel rose
Verner WV5
Blue Gem 3,4 KY3
Hop
Bizivil
Point Stone
Deskins KY4
J and H
Cardinal 3
Wolf Creek 3
Mari 1,2
Sapphire
Mill Creek KY5
Bledsoe
West Tipple
Calico
Harland 1
Rockholds
Terry Glen
Tripple 1-1 TNI
Crane Creek WV6
Amer-Lee
Coal transport-
Tons
28,923
200,000
11,350
11,350
24,300
207,200
100,000
61,453
193,293
120,654
15,000
36,100
Pet.
3.24
22.45
1.27
1.27
2.73
28.24
13.63
8.39
26.34
16.44
2.04
4.92
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
I CAM County, town, Total coal Nameplate ICAM
code Plant name & state used capacity link
Tons MW
4035 Lee Wayne 697,300 402 A
Goldsboro
North Carolina
B
C
D
E
F
G
H
I
4008 Roxboro Person 3,831,600 1,813 A
Roxboro
North Carolina
Mine CP/£7
Cross-Brook Cane VA1
Bel i be Coal
Mel rose
Kern Gem
Knox Prep & Dock
Dixiana
Race Fork
McClure River 1
Well more
Rose Blanch 1 WV6
E and J Coal
Chesterfield WV5
Verner
Red Jacket
Devon-Glen Alum
Big Creek KY4
Wolf Creek 3
Caney Branch 9,11
Majestic
Woodbine Prep. KY5
Mill Creek
West Tipple
Bledsoe
Terry Glen
Bizivil KY3
Hop
Margin 17-20
Blue Gem 3,4
Hickory Tipple
Justus KY6
Daugherty 3,9 TNI
Premium 1
Kopper Glo Tipple
Viers Coal Co.
Jade KYI
Oakwood 1 VA1
Dale, Nora, Bruton
Bel i be
Race Fork
Coal transport-
Tons Pet.
128,500 18.43
9,516 1.36
149,084 21.38
148,274 21.26
31,493 4.52
95,811 13.74
42,348 6.07
39,700 5.69
52,574 7.55
769,700 20.09
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM County, town, Total coal Nameplate
code Plant name & state used capacity
Tons MW
4008 (continued)
ICAM
link
B
C
D
E
F
G
Mine CPA^
Five Oaks
Premier
Norton
Anchor S.
Keen and Runyon
Esserville Plant
and Todmorton
Well more
Harris 1,2 WV5
McNamee Prep.
Adamac
Red Jacket
Ken KYI
McGuire KY2
Majestic KY4
Caney Branch 9,11
Wolf Creek 3
Os borne
Gale Loading Dock
Case 4
Bishop WV6
Oldhouse Branch KY3
Coal transport-
Tons
1,109,000
91,000
126,824
1,700,000
21,200
13,876
Pet.
31.87
3.31
44.73
.55
.36
4027 Sutton
New Hanover
Wilmington
North Carolina
813,600
672
Porter VA1
H and R
Southern Imperial
Mel rose
Va. Pocanontas
Cross Brook-Cane
Harlan Darby
Norton
Todmorten
Dale, Nora, Bruton
Glamorgan Tipple
Mason
Crane Creek WV6
Amer-Lee
Mari 1,2 KY4
Sapphire
Wolf Creek 3
364,200 44.76
18,306 2.25
154,172 18.95
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
4027 (continued)
4050 Weatherspoon
4016 Allen
4003 Belews Creek
4033 Buck
County, town, Total coal Nameplate
& state used capacity
Tons MW
Robeson 208,400 166
Lumberton
North Carolina
Gaston 1,824,728 1,155
Belmont
North Carolina
Stokes 3,023,006 2,160
Walnut Cove
North Carolina
Rowan 569,945 533
Spencer
North Carolina
ICAM
link
D
E
F
G
A
B
C
D
E
F
A
B
C
D
E
A
B
C
A
B
C
D
E
Mine
Point Stone
Ky Gem Coal 1
Blue Gem 3,4
West Tipple
Justus
Shattuck
Klines
Knox Prep and Dock
Norton
Dale, Nora, Bruton
American
Os borne
Wolf Creek 3
Premium
Blue Gem 3,4
Mill Creek
Terry Glen
Mine Nos 1,2
Shattuck,
Klines
Big K
Knox Prep/Norton
Ohio 11, Vogue 3
I/
I/
I/
McNamee Prep
Wolf Creek/Osborne
Norton/Pocahontas
Cross Brook Cane
American
Red Jacket
Majestic
Mill Creek
CPA^/
KY3
KY5
KY6
TNI
VA1
WV6
KY4
KY3
KY5
TNI
VA1
KYI
WV5
TNI
WY6
WV5
KY4
VA1
VA1
WV6
WV5
KY4
KY5
Coal transport-
Tons
21,208
183,207
32,713
39,800
90,900
2,200
41,309
24,561
46,230
3,200
1,493,335
308,822
1,439
17,566
3,566
69,970
2,605,910
347,126
62,276
78,323
295,795
125,404
8,147
Pet.
2.61
22.52
4.02
4.89
43.62
1.06
19.82
11.79
22.18
1.54
81.84
16.92
.08
.96
.20
2.31
86.21
11.48
10.93
13.74
51.90
22.00
1.43
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
I CAM
code Plant name
4025 Cliff side
4043 Dan River
4004 Marshall
4028 Riverbend
6003 Lei and Olds
6014 Young
6032 Heskett
6023 Stanton
3020 Cardinal
County, town, Total coal Nameplate
& state used capacity
Tons MW
Rutherford 1,651,304 781
Cliffsides
North Carolina
Rockingham 433,246 290
Eden
North Carolina
Catawba 4,609,808 2,000
Terrel 1
North Carolina
Gaston 453,277 751
Mt. Holly
North Carolina
Mercer 1,863,800 700
Stanton
North Dakota
Oliver 1,517,121 256
Center
North Dakota
Morton 426,892 100
Mandan
North Dakota
Mercer 735,500 172
Stanton
North Dakota
Jefferson 2,110,100 1,230
Brilliant
Ohio
ICAM
link
A
A
B
C
D
A
B
C
D
E
A
B
C
A
A
A
A
B
A
B
C
D
E
F
Mine
Oakwood/Bel ibe
Premier/Norton
American
Red Jacket
Majestic
Oakwood/Bel ibe
Mill Creek
Justus
Klines
!/
Home Creek
Justus
I/
Glenharold
Noonan
Beulah
Indian Head
Sarpy Creek
Rosebud
Carbon/Helper
Carson Pit
Valley Camp 3
Pleasant Hill
Bologna Coal
I/
CPA^/
VA1
VA1
WV6
WV5
KY4
VA1
KY5
KY6
TNI
WV5
VA1
KY6
TNI
ND1
ND1
ND2
ND2
MT4
UT1
OH1
WV1
KYI
PA1
WY6
Coal transport-
Tons
1,651,304
36,669
74,916
55,670
265,991
2,692,990
904,394
866,150
123,220
23,054
105,398
343,463
4,416
1,863,800
1,517,121
426,892
569,100
166,400
23,000
1,280,800
741 ,600
43,500
6,500
14,700
Pet.
100.00
8.46
17.29
12.85
61.39
58.42
19.62
18.79
2.67
.50
23.25
75.77
.97
100.00
100.00
100.00
77.38
22.62
1.09
60.70
35.15
2.06
.31
.69
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
3095 Lake Road
3059 Ashtabula
3026 Avon Lake
3018 East Lake
3053 Lake Shore
3017 Conesville
County, town, Total coal Nameplate
& state used capacity
Tons MW
Cuyahoga 119,541 160
Cleveland
Ohio
Ashtabula 1,146,300 640
Ashtabula
Ohio
Lorain 2,520,600 1,275
Avon Lake
Ohio
Lake 2,947,000 1,257
Eastlake
Oh in
VII 1 V
Cuyahoga 1,016,600 518
Cleveland
Ohio
Coshocton 2,726,430 1,275
Conesville
Ohio
ICAM
link
A
A
B
C
D
F
G
H
A
B
C
A
C
D
E
F
G
H
I
A
B
C
D
E
A
Mine
Robertsville Pit/
Ellsworth
Bonoman
Cloe/Iselin
Marion
K and R Crawford
I/
I/
i/
_!/
Cravat Coal
Love Ridge
Tatevi lie/ Champ
Cloe/Iselin
.!/
Cravat Coal
I/
Love Ridge
i
I/
Harold
Kopper Slo Tipple
McDowell
Carson Pit
Bos torn' a
King and Hale
C.J — -.—
Simco
|V .
Crava't
Empire
Meadowbrook
Hutt
Lisa
CPA!/
OH1
PA2
PA1
OH1
WV2
WV1
KY3
KY5
KY4
OH1
WV2
KY4
PA2
WV1
OH1
WV6
WV2
WV4
KY3
KY4
KY5
PA1
WV2
KY3
OH1
PA2
OH1
Coal transport-
Tons
119,541
30,200
203,500
909,600
600
200
200
2,406,100
95,700
28,800
255,600
3,300
2,485,900
25,596
125,838
2,666
15,733
16,552
15,815
52,000
563,700
270,200
90,800
39,900
2,726,430
Pet.
100.00
2.63
17.75
79.35
.05
:lf
.02
.02
95.08
3.78
1.14
8.67
.11
84.35
.87
4.27
.09
.53
.52
.54
5.12
55.45
26.58
« 0-5
U* 7O
3.92
100.00
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
1C ATI
code Plant name
3017 (continued)
3092 Pickway
3084 Poston
3087 Edgewater
3081 Miles
County, town, Total coal Nameplate
& state used capacity
Tons MW
Pickaway 261,900 170
Lockbourne
Ohio
Athens 601,500 232
Athens
Ohio
Lorain 416,880 240
Lorain
Ohio
Trumbull 574,390 313
Niles
Ohio
ICAM
link
A
B
A
B
C
A
B
C
D
E
F
A
B
C
0
E
Mine
Schlabach
Speidel
Carson
Carson
Mt. Sterling
Carson Pit
Marmon
Pyro Strip
Benedict 2 and Econ
Cab Strip
Pyro Strip
Benedict 3 and Econ
Swan Pit
Kimble
Carson Pit
Broken Arrow
New Straitsville
Nelsonville
West Freedom
Shoemaker
Piney Fork 1
Hoober
Copperhead
Nelms 2
Deckerd Suzie
Kopper Slo Tipple
Stevan Coal
I/
Various
Allied Fuels
Glen Mary
Valley Camp
Badger 13,14,15
i/
CPA!/
OH1
OH4
OH3
OH4
OH1
PA2
WV1
OH1
WV2
WV5
KYO
PA2
PA1
WV1
WV2
wve
Coal transport-
Tons
211,668
50,232
64,902
346,825
189,773
27,700
27,000
338,280
20,300
3,200
400
14,700
198,000
5,112
9,800
1,588
Pet.
80.82
19.18
10.79
57.66
31.55
6.64
6.48
81.15
4.87
.77
.10
2.56
34.47
.89
1.71
.28
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
3081 (continued)
3049 Burger
3090 Toronto
County, town, Total coal Name pi ate
& state used capacity
Tons MW
Belmont 1,333,100 654
Shady side
Ohio
Jefferson 305,530 206
Toronto
Ohio
ICAM
link
F
G
A
B
C
D
E
F
A
B
Mine
Deckerd Suzie
Cravat
Kimble
Piney Fork 1
Patton Pit
Alexander
Unit 1
Orlando
Powhatan #3
Crown City
Various
Huberta 43
Consol 1,2
CPA^/
OH1
OH4
WV1
KY4
WV4
OH1
OH4
PA2
OH1
WV1
Coal transport-
Tons
265,037
80,153
224,762
295,800
2,138
758,621
2,679
49,100
173,930
131,600
Pet.
46.14
13.95
16.86
22.19
.16
56.91
.20
3.68
56.93
43.07
3005 Sammi s
Jefferson 4,941,840 2,456
Stratton
Ohio
3002 Gavin
Gallia 5,433,310 2,600
Gallipolis
Ohio
A
B
C
D
E
A
B
C
D
E
F
G
H
I
J
K
L
Carson Pit
Betsy
Powhatan 1,3,4
Crown City
K and R Crawford
Eagle Coal
Alexander
Badger 13, 14, 15
Unit 1
Belle Ayr
Carbon/Helper
Morley
I/
Wol f pen
McGuire
I/
Drakes Creek
Pyro/Bened./3/
Swan
Cab Strip
Nelsonville
B and N Coal
OH1
PA2
WV1
WV2
KY4
WY2
UT1
TNI
KYI
VA1
KY2
KY5
KY4
OH4
OH3
OH1
OH2
3,330,840
849,700
427,600
129,200
204,500
937,700
339,400
300
19,600
340,000
539,788
48,079
155,233
1,996,142
196,616
144,152
161,390
67.40
17.19
8.65
2.61
4.14
17.25
6.25
.01
.36
6.26
9.93
.88
2.86
36.74
3.62
2.65
2.97
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975--Continued
ICAM
code Plant name
3002 (continued)
3013 Muskingum
River
3075 Philo
3085 Tidd
3025 Kyger Creek
3101 Vine Street
3032 Miami Fort
County, town, Total coal Nameplate
& state used capacity
Tons MW
Washington 3,459,600 1,638
Beverly
Ohio
Muskingum 116,500 500
Philo
Ohio
Jefferson 393,200 226
Brilliant
Ohio
Gallia 3,345,000 1,086
Gal li poll's
Ohio
Wayne 102,600 104
Orrville
Ohio
Hamilton 1,683,600 557
North Bend
Ohio
ICAM
link
M
N
0
P
Q
R
A
B
C
D
E
F
A
A
B
C
D
E
A
B
C
A
A
B
C
D
E
F
G
Mine
I/
Ann Lorentz 1
Crane Creek
Red Jacket
Keen and Runyon
I/
Sag in aw
Central Ohio
Wharton
Terrco
Keystone #5
Queen Coal
Ma nil on
Saginaw
St. Clairsville
Maidsvil le
Ann Lorentz 1
Deseret
Bologna 248
Benedict 2/Econ
Keystone
Shoemaker
Hoover North
I/
Karen
Hansford
Hazard
\l
Jerry Lynn
Ken/River Queen
CPA^/
WV1
WV2
WV6
WV5
VA1
I NO
OH1
OH2
WV5
PA1
WV6
KYI
OH1
OH1
OHO
WV2
UT1
PA1
OH4
WV6
WV1
OH1
WV4
PA1
WV5
KY4
KY3
KY5
KYI
Coal transport-
Tons
12,400
101,210
132,599
136,201
151,900
20,600
2,868,663
121,537
183,100
300
280,000
6,000
116,500
239,103
32,297
5,100
18,700
98,000
1,416,000
261,000
1,668,000
102,600
6,100
73,700
13,000
21,235
12,448
33,495
933,100
Pet.
.23
1.86
2.44
2.51
2.80
0.38
82.92
3.51
5.29
.01
8.09
.17
100.00
60.81
8.21
1.30
4.76
24.92
42.33
7.80
49.87
100.00
.36
4.38
.77
1.26
.74
1.99
55.42
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
I CAM
code Plant name
3032 (continued)
3019 Beckjord
3077 Tait
3064 Hutchings
3004 Stuart
3079 Acme
County, town, Total coal Nameplate
& state used capacity
Tons MW
Clermont 2,426,600 1,221
New Richmond
Ohio
Montgomery 465,500 449
South Dayton
Ohio
Montgomery 533,600 414
Dayton
Ohio
Adams 5,101,600 2,441
Aberdeen
Ohio
Lucas 355,070 307
Toledo
Ohio
ICAM
link
H
I
J
A
B
C
D
E
F
G
H
A
B
C
D
E
A
B
C
D
E
F
A
B
C
D
E
F
A
B
C
D
Mine
Add ing ton
Georgetown
Universal
Addington/Boyd
Ken/ River Queen
Georgetown
Universal
Karen
Hansford
Keystone
Lynnvil le
Hazard
Majestic
Sapphire
Sunnyhill
Giles
Ferrel
Hazard/Majestic
Giles
Elkhorn
Cole and Ramsey 1
Race Fork
Ferrel
Bevins Br., Hazard
Green Mtn 1
Powhatan
Sapphire
McGregor
Van Lear
Island Creek
Warwick
Brands Run
Powhatan
Bevins Br. /Hazard
CPA^
KY2
OH1
OH4
KY2
KYI
OH1
OH4
PA1
WC5
WV6
INS
KY4
KY5
OH1
KY3
WV5
KY4
KY3
KY5
TNI
VA1
WV5
KY4
KY6
OH1
KY5
WV5
KY3
PA1
WV2
OH1
KY4
Coal transpjart-
Tons
61,122
491,813
37,587
56,900
965,400
898,126
46,574
233,600
179,300
37,700
9,000
121,355
202,767
75,500
39,978
25,900
5,748
36,600
417,452
29,400
32,000
12,400
1,055,531
60,086
2,381,400
297,463
973,500
333,620
10,900
91,500
228,070
19,409
Pet.
3.63
29.21
2.23
2.34
39.78
37.01
1.92
9.63
7.39
1.55
.37
26.07
43.56
16.22
8.59
5.56
1.08
6.86
78.23
5.51
6.00
2.32
20.69
1.18
46.68
5.83
19.08
6.54
3.07
25.77
64.23
5.47
See footnotes at end of table.
Continued
-------
Appendix table 2--Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
3079
3042
3127
3060
3071
3048
2020
2012
Plant name
(continued)
Bay Shore
Hamilton
Elrama
Phillips
Cheswick
Crawford
Portland
County, town, Total coal Nameplate
& state used capacity
Tons MW
Lucas 1,671,600 640
To! edo
Ohio
Butler 96,320 133
Hamilton
Ohio
Washington 1,359,542 510
El rama
Pennsylvania
Allegheny 1,197,000 411
South Heights
Pennsylvania
Allegheny 1,387,000 565
Cheswick
Pennsylvania
Cauphin 89,000 117
Middstown
Pennsylvania
Northampton 768,900 427
Portland
Pennsylvania
ICAM
link
E
A
B
C
D
E
A
B
C
D
E
A
B
C
A
B
C
D
A
B
C
A
B
A
B
C
D
Mine
Sapphire
Bevins Br. /Hazard
Powhatan
Brands Run
I/
I/
I/
Shannon Branch
Lundale
I/
I/
Christopher
Hopwood Const.
Warwick
Rider
Midway Coal
Warwick
Bartins 2
Snyder
Brands Run
Shannon Branch
Boston ia
Warwick
Harold
Apollo
Brands Run
Eagle Coal
Washington
Various/Bark Camp
North Branch
Ambrosia Coal
Pinto Tipple
CP&
KY5
KY4
OH1
WV2
PA1
WVO
OHO
WV6
WV5
PA1
VAO
WV2
PA2
PA1
PA2
PA1
WV2
WV6
PA2
PA1
WV2
PA2
PA1
PA2
WV3
PA1
WV2
Coal transport-
Tons
5,191
601 ,300
1,026,100
37,300
6,100
800
880
2,910
37,300
6,100
800
42,219
846
1,316,477
1,019,599
849
111,301
65,251
992,050
466,723
160,744
84,900
4,100
614,500
34,300
83,600
36,500
Pet.
1.46
35.97
61.38
2.23
.36
.05
.91
3.02
2.23
.36
.05
3.11
.06
96.83
90.09
.08
9.83
5.45
61.26
28.82
9.93
95.39
4.61
79.92
4.46
10.87
4.75
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
to
10
ICAM
code
2017
2019
3016
2001
3098
3044
3010
2002
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Titus Berks 472,900 225
Reading
Pennsylvania
Front Street Erie 380,000 118
Erie
Pennsylvania
Homer City Indiana 2,254,000 1,319
Homer City
Pennsylvania
Keystone Armstrong 3,908,000 1,872
Shelocta
Pennsylvania
Seward Indiana 654,000 268
Seward
Pennsylvania
Shawville Clearfield 1,666,000 640
Clearfield
Pennsylvania
Conemaugh Indiana 3,935,000 1,872
New Florence
Pennsylvania
Brunner Island York 3,505,000 1,559
York Haven
Pennsylvania
ICAM
link
A
B
C
D
E
F
G
H
I
J
A
B
C
A
A
B
A
A
B
A
B
A
B
C
D
E
Mine
I/
Glacial Mining
Romesburg
Cross Brook
I/
Arkwright
Cowen
Big Fork 8,9
Tateville
Lewis Coal
Willowbrook
Nanty-Glo
!/
Clarion Fossil
Fuels
R.E.M. Coal
Kerry Coal
Worrick
Henry
Marion Mine
Casselman Sales
Midway
Delta Mining
Emerald
I/
I/
I/
CPA^
PA1
PA2
MD1
VA1
WV3
WV2
WV4
WV6
KY4
KY3
PA1
PA2
WV6
PA2
PA2
PA1
PA2
PA2
PA1
PA2
PA1
PA2
PA1
MD1
WV2
WV4
Coal transport-
Tons
800
24,800
22,500
36,200
1,900
69,476
54,124
7,200
233,023
22,877
348,224
31,000
776
2,254,000
3,639,000
269,000
654,000
1,645,000
21,000
3,840,000
95,000
3,203,648
278,000
352
15,165
6,835
Pet.
.17
5.24
4.76
7.65
.40
14.69
11.45
1.52
49.28
4.84
91.64
8.16
.20
100.00
93.12
6.88
100.00
98.74
1.26
97.59
2.41
91.43
7.93
.01
.43
.20
See footnotes at end of table.
Continued
-------
Appendix table 2—-Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
2015
2010
2003
2009
2018
2008
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Martins Creek Northampton 708,000 1,163
Martins Creek
Pennsylvania
Sunbury Snyder 1,371,000 410
Shamokin Dam
Pennsylvania
Montour Montour 3,831,000 1,642
Washingtonville
Pennsylvania
New Castle Lawrence 762,260 506
New Castle
Pennsylvania
Cromby Chester 232,000 418
Phoenixville
Pennsylvania
Eddys tone Delaware 1,321,000 1,089
Eddystone
Pennsylvania
ICAM
link
A
B
C
A
B
C
A
A
B
C
A
B
C
D
A
B
C
D
E
Mine
Vargo Coal
O'Donnel 20
Addington
Champion
Mt. Carmel
Processed
Stahlman
W. Freedom
Fox
Washington
Marion Mine
Ambrosia
Big B
Stahlman
W. Freedom Mining
Eagle Coal
I/
Bo s ton i a
Cadogan
Valley Camp 3
Loveridge
O'Donnel
Lorentz
Will iams
Bessemer
Poseytown Prep/
Glacial
Champion
Valley Camp 3
Loveridge
Williams
Lorentz
King Knob
Barbour
CPA^
PA2
WV2
KY4
PA1
PA2
—
PA2
PA1
PA2
OH1
PA2
PA1
WV1
WV2
MD1
PA2
PA1
WV1
WV2
Coal transport-
Tons
562,000
114,000
32,000
651,000
568,000
152,000
3,831,000
277,320
481,930
3,010
9,000
60,000
32,000
131,000
3,000
88,000
314,000
144,000
614,902
Pet.
79.38
16.10
4.52
47.48
41.43
11.09
100.00
63.22
36.38
.39
3.88
25.86
13.79
56.47
.23
6.66
23.77
10.90
46.55
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—-Continued
ICAM
code Plant name
2008 (continued)
3066 Armstrong
3076 Mitchell
3008 Hatfield
3128 Springdale
4048 Robinson
4038 Lee
County, town, Total coal Nameplate
& state used capacity
Tons MW
Armstrong 848,590 326
Kittaning
Pennsylvania
Washington 675,098 449
Monongahela
Pennsylvania
Greene 4,362,980 1,728
Masontown
Pennsylvania
Allegheny 5,470 215
Springdale
Pennsylvania
Darlington 286,100 207
Hartsville
South Carol ina
Anderson 373,027 345
Pelzer
South Carolina
ICAM
link
F
G
H
A
B
C
A
B
C
D
A
B
C
D
A
A
B
C
D
E
F
G
A
B
Mine
Davis Coal
Lost Run Mine
I/
Eagle Coal
Apollo
Marti ki
i/
Arkwright
Powhatan
Marti ki
Add ing ton
Champion
Poseytown Prep/
Glacial
Arkwright
Arkwright
Porter
Virginia Pocahontas
Mel rose
Mari 1,2
Wolf Creek 3
Os borne
Blue Gem
Deby Hd
Rockholds
Terry Glen
G and F 1
T and M
Crane Creek
Maxine
Crossbrook
Hess Creek
Lewis Creek
CPA— Coal transport—
WV3
WV4
KY4
PA2
PA1
KY4
PA1
WV2
OH1
KY4
KY4
PA1
PA2
WV2
WV2
VA1
KY4
KY3
KY5
TNI
WV2
WV6
AL1
VA1
Tons
40,134
107,964
9,000
724,370
116,350
6,128
5,950
645,680
17,340
6,128
769,470
1,687,900
64,270
1,841,340
5,470
62,200
148,123
14,890
42,087
18,400
200
200
9,224
46,972
Pet.
3.04
8.17
.68
85.36
13.71
.91
.88
95.64
2.57
.91
17.64
38.69
1.47
42.20
100.00
21.74
51.77
5.20
14.71
6.43
.07
.07
2.47
12.59
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
4038 (continued)
4034 Canadys
4039 McMeekin
4045 Urquhard
4026 Wateree
4042 Winyah
County, town, Total coal Nameplate
& state used capacity
Tons MW
Colleton 259,600 490
Canadys
South Carolina
Lexington 316,100 294
Columbia
South Carolina
Aiken 446,200 250
Augusta, Ga.
South Carolina
Richland 1,364,600 772
Eastover
South Carolina
Georgetown 631,274 315
Moncks Corner
South Carolina
ICAM
link
C
D
E
F
G
A
B
C
A
B
C
D
A
B
C
D
A
B
C
D
E
A
B
Mine
Straight Line
Blue Gem
Kent
Sandy Fork
Ryan's Creek
Straight Line M
Jet Tipple
Kilowatt Pit.
Nancy Prep
Sandy Fork
Norton Banner
Dixona Prep
Mull ins Plant
Dixiama
Straight Line M
Kilowatt Pit.
Crest/ Red bird
Kent
Wise Dock
Johnson, Jet Tip.
Crest, Redbird
Sandy Fork
Johnson
Jet Tipple
Kilowatt Pit.
Nancy Prep.
Sandy Fork
Crest
Redbird Tipple
Wise Dock
!/
Crest/Redbird Tip
I/
2/ I/
CPA=- Coal transport—
KY4
KY3
TNI
KY5
KY6
KY4
KY3
KY5
VA1
KY4
KY3
TNI
VA1
KY4
KY3
KY5
KY4
KY5
KY3
VA1
TN3
KY3
TNI
Tons
129,088
97,458
37,661
15,131
37,493
250,000
1,116
8,484
43,900
257,880
7,320
7,000
768
340,800
46,592
58,040
108,861
587,230
657,909
3,900
6,700
630,782
492
Pet.
34.60
26.13
10.10
4.06
10.05
96.30
.43
3.27
13.89
81.58
2.32
2.21
.17
76.38
10.44
13.01
7.98
43.03
48.21
.29
.49
99.92
.08
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
I CAM
code Plant name
4051 Grainger
4040 Jefferies
6009 Big Stone
4018 Allen
4021 Bull Run
4010 Gal latin
County, town, Total coal Nameplate
& state used capacity
Tons MW
Horrt 218,204 163
Conway
South Carolina
Berkeley 584,215 346
Moncks Corner
South Carolina
Grant 1,609,300 456
Big Stone
South Dakota
Shelby 1,773,423 990
Memphi s
Tennessee
Anderson 2,426,487 950
Clinton
Tennessee
Sumner 2,406,843 1,255
Gal latin
Tennessee
fc
ICAM
link
A
B
C
D
A
A
B
A
B
A
B
C
D
A
B
C
Mine
Wise Dock
Johnson/Kilowatt
Belmont #1 and 3
Crest/Redbird Tip
Lafollette #2
Johnson/Kilowatt
Belmont 11 and 3
Gascoyne
Wyodak #1
Baldwin 2,3,4
Ohio
Martwick
Drake 3
Gibraltar
Homestead
Johnson/Kilowatt
Crest/Redbird
Kenmont
Harlan
Jerry Lynn
Bushy Mtn. Mine
LaFollette #2
D and R
Richgap 1
S. Hopkins 2
Ziegler 9
Dotiki
Drake
Pyro 2
Island 9
Colonial
Fies
Providence 1
?/ \l
CPA^ Coal transport—
VA1
KY4
KY3
TNI
KY4
ND3
WY2
IL5
KYI
KY4
KY3
KY5
TNI
KY3
KY5
KYI
Tons
92,048
37,227
86,452
2,477
584,215
1,592,200
17,100
481,103
1,292,320
593,459
532,418
1,296,406
4,204
358,037
14,801
2,034,015
Pet.
42.18
17.06
39.62
1.14
100.00
98.94
1.06
27.13
72.87
24.46
21.94
53.43
.17
14.88
.61
84.51
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
N>
00
ICAM County, town, Total coal Nameplate ICAM
code Plant name & state used capacity link
Tons MW
4024 Sevier Hawkins 2,327,825 846 A
Rogersville
Tennessee
B
C
D
E
F
G
H
I
J
K
4013 Johnsonville Humphreys 3,721,149 1,485 A
Johnsonville B
Tennessee C
D
E
F
Mine
Dean Jone 7
Lanham
Black Diamond
Laurel
Mel rose
Horn Bros.
L and M
Little B
Beeline Coal #1
Blackfoot 5
Old Ben 1
Margo
Long Pit
Dan Branch 3,4
New Hignite 2
Paul Coal #1
D and R 2
Duck Run
Drake 3,4
Elkhorn Creek 2C
M and R
Baldwin 2,3,4
P and P 1
Williams 198
Rough River 3,5,6
Margo, Long Pit
Bakersport
Drake 3
Martwick
Homestead
Ohio
South Hopkins
Ziegler 9
Island #9
Kaetzel Pit #3
Margo, Long Pit
Crown City
CPA^
VA1
IN3
TNI
KY5
KY3
WV5
KYI
KY4
IL5
WV6
WV2
KY3
TNI
KYI
INS
TNI
OH1
Coal transport-
Tons
872,290
247,130
648,190
271 ,804
4,538
2,000 •
17,671
28,268
234,351
583
1,000
113,940
16,290
1,620,577
43,055
244,171
1,683,116
Pet.
37.47
10.62
27.85
11.67
.19
.09
.76
1.21
10.07
.03
.04
3.06
.44
43.55
1.16
6.56
45.23
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code Plant name
4009 Kingston
County, town, Total coal Nameplate
& state used capacity
Tons MW
Roane 5,166,413 1,700
Kingston
Tennessee
ICAM
link
A
B
C
D
Mine
Ryan's Creek
Comb's 10
Caudill 's Branch
D and R 2
Jerry Lynn
CPA*/
KY6
KY4
KY3
KY5
Coal transport-
Tons
36,398
291,647
792,348
435,060
Pet.
