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

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     (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

-------
     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

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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

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           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

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          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

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          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

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           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

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             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

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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

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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

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                         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

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                          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

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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

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    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

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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)

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                  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

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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

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    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

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       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

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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

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      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

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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

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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

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                                  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

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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

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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

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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

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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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