.70
5.64
15.34
8.42
4046 Watts Bar
Rhea
Watts Bar Dam
Tennessee
674,455
240
Wisconsin Steel D-l
River Process 21,22
Mies and Bipper Tipple
Little T TNI
Lucking 1
Oliver Springs 3,5,6
Dean
Devonia
H and B 1
Clear Creek 2
A and W 1
McCall 5
Sam 1
Daugherty 3,9
Walnut Mt.
Shemco 3
Buffalo Coal 1
Laco 1
Spradlin
Plateau 2,5
H and W Coal 2
Tripple I 1
Jackson 1
Longwa 4,3
Indian Creek Coal #2
Earl and Rickey Coal #2
New River #2
James Nunley 3 TN2
Volunteer KYI
Little Joe
Hamilton 1,2
Allardt
Cole and Ramsey 1
Phillips and Leab 1
TNI
3,421,551 66.23
186,919 3.62
2,490 .05
291,759 43.26
See footnotes at end of table.
Continued
-------
Appendix table 2--Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
4046
4002
8001
8002
9018
9015
9010
3035
County, town, Total coal
Plant name & state used
Tons
(continued)
Cumberland Stewart 5,996,719
Cumberland City
Tennessee
Big Brown Freestone 5,611,000
Fairfield
Texas
Monticello Titus 3,535,000
Titus
Texas
Carbon Carbon 433,000
Castle Gate
Utah
Gadsby Salt Lake 401,000
Salt Lake City
Utah
Huntington Emery 1,014,000
Canyon Huntington
Utah
Clinch River Russell 1,789,200
Cleveland
Nameplate
capacity
MM
2,600
1,187
1,187
189
183
446
712
ICAM
link
B
C
A
A
A
A
A
A
A
B
Mine CPA^/
Clear Creek 2
Lewi s
D and H Coal 1
Perry and Howard 1
Mash #40
Custom 1 TN2
James Nun ley 3
Wai den Ridge 1
Drake 3 KYI
Providence 1 KYI
Homestead
Ohio
Martwick
Drake 3
Camp 1,2
Big Brown TX1
Monti cello TX1
Deseret UT1
Deseret UT1
Deer Creek UT1
Home Creek VA1
Kent Carb KY4
Coal transport-
Tons
36,874
345,822
5,996,719
5,611,000
3,535,000
433,000
401,000
1,014,000
1,730,200
59,000
Pet.
5.47
51.27
100.00
100.00
100.00
100.00
100.00
100.00
96.70
3.30
Virginia
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, iy/:>--iuiiLiiiucU
ICAM
code
3069
4031
4044
4017
9004
3093
3059
3011
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Glen Lyn Niles 592,100 338
Glen Lyn
Virginia
Potomac River Fairfax 510,300 515
Alexandria
Virginia
Bremo Bluff Fluvanna 526,400 254
Bremo Bluff
Virginia
Chesterfield Chesterfield 551,000 1,484
Chester
Virginia
Central ia Lewis 4,200,000 1,460
Central i a
Washington
Cabin Creek Kanawha 101,100 170
Cabin Creek
West Virginia
Kanawha River Kanawha 1,244,300 439
Glasgow
West Virginia
Amos Kanawha 6,539,500 2,933
St. Albans
West Virginia
ICAM
link
A
B
C
D
E
A
B
C
D
E
F
A
B
C
A
B
C
D
A
A
B
A
B
C
D
E
A
B
C
Mine
Kent Carb
Home Creek
Big Fork 8,9
Chesterfield
I/
Home Creek
Chesterfield
Kent Carb
Red Rocket
I/
I/
Gauley Tip
Chesterfield
Hobet
Kent Carb
Red Rocket
Glenbrook 12
Kentucky
D-Mine
Lewis/Mash 40
Hazard
Central ia Coal
Lorado
Stickney Tipple
K and R
Marion
Marg 11 & Cloe Tip
Not available
Not available
Lorado
Stickney Tipple
D and R 2
2/ I/
CPA— Coal transport—
KY4
VA1
WV6
WV5
KYI
VA1
WV5
KY4
KY3
PA2
TNI
WV4
WV5
KY4
KY3
KY5
TNI
KY4
WAI
WV5
WV6
OH1
PA1
PA2
WV5
WV6
WV5
WV6
KY3
Tons
109,000
408,800
55,500
13,300
5,500
216,300
13,000
256,474
20,526
1,000
3,000
11,797
440,203
74,400
128,536
200,526
45,000
34,316
4,200,000
3,387
97,713
909,600
203,500
30,200
3,300
97,700
4,804,500
2,500
580,907
Pet.
18.41
69.04
9.37
2.25
.93
42.39
2.55
50.26
4.02
.19
.59
2.24
83.63
14.13
23.33
36.39
8.17
13.43
100.00
3.35
96.65
73.10
16.35
2.43
.27
7.85
73.47
.04
8.88
See footnotes at end of table.
Continued
-------
Appendix table 2~Power plants 100 MW or greater using coal, 1975—Continued
ICAM
code
3011
3021
3072
3022
3096
3082
3006
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
(continued)
P. Sporn Mason 1,373,600 1,106
New Haven
West Virginia
Albright Preston 720,019 278
Albright
West Virginia
Fort Martin Monongela 2,988,373 1,152
Maidsville
West Virginia
Rivesville Marion 229,907 110
Rivesville
West Virginia
Willow Island Pleasants 425,497 215
Pleasants
West Virginia
Harrison Hatwood 4,877,232 2,052
Harrison
West Virginia
ICAM
link
D
E
F
A
B
C
D
E
F
A
B
C
A
B
A
B
C
D
A
B
C
D
A
B
C
D
E
F
G
Mine
Paul 1
Black Diamond
Klines
Laurel /Mel rose
Stickney Tipple
D and R 2
M and R
Lorado
Riverside Coal
Kanes Creek
Keontz Strip
North Branch
?/ I/
CPA=- Coal transport-
KY2
VA1
TNI
VA1
WV6
KY3
KY4
WV5
OH4
WV2
MD1
WV3
Eagle-Ringold-SugarPA2
Arkwright
Humphrey 7
Apollo
Kanes Creek
Humphrey 7
Stickney Tipple
National
Valley Camp 3
Badger 13,14,15
Northeast Surface
Carlisle
Lost Run
Cowen
Northeast Surface/
Hornier
Lost Run
Wharton
Keystone/Gaul ey
D and R 2
Hawkeye
I/
WV2
PA1
WV2
WV6
WV5
WV1
WV2
OH2
WV4
WV2
WV4
WV5
WV6
KY3
KY4
KYI
Tons
516,593
634,900
100
418,600
160,365
300,160
35,440
457,135
1,900
669,490
35,599
14,930
172,135
2,816,238
6,534
38,000
164,908
20,465
31,675
255,747
108,075
30,000
2,263,709
121,886
1,110,299
423,270
121,574
827,484
9,010
Pet.
7.90
9.71
.00
30.47
11.67
21.85
2.58
33.28
.14
92.98
4.94
2.07
5.76
94.24
2.83
16.53
71.73
8.90
7.44
60.11
25.40
7.05
46.41
2.50
22.77
8.68
2.49
16.97
.18
See footnotes at end of table.
Continued
-------
Appendix table 2—Power plants 100 MW or greater using coal, 1975—Continued
UJ
LO
I CAM
code
3036
3012
3009
6022
6012
See
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Kammer Marshall 1,528,900 712
Moundsville
West Virginia
Mitchell- Marshall 3,083,500 1,633
Captina Moundsville
West Virginia
Mount Storm Grant 3,303,000 1,662
Mt. Storm
West Virginia
Alma Buffalo 645,000 188
Alma
Wisconsin
Genoa Vernon 1,156,900 346
Genoa City
Wisconsin
footnotes at end of table.
ICAM
link
A
B
C
A
B
C
D
E
G
A
B
C
D
E
A
B
C
D
E
F
G
A
B
C
D
E
F
G
H
Mine
Ireland Mine
El am Dock-
Add ing ton
Slaughter Cr. Dock
Mt. Victory
Ziegler 9
Cravat
Laurel /Mel rose
Northeast Surface/
Horner
I/
Wharton
Laurel Run &
North Branch
Jone Tee
Keontz Strip
Northeast Surface/
Horner
Belle Ayr
Sarpy Creek
Burning Star 4
Baldwin 2,3,4
Ken/River Queen
Majestic
Processed
Allendale
Hanna
Sarpy Creek
Burning Star 2,3
Baldwin 2,3,4,
Will Scarlet
Fossil Fuels
I/
Colonial
Mid America Term
Processed
91 \l
CPA^-' Coal transport-'
WV1
KY2
WVO
KY3
KYI
OH1
VA1
WV2
PA1
WV5
WV3
WV4
MD1
WV2
WY2
MT4
IL5
KYI
KY4
-
IL1
WY3
MT4
IL5
IL6
KY5
TNI
KYI
-
Tons
1,314,300
18,500
196,100
90,589
66,711
280.200
76,600
613,500
3,700
182,028
2,108,000
45,625
767,000
200,347
101,000
106,800
200,400
172,800
6,700
37,300
20,000
199,200
149,700
249,068
101,732
3,700
500
403,500
49,500
Pet.
85.96
1.21
12.83
2.94
2.16
9.09
2.48
19.90
.12
5.51
63.82
1.38
23.22
6.07
15.66
16.56
34.17
26.79
1.02
5.78
3.10
17.22
12.94
21.53
8.79
.32
.04
34.88
4.28
Continued
-------
Appendix table 2-Power plants 100 MW or greater using coal, 1975-Continued
1CAM
code
5029
5005
5021
5026
5017
5020
6018
5033
County, town, Total coal Nameplate
Plant name & state used capacity
Tons MW
Blount Dane 58,500 196
Madison
Wisconsin
Oak Creek Milwaukee 3,168,600 1 692
Oak Creek
Wisconsin
Port Washing- Ozaukee 553,000 400
ton Port Washington
Wisconsin
Valley Milwaukee 612,100 335
Milwaukee
Wisconsin
Columbia Columbia 1,744,859 545
Columbia
Wisconsin
Edgewater Sheboygan 1,011,679 477
Sheboygan
Wisconsin
Nelson Dewey Grant 577,296 227
Cassville
Wisconsin
Rock River Rock 295,212 150
Beloit
Wisconsin
ICAM
link
A
B
A
B
C
D
E
A
B
C
D
E
A
B
C
A
A
B
C
D
E
A
A
B
C
0
— — • .
Mine
Dotiki
Riverview
Will Scarlet
Hanna
Old Ben #1
CPA^/
KYI
IL6
WY3
IN3
Eagle-Ringold-SugarPA2
River Queen
Powhatan
Mt. Carmel
River Queen
Old Ben #1
Old Ben .#21
Colonial
Old Ben #2
Old Ben #1
Col strip
Dotiki
Chinook
Midland
Murdock
Burning Star 2
Burning Star 2
Baldwin 2,3,4
Murdock
Will Scarlet
Burning Star 2
Dotiki
KYI
IL6
OH1
PA2
KYI
IL6
IN3
KYI
IN3
IL6
MT4
KYI
IN3
III
IL4
IL5
IL5
IL4
IL6
IL5
KYI
Coal transport-
Tons
51 ,800
6,700
715,600
187,200
63,000
533,600
1,633,200
23,800
148,000
129,600
201,400
247,300
99,400
163,500
349,200
1,744,859
36,024
108,680
609,397
177,817
79,761
577,296
37,205
31,116
146,863
80,028
Pet.
88.55
11.45
23.72
5.91
1.99
16.84
51.54
3.17
19.73
17.28
26.85
32.97
16.24
26.71
57.05
100.00
3.56
10.74
60.24
17.58
7.88
100.00
12.60
10.54
49.75
27.11
See footnotes at end of table.
Continued
-------
Appendix table 2--Power plants 100 MW or greater using coal, 1975—Continued
I CAM
code Plant name
5022 Pulliam
5035 Weston
9005 Jim Bridger
9007 Johnston
9008 Naughton
County, town, Total coal Nameplate
& state used capacity
Tons MW
Brown 881 ,400 454
Green Bay
Wisconsin
Marathon 257,100 157
Rothschild
Wisconsin
Sweetwater 1,863,000 1,121
Rock Springs
Wyoming
Converse 3,218,000 817
Glenrock
Wyoming
Lincoln 1,719,000 707
Naughton
Wyoming
ICAM
link
A
B
C
D
E
A
B
C
D
E
A
A
A
Mine
Sarpy Creek
Clarion 1215
Pine Flats
Do tiki
Riverview
Vogue
Blackfoot 5
Hawthorn West
Col strip
Doti ki
Murdock
Delta
Will Scarlet
Blackfoot 5
Hawthorn West
Bridger
Johnston
Sorenson
CPA2/
MT4
PA1
PA2
KYI
INS
MT4
KYI
IL4
IL6
INS
WY4
WY3
WY4
Coal transport-
Tons
104,700
153,000
203,900
365,100
54,700
6,600
52,000
95,021
80.879
22,600
1,863,000
3,218,000
1,719,000
Pet.
11.88
17.36
23.13
41.42
6.21
2.57
20.22
36.96
31.46
8.79
100.00
100.00
100.00
I/ Unknown shipments less than 1 percent of total coal consumed have been eliminated from operational status.
2J Foreign source codes are those assigned by the Federal Energy Regulatory Commission and correspond to the
country named in the mine column, i.e. Australia = 3503. *
Source: (16)
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year
Data
sou re
1976:
1
1
3
1
1
1
1
1
1
3
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
2
2
2
2
e^-' Company
Falcon Coal Company
Falcon Coal Company
Marti ki Coal Corp.
Blue Diamond Coal Co.
Tampa Electric Co.
Blue Diamond Coal Co.
Gilbert Fuel Co.
Rochester and Pittsburgh Coal
Rochester and Pittsburgh Coal
Rochester and Pittsburgh Coal
North American Coal
Rochester and Pittsburgh Coal
Helvetia Coal Co.
North Somerset Mining
Old Home Manor
Island Creek Coal
Ea stover Mining Co.
Bell Petroleum
Bell Petroleum
Island Creek Coal
Bell Petroleum
Valley Camp Coal
Zapata Coal Corp.
Allegheny Pittsburgh Coal
Cedar Coal Company
Old Home Manor
Milton Fuller
Eagle Head Coal
Adolph Coors Co.
Garland Coal & Mining
Mine
Oldhouse Branch
Falcon #1
Marti ki
Unnamed
Unnamed
Justus
Crown City
Urling #2
Margaret #11
Urling #3
Josephine #2
Emilie #4
Lucerne #8
Unnamed
No. 8
Vail #20
Virginia #2
Brush Fork #1
Brush Fork #2
Unnamed
Spring Fork
Cedar Grove
Betty
Unnamed
Coal Fork #1
Unnamed
Mel Martinez
McGinley
Lincoln
Garland Bokoshe
County
Breathitt
Breath itt
Martin
Perry
Harlan
McCreary
Gallas
Armstrong
Armstrong
Armstrong
Indiana
Armstrong
Indiana
Somerset
Indiana
Harrison
Wise
Mercer
Mercer
Logan
Kanawha
Kanawha
Logan
Webster
Raleigh
Unlocated
Archuleta
Mesa
Weld
#10 LeFlore
State
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Ohio
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Ohio
Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Pennsylvania
Colorado
Colorado
Colorado
Colorado
Mine,
type
S
S
S
U
U
U
S
U
U
U
U
U
U
U
U
U
U
U
U
S
S
U
U
S
U
U
S
U
U
s,u
,, Capacity
- addition
Mil . tons
1.50
.90
1.20
.30
.80
.60
.50
.20
.20
.45
.30
.25
.40
.10
.20
.40
.30
.20
.20
.40
.40
.50
.50
1.00
.20
.20
.25
.25
.20
.25
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data ,,
source^'
1977:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Company
Peabody Coal. Co.
Peabody Coal. Co.
Helvetia Coal Co.
Cantebury Coal Co.
Old Home Manor
G.M. and W. Coal
G.M. and W. Coal
U.S. Steel Corp.
Benjamin Coal Co.
Westmoreland Coal
Southern Ohio Coal
Laurel Run Mining
El kay Mining Co.
Valley Camp Coal
Southern Appal achia Coal
Riverton Coal Co.
Sunflower Energy Corp.
Peabody Coal Co.
Knife River Coal
Consolidation Coal
Soldier Creek Coal
Republic Steel
Amax Coal
Pontiki Coal
Scotts Branch Co.
Leslie Coal Mining
Island Creek Coal
Southern Ohio Coal
Southern Ohio Coal
Southern Ohio Coal
Mine
Spur
Alston #4
Lucerne #9
Dianne
No. 4
Grove #3
Grove #4
Cumberland
Various mines
Holton-Taggart
Martinka #1
No. 1
Bradshaw
Donaldson
Ivy Creek
Unnamed
Old Blue Ribbon
Seneca
Gascoyne
Glenharold
Soldier Canyon
North River #1
Chinook
Pontiki
Scotts Branch
Lesl ie
Big Creek 1 and
Racoon #2
Meigs #1
Meigs #2
County
Warrick
Ohio
Indiana
Armstrong
Indiana
Cambria
Cambria
Greene
Clearfield
Wise
Marion
Grant
Me Do we! 1
Kanawha
Boone
Fayette
Delta
Routt
Bowman
Mercer, 01 iver
Carbon
Fayette
Clay
Martin
Pike
Pike
2 Unknown
Vinton
Meigs
Meigs
State
Indiana
Kentucky
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Colorado
Colorado
North Dakota
North Dakota
Utah
Alabama
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Ohio
Ohio
Ohio
Mine,
U
U
U
U
U
U
U
U
S
U
U
U
U
U
U
S
U
S
s
s
u
u
s
u
u
u
u
u
u
u
,, Capacity
- addition
Mil. tons
.20
.40
.15
.15
.20
.40
.20
.40
.10
.30
1.20
.40
.50
.50
.30
.50
.10
.20
.10
.10
.40
.70
.70
.40
.20
.20
.10
.40
.50
.40
See footnotes at end of table
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
U)
do
Data
sou re
1977:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1
e=-' Company
Continued
Oak Run Coal
Cedar Coal Co.
Cedar Coal Co.
Baukol-Noonan
Texas Utilities Generating
Zeigler Coal Co.
American Electric Power
Quarto Mining Co.
Colowyo Coal Co.
Jim Walter Resources
Mettiki Coal Corp.
Energy Fuels Corp.
Utah International
Pittsburg & Midway Coal
Texas Utilities Generating
Braztah Corp.
Peabody Coal Co.
Consolidation Coal
Carter Mining Co.
Atlantic Richfield
Big Horn Coal
Wyodak Resources
FMC Corporation
Amax Coal
Old Ben Coal
Sunoco Energy Development
American Electric Power
Peabody Coal
Utah International
U.S. Pipe & Foundry
Mine
Unnamed
Twin Poplar #1
Big John #4
Center
Monticello
Zeigler #11
Al bany
Powhattan #7
Colowyo
Blue Creek #4
Mettiki
Energy 1 and 2
San Juan
Me Kin ley
Martin Lake
Braztah 3,4,5,6
Wilberg
Emery
North Rawhide
Black Thunder
Big Horn #1
Wyodak N and S
Skull Point
Belle Ayr
Old Ben 25,27
Cordero
Various mines
Alston #1
Navajo
Blue Creek #3
County
Fayette
Boone
Boone
01 iver
Titus
Randolph
Athens
Monroe
Moffat
Tuscaloosa
Garrett
Routt
San Juan
Me Kin ley
Panola
Carbon
Emery
Emery
Campbel 1
Campbell
Sheridan
Campbell
Lincoln
Campbell
Franklin
Campbell
Breathitt
Ohio
San Juan
Jefferson
State
Pennsylvania
West Virginia
West Virginia
North Dakota
Texas
111 inois
Ohio
Ohio
Colorado
Alabama
Maryland
Colorado
New Mexico
New Mexico
Texas
Utah
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyomi ng
Wyoming
Wyoming
Illinois
Wyoming
Kentucky
Kentucky
New Mexico
Alabama
Mine,
U
U
U
S
S
U
U
U
S
U
U
s,u
S
S
S
U
U
U
S
S
S
S
S
S
U
S
s,u
S
S
U
,, Capacity
- addition
Mil . tons
.50
.10
.10
2.60
.60
.30
.50
1.00
.60
.10
.20
.90
.30
.70
2.40
.50
.20
.50
2.00
.03
1.40
.10
.80
9.90
1.50
3.00
1.00
1.00
.30
1.50
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
to
VO
Data
sou re
1977:
1
1
1
3
3
1
1
1
1
3
1
1
1
3
1
3
1
3
1
1
3
3
3
2
2
2
3
2
3
3
e— Company
Continued
Midland Coal Co.
Freeman United Coal
Monterey Coal Co.
Amax Coal
Old Ben Coal
Peabody Coal
Chapperal Coal
Bell Coal Corp.
North Somerset Mining
Laurel Run Mining
Rochester & Pittsburgh
Plateau Mining
Eastover Mining
Elkay Mining
Valley Camp Coal
Southern Appal achia Coal
Cedar Coal
Sewell Coal Co.
Island Creek Coal
Cedar Coal Co.
Peabody Coal Co.
Western Slope Carbon
Energy and Export Ltd.
Ruby Construction
Big Ben Coal
Island Creek Coal
Swisher Coal
Swisher Coal
Swisher Coal
Peabody Coal
Mine
Rapatee
Crown #2
Burning Star #5
Wabash
Old Ben #2
Panama
No. 3
Unnamed
Unnamed
No. 1
Iselin #9
E. Tennessee
Virginia #2
Brad shaw
Cedar Grove
Ivy Creek
Big John #3
Meadow River
Unnamed
Big John #2
Kayenta
Hawks Nest
McKinley #1
Sun
Big Ben #1
Unnamed
Gordon Creek #3
Swisher #5
Huntington Canyon
Deer Creek
County
Knox
Macoupin
Jackson
Wabash
Pike
Henderson
Pike
Bell
Somerset
Grant
Indiana
Campbel 1
Wise
McDowell
Kanawha
Boone
Boone
Fayette
Logan
Boone
Navajo
Gunnison
Mesa
Routt
Lucas
Carbon
Carbon
Emery
#4 Emery
Emery
State
11 linois
Illinois
Illinois
Illinois
Indiana
Kentucky
Kentucky
Kentucky
Pennsylvania
West Virginia
Pennsylvania
Tennessee
Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Arizona
Colorado
Colorado
Colorado
Iowa
Utah
Utah
Utah
Utah
Utah
Mine,
type^
S
U
U
U
S
U
U
U
U
U
S
U
U
U
U
U
U
U
S
U
S
U
U
U
U
U
U
U
U
U
,, Capacity
- addition
Mil. tons
.70
1.90
2.80
.70
.40
2.30
.40
.30
.30
.40
.40
.80
.40
.50
1.00
.30
.20
.15
.60
.10
2.30
.10
.10
.30
.20
2.00
.10
.20
.20
1.00
See footnotes at end of table
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1977:
2
2
3
3
2
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e— Company
Continued
Peabody Coal Co.
5M Corporation
Valley Camp of Utah
Valley Camp of Utah
Falcon Coal Co.
Jim Walter Resources
Blazer Fuels Co.
Chimney Rock Coal
Colorado Westmoreland
Empire Energy Corp.
General Exploration
Imperial Coal Co.
Limon Fuels Co.
Sheridan Enterprises
Sunland Mining Corp.
Arch Mineral Corp.
Consolidation Coal Co.
Peabody Coal Co.
Big H Combs Coal
Falcon Coal
Falcon Coal
K-W Mining Co.
Landmark Mining Co.
Southeast Coal Co.
Peabody Coal Co.
Peabody Coal
Peabody Coal Co.
Peabody Coal Co.
Amcord Inc.
Western Coal Co.
Mine
Unnamed
John Henry
Utah #2
Belina #1
Unnamed
Blue Creek 3
Blazer
Chimney Rock
Orchard Valley
Eagle 5
Roadside
Lincoln
Limon
McClane Canyon
Apex 2
Unnamed
Desoto
Lewis
Big H Combs
Kentucky River 1
Haddix 1
Davella 1
No. 2
406
Sinclair-Slope
Alston 3
Camp 11
Graham Hill
Sundance
San Juan
County
Emery
Kane
Carbon
Carbon
Campbel 1
Jefferson
Routt
Archuleta
Delta
Moffat
Mesa
Weld
El bert
Garfield
Routt
Unlocated
Jackson
Clay, Vigo
Letcher
Perry
Breathitt
Martin
Unlocated
Letcher
Muhlenberg
Ohio
Union
Muhlenberg
McKinley
San Juan
State
Utah
Utah
Utah
Utah
Wyoming
Alabama
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
111 inois
11 1 inois
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
New Mexico
New Mexico
Mine,
type^
U
U
U
U
S
U
U
S
U
U
U
U
S
S
U
S
S
S
u,s
u,s
u,s
S
u,s
U
U
U
U
U
S
S
Capacity
-' addition
Mil . tons
.70
.40
.10
.20
.30
.50
.25
.03
.30
.20
.20
.20
.30
.30
.10
1.00
2.00
.20
.10
.25
.25
.05
.40
.08
.40
.60
.50
.30
.20
.20
See footnotes at end of table
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data ,,
source— Company
1977:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1978:
3
3
3
3
3
Continued
Husky Industries
Cherokee Coal Co.
Consolidation Coal Co.
Shannon Coal Co.
W.P. Stahlman Coal Co.
Texas Utilities Co.
Coal Search Corp.
Coastal States Energy
United States Fuel
Washington Irrigation
and Development
Island Creek Coal
Bethlehem Mines Corp.
Big Mountain Coals
Cedar Coal
Southern Appalachian Coal
Arch Mineral Corp.
FMC Corp.
Rosebud Coal Sales
Marti ki Coal Corp.
Rochester and Pittsburgh Coal
Canterbury Coal Co.
G.M. & W. Coal Co.
U.S. Steel Corp.
Mine
Husky Strip
Porter
Westland 2
Unit 246
Unit 248
Big Brown
Knight
Convulsion Canyon
King
Centrali a
Alpine 2
Barbour 108
Big Mountain
Coal burg 1
Lens Creek 1
Seminoe 2
Skull Point
Rosebud
Mar tiki
Urling #3
Dianne
Grove #4
Cumberland
County
Stark
Wagoner
Washington
Clarion
Clarion
Freestone
Sevier
Sev i er
Carbon
Lewi s
Grant
Barbour
Boone
Boone
Kan awn a
Carbon
Lincoln
Carbon
Martin
Armstrong
Armstrong
Cambria
Greene
State
North Dakota
Oklahoma
Pennsylvania
Pennsylvania
Pennsylvania
Texas
Utah
Utah
Utah
Washington
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Wyoming
Wyoming
Wyoming
Kentucky
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Mine,
S
S
U
S
S
S
U
U
U
s
U
U
u,s
U
u,s
s
s
s
s
U
U
U
U
,, Capacity
- addition
Mil . tons
.06
.10
.15
.48
.09
.60
.50
.50
.30
1.00
.15
.10
.20
.20
.10
.50
.80
.30
1.40
.05
.15
.20
.60
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
H1
*-
NJ
Data
sou re
1978:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e- Company
Continued
Benjamin Coal Co.
Westmoreland Coal Co.
Laurel Run Mining
Elkay Mining Co.
Elkay Mining Co.
Valley Camp Coal
Southern Appal achia Coal
Riverton Coal Co.
Sunflower Energy Corp.
Peabody Coal Co.
Kaiser Steel Corp.
Knife River Coal Mining
Soldier Creek Coal
Zeigler Coal Co.
Amax Coal
Old Ben Coal Co.
Youghiogheny and Ohio Coal
Monterey Coal Co.
Cedar Coal Co.
Sewell Coal Co.
Peabody Coal Co.
Cambridge Mining Corp.
Coastal Mining Energy
Swisher Coal Co.
Peabody Coal Co.
Valley Camp of Utah
Western American Energy
Western American Energy
Zeigler Coal Co.
Southeast Coal Co.
Mine
Various mines
Holton-Taggart
No. 1
Bradshaw
Rum Creek
Donaldson
Ivy Creek
Unnamed
Old Blue Ribbon
Seneca
West York
Gascoyne
Soldier Canyon
Zeigler #5
Wabash
Old Ben #2
Cadiz Portal
Unnamed
Twin Poplar #1
Meadow River
Kayenta
CMC
S. Utah Fuels #1
Huntington Canyon
Deer Creek
Belina #1
Thompson
Rilda Canyon
Zeigler #11
Caudill's Br.
County
Clearfield
Wise
Grant
McDowell
Logan
Kanawha
Boone
Fayette
Delta
Routt
Col fax
Bowman
Carbon
Douglas
Wabash
Pike
Harrison
Wayne
Boone
Fayette
Navajo
Mesa
Sevier
Emery
Emery
Carbon
Grand
Emery
Randolph
Letcher
State
Pennsylvania
Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Colorado
Colorado
New Mexico
North Dakota
Utah
Illinois
Illinois
Indiana
Ohio
West Virginia
West Virginia
West Virginia
Arizona
Colorado
Utah
Utah
Utah
Utah
Utah
Utah
Illinois
Kentucky
Mine^ ,
type-'
Mi
S
u
u
u
u
u
u
S
u
S
S
S
u
u
u
S
u
u
u
u
S
u
u
u
u
u
u
u
u
u
Capacity
addition
1 . tons
.10
.30
.40
.50
.30
.50
.30
.20
.10
.20
.50
.50
.20
.60
.70
.50
.40
.01
.20
.20
1.00
.15
.50
.20
.30
.60
.20
.20
.90
.25
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
source Company
Mine
County
State
Mir
ie2/ Capacity
ie-' addition
Mil. tons
1978: Continued
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
See
American Electric Power
Quarto Mining Co.
Consolidation Coal Co.
Colowyo Coal Co.
Anschutz Coal Co.
Decker Coal
Mead Corporation
Jim Walter Resources
Monterey Coal Co.
Mettiki Coal Corp.
Sewanne Mining Co.
Coal Fuels
Utah International
Westmoreland Resources
Utah International
Pitts burg and Midway Coal
Texas Utilities Generating
Braztah Corp.
Peabody Coal Co.
Atlas Minerals
Carter Mining Co.
Atlantic Richfield
Big Horn Coal
Wyodak Resources
Rocky Mountain Energy
Energy Development Co.
Medicine Bow Coal
Old Ben Coal Co.
Inland Steel Co.
Falkirk Mining Co.
footnotes at end of table.
Al bany
Powhattan #7
Canadian
Col owyo
Thompson Creek
E and W Decker
North Mulga
Blue Creek #4
Monterey #2
Metti ke
Rineau #2
Dawson Unit
Trapper
Sarpy Creek
San Juan
McKinley
Martin Lake
Braztah 3,4,5,6
Wilberg
Factory Butte
North Rawhide
Black Thunder
Big Horn #1
Wyodak
Stansbury #1
Vanguard #2
Medicine Bow
Old Ben 25,27
Inland #2
Falkirk
Athens
Monroe
Jackson
Moffat
Pitkin
Big Horn
Jefferson
Tuscaloosa
Cl in ton
Garrett
Rio Blanco
Routt
Moffat
Big Horn
San Juan
McKinley
Panola
Carbon
Emery
Wayne
Campbel 1
Campbell
Sheridan
Campbell
Sweetwater
Carbon
Carbon
Franklin
Hamilton
McLean
Ohio
Ohio
Colorado
Colorado
Colorado
Montana
Alabama
Alabama
Illinois
Maryland
Colorado
Colorado
Colorado
Montana
New Mexico
New Mexico
Texas
Utah
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Illinois
Illinois
North Dakota
U
U
S
S
U
s
U
U
U
U
U
U
s
s
s
s
s
U
U
U
s
s
s
s
U
U
s
U
U
s
.50
1.00
.50
1.40
.10
2.80
.10
.80
1.00
.50
.40
.50
1.70
.50
.90
1.30
3.60
2.00
.50
.30
5.00
2.70
.30
1.70
.40
.20
.30
1.50
.10
5.50
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year--Continued
Data
sou re
1978:
3
3
3
3
3
3
3
3
3
1
3
3
3
3
3
3
3
3
1
1
3
3
1
3
1
3
2
3
3
3
e- Company
Continued
Ea stover Mining Co.
Kerr-McGee Corp.
Eastover Mining Co.
American Electric Power
Utah International
Republic Steel
Amax Coal
Amax Coal
Amax Coal
Peabody Coal Co.
Pontiki Coal Corp.
Scotts Branch Co.
Leslie Coal Mining
Island Creek Coal
Canada Coal Co.
Southern Ohio Coal
Southern Ohio Coal
Southern Ohio Coal
Quarto Mining Co.
North Somerset Mining
Oak Run Coal
Cedar Coal Co.
Island Creek Coal
Island Creek Coal
Tipperary Oil and Gas
CF and I Steel Corp.
Bill's Coal Co.
Texas Utilities Generating
Public Service Oklahoma
Energy Development Co.
Mine
Bell #7
Jacobs Ranch
Brookside #4
Various mines
Navajo
North River #1
New Del ta
Ayrcat
Chinook
Sinclair
Pontiki
Scotts Branch
Lesl ie
Big Creek 1,2
No. 2
Racoon #3
Meigs #1
Meigs #2
Powhattan #4
Unnamed
Unnamed
Big John #4
Unnamed
Upshur #2
Unnamed
Maxwel 1
Bill 's Coal
Monticello
PSO#1
Vanguard 3
County
Bell
Campbell
Harlan
Breathitt
San Juan
Fayette
Saline
Vermill ion
Clay
Muhlenburg
Martin
Pike
Pike
Unlocated
Pike
Vinton
Meigs
Meigs
Monroe
Somerset
Fayette
Boone
Logan
Upshur
Las Animas
Las Animas
Osage
Titus
Sheridan
Carbon
State
Kentucky
Wyoming
Kentucky
Kentucky
New Mexico
Alabama
11 linois
Illinois
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Ohio
Ohio
Ohio
Ohio
Pennsylvania
Pennsylvania
West Virginia
West Virginia
West Virginia
Colorado
Colorado
Kansas
Texas
Wyoming
Wyoming
Mine,
U
S
U
s,u
s
U
s
s
s
s
U
U
U
U
U
U
U
U
U
U
U
U
s
U
U
U
s
s
s
U
,. Capacity
- addition
Mil . tons
.10
2.50
.05
1.00
1.00
.55
1.60
1.50
.60
6.00
.60
.50
.50
.80
.50
.50
.60
.50
3.20
.40
.50
.20
1.20
.50
.50
.10
.25
2.00
.10
.20
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1978:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e- Company
Continued
Jim Walter Resources
Chimney Rock Coal
Coal Fuels
Colorado Westmoreland
Empire Energy Corp.
Empire Energy Corp.
General Exploration
Imperial Coal Co.
Limon Fuels Co.
Morrison-Knudsen Co.
Quinn Devleopment Co.
Amax Coal Co.
Arch Mineral Corp.
Morris Coal
Morris Coal
Peabody Coal Co.
Amax Coal Co.
Cherokee Coal Co.
Big H Combs Coal Co.
Falcon Coal Co.
Falcon Coal Co.
Falcon Coal Co.
Falcon Coal Co.
K-W Mining Co.
Kaneb Services
Plastics Univeral Corp.
Southeast Coal Co.
Peabody Coal Co.
Peabody Coal Co.
Peabody Coal Co.
Mine
Blue Creek #3
Chimney Rock
Anchor-Tresnor
Orchard Valley
Eagle 7
Eagle 9
Roadside
Lincoln
Limon
Hayden Gulch
Tomahawk
Sunspot
Unnamed
Morris 5
Morris 6
Baldwin 2
Ayrshire
Ful ton
Big H Combs
South Fork
Spicewood
Ky River 1
Haddix 1
Davella 3
County
Jefferson
Archuleta
Mesa, Garfield
Delta
Moffat
Moffat
Mesa
Weld
Elbert
Routt
Delta
Fulton
Unlocated
Williamson
Williamson
St. Clair
Warrick
Bourbon
Letcher
Breathitt
Breathitt
Perry
Breathitt
Martin
Breathitt(2 mines)Breathitt
Plastics Univ.
406
Sinclair Slope
Camp #11
Moorman #14
Knox
Letcher
Muhlenburg
Union, Webster
Muhlenburg
State
Alabama
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Illinois
Illinois
111 inois
Illinois
Illinois
Indiana
Kansas
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Mine,
U
S
U
U
U
U
U
U
S
S
S
S
S
U
U
U
S
S
u,s
S
S
u,s
u,s
U
S
S
U
U
U
U
,, Capacity
-' addition
Mi 1 . tons
.50
.07
.30
.20
.30
.45
.30
.10
.50
.10
.08
.50
1.00
.40
.25
.50
.60
.15
.10
1.50
.80
.25
.25
.15
.50
.24
.02
.35
.50
.50
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data
source
1978:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1979:
3
3
3
3
3
' Company
Continued
Peabody Coal Co.
Westmoreland Resources
Cherokee Coal Co.
Garland Coal and Mining
Consolidation Coal Co.
Duquesne Light Co.
Keystone Energy Co.
Leechburg Mining Co.
Shannon Coal Co.
Eugene B. Shirley Co.
Coal Search Corp.
Coal Search Corp.
Coastal States Energy
U.S. Fuel Co.
Utah Power and Light
Island Creek Coal
Laurel Run Mining
Big Mountain Coals
Cedar Coal Co.
A.T. Massey Coal
River ton Coal Co.
Southern Resources
Amax Coal Co.
Canterbury Coal Co.
G.M. and W. Coal Co.
U.S. Steel Corp.
Benjamin Coal Co.
Westmoreland Coal Co.
Mine
Big Sky
Absaloka
Porter
Rosehill
Westland 2
Warwick 5
KECO 1
Foster
Unit 2000
Wallace 1
Knight
Rock Canyon
Convulsion Canyon
King
Wilberg
Alpine 2
Mt. Storm 1
Big Mountain
Coal burg 1
Mingo County
Fayette City
Raleigh Co.
Eagle Butte
Dianne
Grove #4
Cumberland
Various mines
Hoi ton-Taggert
County
Rosebud
Big Horn
Wagoner
Haskell
Washington
Greene
Jefferson,
Armstrong
Armstrong
Clarion
Hopkins
Sevier
Sevier
Sevier
Carbon
Emery
Grant
Grant
Boone
Boone
Mingo
Fayette
Raleigh
Campbel 1
Armstrong
Cambria
Greene
Clearfield
Wise
State
Montana
Montana
Oklahoma
Oklahoma
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Texas
Utah
Utah
Utah
Utah
Utah
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Wyoming
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Virginia
Mine,
type^
S
S
S
S
U
U
S
u
S
S
u
u
u
u
u
u
u
u,s
u
u
u,s
u
S
u
u
u
S
u
,, Capacity
- addition
Mil. tons
.10
.50
.20
.10
.10
.05
.20
.25
.24
.18
.25
.25
.10
.30
.50
.20
.40
.20
.20
.50
.20
.25
3.80
.10
.20
.60
.10
.10
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1979:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e— ' Company
Continued
Laurel Run Mining
Elkay Mining Co.
Valley Camp Coal
Sunflower Energy Corp.
Seneca Coals Ltd.
Amax Coal
Youghiogheny and Ohio Coal
Monterey Coal Co.
Sewell Coal Co.
Western Slope Carbon
Cambridge Mining Corp.
Plateau Mining Co.
Utah Power and Light
Valley Camp of Utah
Western American Energy
Amax Coal
Pontiki Coal Corp.
Scotts Branch Co.
Lesl ie Coal Mining
Island Creek Coal
Southern Ohio Coal
Southern Ohio Coal
Southern Ohio Coal
Island Creek Coal
CF and I Steel Corp.
Texas Utilities Generating
Public Service Oklahoma
Energy Development Co.
Coalite Inc.
Mead Corporation
Mine
No. 1
Rum Creek
Donaldson
Old Blue Ribbon
Seneca
Wabash
Cadiz Portal
Unnamed
Meadow River
Hawks Nest
CMC
Star Point #3
Deer Creek
Belina #1
Thompson
Chinook
Pontiki
Scotts Branch
Lesl ie
Big Creek 1,2
Racoon #3
Meigs #1
Meigs #2
Upshur #1
Maxwel 1
Monticello
PSO #1
Vanguard 3
Bril 1 iant
North Mulga
County
Grant
Logan
Kanawha
Delta
Routt
Wabash
Harrison
Wayne
Fayette
Gunnison
Mesa
Carbon
Emery
Carbon
Grand
Clay
Martin
Pike
Pike
Unlocated
Vinton
Meigs
Meigs
Upshur
Las Animas
Titus
Sheridan
Carbon
Winston
Jefferson
State
West Virginia
West Virginia
West Virginia
Colorado
Colorado
Illinois
Ohio
West Virginia
West Virginia
Colorado
Colorado
Utah
Utah
Utah
Utah
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Ohio
Ohio
Ohio
West Virginia
Colorado
Texas
Wyoming
Wyoming
Alabama
Alabama
Mine,
type^
U
U
U
U
S
U
U
U
U
U
U
U
U
U
U
S
U
U
U
U
U
U
U
S
U
S
S
U
S
U
,, Capacity
- addition
Mil. tons
.50
1.08
.50
.10
.20
.30
.40
.21
.35
.20
.50
.60
.10
.20
.10
.10
.40
.35
.20
.30
.20
.70
.20
.60
.25
2.0
.40
.20
.30
.30
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year--Continued
Data . ,
source— Company
1979:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Continued
Jim Walter Resources
Monterey Coal Co.
Mettiki Coal Corp.
Coal Fuels
Cameron Engineers
Utah International
Western Energy Co.
Westmoreland Resources
Utah International
Pitts burg and Midway
Texas Utilities Generating
Peabody Coal Co.
Carter Mining Co.
Atlantic Richfield
Rocky Mountain Energy Co.
Rocky Mountain Energy Co.
Carter Oil Co.
FMC Corp.
Stansbury Coal Co.
Amax Coal Co.
Kerr-McGee Corp.
Black Butte Coal
Old Ben Coal Co.
Inland Steel Co.
Fa 1 kirk Mining Co.
Sunoco Energy Development
Eastover Mining Co.
Kerr-McGee Corp.
Eastover Mining Co.
American Electric Power
Mine
Blue Creek #4
Monterey #2
Mettiki
Dawson Unit
Station Creek
Trapper
Rosebud
Sarpy Creek
San Juan
McKinley
Martin Lake
Wilberg
N. Rawhide
Black Thunder
Hanna
Twin Creek
Coballo
Skull Point
Stanbury #1
Belle Ayr
East Gillette
Black Butte
Old Ben 25,27
Inland #2
Fa 1 kirk
Cardero
Bell #7
Jacobs Ranch
Brookside #4
Various mines
County
Tuscaloosa
Cl inton
Garrett
Routt
Elbert
Moffat
Rosebud
Big Horn
San Juan
McKinley
Panola
Emery
Campbell
Campbell
Carbon
Lincoln
Campbel 1
Lincoln
Sweetwater
Campbell
Campbel 1
Sweetwater
Frankl in
Hamilton
McLean
Campbell
Bell
Campbell
Harlan
Breathitt
State
Al abama
111 inois
Maryland
Colorado
Colorado
Colorado
Montana
Montana
New Mexico
New Mexico
Texas
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Illinois
Illinois
North Dakota
Wyoming
Kentucky
Wyoming
Kentucky
Kentucky
Mine,
type^
U
U
U
U
S
S
S
S
S
S
S
U
S
S
U
S
S
S
U
S
S
S
U
U
S
S
U
S
U
s,u
,, Capacity
- addition
Mil . tons
.90
1.10
.80
.50
.50
.60
1.40
2.50
1.40
1.50
5.00
.10
2.00
7.10
.20
1.50
1.00
.20
.30
.70
1.20
.60
1.00
.15
.50
3.00
.20
3.90
.05
1.00
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1979:
3
3
3
3
3
3
3
1
1
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e=/ Company
Continued
Zapata Corp-Getty Oil
Groves-Calder
Utah International
Carbon Coal Co.
Armco Steel Corp.
Peter Kiewit and Sons
Ziegler Coal Co.
Pittsburg and Midway
Pittsburg and Midway
Mclnnes Coal Mining
Southeast Coal Co.
American Electric Power
Quarto Mining Co.
Consolidation Coal Co.
W.R. Grace and Hanna Mining
Decker Coal Co.
Coastal Energy and Coal
Jim Walter Resources
Coal Fuels
Empire Energy Corp.
Empire Energy Corp.
General Exploration Co.
General Exploration Co.
Morrison-Knudson Co.
Quinn Development Co.
Morris Coal Inc.
Peabody Coal Co.
Peabody Coal Co.
Zeigler Coal Co.
Amax Coal
Mine
Grizzly Creek
Unnamed
Navajo
Gamerco
Unnamed
Whitney
Ziegler #11
Nortonville
Drake #5
Mclnnes
Eastern Ky
Albany
Powhattan #7
Canadian
Colowyo
Decker
Hamilton
Blue Creek 3
Anchor-Tresner
Eagle 6
Eagle 7
Cameo
Roadside
Hayden Gulch
Tomahawk
Morris 6
Baldwin 2
Baldwin 3
No. 6
Ayrshire
County
Jackson
Huerfano
San Juan
McKinley
LeFlore
Sheridan
Randolph
Hopkins
Muhlenburg
Pike
Letcher
Athens
Monroe
Jackson
Moffat
Big Horn
Skagit
Jefferson
Mesa, Garfield
Moffat
Moffat
Mesa
Mesa
Routt
Delta
Williamson
St. Clair
St. Clair
Douglas
Warrick
State
Colorado
Colorado
New Mexico
New Mexico
Oklahoma
Wyoming
Illinois
Kentucky
Kentucky
Kentucky
Kentucky
Ohio
Ohio
Colorado
Colorado
Montana
Washington
Alabama
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Illinois
Illinois
Illinois
Illinois
Indiana
Mine,
type^
S
S
S
S
U
S
U
S
U
U
U
U
U
S
S
S
U
U
U
U
U
U
U
S
S
U
U
U
U
S
,, Capacity
-' addition
Mil. tons
.50
.10
1.40
1.50
.50
1.00
.30
1.00
.50
.10
.10
.50
.90
.50
2.00
5.70
1.00
.45
.30
.30
.30
.20
.50
.65
.17
.25
.80
.50
.50
1.00
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Ln
O
Data
sou re
1979:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e=- Company
Continued
Peabody Coal
Falcon Coal Co.
Falcon Coal Co.
K-W Mining Co.
Kaneb Services Inc.
Peabody Coal Co.
Peabody Coal Co.
Pitts burg and Midway Coal
Pittsburg and Midway Coal
Knife River Coal Mining
Peabody Coal Co.
Westmoreland Resources
Amcord Inc.
Husky Industries
Youghiogheny and Ohio Coal
Garland Coal and Mining
Cambria Coal Co.
Duquesne Light Co.
Shannon Coal Co.
Shannon Coal Co.
Brazos Electric Power
Texas Utilities Co.
Coal Search Corp.
Coal Search Corp.
Coastal States Energy
U.S. Fuel Corp.
Island Creek Coal
Laurel Run Mining
A.T. Massey Coal
Southern Resources
Mine
Hawthorn West
Ky River 1
Haddix 1
Davella 3
Breathitt(2 mines)
Camp 11
Moorman 14
Fiddle Bow
Pleasant Hill
Savage
Big Sky
Absaloka
Sundance
Husky Strip
Nelms 2
Rosehill
Unit 480
Warwick 5
Unit 2000
Unit 1300
San Miguel
Rockdale
Accord Lake
Rock Canyon
Convulsion Canyon
Mohrland
Alpine 2
Mt. Storm 1
Mingo Co.
Raleigh Co.
County
Greene
Perry
Breathitt
Martin
Unlocated
Union, Webster
Muhlenburg
Hopkins
Hopkins
Richland
Rosebud
Big Horn
Me Kin ley
Stark
Harrison
Haskell
Cambria
Greene
Clarion
Clarion
Atascosa
Milan
Sevier
Sevier
Sevier
Emery
Grant
Grant
Mingo
Raleigh
State
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Montana
Montana
Montana
New Mexico
North Dakota
Ohio
Oklahoma
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Texas
Texas
Utah
Utah
Utah
Utah
West Virginia
West Virginia
West Virginia
West Virginia
Mine,,,
type^
Mi
S
U,S
U,S
U
S
U
S
U
S
S
S
S
S
S
U
S
S
U
S
S
S
S
U
U
U
U
U
U
U
U
Capacity
addition
1 . tons
.80
.25
.25
.05
.50
.50
.50
.25
.50
.10
.50
2.50
.10
.10
.20
.10
.18
.20
.24
.24
.50
.50
.50
.25
.40
.30
.50
.50
1.00
.25
See footnotes at end of table
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1979:
3
3
3
3
3
3
3
3
1980:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e— Company
Continued
Amax Coal Co.
Consolidation Coal Co.
Cravat Coal Co.
Energy Development
Ranchers Energy Corp.
Rocky Mtn Energy Co.
Rocky Mountain Energy Co.
Sheridan Enterprises
Rochester and Pittsburgh Coal
U.S. Steel Corp.
Benjamin Coal Co.
Elkay Mining Co.
Valley Camp Coal Co.
Seneca Coals Ltd.
Youghiogheny and Ohio Coal
Monterey Coal Co.
Western Slope Carbon
Energy and Export Co.
Valley Camp of Utah
Plateau Mining Co.
Swisher Coal Co.
Valley Camp of Utah
Western American Energy
Scotts Branch Co.
Leslie Coal Mining Co.
Island Creek Coal
CF and I Steel
Mclnnes Coal Co.
Mine
Eagle Butte
Pronghorn
De adman
Vanguard 2,3
Campbell Co.
South Haystack
Atlantic Rim
Welch 6
Urling 1
Cumberland
Various Mines
Run Creek
Donaldson
Seneca
Cadiz Portal
Wayne
Hawks Nest
McKinley 1
Belina #2
Star Point 3
Gordon Creek 3
Belina 1
Thompson
Scotts Branch
Leslie
Upshur 1
Maxwel 1
Mclnnes
County
Campbel 1
Campbell
Lincoln
Carbon
Campbel 1
Uinta
Carbon
Sheridan
Armstrong
Greene
Clearfield
Logan
Kanawha
Routt
Harrison
Wayne
Gunnison
Mesa
Carbon
Carbon
Carbon
Carbon
Grand
Pike
Pike
Upshur
Las Animas
Pike
State
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Pennsylvania
Pennsylvania
Pennsylvania
West Virginia
West Virginia
Colorado
Ohio
West Virginia
Colorado
Colorado
Utah
Utah
Utah
Utah
Utah
Kentucky
Kentucky
West Virginia
Colorado
Kentucky
Mine,
S
S
S
S,U
S
S
S
S
U
u
S
u
u
S
u
u
u
u
u
u
u
u
u
u
u
S
u
u
,, Capacity
--' addition
Mil . tons
2.40
2.00
.20
.20
.20
1.50
1.00
.30
.35
.60
.10
.12
.50
.10
.20
.74
.10
.10
.20
.40
.30
.30
.20
.20
.10
.80
.60
.20
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data .,
source— Company
1980:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1
3
2
2
2
Continued
Southeast Coal Co.
Anschutz Coal Co.
Inland Steel Co.
Falkirk Mining Co.
Sunoco Energy Development
Westmoreland Resources
Texas Utilities Generating
Texas Municipal Power Pool
Drummond Company
Eastover Mining Co.
Mintech Corp.
Kerr-McGee Corp.
Eastover Mining Corp.
Amax Coal Co.
American Electric Power
Moon Lake Electric
Zapata Corp. - Getty Oil
Northern Energy Resources
Armco Steel Corp.
Coalite Inc.
Mead Corporation
Jin Walter Resources
Monterey Coal Co.
Mettiki Coal Corp.
Consolidation Coal Co.
Island Creek Coal
Adolph Coors Co.
Merchants Petroleum Co.
Midland Coal Co.
Pittsburg and Midway
Mine
Eastern Kentucky
Thompson Creek 1,3
Inland 1
Falkirk
Cordero
Sarpy Creek
Twin Oaks
Gibbon Creek
Various mines
Bell #7
Watkins Lignite
Jacobs Ranch
Brooks ide #4
Belle Ayr
Various mines
Gordon
Grizzly Creek
Spring Creek
Unnamed
Brilliant
North Mulga
Blue Creek #4
Monterey #2
Metti ki
Unnamed
Upshur 2
King
Unnamed
Unnamed
Edna
County
Letcher
Pitkin
Hamilton
McLean
Campbel 1
Big Horn
Robertson
Grimes
Tuscaloosa
Bell
Adams
Campbell
Harland
Campbell
Breathitt
Rio Blanco
Jackson
Big Horn
LeFlore
Winston
Jefferson
Tuscaloosa
Cl in ton
Garrett
Noble
Upshur
Delta
Routt
Rio Blanco
Routt
State
Kentucky
Colorado
Illinois
North Dakota
Wyoming
Montana
Texas
Texas
Alabama
Kentucky
Colorado
Wyoming
Kentucky
Wyoming
Kentucky
Colorado
Colorado
Montana
Oklahoma
Alabama
Alabama
Alabama
Illinois
Maryland
Ohio
West Virginia
Colorado
Colorado
Colorado
Colorado
Mine,
U
U
U
S
S
S
S
S
S
U
S
S
U
S
s,u
U
S
S
U
S
U
U
U
U
S
U
U
U
S
S
,, Capacity
- addition
Mil. tons
.15
.50
.50
1.00
3.00
2.50
2.00
.20
.60
.30
2.00
2.10
.10
.10
2.00
1.50
1.50
3.00
.20
.18
.10
.20
1.10
.30
2.50
3.00
.25
4.40
.20
1.10
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Ul
u>
Data ..
source-' Company
1980
3
3
3
3
2
2
2
3
3
3
3
3
3
3
3
2
3
3
3
3
3
3
3
3
3
2
3
3
3
3
See
: Continued
Energy Fuels Corp
Coal Fuels
Colorado Westmoreland
Cameron Engineers
Empire Energy Corp
Paul S. Coupey
American Electric Power
Western Energy Co.
Pittsburg and Midway Coal
Texas Utilities Generating
Utah Power and Light
Utah Power and Light
Inspiration Development Co.
Centennial Coal Assoc.
Atlas Minerals
Clinton Oil Co.
Carter Mining Co.
Atlantic Richfield
Shell Oil Company
Northwestern Resources
Rocky Mountain Energy
Peter Kiewit and Sons
Carter Oil Company
Big Horn Coal Co.
Kemmerer Coal Co.
Kemmerer Coal Co.
Bridger Coal Co.
FMC Corp.
Rocky Mtn. Energy Co.
Kerr-McGee Corp.
footnotes at end of table.
Mine
Energy 1,2
Daws on Unit
Converse
Station Creek
Wise Hill 5,6,7
Unnamed
Unnamed
Rosebud
McKinley
Martin Lake
Wi 1 berg
Straight Canyon
Ferron Canyon
Unnamed
Factory Butte
Unnamed
No. Rawhide
Black Thunder
Buckskin
Grass Creek
Hanna
Twin Creek
Coballo
Big Horn #1
Sorenson
Elkol
Bridger
Skull Point
Stansbury 1
Gillette
County
Routt
Routt
Delta
Elbert
Moffat
Routt
Routt
Unlocated
McKinley
Panola
Emery
Emery
Emery
Carbon
Wayne
Sevier
Campbel 1
Campbell
Campbel 1
Hot Sprgs
Carbon
Lincoln
Campbel 1
Sheridan
Lincoln
Lincoln
Sweetwater
Lincoln
Sweetwater
Campbell
State
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Montana
New Mexico
Texas
Utah
Utah
Utah
Utah
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Mine2/ Capacity
type— addition
S,U
U
U
S
s,u
S
S
S
S
S
U
U
U
U
U
U
S
S
S
S
U
S
S
S
S
S
S
S
U
S
Mil . tons
1.00
.50
1.50
.50
2.00
1.00
1.00
2.61
.70
1.00
1.00
2.50
1.00
.50
.20
1.00
2.00
2.80
2.00
.70
.50
1.00
2.00
.50
1.10
1.10
1.65
.20
.25
3.10
Continued
-------
Appendix table 3—-Reported additions to steam coal mining capacity, by year—Continued
Ul
-p-
Data
sou re
1980:
3
2
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e- Company
Continued
Black Butte Coal
Columbine Mining Co.
Coal Fuels
Empire Energy Corp.
General Exploration Co.
General Exploration Co.
Morrison-Knudsen Co.
Sunland Mining Corp.
Mi cor Inc.
Peabody Coal Co.
Peabody Coal Co.
Zeigler Coal Co.
Amax Coal Co.
Falcon Coal Co.
Falcon Coal Co.
Landmark Mining Co.
Pittsburg and Midway Coal
Pittsburg and Midway Coal
Burlington Northern
Westmoreland Resources
Amcord, Inc.
Arch Mineral Corp.
Chaco Energy
Chaco Energy
Cherokee Coal Co.
Coteau Properties Co.
Husky Industries
Youghiogheny and Ohio Coal
Cambria Coal Co.
Duquesne Light Co.
Mine
Black Butte
Rainbow #8
Anchor-Tresnor
Eagle 6
Cameo
Roadside
Hayden Gulch
Apex 2
Unnamed
Baldwin 3
Baldwin 4
No. 6
Ayrshire
Ky River 1
Haddix 1
No. 2
Fiddle Bow
Pleasant Hill
Mussel shell
Absaloka
Sundance
Unit #1
Hospah
Star Lake
Unnamed
Mercer Co.
Husky Strip
Nelms 2
Unit 480
Warwick 5
County
Sweetwater
Sweetwater
Garfield, Mesa
Mo f fat
Mesa
Mesa
Routt
Routt
Unlocated
St. Clair
St. Clair
Douglas
Warrick
Perry
Breath itt
Unlocated
Hopkins
Hopkins
Mussel she! 1
Big Horn
McKinley
San Juan
McKinley
McKinley
San Juan
Mercer
Stark
Harrison
Cambria
Greene
State
Wyoming
Wyoming
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
11 linois
Illinois
Illinois
Illinois
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Montana
Montana
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
North Dakota
North Dakota
Ohio
Pennsylvania
Pennsylvania
Mine,
S
U
U
U
U
U
S
U
S
U
U
U
S
S,U
s,u
s,u
U
S
S
S
S
S
S
S
S
S
S
U
S
U
,, Capacity
-' addition
Mil. tons
4.80
.20
.40
.30
.40
.20
.25
.25
1.00
.80
.50
.50
.20
.25
.25
.10
.25
.50
.30
2.50
.20
.40
.50
.50
2.00
3.00
.10
.10
.01
.05
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data .,
source^-'
Company
Mine
County
State
Mine,/
type^7
Mi
Capacity
addition
1 . tons
1980: Continued
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1981:
3
3
3
3
3
Shannon Coal Co.
Shannon Coal Co.
W.P. Stahlman Coal
Brazos Electric Power
Texas Utilities Co.
C.T. Corp. System
Coal Search Corp.
Coal Search Corp.
Coastal States Energy
United State Fuel
A.T. Massey Coal
Amax Coal Co.
Consolidation Coal Co.
Pittsburg and Midway Coal
Ranchers Energy Corp.
Ranchers Energy Corp.
Rocky Mtn. Energy Co.
Rocky Mtn. Energy Co.
Sheridan Enterprises
Rochester and Pittsburgh Coal
Rochester and Pittsburgh Coal
U.S. Steel Corp.
Benjamin Coal Co.
Monterey Coal Co.
Western Slope Carbon
Valley Camp of Utah
Valley Camp of Utah
Mclnnes Coal Mining
Southeast Coal Co.
Unit 1300
Unit 1300D
Unit 131
San Miguel
Rockdale
Carbon Co.
Accord Lake
Rock Canyon
Convulsion Canyon
Mohrland
Mingo Co.
Eagle Butte
Pronghorn
Wildcat Creek
Campbell Co.
Campbell Co.
South Haystack
Atlantic Rim
Welch 6
Emilie #4
Urling #1
Cumberland
Various mines
Wayne
Hawks Nest
Belina #2
O'Connor #1
Mclnnes
Eastern Kentucky
Clarion
Clarion
Jefferson
Atascosa
Mi lam
Carbon
Sevier
Sevier
Sevier
Emery
Mingo
Campbell
Campbel 1
Campbell
Campbel 1
Campbell
Uinta
Carbon
Sheridan
Armstrong
Armstrong
Greene
Clearfield
Wayne
Gunnison
Carbon
Carbon
Pike
Letcher
Pennsylvania
Pennsylvania
Pennsylvania
Texas
Texas
Utah
Utah
Utah
Utah
Utah
West Virginia
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
West Virginia
Col orado
Utah
Utah
Kentucky
Kentucky
S
S
S
S
S
u
u
u
u
u
u
S
S
S
S
S
S
S
S
u
u
u
S
u
u
u
u
u
u
.24
.18
.11
2.50
2.10
.50
.50
.50
.20
.35
.50
3.403
1.50
3.80
.30
.20
1.00
1.00
1.70
.05
.10
.80
.10
.75
.20
.60
.20
.40
.10
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data , ,
source Company
1981:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Continued
Barnes and Tucker Co.
Anschutz Coal Co.
El Paso Natural Gas
Monterey Coal Co.
Adolph Coors
Coal Fuels
Atlantic Richfield
Western Energy Co.
Utah Power and Light
Atlas Minerals
Atlantic Richfield
Shell Oil Company
Rocky Mtn. Energy Co.
Carter Oil Co.
Rocky Mtn. Energy Co.
Kemmerer Coal Co.
Amax Coal Co.
Kerr-McGee Corp.
Rocky Mtn. Energy Co.
Texas Utilities Generating
Texas Utilities Generating
Texas Municipal Power Pool
Drummond Company
Cameron Engineers
Kerr-McGee Corp.
American Electric Power
Utah Power and Light
Northern Energy Resources
Consolidation Coal Co.
Rocky Mtn. Energy Co.
Mine
Yellow Creek
Thompson Creek 1,3
Thunderbird
Monterey #2
King
Dawson Unit
Mt. Gunnison
Rosebud
Wilberg
Factory Butte
Black Thunder
Buckskin
Hanna
Coballo
China Butte
Sorenson
Bel 1 e Ayr
East Gillette
Black Butte
Forest Grove
Twin Oaks
Gibbon Creek
Various mines
Watkins Lignite
Jacobs Ranch
Various mines
Escalante
Spring Creek
Burnham Complex
Long Canyon
County
Cambria
Pitkin
Campbel 1
Cl inton
Delta
Routt
Gunnison
Un located
Emery
Wayne
Campbel 1
Campbell
Carbon
Campbell
Carbon
Lincoln
Campbell
Campbell
Sweetwater
Henderson
Robertson
Grimes
Tuscaloosa
Adams
Campbel 1
Breathitt
Garfield
Big Horn
San Juan
Sweetwater
State
Pennsylvania
Colorado
Wyoming
Illinois
Colorado
Colorado
Colorado
Montana
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Texas
Texas
Texas
Alabama
Colorado
Wyoming
Kentucky
Utah
Montana
New Mexico
Wyoming
Mine2/
type-
Mi
U
U
S
U
U
U
U
S
U
U
S
S
U
S
S
S
S
S
S
S
S
S
S
S
S
s.u
U
S
S
U
Capacity
addition
1 . tons
.08
.20
2.50
.30
.25
.50
.50
1.55
.20
.20
2.70
2.00
.25
2.00
1.00
1.10
2.00
4.70
1.20
1.00
2.00
3.80
.30
3.00
2.20
2.00
1.00
4.00
2.00
.50
See footnotes at end of table.
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1981:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e-' Company
Continued
Inland Steel Co.
Knife River Coal Mining
Coal Fuels
Colorado Westmoreland
General Exploration Co.
Amax Coal Co.
Freeman United Coal Mining
Nicor Inc.
Peabody Coal
Zeigler Coal Co.
Landmark Mining Co.
Peabody Coal Co.
Amax Coal Co.
Burlington Northern
Consolidation Coal Co.
Peabody Coal Co.
Shell Oil Co.
Arch Mineral Corp.
Chaco Energy
Chaco Energy
Western Coal Co.
Coteau Properties Co.
Knife River Coal Mining
Natural Gas Pipeline
Peabody Coal Co.
Youghiogheny and Ohio Coal
Youghiogheny and Ohio Coal
No. American Coal Corp.
Shell Oil Co.
Coal Search Corp.
Mine
Inland #2
Beulah
Anchor-Tresnor
Orchard Valley
Cameo
Crab
Crown 3
Unnamed
Baldwin 4
No. 6
No. 2
Martwick
Sarpy Creek
Mussel shell
Ranch Project
Big Sky
Pearl
Unit 1
Hospah
Star Lake
Bisti
Mercer
Sprecher
Dunn Center
Nelsonville
Nelms 2
Allison
Athens
Rockdale
Accord Lake
County
Hamilton
Mercer, 01 iver
Mesa, Garfield
Delta
Mesa
Orchard
MaCoupin
Unlocated
St. Clair
Douglas
Unlocated
Muhlenburg
Crow Reservation
Mussel shell
Big Horn
Rosebud
Big Horn
San Juan
Me Kin ley
McKinley
San Juan
Mercer
Grant
Dunn
Perry
Harrison
Belmont
Henderson
Mi 1 am
Sevier
State
11 linois
North Dakota
Colorado
Colorado
Colorado
Illinois
Illinois
Illinois
Illinois
Illinois
Kentucky
Kentucky
Montana
Montana
Montana
Montana
Montana
New Mexico
New Mexico
New Mexico
New Mexico
North Dakota
North Dakota
North Dakota
Ohio
Ohio
Ohio
Texas
Texas
Utah
Mine,
type^
U
S
U
U
U
S
U
S
U
U
U,S
U
S
S
S
S
S
S
S
S
S
S
S
S
U
U
U
S
S
U
,, Capacity
-' addition
Mil. tons
.55
1.20
1.00
.50
.40
1.00
1.00
1.00
.80
.50
.10
.50
5.00
.30
1.50
.50
1.00
.40
.50
1.00
.40
3.00
.20
7.00
.50
.20
.10
1.00
1.00
1.00
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Ul
oo
Data
source
1981:
3
3
3
3
3
3
3
3
3
3
3
1982:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
— ' Company
Continued
Coal Search Corp.
United State Fuel Co.
Atlantic Richfield
Commonwealth Edison Co.
Consolidation Coal Co.
Kemmerer Coal Co.
Pittsburg and Midway Coal
Ranchers Energy Corp.
Rocky Mtn. Energy Co.
Rocky Mtn. Energy Co.
Sheridan Enterprises
Rochester and Pittsburgh Coal
Benjamin Coal Co.
Monterey Coal Co.
Western Slope Carbon
Energy and Export Ltd.
Valley Camp of Utah
Consolidation Coal Co.
Island Creek Coal Co.
Mclnnes Coal Mining
Southeast Coal Co.
Barnes and Tucker Co.
Freeport Coal Co.
El Paso Natural Gas
Coal Fuels
Atlantic Richfield
Mine
Rock Canyon
Mohrland
Coal Creek
Carbon Basin
Pronghorn
North Block
Wildcat Creek
Campbell Co.
So. Haystack
Atlantic Rim
Welch 6
Urling #1
Various mines
Wayne
Hawks Nest
McKinley #1
O'Connor #1
Emery Strip
Upshur #1
Mclnnes
Eastern Kentucky
Yel low Creek
Lorencito
Thunderbird
Dawson Unit
Mt. Gunnison
County
Sevier
Emery
Campbel 1
Carbon
Campbel 1
Lincoln
Campbel 1
Campbell
Uinta
Carbon
Sheridan
Armstrong
Clearfield
Wayne
Gunnison
Mesa
Carbon
Emery
Upshur
Pike
Letcher
Cambria
Las Animas
Campbel 1
Routt
Gunnison
State
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Pennsylvania
Pennsylvania
West Virginia
Colorado
Colorado
Utah
Utah
West Virginia
Kentucky
Kentucky
Pennsylvania
Colorado
Wyoming
Colorado
Colorado
Mine.. Capacity
type^-' addition
U
U
S
S,U
S
S
S
S
S
S
S
U
S
U
U
U
U
S
S
U
U
U
U
S
U
U
Mil. tons
1.00
.28
1.70
.50
1.50
1.50
1.00
.30
.50
.50
1.00
.10
.10
.29
.20
.10
.30
1.50
3.50
.30
.15
.38
.20
2.50
.60
.60
See footnotes at end of table.
Continued
-------
Appendix table 3~Reported additions to steam coal mining capacity, by year—Continued
Ul
VO
Data .,
source' Company
1982
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1
3
3
3
3
3
3
3
3
3
3
3
See
: Continued
Shell Oil Company
Texas Utilities Generating
Atlas Minerals
Carter Mining Co.
Atlantic Richfield
Rocky Mtn. Energy Co.
Carter Oil Co.
Rocky Mtn. Energy Co.
Rocky Mtn. Energy Co.
Wyodak Resources
Kerr-McGee Corp.
Inland Steel Co.
Drummond Company
Cameron Engineers
American Electric Power
Utah Power and Light
Northern Energy Resources
Rocky Mtn. Energy Co.
Old Ben Coal Co.
Amax Coal Co.
Texas Utilities Generating
Texas Utilities Generating
General Exploration Co.
Village Land Co.
Amax Coal Co.
Freeman United Coal Co.
Shell Oil Co.
Western Fuels Assn.
Zeigler Coal Co.
Amax Coal Co.
footnotes at end of table.
Mine
Youngs Creek
Martin Lake
Factory Butte
No. Rawhide
Black Thunder
Hanna
Coballo
Red Rim
China Butte
Wyodak
East Gillette
Inland #2
Ced rum
Watkins Lignite
Various Mines
Escalante
Spring Creek
Long Canyon
Unnamed
Unnamed
Forest Grove
Twin Oaks
Cameo
McGinley
Unnamed
Crown 3
Annex 1
Unnamed
No. 6
Wilson
County
Big Horn
Panola
Wayne
Campbell
Campbel 1
Carbon
Campbel 1
Carbon
Carbon
Campbell
Campbel 1
Hamilton
Tuscaloosa
Adams
Breathitt
Garfield
Big Horn
Sweetwater
Gibson
Knox
Henderson
Robertson
Mesa
Mesa
Unlocated
Macoupin
Logan
Sal ine
Douglas
Knox
State
Montana
Texas
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Illinois
Alabama
Col orado
Kentucky
Utah
Montana
Wyoming
Indiana
Indiana
Texas
Texas
Colorado
Colorado
11 linois
Illinois
Illinois
Illinois
Illinois
Illinois
Mine.
S
S
U
S
S
U
S
S
S
S
s
u
s
s
s,u
u
s
u
u
s
s
s
u
u
u
u
u
u
u
s
,/ Capacity
- addition
Mil. tons
4.00
1.00
.20
1.00
1.90
.25
3.00
1.00
1.00
2.50
3.50
.50
1.80
5.00
2.00
1.00
3.00
.50
2.00
1.10
1.80
2.00
.10
.10
.50
1.00
.20
.70
.50
1.10
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1982:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e— Company
Continued
Peabody Coal Co.
Peabody Coal Co.
Landmark Mining Co.
Peabody Coal Co.
Burlington Northern
Consolidation Coal
Peabody Coal Co.
Shell Oil Co.
Arch Mineral Corp.
Chaco Energy
Chaco Energy
Utah International Inc.
Western Coal Co.
Consolidation Coal Co.
Coteau Propoerties Co.
Husky Industries
Knife River Coal Mining
Nokota Mining Co.
Peabody Coal Co.
Youghiogheny and Ohio Coal
North American Coal
Shell Oil Co.
Rocky Mtn. Energy Co.
Rocky Mtn. Energy Co.
Kerr-McGee Corp.
Inland Steel Co.
Peabody Coal Co.
Utah Power and Light
American Electric Power
Utah Power and Light
Mine
Chieftan
Henderson B
No. 2
Martwick
Mussel shell
Ranch Project
Big Sky
Pearl
Unit 1
Hospah
Star Lake
Wesco
Bisti
Dakota Star
Mercer
Husky Strip
Sprecher
Garrison
Nelsonvil le
Allison
Athens
Rockdale
Red Rim
China Butte
East Gillette
Inland #2
Star Lake
Alton
Various mines
Escalante
County
Sullivan
Henderson
Unlocated
Muhlenberg
Mussel shell
Big Horn
Rosebud
Big Horn
San Juan
Me Kin ley
Me Kin ley
San Juan
San Juan
Mercer
Mercer
Stark
Grant
McLean
Morgan
Belmont
Henderson
Mi lam
Carbon
Carbon
Campbel 1
Hamilton
Me Kin ley
Kane
Breathitt
Gar field
State
Indiana
Kentucky
Kentucky
Kentucky
Montana
Montana
Montana
Montana
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
North Dakota
North Dakota
North Dakota
North Dakota
North Dakota
Ohio
Ohio
Texas
Texas
Wyoming
Wyoming
Wyoming
Illinois
New Mexico
Utah
Kentucky
Utah
See footnotes at end of table.
Mine,
type^
S
U
S,U
U
S
S
S
S
S
S
S
S
S
U
S
S
S
S
U
U
S
S
S
S
S
U
S
S
s,u
U
,, Capacity
- addition
Mil. tons
.50
.50
.10
.50
.30
1.50
.50
1.00
.40
.50
1.00
6.00
.60
4.00
1.10
.10
.30
.50
.50
.10
2.00
1.00
1.00
2.00
2.00
.50
.50
1.00
3.00
1.00
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
e— Company
Mine
County
State
Mine,,
type^
Capacity
addition
Mil. tons
1982:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
1983:
3
3
3
3
3
Continued
Armco Steel Corp.
Rocky Mtn. Energy Co.
Cameron Engineers
Coal Fuels
General Exploration
Amax Coal Co.
Shell Oil Co.
Western Fuels Assn.
Pea body Coal Co.
Peabody Coal Co.
Landmark Mining Co.
Peabody Coal Co.
Peabody Coal Co.
Peabody Coal Co.
Energy Fuels Corp.
United States Fuel
Amax Coal Co.
Atlantic Richfield
Commonwealth Edison
Energy Development
Peabody Coal Co.
Pittsburgh and Midway Coal
Benjamin Coal Co.
Valley Camp of Utah
Consolidation Coal Co.
Barnes and Tucker Co.
Freeport Coal Co.
Atlantic Richfield
Unnamed
Long Canyon
Watkins Lignite
Anchor-Tresnor
Cameo
Unnamed
Annex 1
Unnamed
Chieftan
Penndiana
No. 2
Henderson B
Henderson C
Martwick
McKinna 1,3
Mohrland
Eagle Butte
Coal Creek
Carbon Basin
North Knobs
No. Antelope
Wildcat Creek
Various mines
O'Connor #1
Emery Strip
Yellow Creek
Lorencito
Mt. Gunnison
LeFlore
Sweet water
Adams
Mesa, Garfield
Mesa
Unlocated
Logan
Sal ine
Sullivan
Sull ivan
Unlocated
Henderson
Henderson
Muhlenberg
Emery
Emery
Campbell
Campbel 1
Carbon
Carbon
Campbell
Campbel 1
Clearfield
Carbon
Emery
Cambria
Las Animas
Gunnison
Oklahoma
Wyoming
Colorado
Colorado
Colorado
11 linois
111 inois
Illinois
Indiana
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Pennsylvania
Utah
Utah
Pennsylvania
Colorado
Colorado
U
U
S
U
U
U
U
U
S
S
S,U
U
U
U
U
U
S
S
s,u
S
S
S
S
U
S
U
U
U
.10
.50
2.50
1.00
.10
.50
.50
.50
.50
.50
.10
.50
.50
.50
.50
.41
1.80
2.30
1.00
.50
2.50
1.00
.10
.20
1.50
.32
.40
.70
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1983:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e^-' Company
Continued
Shell Oil Co.
Texas Utilities Generating
Atlas Minerals
Peabody Coal Co.
Atlantic Richfield
Rocky Mtn. Energy Co.
Carter Oil Co.
Peabody Coal Co.
Burlington Northern
Consolidation Coal Co.
Peabody Coal Co.
Arch Mineral Corp.
Arch Mineral Corp.
Chaco Energy
Chaco Energy
Peabody Coal Co.
Utah International
Western Coal Co.
Knife River Coal Mng.
Nokota Mining Co.
North American Coal
Peabody Coal Co.
Youghiogheny and Ohio Coal
Brazos Electric Power
North American Coal
Shell Oil Co.
Consolidation Coal Co.
Energy Fuels Corp.
United State Fuel
Utah International Inc.
Mine
Youngs Creek
Martins Lake
Factory Butte
Rochelle
Black Thunder
Hanna
Coballo
Providence
Mussel shell
Ranch Project
Big Sky
Unit 1
Unit 2
Hospah
Star Lake
Star Lake East
We sco
Bisti
Sprecher
Garrison
Indian Head
Nelsonville
All ison
San Miguel
Athens
Rockdale
Emery Strip
McKinna 1,3
Mohrland
Alton
County
Big Horn
Panola
Wayne
Campbell
Campbel 1
Carbon
Campbel 1
Webster
Mussel shell
Big Horn
Rosebud
San Juan
San Juan
McKinley
McKinley
McKinley
San Juan
San Juan
Grant
McLean
Mercer
Morgan
Belmont
Atascosa
Henderson
Mi lam
Emery
Emery
Emery
Kane
State
Montana
Texas
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Kentucky
Montana
Montana
Montana
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
North Dakota
North Dakota
North Dakota
Ohio
Ohio
Texas
Texas
Texas
Utah
Utah
Utah
Utah
Mine,
type^
S
S
U
S
S
U
S
S
S
S
S
s
s
s
s
s
s
s
s
s
s
u
u
s
s
s
s
u
u
s
,, Capacity
- addition
Mil. tons
2.00
2.00
.10
2.00
2.77
.30
2.00
.80
.30
2.00
.50
.40
.40
.50
1.00
.50
4.00
.50
.50
.50
.40
.50
.10
.50
2.00
2.00
1.50
.50
.53
1.00
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1983:
3
3
3
3
3
3
3
1984:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e— Company
Continued
Amax Coal Co.
Atlantic Richfield
Commonwealth Edison
Northern Energy Resources
Peabody Coal Co.
Pitts burg and Midway Coal
Ranchers Energy Corp.
Benjamin Coal Co.
Valley Camp of Utah
Consolidation Coal Co.
Barnes and Tucker Co.
Freeport Coal Co.
Atlantic Richfield
Burlington Northern
Shell Oil Co.
Texas Utilities Generating
Peabody Coal Co.
Rocky Mtn. Energy Co.
Inland Steel Co.
Natural Gas Pipeline Co.
Nevada Power Co.
Kerr-McGee Corp.
American Electric Power
Utah Power and Light
Rocky Mtn. Energy Co.
Vil lage Land Co.
Amax Coal Co.
Mine
Eagle Butte
Coal Creek
Carbon Basin
Antelope
Gillette
Wildcat Creek
Campbell Co.
Various mines
O'Connor #1
Emery Strip
Yellow Creek
Lorencito
Mt. Gunnison
Circle West
Youngs Creek
Martins Lake
Rochelle
Red Rim
Inland #2
Unnamed
Alton
Jacobs Ranch
Various mines
Escalante
Long Canyon
Me Gin ley
Unnamed
County
Campbell
Campbell
Carbon
Converse
Campbel 1
Campbell
Campbel 1
Clearfield
Carbon
Emery
Cambria
Las Animas
Gunnison
McCone
Big Horn
Panola
Campbell
Carbon
Hamilton
Dunn
Kane
Campbell
Breath itt
Garfield
Sweetwater
Mesa
Unlocated
State
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Pennsylvania
Utah
Utah
Pennsylvania
Colorado
Colorado
Montana
Montana
Texas
Wyoming
Wyoming
Illinois
North Dakota
Utah
Wyoming
Kentucky
Utah
Wyoming
Colorado
111 inois
Mine?/
type*-'
Mi
S
S
S,U
S
S
S
S
S
u
S
u
u
u
S
S
S
S
S
u
S
S
S
s,u
u
u
u
u
Capacity
addition
1 . tons
1.00
4.00
2.50
.50
2.50
1.00
.50
.10
.30
.50
.08
.40
.30
1.00
2.00
1.00
2.00
.50
.20
7.00
4.00
1.80
3.00
2.00
.50
.10
.90
See footnotes at end of table.
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data ,,
source— Company
1984:
3
3
3
3
3
3
3
3
3
2
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Continued
Amax Coal Co.
Shell Oil Co.
Peabody Coal Co.
Peabody Coal Co.
Landmark Mining Co.
Peabody Coal Co.
Peabody Coal Co.
Peabody Coal Co.
Arch Mineral Corp.
Arch Mineral Corp.
Chaco Energy
Chaco Energy
Western Coal Co.
Consolidation Coal Co.
Husky Industries
Knife River Coal Mining
Nokota Mining Co.
Peabody Coal Co.
Youghiogheny and Ohio Coal
Brazos Electric Power
Lower Colorado River Authority
North American Coal
Shell Oil Co.
Energy Fuel Corp.
United States Fuel
Amax Coal Co.
Atlantic Richfield
Commonwealth Edison
Kerr-McGee Coal
Mebll Oil Corp.
Mine
Unnamed
Annex #1
Chieftan
Penndiana
No. 2
Henderson B
Henderson C
Martwick
Unit 1
Unit 2
Hospah
Star Lake
Bisti
Renners Cove
Husky Strip
Sprecher
Garrison
Nelsonville
Al 1 i son
San Miguel
Camp Swift
Athens
Rockdale
McKinna 1,3
Mohrland
Eagle Butte
Coal Creek
Carbon Basin
East Gillette
Unnamed
County
Unlocated
Logan
Sullivan
Sull ivan
Unlocated
Henderson
Henderson
Muhlenberg
San Juan
San Juan
Me Kin ley
Me Kin ley
San Juan
Mercer
Stark
Grant
McLean
Morgan
Belmont
Atascosa
Bastro
Henderson
Mi 1 am
Emery
Emery
Campbell
Campbel 1
Carbon
Campbel 1
Campbell
State
11 1 inois
111 inois
Indiana
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
North Dakota
North Dakota
North Dakota
Ohio
Ohio
Texas
Texas
Texas
Texas
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Mine,
S
U
S
S
U,S
U
U
U
S
S
S
S
S
S
S
S
S
U
U
S
S
S
S
U
U
S
U
s,u
S
S
,, Capacity
- addition
Mil. tons
1.10
.50
1.00
.50
.10
.60
.50
.50
.40
.40
2.00
1.00
.50
3.00
.10
.50
2.50
.20
.10
2.50
.30
1.00
2.00
1.00
.50
4.50
2.00
.50
.50
2.00
Se« f*»tnet«s at
of t«M«
Continued
-------
Appendix table 3—Reported additions to steam coal mining capacity, by year—Continued
Data ,,
source-' Company
1984
3
3
3
3
3
1985
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
See
: Continued
Northern Energy Resources
Northern Energy Resources
Peabody Coal Co.
Peabody Coal Co.
Pittsburg and Midway Coal
:
Western Slope Carbon
Valley Camp of Utah
Consolidation Coal Co.
Moon Lake Electric
Atlantic Richfield
Westmoreland Resources
Dryer Bros. Co.
Peabody Coal Co.
Wyodak Resources
Sunoco Energy Development
Utah Power and Light
Kerr-McGee Corp.
American Electric Power
Utah Power and Light
Consolidation Coal Co.
Kaiser Steel Corp.
Coal Fuels
Sheridan Enterprises
Amax Coal Co.
Shell Oil Co.
Peabody Coal Co.
Landmark Mining Co.
Peabody Coal Co.
Peabody Coal Co.
Westmoreland Resources
footnotes at end of table.
Mine
Cherokee
Antelope
No. Antelope
Gillette
Wildcat Creek
Hawks Nest
O'Connor #1
Emery Strip
Gordon
Mt. Gunnison
Sarpy Creek
Circle West
Rochelle
Wyodak
Cordero
Alton
Jacobs Ranch
Various mines
Escalante
Burnham Complex
York Canyon
Anchor-Tresnor
McClane Canyon
Unnamed
Annex 1
Penndiana
No. 2
Henderson C
Big Sky
Absaloka
County
Carbon
Converse
Campbell
Campbell
Campbel 1
Gunnison
Carbon
Emery
Rio Blanco
Gunnison
Big Horn
Me Cone
Campbell
Campbel 1
Campbell
Kane
Campbell
Breath itt
Farfield
San Juan
Col fax
Mesa, Garfield
Garfield
Un located
Logan
Sullivan
Unlocated
Henderson
Rosebud
Big Horn
State
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Colorado
Utah
Utah
Colorado
Colorado
Montana
Montana
Wyoming
Wyoming
Wyoming
Utah
Wyoming
Kentucky
Utah
New Mexico
New Mexico
Colorado
Colorado
11 1 inois
Illinois
Indiana
Kentucky
Kentucky
Montana
Montana
Mine
type
S
S
S
S
S
U
U
S
U
U
S
S
S
S
S
S
S
s,u
u
S
S
u
u
u
u
S
u,s
u
S
S
2/ Capacity
- addition
Mil. tons
2.00
4.00
2.50
2.50
1.00
.50
.50
.50
2.30
.30
4.50
2.00
3.00
3.50
3.00
4.00
2.50
5.00
1.00
2.00
.70
2.00
2.70
.20
.40
1.00
.10
.60
.50
4.50
Continued
-------
Appendix table 3--Reported additions to steam coal mining capacity, by year—Continued
Data
sou re
1985:
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
e— Company
Continued
Arch Mineral Corp.
Arch Mineral Corp.
Chaco Energy
Chaco Energy
Tucson Gas and Electric
Western Coal Co.
Consolidation Coal Co.
Nokota Mining Co.
Youghiogheny and Ohio Coal
Lower Colorado River Authority
Coastal States Energy
Energy Fuels Corp.
United States Fuel
Amax Coal Co.
Atlantic Richfield
Commonwealth Edison
Mobil Oil Corp.
Northern Energy Resources
Northern Energy Resources
Pittsburg and Midway Coal
Ranchers Energy Corp.
Western Fuel Corp.
Mine
Unit 1
Unit 2
Hospah
Star Lake
Gallo Wash
Bisti
Underwood
Garrison
Allison
Camp Swift
Convulsion Canyon
McKinna 1,3
Mohrland
Eagle Butte
Coal Creek
Carbon Basin
Unnamed
Cherokee
Antelope
Wildcat Creek
Campbell Co.
Converse Co.
County
San Juan
San Juan
Me Kin ley
Me Kin ley
San Juan
San Juan
McLean
McLean
Belmont
Bastro
Sevier
Emery
Emery
Campbell
Campbel 1
Carbon
Campbel 1
Carbon
Converse
Campbell
Campbell
Converse
State
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
North Dakota
North Dakota
Ohio
Texas
Utah
Utah
Utah
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Mine?/
type^7
Mi
S
S
S
S
S
S
S
S
u
S
u
u
u
S
S
s,u
S
S
S
S
S
S
Capacity
addition
1 . tons
.50
.40
2.00
1.50
.60
.50
1.50
3.10
.10
.50
1.80
1.90
.13
2.00
1.50
1.00
2.00
4.00
3.00
1.00
1.00
3.00
I/ Numerals in column 1 refer to following sources of data:
(1) Bureau of Mines Circular 1C 8725, June, 1976 (22)
(2) Bureau of Mines Circular 1C 8719, May, 1976 (21)
(3) Coal Age. February 1978 (2)
2J Mine types are designated as follows:
S = strip
U = underground
S,U = both strip and underground
-------
Appendix table 4—FERC Form 423 coal supply data for power plants supplied by
western coal
ICAM :
code :
9014
9002
9013
9009
9016
9006
9011
9019
5013
5025
5016
5014
5036
5003
Power plant
and state
Choi la
Arizona
Navajo
Arizona
Drake
Colorado
Hayden
Colorado
Arapahoe
Colorado
Cherokee
Colorado
Comanche
Colorado
Valmont
Colorado
Edwards
Illinois
Wallace
Illinois
Fisk
Illinois
Crawford
Illinois
Dixon
Illinois
Joliet
Illinois
: BOM ..:
: region—' :
1804
1835
2049
1608
1708
1804
1835
2049
1608
1708
1708
1608
1708
1956
1708
1956
1956
1608
1708
1956
2230
1608
2230
1608
2230
1956
2230
1956
1956
2049
2230
1956
1975
13,500
340,100
23,800
3,384,700
239,500
146,000
458,500
458,500
111,800
267,800
195,600
2,248,100
269,400
1,607,500
30,900
200,000
573,700
303,000
1,338,300
1,369,000
34,300
10,000
2,949,000
Coal suppl
: 1976 :
445,100
6,083,500 6,
234,900
685,273
685,273 1,
54,300
497,600
56,000
1,581,600 1,
100
2,638,500 2,
265,500
768,863
298,800
756,000
5,000
1,064,000
22,000
—
2,915,000 1,
ied
1977
556,100
64,100
93,000
753,800
149,900
538,200
21,400
869,600
068,013
16,200
915,000
847,300
184,500
537,500
44,200
418,200
640,831
--
881,000
130,000
761,100
347,400
—
969,000
796,000
: 1978
1,139,300
6,290,400
727,500
--
1,553,000
635,300
1,919,400
2,817,300
235,300
273,500
776,684
98,797
2,119
489,000
97,900
549,000
258,400
21,000
1,808,300
1,410,000
See footnote at end of table.
Continued
167
-------
Appendix table 4--FERC Form 423 coal supply data for power plants supplied by
western coal--Continued
ICAM
code
5004
5011
5007
5009
5024
5018
5002
5028
3029
3056
3023
3015
3050
3100
: Power plant :
: and state :
Powerton
Illinois
Waukegan
Illinois
Will County
Illinois
Joppa
Illinois
Hennepin
Illinois
Wood River
Illinois
Baldwin
Illinois
Venice 2
Illinois
State Line
Indiana
Breed
Indiana
Tanners Creek
Indiana
Clifty Creek
Indiana
Mitchell
Indiana
Edwardsport
BOM .:
region^':
2230
1956
1956
2230
2230
1956
1956
2230
1708
1956
2049
2230
1608
1956
1956
1956
2230
1956
2049
1608
1956
1956
1608
1956
1708
2049
1608
1975
228,000
1,509,000
121,000
2,378,000
9,000
17,962
10,251
14,461
10,003
32,571
81,251
212,000
903,000
819,000
29,600
130,300
231,000
1,667,720
1,600
Coal
: 1976
279,000
1,480,000
218,000
2,556,000
50,000
—
--
66,013
716,748
--
--
787,000
1,264,000
~
30,800
10,000
10,600
«
1,077,990
—
suppl ied
: 1977
--
1,523,000
184,000
1,737,000
697,000
--
--
86,010
830,671
173,875
--
528,000
1,315,000
--
126,600
30,500
—
894,600
256,600
--
: 1978
438,500
235,000
1,457,000
462,000
1,563,000
643,100
--
--
1,105,039
208,461
—
62,000
1,202,000
--
677,600
126,800
334,000
51,100
279,400
339,100
337,000
--
See footnote at end of table.
Continued
168
-------
Appendix table 4--FERC Form 423 coal supply data for power plants supplied by
western coal—Continued
ICAM :
code :
3027
6016
6015
6024
6020
6001
6030
6026
6021
6019
7003
7002
7006
3007
3086
Power plant :
and state :
Cayuga
Indiana
Kapp
Iowa
Prairie Creek
Iowa
Sutherland
Iowa
Riverside
Iowa
George Neal
Iowa
Maynard
Iowa
Council Bluffs
Iowa
Des Moines 2
Iowa
Burlington
Iowa
Lawrence
Kansas
LaCygne
Kansas
Tecumseh
Kansas
Shawnee
Kentucky
Marysville
Michigan
BOM .,:
region— :
1956
2230
1956
1608
2049
1608
1956
2230
1956
1956
2049
1956
1956
1956
1956
1956
1708
1956
1956
1708
2230
1956
2230
1975
10,100
137,100
96,200
6,000
31,600
16,000
5,000
16,000
1,152,049
3,455
18,851
301,600
133,835
15,100
798,800
--
338,800
169,900
4,000
Coal suppl
: 1976 :
—
128,600
116,000
98,000
--
2,440,616 2,
—
301,700
181,788
5,300
723,400
107,000 1,
342,100
41,867
--
ied
1977
--
93,200
2,700
118,000
117,000
--
553,780
95,900
299,400
167,061
32,600
708,600
778,900
310,900
41,665
--
: 1978
143,700
92,600
207,500
86,000
--
2,314,500
12,000
1,381,300
291,315
27,700
786,300
46,500
2,539,200
412,000
38,200
50,404
445,920
--
See footnote at end of table.
Continued
169
-------
Appendix table 4—FERC Form 423 coal supply data for power plants supplied by
western coal—Continued
1CAM
code
3014
3001
6031
6028
6007
6008
6010
6005
6100
6002
6025
7014
7013
7001
7004
: Power plant :
: and state :
St. Clair
Michigan
Monroe
Michigan
Fox Lake
Minnesota
Aurora
Minnesota
Boswel 1
Minnesota
Black Dog
Minnesota
High Bridge
Minnesota
King
Minnesota
Riverside
Minnesota
Sherburne Co.
Minnesota
Hoot Lake
Minnesota
Blue Valley
Missouri
Grand Avenue
Missouri
Hawthorne
Missouri
Montrose
Missouri
BOM ..:
region— :
2230
2230
2230
2230
2230
2230
2230
2230
2230
2230
2138
1608
1956
2049
1956
1956
1956
1975
884,000
168,000
42,500
388,700
2,070,900
707,000
775,000
519,000
863,000
647,000
679,400
4,900
69,700
1,600
3,500
806,500
10,000
Coal
: 1976
1,710,000
—
92,700
347,300
2,412,700
689,000
592,000
715,000
709,000
2,424,000
669,400
1,800
—
769,300
--
supplied
: 1977
2,296,000
--
154,500
360,100
2,336,300
649,000
494,000
884,000
790,000
4,067,000
712,200
—
--
541,700
--
: 1978
2,759,000
--
75,000
379,200
2,081,600'
556,000
501,000
801,000
728,000
4,644,000
658,700
--
—
571,700
--
See footnote at end of table.
Continued
170
-------
Appendix table 4--FERC Form 423 coal supply data for power plants supplied by
western coal—Continued
1CAM
code
5012
5001
6013
9020
6029
6017
6004
9017
9003
9001
9012
1007
1006
6003
6014
See
: Power plant
: and state
Meramec
Missouri
Labadie
Missouri
Col strip
Montana
Corette
Montana
Kramer
Nebraska
Sheldon
Nebraska
North Omaha
Nebraska
Gardner
Nevada
Mohave
Nevada
Four Corners
New Mexico
San Juan
New Mexico
Rochester 3
New York
Rochester 7
New York
Lei and Olds
North Dakota
Young
North Dakota
footnote at end
: BOM ..:
: region—':
1956
1608
1708
1956
1835
2049
2230
2230
1608
1956
1956
2049
1956
2049
1804
1835
1835
1608
1608
2138
2138
of table.
1975
7,000
101,000
197,000
700,000
134,500
104,900
148,200
2,000
965,000
655,800
3,820,000
5,941,600
1,243,300
4,000
1,000
1,863,800
1,517,121
Coal suj>pl
: 1976 :
--
208,000
1,422,000 2,
581,000
42,000
245,400
254,266
4,321
1,096,950 1,
820,500
4,174,000 4,
6,757,100 7,
1,263,600 1,
--
--
3,697,800 3,
1,580,835 1,
led
1977
--
154,000
250,000
661,000
195,678
288,620
160,190
279,700
828,400
568,000
390,300
731,300
--
--
371,000
530,452
: 1978
--
48,000
345,000
222,000
482,000
379,000
2,469,000
564,000
239,469
323,657
115,866
1,377,660
1,010,700
2,684,000
6,206,500
2,082,100
--
--
3,539,000
3,392,540
Continued
171
-------
Appendix table 4--FERC Form 423 coal supply data for power plants supplied by
western coal--Continued
I CAM
code
6032
6023
3020
3002
6009
9018
9015
9010
6022
6012
5005
5029
5017
6018
5002
See
: Power plant
: and state
Heskett
North Dakota
Stanton
North Dakota
Cardinal
Ohio
Gavin
Ohio
Big Stone
South Dakota
Carbon
Utah
Gads by
Utah
Huntington
Canyon
Utah
Alma
Wisconsin
Genoa 3
Wisconsin
Oak Creek
Wisconsin
Blount
Wisconsin
Columbia
Wisconsin
Nel son Dewey
Wisconsin
Pul 1 iam
Wisconsin
footnote at end
: BOM ,,:
: region-':
2138
2138
2230
2049
1956
1956
2049
1608
2138
2049
2049
2049
1956
2230
1956
2230
1956
2049
2230
2230
1956
2230
2230
of table.
1975
426,892
569,100
166,400
23,000
937,700
339,400
1,609,300
433,000
401,000
1,014,000
101,000
106,800
199,200
149,700
751,600
--
1,744,859
—
104,700
Coal suppl
: 1976 :
Tons-
527,200
788,800
—
2,010,700 3,
863,400
275,300
2,459,700 2,
454,000
379,000
914,000 1,
101,100
72,700
182,400
170,100
682,300
3,000
1,867,463 1,
169,474
90,800
led
1977
577,200
731,500
—
620,700
812,700
15,800
237,200
585,000
468,000
217,000
198,500
234,200
703,000
14,400
881,426
135,684
67,500
: 1978
472,000
795,000
4,300
68,200
4,312,100
34,500
2,862,300
364,000
212,000
1,538,000
200,700
254,500
677,700
26,600
60,500
1,674,730
1,221,826
115,211
57,300
Continued
172
-------
Appendix table 4—FERC Form 423 coal supply data for power plants supplied by
western coal—Continued
ICAM : Power plant:BOM..: Coal supplied
code : and state : region-^: 1975 : 1976 : 1977 : 1978
Tons
5035 Weston 2230 6,600 17,900 6,400 2,800
Wisconsin
9005 Jim Bridger 1956 1,863,000 2,432,000 4,930,000 4,540,000
Wyoming
9007 Dave Johnston 1956 3,218,000 2,716,000 3,248,000 3,360,000
Wyoming
9008 Naughton 1956 1,719,000 1,170,000 2,730,000 2,340,000
Wyoming 2049 -- 748,000
-- = none
\J BOM = Bureau of Mines
Source: (16)
173
-------
Appendix table 5—Additions to generation capacity: 1976-1990
ICAM : Power system, plant,
code : and location
Coal
requ i red
Coal source
Nameplate
capacity
Data
source
1976:
8002
4023
4020
5038
5002
3043
3108
Texas Power & Light Co.
Monticello #2
Titus Co., Texas
Tampa Electric Company
Big Bend #3
Hillsborough Co., Florida
*has captive reserves available
Georgia Power Co.
Wansley #1
Heard Co., Georgia
(Carrollton) Co., Illinois
Central Illinois Light
(FGD system)
Duck Creek #1
Fulton Co., Illinois
(Canton)
Illinois Power
Baldwin #3
Randolph Co, Illinois
(Baldwin)
Public Service of Indiana
(FGD system)
Gibson #2
Gibson Co., Indiana
(Princeton) Carlinville,
Illinois
Northern Indiana Public
Service
Schahfer #14
Jasper Co., Indiana
(Wheatfield) Valley,
Paonia, Colorado
Monticello, minemouth
Island #9, Kentucky
Old Ben Coal, Franklin
Orient #4, Virden,
Illinois
Baldwin, Illinois
Carter Oil/Monterey
mine
Westmoreland/Orchard
MW
575
446
865
400
635
650
500
1,000 tons
3,300
1,219
2,300
1,080
1,710
1,500
1,200
8,4a
2,8,13
2Q
»o
2,8
2,8
2,8
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990--Continued
ICAM :
code :
1976:
3017
Power system, plant, :
and location : Coal source
Continued
Columbus & Southern Ohio
: Nameplate :
: capacity :
MW
411
Coal
requ i red
1,000 tons
1,100
: Data
: sou rce
2,8,13
Ohio Electric
Conesville #5
Coshocton Co., Ohio
Ireland,Moundsville,
West Virginia
*has captive reserves available
6001 Iowa Public Service Energy Development 520 1,750 2,9
George Neal #3 Hanna, Wyoming
Woodbury Co., Iowa (Salix)
*has captive reserves available
6002 Northern States Power Col strip/Absaloka, 710 2,250 2,9
Sherburne #1 Montana
Sherburne Co., Minnesota
(Becker)
*Mississippi River is water source
(FGD system)
5044 Springfield Utilities Ft. Scott, Kansas 200 650 4b,9
(FGD system) Cherokee Coal, Kansas
Southwest #1
Greene Co., Missouri
(Springfield)
9017 Nevada Power Co. Deer Creek/Clear Creek, Utah 110 365 2 10
(FGD system)
Gardner #3
Clarke Co., Nevada (Moapa)
*has captive reserves
6013 Montana Power Company Col strip-Rosebud, Montana 330 2 367 ? Q
(FGD system) ' '
Col strip #2
Rosebud Co., Montana
(Coal strip)
*has captive reserve available
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Nameplate
capacity
Coal source
Coal
requ i red
Data
source
1976:
6033
8033
9005
2021
5039
9009
1977:
8004
Continued
City of Fremont
Fremont #1
Dodge Co., Nebraska (Fremont)
Texas Utilities Generating
(FGD system)
Martin Lake #1
Rusk Co., Texas (Tatum)
*mine mouth plant
*has captive reserves
Pacific Power & Light
Jim Bridger #2
Sweetwater Co., Wyoming
*has captive reserves
Pennsylvania Power Co.
(FGD system)
Mansfield #1
Beaver Co., Pennsylvania
(Shippingport)
(Duquesne Light Co.)
Union Electric Co.
Rush Island #1
Jefferson Co., Missouri
Colorado-Ute Electric
Assn.
Hayden #2
Routt Co., Colorado
San Antonio Public Service
J.T. Deely #1
Bexar Co., Texas (San Antonio)
Jacobs Ranch, Wyoming
Martin Lake Mine/
Texas Utilities, Texas
captive mine, Wyoming
(Rock Springs) (Jim Bridger)
Powhatan 1,3,4,7, Ohio
Peg Run, Utilities,
Pennsylvania
Glenbrook, Kentucky
Arkwright, West Virginia
Burning Star 2,3,4/
Consol Coal, Illinois
Seneca
Sunoco/Cordero,
Campbell Co., Wyoming
134
750
500
809
575
260
418
1,000 tons
990
3,500
1,800
3,000
1,400
760
1,450
4b,9
2,9
4b,9
10
2,10
2,4b,9
Continued
-------
table 5--Addit1ofis to generation capacity: 1976-1990—Continued
I CAM : Power system, plant,
code : _ and location
Coal source
Name pi ate
capacity
Coal
required
Data
source
1976: Continued
4042
3052
6035
5040
3034
4057
3016
S. Carolina Public Service
Authority
(FGD system)
Winyah #2
Georgetown Co., South Carolina
(Georgetown)
Kentucky Utilities Co.
Ghent #2
Carroll Co., Kentucky (Ghent)
Potter, Mack, Stoney Fork,
Creech, Kentucky
RP, Hazard, Kentucky
Baukol Noonan, Center,
North Dakota
Minnkota Power Co-op
Square Butte
Oliver Co., North Dakota
(Center)
*addition to Young Plant-26,000 water afy (Missouri River)
*mine mouth
Central Ilinois Public
Service
(FGD system)
Newton #1
Jasper Co*., Indiana (Petersburg)
Indianapolis Power & Light
(FGD system)
Petersburg #3
Pike Co., Indiana (Petersburg)
Mississippi Power Co.
Jackson Co. #1 (Daniel #1)
Jackson Co., Mississippi
(Moss Point)
Pennsylvania Electric
Homer City #3
Indiana Co. (Homer City)
Delta, Marion, Illinois
Blackfoot #5, Indiana
Abbot I/ Blue Creek, Kentucky
Swisher Coal, Emery Co., Utah
(Subsidiary)
Lucerne 6,8,9/Homer City/Hawk/
Josephine 2,
Sweard, Pennsylvania
MW
280
550
234
550
515
500
650
_
1.000 tons
463 2,5,8,13
600
2,500
1,100
1,200
750
2,4a,8
2,9
2,4a,8
2,8
2,4a,8,13
1,300 4a,10,8
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
Name pi ate
capacity
MW
615
Coal
requ i red
Data
source
1977:
3020
6036
7018
9010
9005
7002
6002
Continued
Cardinal Operating Co.
(Buckeye Power Inc.)
(Ohio Power)
Cardinal #3
Brilliant, Ohio
Interstate Power Co.
Lansing #4
Allamakee Co., Iowa
Southwestern Electric Power
Welsh #1
Morris Co., Texas (Cason)
Utah Power & Light
(FGD system)
Huntington Canyon
Emery Co., Utah
*14,000 afy (Electric Lake)
*has captive reserves
Pacific Power & Light
Jim Bridger #3
Sweetwater Co., Wyoming
(Rock Springs)
*has captive reserves
Kansas City Power & Light
(FGD system)
LaCygne #2
Linn Co., Kansas (LaCygne)
Donaldson/Charleston,
West Virginia
Amax, Gillette, Wyoming
Amax/Belle Ayr, Campbell
Co., Wyoming
Peabody/Deer Creek,
Huntington Canyon, Utah
Jim Bridger, Wyoming
Amax, Gillette, Wyoming
Northern States Power
(FGD system)
Sherburne #2
Sherburne Co., Minnesota
(Becker)
*Mississippi River is water source
Colstrip/Absaloka,Montana
324
528
400
500
630
680
1,000 tons
1,500
943
1,586
1,300
1,800
1,400
2,250
2,4a,10
2,10
2,9
2,9
4b,9
2,9
2,9
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
: Name pi ate : Coal
: capacity : requ i red
ICAM : Power system, plant,
code : and location
Coal source
Data
source
1977: Continued
5039 Union Electric Company
Rush Island #2
Jefferson Co., Missouri
(Crystal City)
5015 Associated Electric Co-op
New Madrid #2
(New Madrid)
6033 Fremont Dept. Utilities
Fremont #2
Dodge Co., Nebraska
(Fremont)
3106 East Kentucky Power Co-op
Spurlock #1
Maysville Co., Kentucky
7017 Oklahoma Gas & Electric
Muskogee #4
Muskogee Co., Oklahoma
(Muskogee)
7016 Southwestern Public
Service Company
Harrington #1
Potter Co. (Amarillo) Texas
1978:
8004 San Antonio Public
Service
(oil & coal)
J.T. Deely #2
Bexar Co., Texas
(San Antonio)
Burning Star 2,3,4/
Consolidation, Illinois
Baldwin I/
New Madrid Co., Missouri
Jacobs Ranch, Wyoming
Addington Bros.#5,
Eastern Kentucky
Arco/Black Thunder,
Campbell Co., Wyoming
Arco/Black Thunder,
Campbell Co., Wyoming
Amax/Belle Ayr, Wyoming
McKinley Mine, New Mexico
Sunoco/Cordero,
Campbell Co., Wyoming
MW
575
600
87 or
200
300
572
360
418
1,000 tons
1,800
1,900
450
1,000
1,650
1,000
1,450
2,9
2,9
10
8,2,13
9,2
4b,7
1,2,9
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
DO
O
ICAM :
code :
1978:
3040
9023
4056
4056
8002
8003
7019
Power system, plant, : : Nameplate
and location : Coal source : capacity
MW
Continued
Louisville Gas & Elec. Star U.G., Riverview/Spot 425
(FGD system) Mkt., Western Kentucky
Mill Creek #3
Jefferson Co., Kentucky
(Kosmosdale)
Pacific Power & Light Amax/Belle Ayr, 330
Wyodak #1 Gillette, Wyoming
Gillette, Wyoming
South Mississippi Electric Sandyfork, Kentucky 180
Power Assoc.
Morrow #1
Lamar Co., Mississippi
(Purvis)
*captive reserves
Morrow #2 Sandyfork, Kentucky 180
Lamar Co., Mississippi
(Purvis)
Texas Power & Light Monticello
Monticello #3 captive, Hopkins Co., Mine, Texas
Mt. Pleasant, Texas
*lignite-mine mouth
Texas Utilities Gener. Martin Lake Mine, Texas 750
Martin Lake #2
Rusk Co., Texas
(Tatum)
*captive reserve-mine mouth
*1 ignite
(FGD system)
Southwestern Electric Amax Coal/Belle Ayr, Wyoming 528
Power
: Coal : Data
: required : source
1,000 tons
1,035 8
1,
1,600 1,
400 8
1,
400 8
1,
3,900 9
1,
2,5,13
2,5
4a,13
4a,13
2,4b
5,000 9
l,4b
1,700 l,2,5b
9
Flint Creek #1
Benton Co., Arkansas
(Siloam Springs)
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant, : : Nameplate : Coal : Data
code : and location : Coal source : capacity : required : source
MW 1,000 tons
1978: Continued
7017 Oklahoma Gas & Electric Arco/Black Thunder, 572 1,650 l,2,4b,9
Muskogee #5 Campbell Co., Wyoming
Muskogee Co., Oklahoma
5017 Wisconsin Power & Light Arco/Black Thunder, 513 1,900 l,4a,9
(FGD system) Campbell Co., Wyoming
Columbia #2
Columbia Co., Wisconsin
(Portage)
(Wisconsin Public Service/
Madison Gas & Electric) '
9014 Arizona Public Service Co. Pittsburg & Midway/ 263 800 l,2,4b
(FGD system) McKinley, Gallup, New Mexico 7,8
Cholla #2
Navajo Co., Arizona
(Joseph City)
*water requirements estimated at 25,700 afy
*limestone scrubber
9025 Arizona Electric Power Mentmore Mine, Gallup, 175 550 7,9
Co-op New Mexico (Also Colorado) 1,2
(FGD systems)
Apache #2
Cochise Co., Arizona
(Cochise)
*has captive reserves, unit train (90 cars)
3017 Columbus & Southern Ohio Ireland, Mounds- 375 1,100 1,2,3
Electric ville, Wyoming 4a,8,13
(FGD system)
Conesville #6
Coshocton Co., Ohio
(Conesville)
*has captive reserves
N/A Upper Peninsula Col strip-Rosebud/ 80 100 l,4a,8,13
Generating Co. Westmoreland (50%), Montana
Presque Isle #7 Absaloka-Sarpy/
Marquette Co., Michigan Western Energy Co., (50%) Montana
(Marquette)
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—-Continued
ICAM : Power system, plant,
code : and location
Coal source
: Nameplate : Coal
: capacity : requ i red
Data
source
1978: Continued
N/A Upper Peninsula
Generating Co.
Presque Isle #8
Marquette Co., Michigan
(Marquette)
7016 Southwestern Public Service
Harrington #2
Potter Co., Texas
(Amarillo)
*coal and gas
9022 Utah Power & Light
(FGD system)
Emery #1
Emery Co., Utah
(Castle Dale)
*14,000 afy
*has captive reserves
3032 Cincinnati Gas & Electric
(FGD system)
Miami Fort #8
Hamilton Co., Ohio
(North Bend)
5041 Southern Ilinois Power
Co-op
Williamson Co., Illinois
(Marion)
3043 Public Service of Indiana
(FGD system)
Gibson #3
Gibson Co., Indiana
(Princeton)
4059 Alabama Power Co.
James Miller #1
Jefferson Co.,
Birmingham, Alabama
*coal will be trucked
Col strip-Rosebud/
Westmoreland (50%), Montana
Absaloka-Sarpy/
Western Energy Co., (50%) Montana
Arco/Black Thunder,
Campbell Co., Wyoming
McKinley/P & M, New Mexico
Deseret (Chorch), Huntington,
Utah
Tiltonville, (Georgetown),
Ohio
Delat Mine/Annax, Illinois
Carter Oil/Monterey mine,
Carlinville, Illinois
King Coal Co..Jefferson
Co., Alabama
MW
80
317
415
500
272
650
660
1.000 tons
100
1,000
650
1,200
768
1,500
950
l,4a,8,13
l,2,4b,9
l,4b,9
3,4a,8,13,12
1,2,8,12
1,8
1,2,4,8,13
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant : : Nameplate : Coal : Data
code : and location : Coal source : capacity : required : source
MW 1,000 tons
1978: Continued
4060 Alabama Power Co-op Champion, Big Bend, 235 300 1,2,8,13
(FGD system) Hamilton Mine, Alabama
Tombigbee #2
Washington Co., Alabama
(LeRoy)
4020 Georgia Power Co. Old Ben #24, Illinois, 865 1,500 l,4a,8,13
Wansley #2 Indiana Blackfoot #5
Heard Co., Georgia
(Carroll ton)
4058 Savannah Electric & Power D & H, Tennessee 342 1,000 l,4a,8,ll
Port Wentworth #1 Osborne, Virginia
Chatham Co., Georgia Premele, Kentucky
(Savannah)
Conversion From Oil & Gas to Coal
5032 Springfield Municipal Crown 2 Mine, Virden,111inois 193 565 l,2,4a
Dallman #3 Murdock Mine, Murdock Illinois 7,10
Springfield, Illinois
(Sangamon Co.)
*electro-static precipitator-wet limestone
5042 Illinois Power Co. Energy Fuels, Routt 450 1,200 4a,l,7
Havana #6 Co., Colorado
Mason Co. (Havana) Illinois Beechford-Tilford
Golden Oak, Kentucky
1979:
6039 United Power Assoc. Co-op Falkirk mine/North Dakota 500 2,500 l,4b,9
Coal Creek #1
McLean Co., North Dakota (Falkirk)
Power Assoc. - ownership: 44% UPA, 56% CPA.
(FGD system)
Construction in progress - 15,000 water afy (Missouri River)
*1 ignite
Continued
-------
Appendix table 5~Additions to generation capacity: 1976-1990--Continued
00
.e-
ICAM : Power system, plant : : Nameplate : Coal : Data
code : and location : Coal source : capacity : required source
MW 1,000 tons
1979: Continued
6038 Nebraska Public Power Arco/Black Thunder, Wyoming 650 2,000 l,2,4b,9,16
District
Lincoln Co., Nebraska
(Sutherland)
*Sutherland Reservoir is water source-railroad spur planned
6022 Dairyland Power Coop. Belle Ayr/Amax, 350 1,000 4a,ll
Alma #6 Gillette, Wyoming
Buffalo Co., Wisconsin
(Alma)
*joint1y owned w/Northern States Power
3107 Indiana & Michigan Chinook/Amax, Indiana 1,300 3,000 4a
Electric Co. Ayrshire/Amax, Indiana
Sullivan #1 Minnehana/Amax, Indiana
Sullivan Co. (Sullivan)
Indiana
9012 Public Service of Navajo, San Juan, New Mexico 534 1,933 9,l,2,4b
New Mexico
San Juan #3
San Juan, New Mexico
(Water Flow)
*water source is San Juan River-20,200 afy
*captive reserves
3110 Southern Indiana Old Ben Coal, 1,2/Indiana 250 700 l,4a,5,12
Gas & Electric
Brown #1
Possy Co., Indiana
8003 Texas Utilities Gener. Martin Lake Mine, Texas 750 3,000 l,4b,9
(FGD system)
Martin Lake #3
Rusk Co., Texas (Tatum)
*mine mouth plant
*captive reserves
*1 ignite
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant
code : and location
CO
Ln
Coal source
Nameplate
capacity
Coal
requ i red
: Data
: source
1979: Continued
4060 Alabama Power Co-op
(FGD system)
Tombigbee #3
Washington Co., Alabama
(Leroy)
8005 Houston Lighting & Power
W. A. Parish #5
Ft. Bend Co., Texas
(Richmond)
8007 Lower Colorado River Auth.
City of Austin
Fayette #1
Fayette Co., Texas
3108 Northern Indiana Public
Service
Schahfer #15
Jasper Co., Indiana
(Wheatfield)
9025 Arizona Electric Power
Co-op
(FGD system)
Apache #3
Cochise Co., Arizona (Cochise)
*has captive reserves
9026 Salt River Project
(FGD system)
Coronado #1
Apache Co., Arizona
(St. John's)
9024 Colorado-Ute Electric
Assoc.
Craig #2
Moffat Co., Colorado (Craig)
*mine mouth
Big Ben Mining Co. (50/50)
Champion, Alabama
Kerr-McGee/Jacobs Ranch,
Gillette, Wyoming (Coal
from N. Montana in 1981-Ash)
Decker Mine/Montana
Black Thunder/Wyoming
Westmoreland/Orchard Valley,
Paonia, Colorado
Hanna Mine, Wyoming
Mentmore, New Mexico
San Juan, Farmington,
New Mexico Kaiser, York
Canyon, New Mexico
Coastal States, Utah
Trapper Mine
Utah International, Utah
MW
235
660
550
527
204
395
400
1,000 tons
300
2,350
2,200
1,200
550
730
1,225
1,8,12,13
2,4b,9
l,2,4b,9
1,2,11,8
l,2,4a,9,16
l,2,4b,
9,11,16
1,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
I CAM : Power system, plant
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
1,000 tons
1,500
2,100
Data
source
1979: Continued
3043 Public Service of Indiana
(FGD system)
Gibson #4
Gibson Co., Indiana
(Princeton)
7022 Kansas Power & Light
(FGD system)
Jeffrey Energy Center #1
Pottawatomie Co., Kansas
(Belvue)
*5 mile railroad spur line
3109 Monongahela Power Co.
(FGD system)
(Allegheny Power System)
Pleasants #1
Pleasants Co., West Virginia
(St. Mary's)
N/A Upper Peninsula Generating
Company
Presque Isle #9
Marquette Co., Michigan
(Marquette)
6001 Iowa Public Service
George Neal #4
Wood bury Co., Iowa
(Salix)
*has captive reserves
6026 Iowa Power & Light
Council Bluffs #3
Pottawatomie Co., Iowa
(Council Bluffs)
6040 Omaha Public Power Dist.
Nebraska City #1
Otoe Co., Nebraska
(Nebraska City)
*3 mile railroad spur
Carter Oil/Monterey mine,
Carlinville, Illinois
Amax/Belle Ayr,
Gillette, Wyoming
Northeast Surface,
West Virginia
Col strip-Rosebud/
Westmoreland Coal/Montana (50%)
Absaloka-Sarpy/
Western Energy Co./Montana (50%)
Vanguard & Rimrack,
Hanna, Wyoming
Carter Oil/Rawhide Mine, Wyoming
Eagle Butte-Campbell
Gillette, Wyoming
Carter Oil/Rawhide,
Gillette, Wyoming
Rosebud, Hanna, Wyoming
MW
650
680
626
90
576
650
575
1,500
100
1,750
2,000
2,500
1,8
Mb,9
l,4a,8,13
l,4a,8,13,12
1,2,11,9
l,2,4b,9
l,2,4b,11.9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
• Data
source
1979:
7026
7027
6041
1980:
6039
9014
7023
Continued
Oklahoma Gas & Electric
Sooner #1
Noble Co., Oklahoma
(Ponca City)
Public Service of Okla.
Northeastern #3
Rogers Co., Oklahoma
(Oolagah)
*has captive reserves
Heartland Consumer Power
Dist.
Heartland
Southeastern South Dakota
*water source is Missouri River
United Power Assoc.
Coal creek #2
Underwood, North Dakota
McLean Co.
*Lignite
*Water-15,000 afy (Missouri River)
Arco/Black Thunder,
Campbell, Wyoming
Kerr/McGee,
Gillette, Wyoming
Rodgers Co. Mine/
Public Service, Oklahoma
Bighorn, Wyoming
Gillette, Wyoming
Fal kirk Mine,
McLean Co., North Dakota
Midway/McKinley
Gallup, New Mexico
Arizona Public Service
Choi la #3
Navajo Co., Joseph
City, Arizona
*water requirements estimated at 35,700 afy
Arkansas Power & Light
White Bluff #1
Jefferson Co., Arkansas
(Redfield)
Kerr/McGee/Jacobs
Ranch, Wyoming
MW 1,000 tons
515 1,650 l,2,4b,9
450
200
500
289
700
1,450
600
2,000
827
2,500
l,4b,9
4b,9
l,4b
4a,l
1,2,45,11,9
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
: Data
: source
00
00
1980: Continued
9031 Basin Electric Power
Cooperative
Laramie River #1
Wheatland, Wyoming
3104 Big Rivers Electric Corp.
(Green)
Robert Reid #2
Webster Co., Kentucky
4008 Carolina Power & Light Co.
Roxboro #4
Pierson Co. (Roxboro)
North Carolina
8006 Central Power & Light
Coletto Creek #1
Gonzales Co.
(Victoria) Texas
*30 million tons coal over 25
2014 Delrnarva Power & Light
Indian River #4
Sussex Co., Delaware
3040 Louisville Gas & Electric
Mi 11 creek #4
Jefferson Co., Kentucky
(Kosmosdale)
2021 Pennsylvania Power
Mansfield #3
Shipping Port, Pennsylvania
5043 Wisconsin Electric Power
Pleasant Prairie #1
Kenosha Co., Wisconsin
Jim Bridger, Wyoming
Sun Oil, Cordero, Wyoming
Martwick, Homestead/
Peabody Coal, Kentucky
Ken 16, Mingo Co.,
West Virginia Island Creek,
Kentucky
Colo-Wyo, Axial, Colorado
years
Avery Coal, Pennsylvania
Cooks Run,
Westport, Pennsylvania
Continental Coal, Ohio
Riverview, Star/Peabody,
Western Kentucky
Powhatan, Ohio
Arkwright, West Virginia
Gal latin, Pennsylvania
North Rawhide, Wyoming
MW
500
240
720
550
400
495
825
580
1,000 tons
1,600
950
900
1,300
800
600
3,000
1,000
l,2,3,4b,9
1,5,13
l,4a,8,13,7
l,4b,8,7
1,2,5,11,8
l,2,4a,8,13
l,4a,5,13
l,4a,12,14
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
00
vO
ICAM : Power system, plant
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
: Data
: source
1980:
3109
7016
6043
8005
8007
9030
Continued
Monongahela Power
(FGD system)
Pleasants #2
Pleasants Co. West Virginia
(Eureka)
Southwestern Public Service
Co.
Harrington #3
Potters Co., Texas
(Amarillo)
East River Electric Power
Co-op
Basin #1
Brule Co., South Dakota
Houston Lighting & Power
W. A. Parish #6
Ft. Bend Co., Texas
(Richmond)
*coal/gas/oil
Lower Colorado River Auth.
City of Austin
Fayette #2
Fayette Co., Texas
7025
Northeast Surface
Arco/Black Thunder,
Campbell Co, Wyoming
McKinley/P & M, New Mexico
Belle Ayr/Amax,
Gillette, Wyoming
Kerr-McGee/Jacobs Ranch/
Gillette, Wyoming
Decker Coal, Montana
Black Thunder/ARCO, Wyoming
Amax/Belle Ayr,
Gillette, Wyoming
Portland General Electric
Carty #1
Morrow Co., Oregon
(Boardman)
*proposed slurry pipeline from Eastern Wyoming
*water source is Columbia River
Cajun Electric Power Co-op
Big Cajun 2 #1
Pointe Coupee Parish,
Louisiana
(New Roads)
Jim Bridger, Wyoming
Buckskin, Gillette, Wyoming
MW
626
317
150
660
550
530
550
1,000 tons
1,500
1,000
500
2,350
2,200
1,600
2,000
1,8,13,14
l,4b,8
4b,9,14
l,2,4b,9
l,2,4b,9
l,4b,9
1,2,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990--Continued
I CAM :
code :
1980:
6007
Power system, plant :
and location :
Continued
Minnesota Power & Light Peal
: Name pi ate :
Coal source : capacity :
MW
Dody/Big Sky, 500
Coal
required
1,000 tons
1,900
: Data
: source
l,4b,9
Clay Boswell #4
Itasca Co., Minnesota
(Cohasset)
7029 Kansas City Power & Light
latan #1
Platte Co., Missouri
7018 Southwestern Electric Power
Welsh #2
Morris Co., Texas
(Cason)
*has captive reserves
*low sulfur coal-rail delivery
9022 Utah Power & Light
(FGD system)
Emery #2 (Hunter)
Emery Co., Utah
(Castle Dale)
*water, 14,000 afy
*has captive reserves
9026 Arizona Salt River Project
(FGD system)
Coronado #2
Apache Co., Arizona
(St. Johns)
7022 Kansas Power & Light
(FGD system)
Jeffrey Energy Center #2
Pottawatomie Co., Kansas
(Belvue, Kansas)
*5 mile railroad spur line
3041 Consumer Power Co.
Campbell #3
Ottawa Co., Michigan
(Port Sheldon)
Col strip, Montana
Belle Ayr, Eagle Junction
Mines, Wyoming
Amax/Belle Ayr, Campbell
Co., Wyoming
American Coal,
Huntington, Utah
Coastal States, Utah
San Juan,
Farmington, New Mexico
Amax/Belle Ayr,
Gillette, Wyoming
Crown City, Ohio
726
528
415
395
680
770
2,700
1,586
650
730
2,100
1,500
l,2,4b,7,9
l,4b,9
l,4b,9,16
l,4a,8,13,
11,14
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1980:
3094
Power system, plant,
and location
Continued
Lansing Board of Water
: Coal source
Crown City, Warner
: Nameplate :
: capacity :
MW
169
Coal
required
1,000 tons
400
: Data
: source
l,4a,8,14
7026
7027
6042
3067
9024
Erickson #2
Eaton Co., Michigan
(Lansing)
Oklahoma Gas & Electric
Sooner #2
Noble Co., Oklahoma
(Ponca City)
Public Service of Oklahoma
Northeastern #4
Rogers Co., Oklahoma (Oolagah)
Public Service Oklahoma/
Sheridan Wyoming
*has captive reserves
Collieries, Ohio
Arco/Black Thunder, Wyoming
Campbell Co., Wyoming
Kerr-McGee,Gillette, Wyoming
Seminoe 2, Wyoming
City of Lincoln
Laramie #2
Lancaster Co., Nebraska
(Lincoln)
*Sutherland Reservoir is water source-rail road spurs planned.
East Kentucky Rural
Electric Co-op
John Sherman Cooper
Pulaski Co., Kentucky
(Burnside)
Colorado Ute Electric
Association
Craig #1
Moffat Co., Colorado
*mine mouth
*Yampa River as water source
Highlands River/Del Coal/
Ikerd Bandy/Cane Run/
J & S Coal/Kentucky
Trapper Mine, Utah
International, Colorado
567
450
200
500
400
1,650
1,450
700
600
1,225
l,2,4a,9
l,4b,9
3,9,14
4a,8
1,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—-Continued
ICAM :
code :
1980:
7021
Power system, plant,
and location
Continued
Kansas City Bd of Public
: Coal source
Carter Oil /Rawhide
: Nameplate :
: capacity :
MW
300
Coal
requ i red
1,000 tons
850
: Data
: source
Utilities
Nearmen Creek #1
Kansas City, Kansas
Wyandotte Co.
*1000 ft. railroad spur line
9005 Pacific Power & Light
Jim Bridger #4
Sweetwater Co., Wyoming
(Rock Springs)
*has captive reserves
Texas Municipal Power Pool
San Miguel #1
McMullen Co., Texas
*has captive reserves
City of Colorado Springs
R.D. Nixon #1
El Paso Co., Colorado
(Colorado Springs)
Anes (Iowa) Municipal
Electric System
Ames Unit #8
Ames, Iowa
Story Co.
3111 Cincinnati Gas & Electric
(FGD system)
East Bend #2
Boone Co., Kentucky
(Rabbit Hash)
8009
9027
1981:
N/A
& Caballo, Gillette, Wyoming
Central Prep, Saline Co., Illinois
Bridger Mine, Wyoming
San Miguel Strip Mine, Texas
Colowyo, Craig, Colorado
500
400
200
Not available
65
Kentucky Prince Coal,
Perry Co., Kentucky
600
2,000
1,600
750
150
700
l,2,4b,9
4b,l,8,15
8,l,2,4b
1,5
l,4a,7,8,13
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate
capacity
Coal
regu i red
Data
source
1981: Continued
4055 Gainesville-Alachua Co.
Oeerhaven #2
Alachua Co., Florida
(Hagne)
(FLA.) Regional Electric
*FEA ordered conversion from 2.4
mmbl of oil to 600,000 tons coal
N/A Grand Haven (MI)
Bd of Light & Power
Grand Haven #3
Ottawa Co., Michigan
N/A Grand Haven (MI)
Bd of Light & Power
Grand Haven #4
Ottawa Co., Michigan
N/A Grand Island (Neb)
Electric Dept.
Platte #1
Hall Co., Grand Island,
Nebraska
3114 Indiana Statewide Rural
Electric Coop., Inc.
(Hoosier)
Merom #2
Merom, Indiana
7049 Grand River Dam Auth.
(Oklahoma)
Chouteau #1
Mayes Co., Pryor, Oklahoma
6051 Iowa Southern Util.
Co.
Ottumwa #1
Chillicothe, Iowa
Mine No. 22
Big Creek Mine, West Virginia
Not available
Not available
Wyodak Corp, Gillette,
Wyoming
Blackfoot #5, Indiana
Center Point, Indiana
North Rawhide, Powder
River, Wyoming
Cordero Mine,
Gillette, Wyoming
MW
235
40
40
100
500
490
675
1,000 tons
600
50
50
400
1,350
1,900
2,500
1,8,13,7
l,4a
l,4a
l,4b,7
1,5
l,2,4b,5
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant, :• Nameplate i Coal i Data
code : and location : Coal source : capacity : required : source
MW 1.000 tons
1981: Continued
4057 Mississippi Power Co. SwisherCoal, Utah 518 750 l,2,4a,8,13
Gulf Power Company Co., Utah
(50-50 Ownership)
Jackson Co. #2
(Daniel #2)
Cumbest Bluff, Mississippi
6038 Nebraska Public Power Arco/Black Thunder, Wyoming 650 2,000 l,2,4b,9
District
Gentleman #2
Sutherland, Nebraska
*Sutherland Reservoir is water source-railroad spurs planned
9012 Public Service of Wesco, San Juan, New Mexico 534 1,933 1,2,9
New Mexico
San Juan #4
San Juan Co., New Mexico
Waterflow
*water - 20,200 afy (San Juan River)
9029 Sierra Pacific Power Coastal States, 250 1,000 l,4b,7,9
Valmy #1 Salina, Utah
Battle Mountain,
Humboldt Co., Nevada
(Valmy)
8014 Texas Power & Light San Juan Mine, 545 2,100 l,8,4b
Sandow #4 New Mexico
Mi lam Co., Texas
(Rockdale)
*1 ignite
9014 Arizona Public Service Pittsburg & Midway/ 375 1,200 l,9,4b
(FGD system) McKinley, Gallup, New Mexico
Cholla #4
Navajo Co., Arizona
(Joseph City)
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
I CAM : Power system, plant, ::Name pi ate :Coal i • Data
code : and location : Coal source : capacity : required : source
MW 1.000 tons
1981: Continued
3106 East Kentucky Power Addington Bros. #5/ 500 1,000 2,8
Coop., Inc. Boyd Co., Kentucky
Spurlock #2
Mason Co., Kentucky
(Maysville)
6047 Montana-Dakota Knife River, 414 1,100 2,4b
Utilities Co. Beulah, North Dakota
Coyote #1
Beulah, North Dakota
Mercer Co.
*Mine mouth
*water 11,000 afy (Lake Sakakawea)
7025 Cajun Electric Power Jim Bridger, Wyoming 550 2,000 1,2,9,15,16
Co-op Buckskin, Gillette, Wyoming
Big Cajun #2
to New Roads, Louisiana
Ui
3104 Big Rivers Electric Co-op Homestead/Peabody Coal, 200 800 l,4a,8,13
(FGD system) Kentucky
Robert Reid #3
(Green)
Webster Co., Kentucky (Sebree)
9028 Public Service of Co. Amax/Belle Ayr, 500 1,600 l,2,4b,9
Pawnee #1 Gillette, Wyoming
Morgan Co., Colorado
(Brush)
6009 Otter Tail Power Co. Gascoyne/Knife River 410 2,500 l,4b,9
Big Stone #2 Coal, North Dakota
Grant Co., South Dakota
(Big Stone City)
*addition to Big Stone Plant
(lignite)
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
I CAM :
code :
1981:
8009
Power system, plant,
and location
Continued
Texas Municipal Power Pool
Coal source
San Miguel strip, Texas
: Name pi ate :
: capacity :
MW
400
Coal
requ i red
1,000 tons
1,600
: Data
: source
4b,9
San Miguel #2
McMullan Co., Texas
*mine mouth
*has captive reserves
9031 Basin Electric Power
Cooperative
Laramie River #2
Platte Co., Wyoming
(Wheatland)
5019 Associated Electric Co-op
Thomas Hill #3
Randolph Co. Missouri
(Thomas Hill)
*captive reserves
5040 Central Illinois Public
Service
(FGD system)
Newton #2
Jasper Co., Illinois
(Newton)
8005 Houston Light & Power
W. A. Parish #7
Ft. Bend Co., Texas
4059 Alabama Power Co.
James Miller #2
Jefferson Co., Alabama
(West Jefferson)
*coal will be trucked
3052 Kentucky Utilities
Ghent #3
Carroll Co., Kentucky (Ghent)
Sun Oil/Cordero mine,
Buckskin, Gillette, Wyoming
(After 1981)
Bee Veer, Prairie Hill/
Peabody Coal, Missouri
Delta, Illinois
Kerr McGee/Jacobs Ranch,
Gillette, Wyoming
King Coal .Jefferson
Co., Alabama
Southeast Coal, Kentucky
500
670
550
750
660
500
1,600
800
1,100
2,580
950
600
3,4b,9
l,2,4b,8,12
l,2,4a,8
8,1,2,4b
2,4,8,13
l,4a,8
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—-Continued
ICAM :
code :
1981:
3121
1982:
7023
Power system, plant, :
and location : Coal source
Continued
Appalachian Power Co. Lorado Prep, Wyoming
Mountaineer (Project 131)
Mason Co., West Virginia
(New Haven)
Arkansas Power & Light Gillette
: Nameplate :
: capacity :
MW
1,300
700
Coal : Data
required : source
1,000 tons
3,600 4a,7,l
2,500 l,2,3b,ll,9
White Bluff #2 Jacobs Ranch/Wyoming
Jefferson Co., Arkansas Antelope/Wyoming
(Redfield)
4042 South Carolina Public Potter, Mack, Stoney Fork, 280 750 13,11
Serv. Auth. Creech, Kentucky
(FGD system)
Winyah #3
Georgetown Co., South Carolina
(Georgetown)
6046 Basin Electric Power Mine Mouth 438 2,600 l,2,4b
Cooperative Beulah-Hazen, North Dakota
Antelope Valley #1 Buckskin, Gillette, Wyoming
Beulah, North Dakota (After 1981)
Mercer Co.
(lignite)
*mine mouth
*water - 19,000 afy (Lake Sakakawea)
7028 Central Louisiana Gillette, Wyoming 530 1,750 l,2,4b,9
Electric
Rodemacher #2
Rapids Parish, Louisiana
(Boyce)
4065 Carolina Power and Ken 16/Mingo Co., 720 2,800 l,4a,ll,13,16
Light Co. West Virginia Potter,
Mayo #1 Mack, Stoney Fork
Person Co., North Carolina
(Roxboro)
Creech, Kentucky
* captive reserves
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
: Nameplate : Coal
: capacity : required
MW 1,000 tons
Coal source
Data
source
1982: Continued
6027 City of Muscatine
Muscatine #9
Muscatine Co., Iowa
(Muscatine)
3120 Indiana & Michigan
Electric Co.
Rockport #1 (Project 2601)
Rockport, Indiana
3114 Indiana Statewide Rural
Electric Cooperative, Inc.
Merom #1
Merom, Indiana
N/A Marquette Bd of
Light and Power
Shiras #3
Marquette Co., Michigan
6013 Montana Power Co.
(FGD System)
Col strip #3
Rosebud Co., Montana
(Colstrip)
*captive reserves
8015 Texas Municipal
Power Agency
Gibbons Creek #1
Walker Co., Texas
(Huntsville)
*1ignite
*captive
7031 Western Fanners
Electric Coop.
Eastern Oklahoma #1
Choctaw Co., Oklahoma
(Ft. Towson)
Orient 3 & 6, Illinois
Helper, Utah
North Rawhide, WY
Blackfoot #5, Indiana
Center Point, Indiana
Peabody Coal, East Ohio
Western Energy, Montana
Rosebud, Montana
Gibbons Creek, Grimes Co.
Mine/Texas
Choctaw Mine, Oklahoma
150
1,300
490
44
700
408
376
250
3,000
1,350
170
2,367
1,200
1,000
l,4b,9,7
1,11,8
1,5
l,2,4a,8,13
Mb,9
l,2,4b
l,3,4b,8
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
VO
VO
Coal source
Name pi ate
capacity
Coal
requ i red
1982: Continued
5035 Wisconsin Public
Service Corp.
Weston 13
Marathon Co., Wisconsin
(Rothschild)
*scrubber not required
*low sulfur use
9024 Colorado-Ute Electric
Assn.
Craig 14
Moffat Co., Colorado
(Craig)
*mine mouth
3043 Public Service of Indiana
Gibson #5
Gibson Co., Indiana
(Princeton)
7021 Kansas City Board of
Public Utilities
Near-man Creek #2
Kansas City, Kansas
Wyandotte Co.
Central Prep, Saline Co.,
Illinois
4059 Alabama Power Co.
James Miller #3
Jefferson Co.
Birmingham, Alabama
*coal will be trucked
& rail
4063 Georgia Power Co.
Scherer #1
Monroe Co., Georgia (Forsyth)
Black Thunder, Wyoming
Trapper Mine, Colorado
Carter Oil, Illinois
Carter Oil/Rawhide
& Caballo, Gillette, Wyoming
King Coal Co.,Jefferson
Co. Alabama
Bessie Mine,
Drummond, Alabama
Ken 16, Mingo Co,
West Virginia Westmoreland,
West Virginia Ireland Mine,
Consol Coal, West Virginia
MW
300
380
650
300
660
818
1,000 tons
800
1,225
1,500
1,000
950
1,200
Data
source
l,4a,7,12
15,16
2,1,4,8,7
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990--Continued
NJ
O
o
ICAM : Power system, plant,
code : and location
Coal source
1982: Continued
5013
Central Ilinois Light
Edwards #4
Peoria Co., Illinois
(Bartonville)
7022 Kansas Power & Light
Jeffrey Energy Center #3
Pottawatomie Co., Kansas
(Bellvue)
(FGD system)
*5-mile railroad spur line
7018 Southwestern Electric Power
Welsh #3
Morris Co., Texas
(Cason)
*low sulfur coal-rail delivery
9034 Utah Power & Light
Garfield #1
Garfield Co., Texas
(Escalante)
*has captive reserves
9026 Salt River Project
Coronado #3
Apache Co., Arizona
(St. Johns)
(FGD System)
(Indefinite)
3129 Grand Haven Board
of Power & Light
Island #3
9049 Western Farmers
Electric Co-op
Southeast #1 (Hugo)
Sarpy Creek, Montana
Amax/Belle Ayr,
Gillette, Wyoming
Amax/Belle Ayr,
Campbell, Wyoming
Deseret Mine, Utah
Belina #l/Utah
Coastal States, Utah
San Juan, New Mexico
Not available
Not available
Nameplate
capacity
MW~
500
680
Coal
required
528
500
350
100
400
1.000 tons
1,300
2,110
1,586
1,625
1,000
350
1,500
Data
source
4a,8,ll
l,3,4b,9,16
l,4b,7,9
4b,9,14
1,9
15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
: Nameplate : Coal
: capacity : required
Data
source
ro
o
1982:
5043
3117
7048
4062
2021
1983:
9028
9024
Continued
Wisconsin Electric Power
Pleasant Prairie #2
Kenosha Co., Wisconsin
Dayton Power & Light
Killeen #2
Adams Co., Ohio
(Wrightsville)
Southwestern Public Service
Tolk #1
Earth, Texas
City of Lakeland
(Florida)
Mclntosh #3
Polk Co., Florida
(Lakeland)
Duquesne Light Co.
Mansfield #2
Beaver Co., Pennsylvania
(Shipping port)
(FGD system)
*captive reserves
Public Service of Colorado
Pawnee #2
Morgan Co., Colorado (Brush)
Colorado Ute Electric
Association1
Craig #3
Moffat Co., Colorado
(Yampa)
*mine mouth
North Rawhide, Wyoming
Sapphire Mine/Elkorn &
Jellico, Kentucky
Ferrel/Hampton Co, West Virginia
Arco/Black Thunder,
Campbell Co, Wyoming
Eagle, Illinois
Little Joe, Kentucky
Kaneb Services, Inc.
Powhatan, Ohio
Pegs Run, Pennsylvania
Arkwright, West Virginia
Amax/Belle Ayr,
Gillette, Wyoming
Trapper Mine, Colorado
MW
580
600
513
364
825
500
400
1.000 tons
1,000
1,400
1,500
300
2,000
1,600
1,200
l,4a,8
l,2,4a,8,13
1,2,3,8
4a,7,ll
4a,13
4b,9
4b,15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
1NameplateiCoal
capacity : required
1,000 ton;
source
1983: Continued
7025 Cajun Electric
Power Coop
Big Cajun #2
New Roads, Louisiana
5038 Central Illinois Light
(FGD system)
Duck Creek #2
Fulton Co., Illinois
9014 Arizona Power
Service Co.
Cholla #5
Navajo Co., Arizona
(Joseph City)
*water, 25,700 afy
4069 Florida Power Corp.
Crystal River #4
Crystal River, Florida
N/A South Carolina Public
Service Auth.
Site X #1
8005 Houston Light & Power
W.A. Parish #8
Ft. Bend Co., Texas
(Richmond)
3052 Kentucky Utilities Co.
Ghent #4
Ghent, Kentucky
3115 Louisville Gas & Electric
Trimble Co. #1
Trimble Co., Kentucky
(Wise's Landing)
Jim Bridger, Wyoming
Buckskin, Gillette, Wyoming
Orient #4, Virden, Illinois
Pittsburg & Midway/McKinley,
Gallup, New Mexico
Electro Mine, Kentucky
Kerr-McGee/Jacobs Ranch,
Gillette, Wyoming
Southeast Prep., Kentucky
Riverview, Star/
Peabody Coal, Kentucky
MW
550
400
350
640
450
600
500
495
2,000
1,080
1,200
700
469
2,579
1,437
600
1,8
1,2,8,15
l,4b
l,2,4a,ll,7
2,5
4b,8,15,16
1,5,13,7
l,4a,8,13
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
NJ
O
OJ
Coal source
Nameplate
capacity
Coal
requ i red
1983: Continued
6013 Montana Power Company
(FGD system)
Col strip #4
Rosebud Co., Montana
*captive reserves
9032 Nevada Power Co.
(FGD system)
Warner Valley #1
Washington Co., Utah
(St. George)
*captive reserves
*slurry from Alton Field, UT
1010 New York State Electric
& Gas
Cayuga Lake #1
Tompkins Co., New York
(Ithaca)
7017 Oklahoma Gas &
Electric Co.
Muskogee #6
Muskogee Co., Oklahoma
(Muskogee)
7015 Sikeston (MO)Bd. of
Municipal Utilities
Sikeston #1
Sikeston, Missouri
Scott Co.
*limestone scrubbers
3110 Southern Indiana
Gas & Electric
Brown #2
Posse Co., Indiana
Col strip-Rosebud/
Western Energy, Montana
King/Hiawatha,
Carbon Co, Utah
Iselin/Rayne, Pennsylvania
Century, West Virginia
Romesburg, Maryland
Arco/Black Thunder
Campbell Co., Wyoming
Jim Bridger, Wyoming
Central Prep.,
Saline Co., Illinois
Old Ben Coal 1,2/Indiana
Blackfoot #5
MW
700
1.000 tons
2,367
250
800
850
2,000
505
1,500
235
600
250
800
: Data
source
l,4b
l,4b,9,7,16
l,4a,8
15,16
1,2,45,11,15
1,5,8
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990--Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
Data
source
1983:
4070
9022
5020
6052
3108
9023
7039
Continued
Seminole Electric
Bostwick #1
Putnam Co., Florida
(Palatka)
*167 million tons between 1982-2010
Dotiki Mine/Kentucky
New Mine White Co./Illinois
Utah Power & Light
Emery #3 (Hunter)
Naughton, Wyoming
*water, 14,000 afy
Deseret (Chorch).Huntington,
Utah
Wisconsin Power & Light
Edgewater #5
Sheboygan Co., Wisconsin
(Edgewater)
*50% owned by Wisconsin Electric Power
Coal Creek Mine/
Campbell Co., Wyoming
Iowa-Illinois Gas &
Electric Co.
Louisa #1
Muscatine, Iowa
*jointly owned w/several utilities
Seminoe 1, Wyoming
Northern Indiana
Public Service
Schahfer #17
Jasper Co, Indiana
(Wheatfield)
Hanna Mine, Wyoming
Westmoreland/Orchard Valley/
Paonia, Colorado
MW
600
415
400
685
380
Pacific Power & Wyodak Mine/Wyoming 330
Light
Wyodak #2
Campbell Co., Wyoming
(Gillette)
*water is recycled waste water from Gillette Municipal Sewage System
Arkansas Power & Light
Independence #1
Independence Co., Arkansas
(Newark)
Kerr-McGee/Jacobs Ranch,
Gillette, Wyoming
(A G & S Lignite Mine
late 80's, Arkansas)
700
1,000 tons
2,000
650
800
2,500
1,200
5,500
2,500
2,3,11
l,4b
l,4a,8
l,2,3,4b,ll
3,7
3,4b,9
l,2,3,4b,11,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
1983:
8015
4059
7023
7014
O
Ui
3034
7026
1984:
3120
Coal source
: Nameplate : Coal
: capacity : required
Continued
Texas Municipal Power Pool
Gibbons Creek #2
Walker Co., Texas
(Huntsville)
*has captive reserves
Alabama Power Co.
James Miller 14
Jefferson Co., Alabama
(West Jefferson)
Arkansas Power & Light
White Bluff #4
Jefferson Co, Arkansas
City of Independence
Missouri
Blue Valley #4
Jackson Co. Missouri
(Independence)
Indianapolis Power &
Light
Petersburg #4
Pike Co., Indiana
(Petersburg)
Oklahoma Gas &
Electric Co.
Sooner #3
Noble Co., Oklahoma
Indiana & Michigan
Electric Co.
Rockport #2 (Project 2601)
Rockport, Indiana
Gibbons Creek, Grines Co.
Strip Mine, Texas
King Coal, Alabama
Kerr-McGee/Jacobs Ranch
Wyoming
Seminoe, Wyoming
United Coal, Oklahoma
85% Contracted
Lynnville, Indiana
R & H/ Old Ben, Indiana
Center Point, Indiana
Arco/Black Thunder
Campbell Co., Wyoming
Helper, Utah
North Rawhide, Wyoming
MW
400
660
700
150
515
700
1,300
1,000 tons
1,200
950
2,800
400
1,200
2,500
3,000
Data
source
4b,9
2,4,8,13
4b,ll
13
15,16
1,11,8
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990--Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate
capacity
o
o>
1984: Continued
9035 Plains Electric GST
Plains #1
McKinley Co. (Prewitt),
New Mexico
2500 Ac. Site for Expansion to
9031 Basin Electric Power
Cooperative
Lararnie River #3
(Wheatland), Wyoming
Platte Co.
4042 South Carolina Public
Authority
Winyah #4
Georgetown Co.,
South Carolina (Georgetown)
3116 Detroit Edison Co.
Belle River #1
St. Clair Co., Mississippi
(St. Clair)
3066 Allegheny Power
Service Corp.
Lower Armstrong #1
Armstrong Co., Pennsylvania
3111 Cincinnati Gas & Electric
East Bend #1
Boone Co., Kentucky
(Rabbit Hash)
(FGD system)
3041 Consumers Power Co. (MI)
Campbell #4
Ottawa Co, Mississippi
(Port Sheldon)
San Juan, New Mexico
3-4 Units (1000 MW)
Jim Bridger, Gillette, Wyoming
Sun Oil/Cordero Mine
Potter, Mack, Stoney Fork,
Creech, Kentucky
Decker, Montana
Eagle Coal, Pennsylvania
Jerry Lynn,
Perry Co, Kentucky
Crown City, Ohio
MW
330
Coal
requ i red
Data
: source
500
280
676
625
650
800
1,000 tons
1,035
1,600
463
900
1,500
700
1,000
4b,8,15,16
l,2,4b,9,15
1,6,13
l,4a,8,13
1,7,15
l,4a,7,8
1,14
Continued
-------
Appendix table 5~Additions to generation capacity: 1976-1990—Continued
NJ
o
KM :
code :
1984:
4063
2023
3062
9050
Power system, plant,
and location
Continued
Georgia Power Co.
Scherer #2
Monroe Co., Georgia
(Forsyth)
*coal via Southern Railway
Baltimore Gas &
Electric
Brandon Shores #1
Anne Arundel Co, Maryland
East Kentucky
Power Coop
J.K. Smith #1
Golden Valley
Electric Assn., Inc.
Healy #3
Alaska
: Coal source
Westmoreland Coal ,
West Virginia
from Appalachian, W.V.
Not available
Diamond Coal 5,6,7
Floyd County, Kentucky
Not available
: Nameplate :
: capacity :
MW
818
610
600
115
Coal : Data
required : source
1,000 tons
1,200 l,4a,ll,8,i:
1,150 7,11
2,000 15,16
500 15,16
8016 Houston Light & Power
Freestone #1
Freestone Co., Texas
(Fairfield)
(Lignite)
*captive reserves
6053 Minnesota Power & Light
Fl oodwood
St. Louis Co., Minnesota
(Fl oodwood)
*subbituminous
9032 Nevada Power Company
Warner Valley #2
Washington Co., Utah
(St. George)
*water, 10,000 afy-proposed
*captive reserves
*slurry from Alton Field, UT
Big Brown Mine,
Freestone Co, Texas
Big Sky, Montana
King/Hiawatha,
Carbon Co, Utah
750
800
250
2,750
3,200
800
l,4b
l,3,4b
l,4b,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
Data
source
o
00
1984:
6002
Continued
Northern States Power
Sherburne #3
Sherburne Co, Minnesota
(Becker)
(FGD System)
*Mississippi River is water source
9038
7042
8010
N/A
3131
9051
9052
8011
Col strip, Montana
Absaloka Mine,
Westmoreland, Montana
Public Service of Colo.
Future #1
Southeastern, Colorado
Southwestern Electric
Power Co.
H. W. Prikey #1
Hallsville, Texas
Harrison Co.
Texas Utilities
Generating Co.
Forest Grove #1
Athens, Texas
Big River Electric
Wilson #1 (Brec Station 4)
Centertown, Kentucky
Kentucky Utilities Co.
Hancock #1
Oak Creek Power Co.
Oak Creek ST3
Public Service
Southeastern #1
Las Animas, Colorado
Texas Utilities Gener.
Twin Oak #1
Robertson Co., Texas
(Bremond)
*1 ignite
*captive reserves-mine mouth
Jacobs Ranch, Wyoming
Trapper Mine/Utah
Intn'l, Colorado
Hallsville Co Mine, Texas
Assume mine mouth
near Athens, Texas
Not available
Not available
Not available
Not available
Twin Oaks Mine, Texas
ALCOA, Robertson Co, Texas
800
500
640
750
440
650
800
470
750
1,000 tons
2,250
1,600
2,500
3,000
1,500
2,000
2,500
1,500
3,000
l,4b,9,ll,7
l,4b,9,13,7
1,2
15,16
15,16
15,16
l,2,4b,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1984:
5046
Power system, plant,
and location
Continued
Western Illinois
: Coal source :
River King 6/Baldwin 2,3,4,
Name pi ate :
capacity :
MW
400
Coal
requ i red
1,000 tons
750
: Data
: source
1
4069
8015
NJ
O
VO
6046
N/A
3020
1985:
3066
Power Coop. Illinois
Pearl Station #2
Pike Co., Illinois
(Pearl)
Florida Power Corp.
Crystal River #5
Crystal River, Florida
Texas Municipal
Power Pool
Gibbons Creek #3
Walker Co., Texas
(Huntsville)
*lignite-captive reserves
Basin Elec. Power Co-op
Antelope Valley #2
Mercer Co., North Dakota
(Beulah)
(FGD system)
*water 19,000 afy (Lake Sakakawea)
*1 ignite
*mine mouth
Creech,
Coalgood, Harlan Co., Kentucky
Gibbons Creek Grimes Co.
Strip Mines, Texas
Beulah-Hazen, North Dakota
Buckskin, Gillette, Wyoming
(After 1981)
Sunflower Electric
Co-op
Homcomb #1
Kansas
Buckeye Power Inc.
(Ohio Power)
Cardinal #4
Jefferson Co., Ohio
(Brilliant)
Allegheny Power Service Corp.
Lower Armstrong #2
Armstrong Co., Pennsylvania
Not available
Carson Pit, Ohio
Eagle Coal, Pennsylvania
640
400
440
300
615
625
700
1,200
2,900
1,000
1,500
1,500
3,4b
1,4b,9
15,16
4a
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
NJ
M
O
ICAM :
code :
1985:
3116
4065
3117
7008
N/A
N/A
Power system, plant,
and location
Continued
Detroit Edison Co.
Belle River #2
St. Clair Co., Mississippi
Carolina Power & Light Co.
Mayo #2
Person Co., North Carolina
(Roxboro)
Dayton Power & Light
Killeen #1
Adams Co., Ohio
(Wrightsville)
Empire District Electric
Coop.
As bury #3
Jasper Co., Missouri
(As bury)
(Indefinite)
Florida Power & Light Co.
Martin Co. #3
Florida
indefinite
Gulf Power Co.
Ellis #2
Florida
*Indefinite
: Coal source :
Decker, Montana
Ken 16/Mingo Co., West Virginia
Potter, Mack, Stoney Fork,
Creech, Kentucky
Saphire Mine/
Hampton Div, Kentucky
Ferrel , West Virginia
Seminoe 1, Wyoming
Not available
Not available
Nameplate : Coal : Data
capacity : required : source
MW 1,000 tons
676 900 l,4a,8,7,
13,12
736 850 l,4a,ll,
13,16
600 1,400 1,2,8,13,7
300 1,000 l,4b,9
640 1,000 1,15,16
500 1,000 1,8,13
N/A Gulf States Utilities
Nelson #6
Calcasis Parish, Louisiana
3125 Indianapolis Power
and Light
Patriot #1
Marion Co. Indiana
(Indianapolis)
Jacobs Ranch, Wyoming
Lynnville, Indiana
540
650
2,500
1,500
l,4b,9,15,16
l,4a,7
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1985:
3115
Power system, plant,
and location
Continued
Louisville Gas & Electric
: Coal source
Riverview, Star/
: Nameplate :
: capacity :
MW
495
Coal
__ requ i red
1,000 tons
600
: Data
: source
l,4a,8,13
Trimble Co. #2
Trimble Co., Kentucky
(Wise's Landing)
6044 Nebraska Public Power
District
Comstock #1
Comstock, Nebraska
Custer Co.
*river reservoir required
9033 Nevada Power Co.
Harry Allen #1
Clark Co., Nevada
(Las Vegas)
*captive reserves
*slurry
3051 Potomac Electric Power
Dickerson #4
Montgomery Co., Maryland
(Appalachian Coal)
3118 Richmond Indiana
Power & Light
Whitewater Valley #3
Wayne Co., Indiana
(Whitewater)
4023 Tampa Electric Co.
Big Bend #4
Hillsborough Co., Florida
*captive reserves
6040 Omaha Public Power
District
Nebraska City #2
Nebraska City, Nebraska
Peabody Coal, Kentucky
Black Thunder/Arco, Wyoming
King (Hiawatha),
Carbon Co, Utah
Future Coal Slurry Line from
Alton Field, Utah
Eagle Coal, Pennsylvania
Romesburg, Maryland
Loveridge, West Virginia
Hawthorn/Peabody, Indiana
Island #9, Kentucky
Poland Imports
North Rawhide,
Gillette Wyoming
Rosebud, Hanna, Wyoming
600
500
800
193
425
565
2,000
295
3,000
384
1,000
2,500
l,2,4b
l,2,4a,8,13
1,11,8
2,11
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
Data
source
1985:
9040
9022
5047
1012
8003
4063
Continued
Tucson Gas & Electric
Springerville #1
Apache Co., Arizona
(Springerville)
*captive reserves
Utah Power & Light
Emery #4 (Hunter)
Naughton, Wyoming
*water, 14,000 afy
Wisconsin Electric Power
Koshkonong #1
Jefferson Co., Wisconsin
Upper Peninsula
Power Co. (MI)
Unsited Coal #1
New York State Electric
& Gas
Somerset #1
Somerset, New York
*bi turn i nous
Texas Utilities Gener. Co.
Martin Lake #4
Rusk Co., Texas
(Tatum)
Georgia Power Co.
Scherer #3
Monroe Co., Georgia
(Forsyth)
Westmoreland/West Virginia
1011
San Juan Basin Coal,
Santa Fe, New Mexico
Deseret (Chorch),
Huntington, Utah
Carbon Fuel Mine, Wyoming
Power Authority of
New York
Arthur Kill #1 (MTA)
Richmond Co., New York
(Staten Island)
(Coal/Oil/Refuse) - conversion to coal only
Iselin/McArthur, Pennsylvania
Martin Lake Mine, Texas
Ken 16, Mingo
Co, West Virginia
Champion, Pennsylvania
MW
350
400
400
90
850
793
818
700
1,000 tons
1,000
650
500
333
2,000
3,000
1,200
1,700
1,3,11,8
l,4b,9
l,4a,14
3,5
1,3,7
4b,l,16
2,l,4a,8,14
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
: Nameplate : Coal
: capacity : required
Coal source
Data
source
1985: Continued
3108 Indiana Public Service
Schafer #18
Jasper Co, Indiana
(Wheatfield)
7025 Cajun Electric
Power Coop.
Big Cajun 3 #1
Southern Louisiana
*subbituminous
7048 Southwestern Public Serv.
Tolk #2
Earth, Texas
8003 Texas Utilities Gener.
Martin Lake #4
Rush Co., Texas (Tatum)
*mine mouth
*captive reserves
*1 ignite
(FGD System)
8012 Houston Lighting &
Power
Limestone #1
Limestone Co, Texas
* lignite
7026 Oklahoma Gas &
Electric Co.
Sooner #4
Noble Co., Oklahoma
4070 Seminole Electric
Coop (FLA)
Bostwick #2
Putnam Co., Florida
(Palatka)
Orchard Valley/
Westmoreland, Colorado
New Mine/Spadra
Arkansas
Arco/Black Thunder,
Campbell Co., Wyoming
Martin Lake Mine, Texas
Mine mouth Grass Creek
Leon & Greeston Co., Texas
Arco/Black Thunder
Campbell Co., Wyoming
Dotiki Mine/MAPCO,
Kentucky
MW
380
550
508
750
750
500
600
1,000 tons
700
2,000
1,500
3,000
3,000
1,800
2,000
13,15
3,5,7
l,4b,8,15
9,1
15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
"1 Nameplate :Coal I Data
: capacity : required : source
1985: Continued
5044 Springfield Utilities (MO)
Southwest #2
Greene Co., Missouri
(Springfield)
9042 Platte River Power Auth.
Rawhide #1
Larimer Co. Colorado
*bituminous
9034 Utah Power & Light
Garfield #2
Garfield Co., Utah
(Escalante)
*has captive reserves
9029 Sierra Pacific Power
Valmy #2
Battle Mountain,
Humbolt Co., Nevada
N/A Big Rivers Electric Corp.
Wilson #2 (Brec Station 4)
Livermore, Kentucky
N/A Gulf Power Co.
Caryville #1
Florida
N/A Kentucky Power Co.
(AEP)
Project 2602 #1
N/A Oak Creek Power Co.
Oak Creek ST1
Colorado
N/A Oak Creek Power Co.
Oak Creek ST2
Colorado
Ft. Scott, Kansas
Cherokee Coal, Kansas
Gillette Mine, Wyoming
Colowyo Coal, Wyoming
Utah #2/Utah
Deseret Mine/Utah
Coastal States
Salina, Utah
McKinley Mine, Pittsburgh &
Midway, New Mexico
Western Kentucky
Not available
Not available
Not available
Not available
MW
250
255
500
250
440
553
800
800
1,000 tons
650
800
1,625
1,000
N/A
N/A
N/A
N/A
3,14
3,4b,7
4b,9,14
1,7,9,11
11
15,16
15
15,16
15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1985:
N/A
Power system, plant,
and location
Continued
Deseret Generating
: Coal source
Not available
: Nameplate :
: capacity :
MW
360
Coal
requ i red
1,000 tons
N/A
: ' Data
: source
15,16
& Transmission
Moonlake #1
Utah
6047 Montana Dakota Utilities Beulah Mine, North Dakota 410 1,100 4b,7,8
Coyote #2
Mercer Co., North Dakota
(Beulah)
*has captive reserves
*dry S0? and particulate removal system
7039 Arkansas Power & Light Antelope, Wyoming 700 2,500 l,2,4b,ll,9
Independence #2 Kerr-McGee/Jacobs Ranch,
Independence Co., Arkansas Gillette, Wyoming
(Newark) ( A G & S lignite mine
late 80's, Arkansas)
1986:
N/A Springfield Municipal Not available 192 N/A 15,16
Undesignated #1
2024 General Public Utilities Not available 625 N/A 1
Coho #1
Lake City, Pennsylvania
9033 Nevada Power Company U.S. Fuel/Hiawatha, 500 ea. 3,200 l,4b,9
Harry Allen #2&3 Carbon Co., Utah
Clark Co., Nevada Atlas Fuels, Hanksville, Utah
(Las Vegas)
*4 mile rail spur
*slurry pipeline from Alton, UT
*captive reserves
3066 Allegheny Power Eagle Coal, Pennsylvania 625 1,500 1,15
Service Corp.
Lower Armstrong #3
Armstrong Co., Pennsylvania
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
I CAM : Power system, plant,
code : and location
Coal source
: Nameplate : Coal
: capacity : required
Data
source
1986: Continued
N/A Public Service of
Colorado
Southeastern C01
Las Animas, Colorado
7028 Central Louisiana Electric
Rodemacher #3
Rapids Parish, Louisiana
(Boyce)
*uncertain
8016 Houston Light & Power
(lignite)
Freestone #2
Freestone Co., Texas
(Fairfield)
*captive reserves
9027 Colorado Springs Elec.
Dept.
Nixon #2
El Paso Co., Colorado
(Fountain)
N/A Southwestern Electric
Power Co.
Mansfield
Texas or Arkansas
N/A Western Fanners Elec. Coop
*coal/oil
N/D #2
Oklahoma
N/A Mississippi Power &
Light Co.
Unsited A #1
Mississippi
N/A Mississippi Power Co.
Undesignated Site A
Not available
Jacobs Ranch/Wyoming
Kerr-McGee/Jacobs Ranch
Gillette, Wyoming
Colowyo,Craig, Colorado
Not available
Not available
Not available
Not available
MW
470
510
750
350
640
350
700
548
1,000 tons
N/A
1,750
2,775
767
N/A
N/A
N/A
N/A
15,16
4b,9
l,4b,8,15
4b,9,15
l,4b
15,16
15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1986:
N/A
N/A
N/A
3126
N/A
N/A
N/A
5035
N/A
Power system, plant,
and location
Continued
South Carolina Public
Service Authority
Site X #2
Detroit Edison Co., Inc.
Unsited
Kentucky Utilities Co.
Hancock #2
Buckeye Power Inc.
Buckeye #1
Ohio
Houston Lighting & Power
Limestone #2
Limestone Co, Texas
Texas Municipal Power Pool
Unspecified #2
Illinois Power
Unsited Fossil
*bituminous
Wisconsin Public Service
Corp.
Weston #4
Rothschild, Wisconsin
(Marathon Co.)
*subbituminous
Montana-Dakota
Utilities
Fossil
*1 ignite
: Coal source :
Not available
Not available
Not available
Not available
Minemouth
Northwestern Resources Co.
Leon & Greestone Co., Texas
Not available
Not available
Black Thunder, Wyoming
Not available
Name pi ate :
capacity :
MW
450
650
700
650
750
200
450
300
120
Coal : Data
required : source
1,000 tons
N/A 15,16
N/A 3
N/A 3
N/A 3
3,500 3,7
N/A 3
N/A 3
N/A 3
N/A 3
N/A Florida Power Corp.
Fossil #1
*bituminous
Not available
660
N/A
3,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
to
t-*
00
I CAM :
code :
1986:
7041
7044
7045
N/A
N/A
N/A
N/A
7025
N/A
9045
Power system, plant,
and location
Continued
CK Clippins
Arkansas Power & Light
Coal #6
Louisiana Power & Light
Coal #7
Central Louisiana
Electric Co.
Dolet Hills #1
*1 ignite
Big Rivers Electric
Unnamed #2
Centertown, Kentucky
Commonwealth Edison Co.
Unspecified
Upper Peninsula Power
Unsited #2
Missouri Public
Service Co.
Plant X #1
Cajun Electric Power Coop
Big Cajun 3 #1
*1 ignite
Oklahoma Gas & Electric
Unsited Coal #3
Utah Power & Light
Nephi #1 (Plant X)
Juab Co. (Nephi), Utah
: Coal source
Lignite
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
: Nameplate :
capacity :
-MW
700
700
640
440
550
90
100
540
500
500
Coal
requ i red
1,000 tons
N/A
N/A
N/A
N/A
N/A
333
N/A
.N/A
N/A
N/A
: Data
: source
3
3
3
7
15,16
3
3
3
3,4b
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant, : : Nameplate : Coal : • Data
code : and location : Coal source : capacity : required : source
MW 1,000 tons
1986: Continued
9037 Pacific Gas & Electric Belina 1, Utah 2, Valley 800 2,600 3
Fossil #1 Camp, Utah
Salano, California
(Collinsville)
*bituminous, captive reserves
4067 Tampa Electric Co. Brown-Badgett, Kentucky 425 500 4a,l,2
Beacon Key-Ruskin
Hillsborough Co., Florida
(Ruskin)
4023 Tampa Electric Co. Not available 425 500 4a,l,2
Big Bend #4
Hillsborough Co., Florida
(Tampa)
7046 Central Telephone & Not available 400 1,250 4b
Utilities Corp.
Unnamed #1
Central Kansas
9047 Montana Power Co. Not available 350 1,100 4b,9
Unnamed
Unsited
8017 City Public Service Not available 375 N/A 4b
of San Antonio
Unnamed
San Antonio, Bexar Co., Texas
8007 Lower Colorado Texas Resources Development N/A 4,000 11
River Authority Fayette, Washington Co, Texas
Fayette #3
LaGrange, Texas
N/A Jacksonville Electric Not available 563 N/A 15,16
Authority
Unsited #1
Florida
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1986:
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Power system, plant,
and location
Continued
South Carolina Electric &
Gas Co.
Undesignated #1
Kaukauna, City of
Water & Electric Depts.
Kaukauna #1
Arkansas Power & Light
Unsited Cl
Central Louisiana
Electric Co.
Rodenmacher #3
Louisiana Power &
Light Co.
LPL-Coal Unit Bl
Cajun Electric Power
Co-op
Big Cajun 4 #1
Oklahoma Gas &
Electric Co.
Unknown #1
Al lied Power Co-op
Unsited #1
Central Iowa Power Co-op
Guthrie County #1
Nebraska Public
Power District
Fossil Unit #3
Public Service
of Colorado
Unsited #1
Coal source
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
: Nameplate :
: capacity :
MW
500
150
N/A
N/A
N/A
560
500
550
550
650
470
Coal
required
1,000 tons
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Data
: source
15,16
15,16
15
15
15
15,16
15,16
15,16
15,16
15,16
15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1986:
N/A
3098
1987:
8011
Power system, plant, :
and location : Coal source
Continued
Tri State Generating Not available
& Transmission Assn., Inc.
Unsited #1
Col orado
General Public Utilities Worrick, Pennsylvania
Seward #7
Indiana Co., Pennsylvania
(Seward)
Texas Utilities Twin Oaks Mine, Texas
: Nameplate :
: capacity :
MW
500
800
750
Coal
requ i red
1,000 tons
N/A
1,800
3,000
: Data
: source
15,16
l,4a,8,3,
6,13
l,4b,9,15
Generating Co.
Twin Oak #2
Robertson Co., Texas
(Bremond)
*mine mouth
*captive reserves
*1 ignite
3084 Columbus & Southern
Ohio Electric
Poston #5
Athens Co., Ohio
(Athens)
(FGD System)
*captive reserves
5041 Southern Illinois Power
Cooperative
Marion #5
Williamson Co., Illinois
(Marion)
1014 Central Maine Power
Sears Island
(Sears Island) Waldo Co.,
Maine
Alcoa/Robertson Co., Texas
Ireland,
Moundsville, West Virginia
444
Not available
150
Not available
600
1,000
400
1,400
1,8,15
l,4a,8
l,4a,8
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate
capacity
Coal
requ i red
Data
source
1987: Continued
5040 Central Illinois Public
Service
Plant X No. 1 (Newton #3)
Jasper Co., Illinois
(Newton)
(FGD System)
N/A Delmarva Power & Light
Vienna #9
N/D
9036 ICPA-Los Angeles Dept.
of Water & Power
Inter-mountain #1
Lynndyl, Utah
* water 50,000 afy
N/A Florida Power Corp.
Fossil #2
4063 Georgia Power Co.
Scherer #4
Monroe Co., Georgia
(Forsyth)
7040 Gulf States Utilities
Nelson #5
Calacasse Parish, Louisiana
(Westlake)
3125 Indianapolis Power & Light
Patriot #2
Indiana
7021 Kansas City Bd of Public
Utilities
Nearman #2
Kansas City, Kansas
Wyandotte Co.
*l,000-ft. rail spur lines
Not available
Not available
Not available
Not available
Virginia, East. Kentucky
Kerr-McGee, Wyoming
Not available
Carter Oil/Rawhide
& Caballo, Gillette, Wyoming
Midwest, Saline Co., Illinois
MW
600
400
750
540
650
319
1,000 tons
1,480
N/A
2,500
2,500
850
850
1,8
1,3
l,4b,9
660
818
N/A
1,200
1,16
l,4a,8,13
l,4b,9
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1987:
9033
Power system, plant,
and location
Continued
Nevada Power Company
: Coal source
U.S. Fuel /Hiawatha,
: Nameplate :
: capacity :
MW
500
Coal
required
1,000 tons
2,275
Data
source
Mb.9
Harry Allen #4
Clark Co., Nevada
(Las Vegas)
*4 mile rail spur
*slurry pipeline from Alton,
*captive reserves
6001 Iowa Public Service
George Neal #5
Wood bury Co., Iowa
(Salix)
N/A Wisconsin Electric Power
Ozaukee Co, Wisconsin
N/A Florida Power &
Light Co.
Martin County #4
Florida
N/A Minnesota Power &
Light Co.
Undesignated #1
6002 Northern States Power
Sherburne #4
Sherburne Co., Minnesota
(Becker)
(FGD system)
*Mississippi River is water
N/A Northern States Power
N/D #2
Wisconsin
N/A West Texas Utilities
N/D
Carbon Co., Utah
Atlas, Hanksville, Utah
UT
Vanguard Mine
Not available
Col strip, Montana
source
Col strip, Montana
Not available
600
555
800
650
640
1,500
N/A
2,250
N/A
N/A
7,11
Not available
Not available
600
640
1,500
N/A
7
1,15,16
15,16
1,11
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990--Continued
ICAM : Power system, plant,
code : and location
Coal source
: Nameplate : Coal
: capacity : required
MW 1,000 tons
Data
source
1987: Continued
3111 Cincinnati Gas & Electric
East Bend #3
Boone Co., Kentucky
(Rabbit Hash)
(FGD System)
3122 Columbus & Southern
Ohio Electric
Newbury #1
3110 Southern Indiana Gas
& Electric
Brown #3
Posse Co., Indiana
3115 Louisville Gas & Electric
Trimble Co. #3
Trimble Co., Kentucky
(Wise's Landing)
Kentucky Prince Coal,
Perry Co., Kentucky
Not available
Not available
Not available
and Light (TX)
Lake Diversion-Kemp #1
*subbituminous
700
375
530
675
N/A
N/A
N/A
N/A
3,16
3,2
N/A
N/A
N/A
N/A
N/A
East Kentucky Power Coop
Unsited
Texas Utilities
Services, Inc.
Unsited Coal #2
*1 ignite
Unsited Coal #3
*1 ignite
Columbus & Southern Ohio
Poston #5
Central Power
Not available
Not available
Not available
Not available
Not available
1,130
750
750
444
640
N/A
N/A
N/A
N/A
N/A
3
3
3
15,16
3,15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1987:
N/A
9037
N/A
2022
Power system, plant, :
and location : Coal source
Continued
Kentucky Power Co. Not available
(AEP)
Project 2602 #2
Pacific Gas & Electric Belina 1, Utah/2, Utah
Fossil #2
Salano Co, California
(Collinsville)
*bituminous, capitve reserves
Potomac Electric Not available
Montgomery Co., Maryland
Atlantic City Not available
Electric Co.
Deepwater
New Jersey
*bituminous
: Nameplate :
: capacity :
MW
N/A
800
800
300
Coal
requ i red
1,000 tons
N/A
2,600
N/A
N/A
: Data
: source
3,4b,7
7
3
N/A Upper Peninsula Not available
Power Co.
Unsited Coal #3
N/A Associated Electric Coop. Not available
Unsited Coal
*bituminous
N/A Dairyland Power Not available
Coop., Inc.
Southern Minnesota
*bituminous
N/A Virginia Electric & Power Not available
Company
Fossil Unit #1
N/A South Carolina Public Not available
Service Auth.
Site X #3
90
630
800
840
450
N/A
N/A
N/A
N/A
N/A
3,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
NJ
NO
ON
ICAM :
code :
1987:
N/A
N/A
7029
N/A
N/A
N/A
N/A
N/A
N/A
1988:
N/A
4074
Power system, plant, :
and location :
Continued
Alabama Power Co.
Unsited-Site A #1
Mississippi Power & Light
Coal #8
Kansas City Power & Light
latan #2
*subbituminous
Southwestern Elec. Power
Lake Diversion
Oklahoma Gas & Electric
Unsited Coal #4
Commonwealth Edison Co.
Unspecified
Baltimore Gas & Electric
BC Coal Unit #1
Mississippi Power & Light Co
Unsited A #2
Mississippi
Colorado Ute Elec. Assn.
Southwest #1
*bituminous
Soyland Power Coop
Unsited
Mississippi Power &
Coal source :
Not available
Not available
Not available
Not available
Not. available
Not available
Not available
Not available
Colowyo Coal, Wyoming
Illinois Coal
Don Bow Processed/Kentucky
Nameplate :
capacity :
MW
800
820
726
517
500
550
N/A
700
250
600
700
Coal
requ i red
1,000 tons
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
1,250
1,500
: Data
: source
3
3,7
3,16
3
3
15,16
15
15,16
3
7
3,7,13
Light Co.
Mississippi
Desota Co., Mississippi
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1988:
N/A
N/A
9040
N/A
N/A
Power system, plant,
and location
Continued
Navajo Indian Tribal
Govt.
Unnamed
South Carolina Electric &
Gas Co.
Undesignated #2
Tucson Gas &
Electric Co.
Springerville 12
Apache Co., Arizona
(Springerville)
Oklahoma Gas &
Electric Co.
Unknown #2
Public Service
of Colorado
Unsited #2
: Coal source
McKinley Co.
(Crown point)
Not available
San Juan Basin Coal
Sante Fe, New Mexico
Not available
Not available
: Namepl ate :
: capacity :
MW
300-400
500
350
500
470
Coal
requ i red
1,000 tons
N/A
N/A
1,000
N/A
N/A
: • Data
: source
4b
15,16
15,16
15,16
15,16
N/A Tri-State Generating
& Transmission Assn., Inc.
Unsited #2
Colorado
N/A Alabama Power Co.
Unsited-Site A #2
Birmingham, Alabama
1013 Niagra Mohawk Power
Lake Erie #1
Chautauqua Co., New York
(Dunkirk)
*possible use of western coal
9045 Utah Power & Light
Nephi n (Plant Y)
*bituminous
Not available
Not available
Montana & Wyoming
Not available
500
818
850
500
N/A
N/A
2,000
N/A
15,16
1,13
3,15,16
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990--Continued
ICAM : Power system, plant, • •Nameplate :Coal i Data
code : and location : Coal source : capacity : required : source
MW 1,000 tons
1988: Continued
9036 ICPA Los Angeles Dept. of Not available 750 2,500 l,4b,9
Water & Power
Intermountain #2
Lynndyl, Utah
*water 50,000 afy
8006 Central Power a Light Colowyo,Craig, Colorado 550 1,000 l,2,4b,9
Coleto Creek #2
Victoria, Texas
Gonzales Co.
9033 Nevada Power Company U.S. Fuel/Hiawatha, 500 2,275 l,4b,ll,S
Harry Allen #4 Carbon Co., Utah
Clark Co., Nevada (Las Vegas) Atlas, Hanksville, Utah
*4 mile rail spur
*slurry pipeline from Alton, UT
*captive reserves
N/A Arkansas Power & Light Not available N/A N/A 15
Unsited #2
N/A Tucson Gas & Electric San Juan Basin Coal, 350 N/A 1 11
N/D #2 Santa Fe, New Mexico
N/A Baltimore Gas & Electric Co. Not available N/A 1,150 7,11
Brandon Shores #2
Anne Arundel Co, Maryland
9043 Unknown Company Not available 330 1 100 4b 9
Gillette #1
Gillette, Wyoming
Campbell Co.
*may expand by 500 MW in 2000
7047 Empire Energy Ctr., Western Coal 120 N/A 4b
MO.
Center #4
Jasper Co., Missouri
Joplin/(Area)
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1988:
N/A
9041
7020
N/A
N/A
1989:
N/A
N/A
Power system, plant, :
and location : Coal source
Continued
South Carolina Public Not available
Site X #4
Public Service Co. Not available
of New Mexico •
Bisti #1
San Juan Co., New Mexico
Arkansas Power & Light Co. Sparta Mine/Arkansas
Mine mount
Arkansas Lignite Energy
Center #1 (AR-LEC)
Calhoun Co. Arkansas
Upper Peninsula Power Not available
Unsited #4
San Antonio Public Not available
Service Board
Undesignated #1
Arkansas Power & Light Not available
Unsited C2
Oklahoma Gas & Not available
Electric Co.
Unknown #3
: Nameplate :
: capacity :
MW
450
500
750
90
500
N/A
500
Coal
regu i red
1,000 tons
N/A
N/A
N/A
N/A
N/A
N/A
N/A
: Data
source
15,16
4b
7
15,16
15,16
15
15,16
N/A Tri State Generating Not available
& Transmission Assn., Inc.
Unsited #3
Colorado
3125 Indianapolis Power & Light Not available
Patriot #3
5047 Wisconsin Elec. Power Not available
Kosakonong 12
Jefferson Co., Wisconsin
500
650
400
N/A
N/A
500
15,16
1
l,4a
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990—Continued
[VJ
U>
O
ICAM :
code :
1989:
9036
N/A
5038
Power system, plant,
and location
Continued
ICPA Los Angeles Dept. of
Water & Power
Inter-mountain #3,4
Lynndyl, Utah
*water 50,000 afy
Northern States Power
Unsited #1
Central Illinois
: Coal source
Not available
Col strip/Montana
Freeman, Virden, Illinois
: Nameplate :
: capacity :
MW
750 ea.
800
500
Coal
requ i red
1,000 tons
2,500
N/A
N/A
: Data
: source
l,4b,9,16
1,11
1,2
3115
1013
N/A
9044
Light Company
Duck Creek #3
Canton, Illinois
Louisville Gas & Electric
Trimble #4
Trimble Co., Kentucky
Niagara Mohawk
Power Corp.
Lake Erie #2
Dunkirk, New York
Chautauqua Co.
Not available
Montana & Wyoming
Not available
Pennsylvania Power
& Light
Z-2
Unlocated
*Possibly along Susquehanna River, Danpan Co.
Intermountain Consumers
Power Association
*Late 1980's
Hatch Flats
Rio Blanco Co., Colorado
Roosevelt, Utah
Future Plants-1990s
N/A
Florida Power Corp.
Fossil #3
Not available
675
850
800
300-800
660
N/A
2,000
1,800
N/A
N/A
l,2,4a,ll,8
4a
4b
15,16
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM : Power system, plant,
code : and location
Coal source
Nameplate : Coal
capacity : required
Data
source
1990s: Continued
N/A Oklahoma Gas &
Electric Co.
Unknown il
7020 Arkansas Power & Light
Mine mouth
Arkansas Lignite Energy
Center #2 (AR-LEC)
Calhoun Co., Arkansas
N/A General Public Utilities
Pennsylvania
N/A Metropolitan Edison
Scottsville #1
Pennsylvania
N/A Pennsylvania Power Co.
Wehrum #1
N/A N/D
N/A N/D
N/A Gulf Power Co.
Now indefinite
Ellis #3 (Florida)
N/A Nevada Power Company
Indefinite
Reid Gardner #4
N/A Tucson Gas & Electric
N/D #3
San Juan Basin Coal/Santa Fe
N/A Utah Power & Light
Indefinite
Naughton #4
Kemmerer, Wyoming
Not available
Sparta Mine, Arkansas
Not available
Not available
Not available
MW
500
750
N/A
625
300
1,000 tons
N/A
N/A
N/A
N/A
N/A
Not available
Not available
Not available
Not available
Not available
Not available
625
800
500
125
350
415
N/A
N/A
N/A
N/A
N/A
N/A
15,16
15
15
Continued
-------
Appendix table 5--Additions to generation capacity: 1976-1990--Continued
ICAM :
code :
1990s:
N/A
N/A
N/A
N/A
N/A
N/A
N/A
9026
N/A
N/A
N/A
N/A
Power system, plant,
and location
Continued
Indefinite
Naughton #5
Kemmerer, Wyoming
Washington Water
Power Company
WWP #1
Late 1980 's
Florida Power & Light
N/D 80 's
N/D #1
N/D 80 's
N/D #2
Wisconsin Electric Power
Unnamed
Ozaukee Co., Wisconsin
Unknown
Junsau or Adams Co.
Salt River Project
Coronado #3
Apacas Co. (St. John's)
Alabama Power Co.
Un sited-Site A #3
Sou the rn Ca 1 i f o r n i a
East Coal #'s 1-4
Ed i son
Unsited #1
Empire Energy
: Coal source
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Not available
Western Coal
: Nameplate :
: capacity :
MW
415
500
730
N/A
730
600
300
350
800
1,000/ea
1,500
300
Coal
required
1,000 tons
N/A
N/A
N/A
N/A
N/A
800
400
730
N/A
N/A
N/A
1,000
: Data
source
4a
4a
4b
15
4b
7
4b
Center, Mo.
Center #5
Jasper Co. (Joplin Area)
Continued
-------
Appendix table 5—Additions to generation capacity: 1976-1990—Continued
ICAM :
code :
1990s:
N/A
3084
9041
9041
9034
N/A
Power system, plant, : :
and location : Coal source :
Continued
State of Montana Not available
Dept. of Natural Resources
Energy Park #1
Gascow AFB, Montana
(Valley Co.)
#2 Not available
#3 Not available
Columbus & Southern Ireland,
Ohio Electric Moundsville, West Virginia
Poston #6
Athens Co., Ohio
(Athens)
(FGD system)
*captive reserves
Public Service Co. Not available
of New Mexico
Bisti #2
San Juan Co., New Mexico
Public Service Co. Not available
Bisti #3
San Juan Co., New Mexico
Utah Power & Light Not available
Garfield #3
Garfield Co. Utah
Utah Power & Light Not available
Garfield #4
Garfield Co. Utah
Nameplate :
capacity :
MW
300
300
300
444
500
500
500
500
Coal : Data
required : source
1,000 tons
960 4b
960 4b
960 4b
1,000 1,8,15,16
N/A 4b
N/A 4b
1,625 4b
1,625 4b
See footnotes on next page.
Continued
-------
Sources for scenario data:
1. "New Generating Plants," "Power Engineering," May 1978
2. Commercial Coal Power Plants, September 1978, NUS Corporation
3. Additions to Generating Capacity 1978-1987 for the Contiguous United States, October 1978, U.S.D.O.E.
4. Projects to Expand Fuel Sources in Eastern States - Update
a. Eastern States #8765 b. Western States #8772
5. Status of Coal Supply Contracts for New Electric Generating Plants 1976-1985, January 1977, F.P.C.
6. Region 8 - 1977 Power Plant Summary, U.S.E.P.A., Denver, CO. 80295, March 1978
7. Clippings File: "Wall Street Journal," "Coal Outlook"
8. "Coal Outlook," January 10,1977, October 1976, Pasha Publications
9. BOM 1C 8719, May 1976
10. F.P.C. Status Report, January 1977
11. "Coal Week," McGraw-Hill, Inc., New York (also Keystone Coal Industry Manual, McGraw-Hill, 1976-1979.)
12. F.E.R.C. Data Table of Future Coal-Fired Electrical Generation Facilities, June, 1979.
13. "New Coal-Fired Plants Scheduled to Come On Line, 1976-1985", ICF, Incorporated, April, 1979.
14. Staff Interpolation of Mine Source on Basis of Utility-Historical Contracts.
15. "Coal Fired Powerplants1 Federal Status Report", April 79, U.S. Dept. of Commerce
16. "Inventory of Power Plants in the United States", April 79, U.S. Dept. of Energy
-------
Appendix table 6—Power plants with no
western coal, 1985
expansion plans supplied by
1CAM
code
9013
9006
9011
5025
5016
5014
5036
5003
5004
5011
5007
5009
Plant name
Drake
Cherokee
Comanche
Wallace
(retired-1980)
Fisk
(retired-1980)
Crawford
Dixon
Joliet
Power ton
Waukegan
Will County
Joppa
County, state,
& town
El Paso
Colorado
Colorado Sprgs
Adams
Colorado
Denver
Pueblo
Colorado
Pueblo
Tazewel 1
Illinois
East Peoria
Cook
Illinois
Chicago
Cook
Illinois
Chicago
Lee
Illinois
Dixon
Will
11 1 inois
Joliet
Tazewel 1
Illinois
Pekin
Lake
Illinois
Waukegan
Will
Illinois
Joliet
Massac
Illinois
Joppa
Total
coal
needed
1,000
459
2,518
1,608
508
1,338
1,369
228
3,707
3,029
1,903
2,544
3,424
Western
coal
needed
tons
280
179
269
2,249
1,608
303
1,338
1,368
34
10
2,949
228
1,509
121
2,378
9
Pet.
100.00
10.68
89.32
100.00
59.65
100.00
100.00
14.91
4.39
79.55
7.53
79.30
6.36
93.47
0.26
Source
C001
C001
WY02
C001
WY02
MT04
MT04
MT04
WY03
UT01
MT04
MT04
WY03
MT04
MT04
WY02
Continued
235
-------
Appendix table 6—Power plants with no expansion plans supplied by
western coal, 1985--Continued
ICAM
code
5024
6004
9003
9001
6003
6014
6032
6023
9018
9015
6012
5005
: : Total
Plant name : County, state, : coal
: & town : needed
Hennepin
North Omaha
Mohave
Four Corners
New Mexico
Fruitland
Leland Olds
Young
Heskett
Stanton
Carbon
Gadsby
Genoa 3
Oak Creek
1,000
Putnam 716
11 1 inois
Hennepin
Douglas 965
Nebraska
Omaha
Clark 3,820
Nevada
Laughl in
San Juan 5,942
Mercer 1,864
North Dakota
Stanton
Oliver 1,517
North Dakota
Center
Morton 427
North Dakota
Mandan
Mercer 736
North Dakota
Stanton
Carbon 433
Utah
Castle Gate
Salt Lake 401
Utah
Salt Lake City
Vernon 1,157
Wisconsin
Genoa City
Milwaukee 3,169
Wisconsin
Oak Creek
: Western :
: coal
needed
tons Pet.
18 2.51
965 100.00
3,820 100.00
5,942 100.00
1,864 100.00
1,517 100.00
427 100.00
569 77.31
166 22.55
433 100.00
401 100.00
199 17.20
150 12.96
716 22.59
Source
MT04
WY03
AZ01
NM01
ND02
ND01
ND02
ND02
MT04
UT01
UT01
WY03
MT04
WY03
Continued
236
-------
Appendix table 6—Power plants with no expansion plans supplied by
western coal, 1985--Continued
I CAM
code
5022
9007
5018
5028
3029
3056
3023
3015
3050
3100
3027
Plant name County, state,
& town
Pull i am
Dave Johnston
Wood River
Venice 2
(retired-1980)
State Line
Breed
Tanners Creek
Clifty Creek
Mitchell
Edwardsport
(retired-1980)
Cayuga
Brown
Wisconsin
Green Bay
Converse
Wyoming
Glenrock
Mad i son
111 inois
East Alton
Madison
11 1 inois
Venice
Lake
Indiana
Hammond
Sullivan
Indiana
Sul livan
Dearborn
Indiana
Lawrenceburg
Jefferson
Indiana
Madison
Lake
Indiana
Gary
Knox
Indiana
Edwardsport
Vennil ion
Indiana
Cayuga
Total
coal
needed
1,000
881
3,218
1,064
340
2,159
1,018
2,164
4,204
1,706
243
2,629
: Western
: coal
: needed
tons
105
3,218
14
33
10
10
212
903
819
30
130
231
1,668
2
10
Pet.
11.92
100.00
1.32
3.10
0.94
0.94
62.35
41.82
37.93
2.95
6.01
5.49
97.77
0.83
0.38
Source
MT04
WY03
WY03
MT04
C001
UT01
WY03
WY03
MT04
WY02
UT01
WY02
WY03
C001
WY02
Continued
237
-------
Appendix table 6—Power plants with no expansion plans supplied by
western coal, 1985--Continued
ICAM
code
6016
6015
6024
6020
6030
6021
6019
7003
7006
3086
3014
3001
: : : Total
: Plant name : County, state, : coal
: : & town : needed
Kapp
Prairie Creek
Sutherland
Riverside
Maynard
Des Moines 2
Burlington
Lawrence
Tecumseh
Marysvil le
St. Clair
Monroe
1,000
Clinton 604
Iowa
Cl in ton
Linn 471
Iowa
Cedar Rapids
Marshall 198
Iowa
Marshall town
Scott 475
Iowa
Bettendorf
Blackhawk 44
Iowa
Waterloo
Polk 433
Iowa
Des Moines
Des Moines 524
Iowa
Burlington
Douglas 799
Kansas
Douglas
Shawnee 5,146
Kentucky
Paducah
St. Clair 54
Michigan
Marysvil le
St. Clair 2,983
Michigan
Belle River
Monroe 6,484
Michigan
Monroe
Western
coal
needed
tons Pet.
137 22.68
96 20.38
6 3.03
5 2.53
32 16.16
16 3.37
19 43.18
134 30.95
15 2.86
799 100.00
170 3.30
4 0.74
884 29.63
168 2.59
Source
MT04
C001
WY01
MT04
C001
WY03
WY03
WY02
WY02
WY03
MT04
MT04
MT04
MT04
Continued
238
-------
Appendix table 6—Power plants with no expansion plans supplied by
western coal, 1985—Continued
ICAM : Total
code Plant name County, state, : coal
& town : needed
: Western
: coal Source
: needed
1,000 tons Pet.
6031 Fox Lake
6028 Aurora
6008 Black Dog
6010 High Bridge
6005 King
6011 Riverside
6025 Hoot Lake
7014 Blue Valley
7013 Grand Avenue
(retired-1980)
7001 Hawthorne
5022 Pull i am
9007 Dave Johnston
Martin 43
Minnesota
Sherburn
St. Louis 389
Minnesota
Aurora
Dakota 1,042
Minnesota
Minneapol is
Ramsey 886
Minnesota
St. Paul
Washington 1,668
Minnesota
Still water
Hennepin 952
Minnesota
Minneapol is
Otter Tail 679
Minnesota
Fergus Falls
Jackson 194
Missouri
Independence
Jackson 173
Missouri
Kansas City
Jackson 1 ,032
Missouri
Kansas City
Brown 881
Wisconsin
Green Bay
Converse 3,218
Wyoming
Glen rock
43 100.00 MT04
389 100.00 MT04
707 67.85 MT04
755 85.21 MT04
519 31.12 MT04
952 100.00 MT04
679 100.00 ND02
70 36.08 WY03
5 2.58 C001
2 1.03 UT01
4 2.31 WY03
807 78.20 WY03
105 11.92 MT04
3,218 100.00 WY03
Continued
239
-------
Appendix table 6--Power plants with no expansion plans supplied by
western coal, 1985--Continued
ICAM
code
5018
5028
3029
3056
3023
3015
3050
3100
3027
7004
5012
5001
Plant name : County, state, :
: & town
Wood River
Venice 2 *
(retired-1980)
State Line
Breed
Tanners Creek
Clifty Creek
Mitchell
Edwardsport
(retired-1980)
Cayuga
Montrose
Meramec
Labadie
Madison
11 linois
East Alton
Madison
11 linois
Venice
Lake
Indiana
Hammond
Sul 1 ivan
Indiana
Sul livan
Dearborn
Indiana
Lawrenceburg
Jefferson
Indiana
Madison
Lake
Indiana
Gary
Knox
Indiana
Edwardsport
Vermil ion
Indiana
Cayuga
Henry
Missouri
Cl in ton
St. Louis
Missouri
St. Louis
Frankl in
Missouri
Labadie
Total
coal
needed
1,000
1,064
340
2,159
1,018
2,164
4,204
1,706
243
2,629
1,799
1,936
5,804
: Western :
: coal :
: needed
tons
14
33
10
10
212
903
819
30
130
231
1,668
2
10
10
7
101
Pet.
1.32
3.10
0.94
0.94
62.35
41.82
37.93
2.95
6.01
5.49
97.77
0.83
0.38
0.56
0.36
1.74
Source
WY03
MT04
C001
UT01
WY03
WY03
MT04
WY02
UT01
WY02
WY03
C001
WY02
WY03
WY02
WY03
Continued
240
-------
Appendix table 6~Power plants with no expansion plans supplied by
western coal, 1985—Continued
ICAM :
code : Plant name
9020 Corette
6029 Kramer
6017 Sheldon
9016 Arapahoe
9019 Valmont
County, state, :
& town :
Yellowstone
Montana
Billings
Sarpy
Nebraska
Bel levue
Lancaster
Nebraska
Hal lam
Denver
Colorado
Denver
Boulder
Colorado
Boulder
Total
coal
needed
1,000
700
239
254
575
231
Western
coal
needed
tons Pet.
700 100.00
87 36.40
18 7.53
134 56.07
148 58.27
2 0.79
195 34.01
112 19.44
268 46.55
200 86.62
31 13.38
Source
MT04
WY03
WY04
C001
WY03
UT01
WY03
COO 7
C001
WY03
C007
Source: Appendix tables 2 and 5.
241-
-------
Appendix table 7—New power plants and power plants with expansion plans supplied
by western coal, 1985
ICAM
code
3002
3020
3045
3104
3107
4057
5002
5013
5017
5035
5043
See
Plant :
Gavin
Cardinal
Bailly
Schahfer
Sullivan
Jackson Co.
Baldwin
Edwards
Columbia
Weston
Pleasant Prairie
footnotes at end of
County, state,
and town
Gallia
Ohio
Galliopol is
Jefferson
Ohio
Bril liant
Porter
Indiana
Chesterton
Jasper
Indiana
Wheatfield
Sullivan
Indiana
Sullivan
Jackson
Mississippi
Moss Point
Randolph
Illinois
Baldwin
Peoria
Illinois
Bartonvil le
Columbia
Wisconsin
Madison
Marathon
Wisconsin
Rothchild
Kenosha
Wisconsin
Pleasant Prairie
table.
Total
coal , ,
needed—'
1,000
2J 5,433
3/ 4,810
2/ 2,590
2/ 2,400
2/ 6,000
2J 1,970
3/ 5,878
3/ 3,090
3/ 3,645
3/ 1,297
I/ 3,000
: Western
: coal Source
: needed CPA
tons Pet.
1,000 18.41 WY02
500 10.40 UT01
1,300 50.19 C004
1,250 52.08 C004
6,000 100.00 WY02
1,000 50.76 UT01
100 1.70 WY03
450 14.56 MT04
3,645 100.00 MT04
1,297 100.00 MT04
3,000 100.00 MT04
Continued
. 242
-------
Appendix table 7—New power plants and power plants with expansion plans supplied
by western coal, 1985—Continued
I CAM
code
Plant
County, state,
and town
Total
coal ,,
needed-
Western
coal
needed
Source
CPA
6001 George Neal
6002 Sherburne Co.
6007 Boswell
6009 Big Stone
6013 Col strip
6022 Alma
6026 Council Bluffs
6035 Square Butte
6037 Sioux Falls
6038 Gentleman
6039 Coal Creek
See footnotes at end of table.
Woodbury
Iowa
Salix
Sherburne
Minnesota
Becker
Itasca
Minnesota
Cohasset
Grant
South Dakota
Big Stone
Rosebud
Montana
Col strip
Buffalo
Wisconsin
Alma
Pottawatamie
Iowa
Council Bluffs
Oliver
North Dakota
Center
Minnehaha
South Dakota
Sioux Falls
Lincoln
Nebraska
Sutherland
McLean
North Dakota
Falkirk
1,000 tons Pet.
2/3/ 4,476 4,469 99.84 WY03
3/ 9,647 9,647 100.00 MT04
2/ 3,971 1,900 47.85 MT04
4,109 4,109 100.00 ND03
3/ 4,931 4,931 100.00 MT04
1,945 300 15.42 WY02
3/ 2,302 2,302 100.00 WY03
4/ 2,500
Tlrucks)
2,500 100.00 ND02
4/ 600 600 100.00 MT04
2/ 4,000 4,000 100.00 WY02
2/ 5,500 5,500 100.00 ND01
Continued
243
-------
Appendix table 7--New power plants and power plants with expansion plans supplied
by western coal, 1985—Continued
I CAM
code
6040
6041
6043
6045
6046
7016
7017
7018
7019
7022
7023
Plant :
Nebraska City
Heartland
Basin
Brookston
Antelope Val ley
Harrington
Muskogee
Welsh
Flint Creek
Jeffrey
White Bluff
See footnotes at end of
County, state,
and town
Otoe
Nebraska
Nebraska City
Union
South Dakota
Elk Point
Brule
South Dakota
Chamberlain
St. Louis
Minnesota
Brookston
Mercer
North Dakota
Beulah
Potter
Texas
Amaril lo
Muskogee
Oklahoma
Muskogee
Morris
Texas
Cason
Benton
Arkansas
Si loam Sprgs
Pottawatomie
Kansas
Westmoreland
Jefferson
Arkansas
Red field
table.
: Total
: coal , ,
: needed—
1,000
4/ 2,500
4/ 600
4/ 500
4/ 3,200
4/ 5,500
2/ 3,000
2] 3,300
4/ 3,501
47 1,700
2/ 8,400
1/10,600
: Western
: coal
: needed
tons Pet.
2,500 100.00
600 100.00
500 100.00
3,200 100.00
5,500 100.00
3,000 100.00
3,300 100.00
3,501 100.00
1,700 100.00
4,000 47.62
Source
CPA
WY02
WY02
MT04
MT04
ND02
WY02
WY02
WY02
WY02
WY02
10,600 100.00 WY02
Continued
244
-------
Appendix table 7—New power plants and power plants with expansion plans supplied
by western coal, 1985—Continued
I CAM j
code Plant
7025 Big Cajun
7026 Sooner
7027 Northeastern
7028 Rodemacher
7031 Unsited
7033 Unsited
7034 CRS Joint
7037 Unsited
7039 Unsited
7040 Hel son
8004 J. T. Deely
County, state,
and town
Point Coupee
Louisiana
New Roads
Noble
Oklahoma
Ponca City
Rogers
Oklahoma
Oolagah
Rapides
Louisiana
Boyce
Okmulgee
Oklahoma
Okmulgee
Tul sa
Oklahoma
Tulsa
Creek
Oklahoma
Bristow
Paul kner
Arkansas
Conway
Pulaski
Arkansas
Olmstead
Calacasie
Louisiana
Westlake
Bexar
Texas
San Antonio
Total
coal .,
needed—
1,000
2/ 6,000
2/ 3,300
4/ 2,900
I/ 3,500
4/ 2,250
4/ 2,250
4/ 800
4/ 2,500
4/ 2,500
I/ 5,000
2J 2,900
Western
coal
needed
tons
1,000
4,000
3,300
2,900
3,500
2,250
2,250
800
2,500
2,500
5,000
1,000
Pet.
16.67
66.67
100.00
100.00
100.00
100.00
100.00
100.00
100.00
100.00
100.00
34.48
Source
CPA
MT04
WY02
WY02
WY01
WY02
WY02
WY02
WY02
WY02
WY02
WY02
WY02
See footnotes at end of table.
Continued
245
-------
Appendix table 7--New power plants and power plants with expansion plans supplied
by western coal, 1985--Continued
I CAM
code
8005
8006
8007
8013
8C14
8016
8017
8018
8019
8020
8021
8022
: Plant
Parish
Coleto Creek
Fayette
South Plains
Sandow
Unsited
Unsited
Unnamed
Unsited
Unsited
Unnamed
Unnamed
See footnotes at end
: County, state,
: and town
Fort Bend
Texas
Richmond
Victoria
Texas
Victoria
Fayette
Texas
Muldoon
Yoakum
Texas
Plains
Johnson
Texas
Cleburne
Hunt
Texas
Greenv il le
Coll in
Texas
McKinney
Ft. Bend
Texas
Richmond
Hill
Texas
Hillsboro
Parker
Texas
Poolville
Will iamson
Texas
Georgetown
Milan
Texas
Rockdale
of table.
Total
coal .,
needed—'
1,000
•2/ 9,859
2/ 3,250
2J 2,000
4/ 2,260
I/ 3,000
4/ 2,500
I/ 2,500
4/ 2,775
I/ 2,500
4/ 2,500
I/ 500
I/ 500
Western
coal
needed
tons Pet.
4,100 41.59
1,500 46.15
2,000 100.00
2,260 100.00
3,000 100.00
2,500 100.00
2,500 100.00
2,775 100.00
2,500 100.00
2,500 100.00
500 100.00
Source
CPA
WY02
C001
MT04
WY02
NM01
NM01
NM01
WY02
NMC1
NM01
MT04
500 100.00 MT04
Continued
246
-------
Appendix table 7—New power plants and power plants with expansion plans supplied
by western coal, 1985--Continued
I CAM
code
Plant
: County, state,
: and town
: Total
: coal ,,
needed—
: Western
: coal
: needed
: Source
: CPA
9002 Navajo
9005 Jim Bridger
9008 Naughton
9009 Hayden
9010 Huntington Canyon
9012 San Juan
9014 Choi la
9017 Gardner
9021 Snowflake
9022 Emery
9023 Wyodak
See footnotes at end of table.
Coconino
Arizona
Page
Sweetwater
Wyoming
Rock Springs
Lincoln
Wyoming
Kemmerer
Routt
Colorado
Hayden
Emery
Utah
Huntington
San Juan
New Mexico
Waterflow
Navajo
Arizona
Joseph City
Clark
Nevada
Moapa
Navajo
Arizona
Snowflake
Emery
Utah
Castle Dale
Campbell
Wyoming
Gillette
1.000 tons Pet.
21 3,377 1,877 55.58 AZ01
1,500 44.42 AZ01
3/ 7,263 7,263 100.00 WY04
3/ 4,519 4,519 100.00 WY04
2J 1,445 1,445 100.00 C001
3/ 2,314 2,314 100.00 UT01
3/ 7,042 7,042 100.00 NM01
3/ 3,977 3,977 100.00 NM02
.3/ 1,021 1,021 100.00 UT01
4/ 400 400 100.00 NM02
2/ 2,600 2,600 100.00 UT01
4/ 1,100 1,100 100.00 WY02
Continued
247
-------
Appendix table 7—New power plants and power plants with expansion plans supplied
by western coal, 1985--Continued
I CAM
code
Plant
County, state,
and town
: Total
: coal , ,
: needed—
: Western
: coal
: needed
Source
CPA
9024 Craig
9025 Apache
9026 Coronado
9027 Nixon
9028 Pawnee
9029 North Valmy
9030 Boardman
9031 Laramie River
9032 Warner Valley
9033 Allen
9034 Garfield
Moffat
Colorado
Craig
Cochise
Arizona
Cochise
Apache
Arizona
St. John's
El Paso
Colorado
Colorado Sprgs
Morgan
Colorado
Brush
Humboldt
Nevada
Valmy
Morrow
Oregon
Boardman
Platte
Wyoming
Wheat!and
Washington
Utah
St. George
Clark
Nevada
Las Vegas
Garfield
Utah
Escalante
See footnotes at end of table.
1.000 tons Pet.
4/ 4,900 4,900 100.00 C001
21 1,100 1,100 100.00 NM02
2/ 4,500 1,000 22.22 UT01
3,000 66.67 NM02
500 11.11 NM03
4/ 3,051 3,051 100.00 C001
21 3,200 3,200 100.00 WY02
4/ 1,000 1,000 100.00 UT01
2J 1,600 1,200 75.00 WY02
2] 4,800 4,800 100.00 WY02
2] 1,600 400 25.00 UT02
V 9,100 9,100 100.00 UT01
4/ 6,500 6,500 100.00 UT02
Continued
248
-------
Appendix table 7~New power plants and power plants with expansion plans supplied
by western coal, 1985--Continued
ICAM
code
9035
9036
9037
9038
9039
9040
6047
9042
9043
9044
9045
See
Plant
Plains
Inte mountain
Unsited
Future
Pioneer
Springvil le
Coyote
Unsited
Gillette
Hatch Flats
Energy Park
footnotes at end
County, state,
and town
Santa Fe
New Mexico
Santa Fe
Wayne
Utah
Cainevil le
Solano
California
Fairfield
Pueblo
Colorado
Pueblo
Ada
Idaho
Orchard
Pi ma
Arizona
Marana
Mercer
North Dakota
Beulah
Yellowstone
Montana
Bil lings
Campbel 1
Wyoming
Gillette
Rio Blanco
Colorado
Rangely
Valley
Montana
Glascow AFB
of table.
Total
coal , ,
needed—
1,000
4/ 1,035
y 9,500
2/ 2,600
4/ 3,200
4/ 1,600
2J 1,000
2/ 2,200
4/ 1,100
4/ 1,100
4/ 1,000
4/ 2,900
Western
coal
needed
tons
1,305
9,500
1,000
3,200
1,600
1,000
2,200
1,100
1,100
1,000
2,900
Pet.
100.00
100.00
38.46
100.00
100.00
100.00
100.00
100.00
100.00
100.00
Source
CPA
NM02
UT02
UT01
C001
UT01
NM04
ND02
MT04
WY02
C001
100.00 MT02
Continued
249
-------
Appendix table 7—New power plants and power plants with expansion plans supplied
by western coal, 1985—Continued
I CAM
code
: County
Plant : and
, state,
town
Total
coal , ,
needed—
1,000 tc
Western
coal
needed
)ns Pet.
Source
CPA
9046 Unnamed
9047 Sheridan Project
3116 Belle River
7021 Nearman Creek
Gregory
South Dakota
Fairfax
Sheridan
Wyoming
Sheridan
St. Clair
Missouri
St. Clair
Wyandotte
Kansas
Kansas City
4/ 800 800 100.00
WY02
4/ 1,600 1,600 100.00 WY01
21 2,500
800 32.00 MT04
2/ 1,700 1,000 58.82 WY02
_!/ This column is calculated by adding the total amount of coal used in 1975
plus the total amount of coal needed for expansion. The estimated amount of
coal needed for expansion was reported in (_3) and(40.
2J These plants have made contractual arrangements for western coal. It is
assumed that their western coal need will be the amount called for in the contract.
As further data becomes available it will be incorporated into the analysis.
3/ These plants existed in 1975, used some western coal in 1975, and have
plans for expansion. Their western coal need is determined by calculating the
percentage of western coal used in 1975 and applying this percentage to the
total amount of coal needed in 1985. (Analysis of 1976-1985 FERC Form 423 data
may necessitate changing this assumption for individual plants.)
$J These plants are all new plants which plan to use some western coal.
Considerations used in determining their western coal need include: 1) geo-
graphical location (all new plants in western states and those in western
Wisconsin, western Minnesota, western Iowa, and western Missouri are assumed
to use 100 percent western coal), 2) past use of western coal by plants in
the same power system, and 3) reported planned use of western coal but no
formal contractual details are available. (Analysis of 1976-1985 FERC Form
423 data may necessitate changing this assumption for individual plants.)
Sources: (3.), (1), (20), (21)
250
-------
Appendix table 8—Standard Metropolitan Statistical Areas appearing in the
residential demand analysis
State and SMSA
Utility
Alabama
Birmingham
Alaska
Arizona
Phoenix
Tucson
Arkansas
None
California
Anaheim
Los Angeles
San Diego
San Francisco
San Jose
Colorado
Colorado Springs
Denver
Connecticut
Bridgeport
Hartford
Water bury
Delaware
Wilmington
District of Columbia
Washington
Florida
Fort Lauderdale
Orlando
Georgia
Atlanta
Idaho
Boise
City
Illinois
Chicago
Decatur
Peoria Central
Alabama Power Company
None
Salt River Power District
Tucson Gas and Electric Co.
City of Anaheim L and P
L.A. Dept. of W and P
San Diego Gas and Electric Co.
Pacific Gas and Electric Co.
Pacific Gas and Electric Co.
Colo. Springs Dept. of Pub. Uts.
Public Service of Colorado
The United Illuminating Co.
The Hartford Elec. Light Co.
The Conn. Light and Power Co.
Delmarva Power and Light Co.
Potomac Electric Power Co.
Florida Power and Light Co.
Orlando Utilities Commission
Georgia Power Co.
Idaho Power Co.
Commonwealth Edison
Illinois Power Co.
Illinois Light Co.
Co.
Continued
251
-------
Appendix table 8--Standard Metropolitan Statistical Areas appearing in the
residential demand analysis—Continued
State and SMSA
Utility
Indiana
Evansvil1e
Fort Wayne
Indianapolis
Lafayette
Muncie
Iowa
Des Moines
Sioux City
Kansas
Topeka
Kentucky
Lexington
Louisville
Owensboro
Louisiana
Lafayette
Lake Charles
New Orleans
Maine
Portland
Maryland
Baltimore
Massachusetts
Boston
Fall River
Pittsfield
Springfield
Michigan
Flint
Minnesota
Duluth
Minneapolis
Rochester
Mississippi
Jackson
Southern Indiana G. and E. Co.
Indiana and Michigan Elec. Co.
Indianapolis Power and Lt. Co.
Public Service Co. of Indiana,
Indiana and Michigan Elec. Co.
Iowa Power and Light Co.
Iowa Public Service Co.
The Kansas Power and Light Co.
Inc.
Kentucky Utilities Co.
Louisville Gas and Elec.
Owensboro Mun. Utilities
Co.
Lafayette Utilities System
Gulf States Utilities Co.
New Orleans Public Service, Inc.
Central Maine Power Co.
Baltimore Gas and Electric Co.
Boston Edison Co.
Fall River Electric Light Co.
Western Mass. Electric Co.
Western Mass. Electric Co.
Consumers Power Co.
Minnesota Power and Light Co.
Northern States Power Co. Minn.
Rochester Dept. of Pub. Uts.
Mississippi Power and Light Co.
Continued
252
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Appendix table 8--Standard Metropolitan Statistical Areas appearing in the
residential demand analysis—Continued
State and SMSA
Utility
Missouri
Columbia
Kansas City
St. Louis
Montana
Billings
Great Falls
Nebraska
Lincoln
Omaha
Nevada
None
New Hampshire
Manchester
Nashua
New Jersey
Atlantic City
Newark
New Mexico
Albuquerque
New York
Binghamton
Buffalo
New York City
Rochester
North Carolina
Charlotte
Fayetteville
Raleigh
North Dakota
Fargo
Ohio
Cincinnati
Cleveland
Columbus
Dayton
Columbia Water and Light Dept.
Kansas City Power and Light Co.
Union Electric Co.
The Montana Power Co.
The Montana Power Co.
Lincoln Electric System
Omaha Public Power District
Public Service of New Hampshire
Public Service Co. of New Hampshire
Atlantic City Electric Co.
Public Service Elec. and Gas Co.
Public Service Co. of New Mexico
New York State E. and G. Corp.
Niagara Mohawk Power Corp.
Consol. Edison Co. of N.Y., Inc.
Rochester Gas and Elec. Corp.
Duke Power Co.
Fayetteville Pub. Wks. Comm.
Carolina Power and Light Co.
Northern States Power Co.
The Cincinnati Gas and Elec. Co.
The Cleveland Elec. Ilium. Co.
Columbus and S. Ohio Elec. Co.
The Dayton Power and Light Co.
Continued
253
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Appendix table 8—Standard Metropolitan Statistical Areas appearing in the
residential demand analysis—Continued
State and SMSA
Utility
Oklahoma
Oklahoma City
Oregon
Portland
Pennsylvania
Erie
Harrisburg
Philadelphia
Pitts burg
Scranton
Rhode Island
Providence
South Carolina
Columbia
Greenville
South Dakota
Sioux Falls
Tennessee
Knoxville
Memphis
Nashville
Texas
Dallas
El Paso
Fort Worth
Galveston
Houston
Lubbock
San Antonio
Utah
Salt Lake City
Vermont
None
Virginia
Norfolk
Richmond
Roanoke
Oklahoma Gas and Electric Co.
Portland General Electric Co.
Pennsylvania Electric Co.
Pennsylvania Power and Lt. Co.
Philadelphia Electric Co.
Duquesne Light Co.
Pennsylvania Power and Lt. Co,
The Narragansett Electric Co.
So. Carolina Elec. and Gas Co.
Duke Power Co.
Northern States Power Co.
Knoxville Utilities Board
Memphis Lt. Gas and Wtr. Division
Nashville Electric Service
Dallas Power and Light Co.
El Paso Electric Co.
Texas Electric Service Co.
Houston Lighting and Power Co.
Houston Lighting and Power Co.
Southwestern Public Service Co.
San Antonio Public Service Board
Utah Power and Light Co.
Virg. Elec. and Power Co.
Virg. Elec. and Power Co.
Appalachian Power Co.
Continued
254
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Appendix table 8—Standard Metropolitan Statistical Areas appearing in the
residential demand analysis--Continued
State and SMSA Utility
Washington
Seattle Seattle Dept. of Lighting *
West Virginia
Charleston Appalachian Power Co.
Wisconsin
Appleton Wisconsin Michigan Power Co.
Green Bay Wisconsin Public Service Corp.
Milwaukee Wisconsin Electric Power Co.
Racine Wisconsin Electric Power Co.
Wyoming
None
Source: (11)
255 .j.s. QOVEHHHEHT PBIFTINO OFFICE : 1980 0-620-i|O6/5162
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